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191-011
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/15/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231115 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT TBU D-07RD2 50733201170200 192155 11/5/2023 READ Caliper Survey TBU D-17RD 50733201680100 181023 11/5/2023 READ Caliper Survey TBU D-47 50733201950200 191011 11/4/2023 READ Caliper Survey Please include current contact information if different from above. T38136 T38137 T38138 T38139 11/21/2023 TBU D-47 50733201950200 191011 11/4/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.21 10:31:56 -09'00' OF T13� yw\ I yj�s, THE STAT Alaska Oil and Gas 44,=---s i , of LA Conservation Commission sKAL 333 West Seventh Avenue OF GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASy' Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager ��® ��� (� � Hilcorp Alaska, LLC 17 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai Oil Pool, TBU D-47 Permit to Drill Number: 191-011 Sundry Number: 317-483 Dear Mr. Golis: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC 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, Lt(g/ Hollis S. French Chair DATED this, day of October, 2017. RBDMS V-qui;i 1 3 2017 0 0 RECEIVED • nrr 10 2017 AOG STATE OF ALASKA 07-Slol /Z /, 7 ALASKA OIL AND GAS CONSERVATION COMMISSION L,'\,— APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Frac,t�re S imulate El Repair Well ❑ Operations shutdown El Suspend ❑ Perforate El Other S imulat44 e, Pull Tubing El Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well El Alter Casing El Other: El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development 0, 191-011 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ElService El 6.API Number. Anchorage,AK 99503 50-733-20195-02 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0✓ Trading Bay Unit D-47 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools i 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,930 , 9,885 " 11,783 • 9,757 % 2,000 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 398' 33" 398' 398' Surface 3,305' 16" 3,305' 3,948' 3,630 psi 1,020 psi Intermediate Production 10,978' 9-5/8" 10,978' 9,145' 6,870 psi 4,760 psi Liner 1,190' 7" 11,925' 9,881' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,659-11,744 • 8,764-9,723 4-1/2" 12.6#/L-80 10,008 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/25/2017 OIL 0 • WINJ ❑ WDSPL El Suspended El 16.Verbal Approval: Date: GAS ❑ WAG El GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned El 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com Contact Phone: (907)283-1329 Authorized Signature: t--3 (-_, Date: 'Di 9 I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. .y) , H g 3 Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDIVIS l U— OCT 1 3 2017 Spacing Exception Required? Yes ❑ No lZ. Subsequent Form Required: /0_ ( o% ( :_xte....____\_ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1 u `Z. ,t- ��i3 /Qui i �x. x(0 07, ORIGINAL (& - ,z-►-, Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate . • Well Work Plan Well: D-47 Hilcorp Alaska,Lb Date: 10/06/2017 Well Name: D-47 API Number: 50-733-20195-02 Current Status: ESP Producer Leg: Leg#A-2 (northwest) Estimated Start Date: October 25, 2017 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 191-011 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: "3,440 psi @ 8,764'TVD 0.393 psi/foot(7.55 ppg)SIBHP from ESP Gauge Maximum Expected BHP: 3,440 psi @ 8,764'TVD 0.393 psi/foot(7.55 ppg)SIBHP from ESP Gauge Max Potential Surface Pressure: "'2,000 psi Squeeze Pump Discharge Limit ** Note:this is a no-flow well 11-25-2013 Brief Well Summary D-47 a comingled G and Hemlock producer. Total fluid production from this well has declined since the June 2014 workover. This decrease is believed to have been caused by scale form tion in the well bore and perforation tunnels. Well Obiective Hilcorp plans to pump an acid soak down the production tubing and across the perforations to clean up any scale deposition. I Procedure:at („,y 145 1. MIRU pumping equipment. 2. Shut down ESP. 3. Pressure test surface lines to ±2,000 psi (treatment pump relief valve limit). 17 4. 4. Open back side, pump FIW down tubing taking returns up the annulus. 5. Pump ±4,500 gallons of±7.5% Hydrochloric Acid %c 7 6A� 6. Close the 9-5/8" casing return line and bullhead the chemical pills across the perfs with 175 barrels of FIW for displacement. 7. Shut down pump and let acid soak for±6 hours. 8. RD Pumping equipment. 9. Return well to production. 10. Schedule a No-Flow test within 14 days of stable production. Attachments: 1. Wellbore Schematic Current 2. Pumping Unit Diagram II • • McArthur River Field,TBU Well: D-47 SCHEMATIC Last Completed:06/30/14 PTD: 191-011 liilcorp Alaska,LLC API: 50-733-20195-02 RKB to TBG Head=40.3' Tree connection:4-1/16"5,000# CASING DETAIL J 'I. Size Wt Grade Conn ID Top Btm l' 33" Surf 398' ili 16" 102 X-56 Butt-Weld cpl 14.75 Surf 3,305' L 47 L-80 BTC 8.861 Surf 8,524' ' 9-5/8" 53.5 8.535 8,524' 10,978' 7" 29 N-80 TKC 6.185 10,735' 11,925' TUBING DETAIL 4-1/2" 12.6 L-80 R2IBT-M 3.958 Surf 10,008' i ', va E Abel/` JEWELRY DETAIL �m i � I a Depth Depth gel G,..IL No (MD) (TVD) ID OD Item 10,008' 8,212' N/A 5.13 Bolt On Discharge }t -P 10,010' 8,214' N/A 5.13 Pump-SG7300(x4) 1.' 4 1 10,087' 8,279' N/A 5.13 Intake 10,106' 8,295' N/A 5.62 Motor- 562 Series,340 HP(x2) 10,170' 8,348' N/A Anode _ 2 10,735' 8,830' TIW SN-6-AT Liner Top Packer I G-1 G-2 PERFORATION DETAIL D 2 Zone Interval(MD) Interval(TVD) Ft SPF Status G-1 10,659' 10,677' 8,764' 8,780' 18 5 Open f/Prod G-3 G-2 10,704' 10,725' 8,803' 8,822' 21 5 Open f/Prod G-4 G-3 10,760' 10,790' 8,852' 8,879' 30 5 Open f/Prod G-4 10,816' 10,885' 8,901' 8,962' 69 5 Open f/Prod L. Csg Shoe @10978°1- 0-7 G-5 10,974' 11,038' 9,041' 9,098' 64 5 Open f/Prod HK-1 G-7 11,149' 11,164' 9,197' 9,211' 15 5 Open f/Prod ` B-1 11,175' 11,225' 9,220' 9,265' 50' 48 Open f/Prod HK-2 B-1 11,182' 11,222' 9,227' 9,262' 40 5 Open f/Prod B-2 11,250' 11,265' 9,288' 9,301' 15' 12 Cmt Sqz - HK-3 B-2 11,280' 11,310' 9,315' 9,341' 30' 12 Cmt Sqz B-3 11,340' 11,400' 9,368' 9,442 60' 30 Open f/Prod 3' B-3 11,350' 11,397' 9,377' 9,419' 47 5 Open f/Prod HK-4 B-4 11,397' 11,525' 9,419' 9,532' 128 5 Open f/Prod ''.7- B-4 11,400' 11,470' 9,422' 9,484' 70' 12 Open f/Prod - HK-5 B-5 11,560' 11,660' 9,563' 9,650' 100 5 Open f/Prod B-6 11,699' 11,744' 9,684' 9,723' 45 5 Open f/Prod Cleanout to 4,-- 11 783 c .' .HK-6 1029/13 / ' N. PBTD=11,834' TD=11,930' MAX HOLE ANGLE=48° Updated By:JLL 06/26/17 • • LU qaa g o Q� U oa N ` L.L. 2Y 2 LL w M 3 w �n w `� J z — ow Y2 <Q zCS 0 as gas 0 W LA te 2 o1 as w Ln U 2 K W () 2 W C W W tt • • OF T74 ,$), THE STATE Alaska Oil and Gas ti�•~._`i���, of T e c TA Conservation Commission lsr;E !, 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 she, Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis SCANNED APR F 017 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-47 Permit to Drill Number: 191-011 Sundry Number: 317-073 Dear Mr. Golis: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC 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 t. Foerster Chair DATED this /Sty of February, 2017. RBDMS L U FEB 1 6 2017 • • . RECEIVED IVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 1 4 2017 APPLICATION FOR SUNDRY APPROVALS ZA isI/ 20 AAC 25.280 PAOG 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate 9(Acid) Pull Tubing El Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska,LLC ' Exploratory El Development 0 . 191-011 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99503 50-733-20195-02 . 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes 0 No 0 / Trading Bay Unit/D-47 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 + McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,930 ` 9,885 . 11,783 - 9,757 • 2,000 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 398' 33" 398' 398' Surface 3,305' 16" 3,305' 3,948' 3,630 psi 1,020 psi Intermediate Production 10,978' 9-5/8" 10,978' 9,145' 6,870 psi 4,760 psi Liner 1,190' 7" 11,925' 9,881' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,659-11,744 ` 8,764-9,723 4-1/2" 12.6#/L-80 10,008 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A • 12.Attachments: Proposal Summary 9 Wellbore schematic 9 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigrapl❑ Development 0 - Service El 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/1/2017 OIL 9 ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe Email dmartowet hilcorp.com Printed Name Stan W.Golis Title Operations Manager / Signature ("*......40-) rL., Date(907)777 8356 Z t (y , 2.0 11 i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `1 Plug Integrity ❑ BOP Test El Mechanical Integrity Test 0 Location Clearance 0 4S. ,F- 2..t r 5 1 iq Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ FiBDEA5 t(-• �"E 1 C 2r 7 Spacing Exception Required? Yes El No 2/ Subsequent Form Required: 10 -- 401/( u u APPROVED BY Approved by: /23444— COMMISSIONER THE COMMISSION Date: 2 "'I -/7 71S�t!� Submit Form and Form 10-403 Revised 11/2015 OARoteGplIiNoAiltl for 2 months from the ate of approval. Attachments in Duplicate • • • Well Work Plan Well: D-47 Hilcorp Alaska,LL Date:02/10/2017 Well Name: D-47 API Number: 50-733-20195-02 Current Status: ESP Producer Leg: Leg#A-2 (northwest) Estimated Start Date: March 1, 2017 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 191-011 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907)777-8356(0) Current Bottom Hole Pressure: —3,440 psi @ 8,764'ND 0.393 psi/foot(7.55 ppg)SIBHP from ESP Gauge Maximum Expected BHP: ^'3,440 psi @ 8,764'ND 0.393 psi/foot(7.55 ppg)SIBHP from ESP Gauge Max Potential Surface Pressure: 2,000 psi Squeeze Pump Discharge Limit ** Note:this is a no-flow well 11-25-2013 Brief Well Summary D-47 a comingled G and Hemlock producer. Total fluid production from this well has declined since the June 2014 workover. This decrease is believed to have been caused by scale formation in the well bore and perforation tunnels. J Well Objective Hilcorp plans to pump an acid soak down the production tubing and across the perforations to clean up any scale deposition. d Procedure: 1. MIRU pumping equipment. 2. Shut down ESP. 3. Pressure test surface lines to 2,000 psi (treatment pump relief valve limit). ✓- 4. Mix chemicals and pump in the following sequence: a. Open back side, pump FIW down tubing taking returns up the annulus. b. Pump±4,500 gallons of±7.5% Hydrochloric Acid✓ c. Close the 9-5/8" casing return line and bullhead the chemical pills across the perfs with >_175 barrels of FIW for displacement. 5. Shut down pump and let acid soak for±6 hours. 6. RD Pumping equipment. 7. Return well to production. 8. Schedule a No-Flow test within 14 days of stable production. ✓ Attachments: 1. Wellbore Schematic Current 2. Pumping Unit Diagram IcArthur River Field, TBU 14 • Well: D-47 SCHEMATIC As Completed: 06/30/14 HiIcorp.tIa.3ka,1,1.1. RKB to TBG Head=40.3' CASING DETAIL Tree connection:4-1/16"5,000# Jii `L. TYPE SIZE WT GRADE THRD ID TOP BTM. ef Pi kl Conductor 33" Surf 398' Surf 16" 102 X-56 Butt-weldedl14.75 Surf 3,305' cpl 9-5/8" 47 L-80 BTC 8.861 Surf 8,524' 4. 53.5 8.535 8,524' 10,978' 4. Liner 7" 29 N-80 TKC 6.185 10,735' 11,925' r TUBING DETAIL 8p if. Tubing 4-1/2" 12.68 L-80 R218T-M 3.958 Surf 10,008' s E. aJEWELRY DETAIL ° ° NO. Depth OD ID Item 1 10,008' 5.13 Bolt On Discharge 2 10,010' 5.13 Pump-SG7300(x4) I , - 3 10,087' 5.13 Intake sr 4 10,106' 5.62 Motor- 562 Series,340 HP(x2) 5 10,170' Anode 6 10,735' TIW SN-6-AT Liner Top Packer 1 . ii 1 G-1 G-2 PERFORATION DETAIL .{ 2 Zone Interval(MD) Interval(TVD) Ft SPF Status G-1 10,659' 10,677' 8,764' 8,780' 18 5 Open f/Prod ' G-3 G-2 10,704' 10,725' 8,803' 8,822' 21 5 Open f/Prod 00 G-4 G-3 10,760' 10,790' 8,852' 8,879' 30 5 Open f/Prod G-5 G-4 10,816' 10,885' 8,901' 8,962' 69 5 Open f/Prod L Csg Shoe N. 010978'OIL G-7 0-5 10,974' 11,038' 9,041' 9,098' 64 5 Open f/Prod HK-1 G-7 11,149' 11,164' 9,197' 9,211' 15 5 Open f/Prod ° B-1 11,175' 11,225' 9,220' 9,265' 50' 48 Open f/Prod • HK-2 8-1 B-2 11,182' 11,250' 11,222' 11,265' 9,227' 9,262' 40 5 Open f/Prod 9,288' 9,301' 15' 12 Cmt Sqz B-2 11,280' 11,310' 9,315' 9,341' 30' 12 Cmt Sqz HK-3 B-3 11,340' 11,400' 60' 30 Oen f/Prod 9,368' 9,442' P E - B-3 11,350' 11,397' 9,377' 9,419' 47 5 Open f/Prod $o �^ = B-4 11,397' 11,525' 9,419' 9,532' 128 5 Open f/Prod = 00 t• - HK-4 B-4 11,400' 11,470' 9,422' 9,484' 70' 12 Open f/Prod B-5 11,560' 11,660' 9,563' 9,650' 100 5 Open f/Prod HK-5 B-6 11,699' 11,744' 9,684' 9,723' 45 5 Open f/Prod Cleanout to 11,793•on ,. = HK-6 10/29/13 PBTD=11,834' TD=11,930' MAX HOLE ANGLE=48° Updated by: JLL 2014/06/27 • • , I oo / § o R§ | § () \ z ! } 2 �§ o o C) a- m. � * | | | , 1 Mil .1||!; § @ _ . © ƒ i i 0 9)1 0 X , } ! § § ■ Imag¢_~roject Well History File Cover I:~....ye XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ]_...~ ./- ~) _/ _/_ Well History File Identifier Organizing I,~o,,,~! [] RES~,~.~ ~ Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROB~ERYL MARIA WINDY Project Proofing BY: BEVERLY ROBI~SHERYL MARIA WINDY Scanning Preparation x30= + OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: IS/ = TOTAL PAGES BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ~si Production Scanning Stage 1 PAGE COUNT FROM SCANNED F~LE: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL A'CI'ENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO BEVERLY R~HERYL MARIA WINDY DATE:,~_~S/ IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES ~ NO BEVERL'~~INCENT SHERYL MARIA WINDY DATE.~'~_~ /SI ~-'-~::> ReScanned (indiwdu~l page RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IS/ Quality Checked 12/10102Rev3NOTScanned.wpd w+tc ,,;R;•,a an r. s4s: .yi- ,"gra' c <*i;:, a� ,'r., 'r ;..+'z.- &... t. ;t.':sn. y,,.. ® • ��, rl//T THE STATE i i 2 a)::--; a „,V-;-s "_ --41../..6. ._...�_L \,....1— .... #447---...:=_:::47--f } 333 West Seventh Avenue I x L !F' C �` Vt:;::'OTZ SEAN P aRNLI L Anchorage Aoskc, 99501 3,572 SCANDan Marlowe � MAY 162014 Operations Engineer Hilcorp Alaska, LLC I 1 ” 0 11 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-47 Sundry Number: 314-292 Dear Mr. Marlowe: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, / i Daniel T. Seamount, Jr. f"< Commissioner DATED this v day of May, 2014. Encl. mac, �T mg ` STATE OF ALASKA RE C E Y E D ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 5 20j4 APPLICATION FOR SUNDRY APPROVALS arS s/f//}- 20 MC 25.280 � � 1.Type of Request: Abandon 0 Plug for Redrill ID Perforate New Pool❑ Repair Well❑ �f'1'g '�pcov€d Program❑ Suspend❑ Plug Perforations 0 Perforate❑ Pull Tubing 0 Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other Replace ESP • 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development Q• 191-011 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ID Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20195-02- 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A/ Will planned perforations require a spacing exception? Yes ❑ No❑ Trading Bay Unit/D-47 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 • McArthur River Field/Hemlock Oil and Middle Kenai G Oil Pools. 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): - 11,930 -9,885 -11,783 ,9,757 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 398' 33" 398' 398' Surface 3,305' 16" 3,305' 2,948' 2,630 psi 1,020 psi Intermediate 10,978' 9-5/8" 10,978' 9,145' 6,870 psi 4,760 psi Production Liner 1,179' 7" 11,925' 9,881' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic/ See Schematic 4-1/2" 12.6#/L-80 10,508 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal Q- 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch O. Exploratory ❑ Stratigraphic❑ Development 0 ' Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/20/2014 Oil I] - Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ 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 Dan Marlowe Email dmarlowe(cr�hilcorp.com Printed Name Dan Ma owe Title Operations Engineer Signat Phone (907)283-1329 Date 5/5/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so sothat a representative may witness Sundry Number: %k` 1-1^ .. Plug Integrity 0 BOP Test +7 Mechanical Integrity Test ❑ Location Clearance ❑ Other: Z5C'D �s� C.'� ICS r Spacing Exception Required? Yes ❑ No 27 Subsequent Form Required: /0_ LI 09 0 Approved by:L APPROVED BY / COMMISSIONER THE COMMISSION Date:S"�// 5.-]-/Y ?M 3/4M .4t .,/., y Submit Form and Rettig g( d o o Approve0pRaloG rNorA Enths from the date of approval. Attachments in Duplicate 14 Well Work Prognosis .. ,. Well: D-47 HilcorN Alaska,LLC Date: 05/05/2014 Well Name: D-47 API Number: 50-733-20195-02 Current Status: ESP Producer Leg: Leg#A-2 (northwest) Estimated Start Date: May 20, 2014 Rig: HAK#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 191-011 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907)-777-8420(0) (985)-867-0665 (M) AFE Number: Budgeted Cost: Current Bottom Hole Pressure: -3,100 psi @ 10,600'MD(8644'TVD) 0.36 psi/foot-Current Phoeinix Data Maximum Expected BHP: -3,980 psi @ 10,600'MD(8644'TVD) 0.46 psi/foot SW Gradient-no new perfs Max.Allowable Surface Pressure: 0 psi using 0.46 psi/foot SW Gradient Brief Well Summary D-47 a comingled G and Hemlock producer.The ESP experienced a down-hole failure May 03,2014.We plan to pull and replace the ESP. No perforations will be added. Procedure: 1. MIRU HAK#1 Pulling Unit. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e-line and RIH to+/-10,500'and punch tubing. 3. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. POOH with tubing string and ESP pump laying down the same. 5. PU, RIH with ESP completion. 6. Land ESP with the bottom of the assembly at+/-10,600'. , 7. ND BOP, NU wellhead and test. ca5' 8. Turn well over to production. ��AX 9. RDMO HAK#1. h' Attachments: IL- 4,I 1. Current Well Schematic $-1 2. Current Wellhead Diagram 3. Proposed Well Schematic 4. BOP Drawing * 14Arthur River Field, TBU SCHEMATIC WeclI D-47 As Completed: 11/11/13 Hileorp Alaska,LLC RKB to TBG Head=40.3' Tree connection:4-1/16"5,000# CASING DETAIL 4.: L TYPE SIZE WT GRADE THRD ID TOP BTM. Conductor 33" Surf 398' Butt-welded Surf 16" 102 X-56 14.75 Surf 3,305' c PI L Production 9-5/8" 47 L-80 BTC 8.861 Surf 8,524' 53.5 8.535 8,524' 10,978' Liner 7" 29 N-80 TKC 6.185 10,735' 11,925' 4 PI fi TUBING DETAIL P , Tubing 4-1/2" 12.68 L-80 R2 IBT-M 3.958 Surf 10,508' Bis `` m_1 JEWELRY DETAIL ' NO. Depth OD ID Item 1 r,. "° 1 10,508' 6.75 Head Bolt On Discharge 1. k 2 10,508' 6.75 Pump (x2) . _ -'1 1 It' 3 10,552' 6.75 Pump Intake k 2 4 10,553' 7.38 Protectors (x2) I`,m 14 5 10,571' 7.38 Top of Motor (x2) s., 6 10,611' 4.5 Bottom of ESP(Phoenix Gauge) /'► I 9 - 7 10,735' TIW SN-6-AT Liner Top Packer Gii-F, 0 PERFORATION DETAIL G-1 Zone Interval(MD) Interval(TVD) Ft SPF Status G-2 G-1 10,659' 10,677' 8,764' 8,780' 18 5 Open f/Prod ah :' 7 G-2 10,704' 10,725' 8,803' 8,822' 21 5 Open f/Prod G-3 10,760' 10,790' 8,852' 8,879' 30 5 Open f/Prod G-3 G-4 10,816' 10,885' 8,901' 8,962' 69 5 Open f/Prod e G_4 G-5 10,974' 11,038' 9,041' 9,098' 64 5 Open f/Prod ' , G-5 G-7 11,149' 11,164' 9,197' 9,211' 15 5 Open f/Prod Y ° Csg shoe @10978'OIL G-7 B-1 11,175' 11,225' 9,220' 9,265' 50' 48 Open f/Prod B-1 11,182' 11,222' 9,227' 9,262' 40 5 Open f/Prod - HK-1 8-2 11,250' 11,265' 9,288' 9,301' 15' 12 Cmt Sqz B-2 11,280' 11,310' 9,315' 9,341' 30' 12 Cmt Sqz r I HK-2 B-3 11,340' 11,400' 9,368' 9,442' 60' 30 Open f/Prod 4..,,« B-3 11,350' 11,397' 9,377' 9,419' 47 5 Open f/Prod I� HK-3 ;•,« = B-4 11,397' 11,525' 9,419' 9,532' 128 5 Open f/Prod f.. --o+ B-4 11,400' 11,470' 9,422' 9,484' 70' 12 Open f/Prod - B-5 11,560' 11,660' 9,563' 9,650' 100 5 Open f/Prod i f ' - HK-4 B-6 11,699' 11,744' 9,684' 9,723' 45 5 Open f/Prod trt f ..r. HK-5 Updated by: .ILL 12/12/13 1 cianout to 11,7a3'on Vt. 's- HK-6 10/29/13 ice; . PBTD=11,834' TD=11,930' MAX HOLE ANGLE=48' .;Arthur River Field, TBU PROPOSED well: D-47 As Completed: 11/11/13 HiIcorp Alaska,LLC RKB to TBG Head=40.3' CASING DETAIL Tree connection:4-1/16"5,000# 4:: TYPE SIZE WT GRADE THRD ID TOP BTM. Conductor 33" Surf 398' v Butt-welded Surf 16" 102 X-56 14.75 Surf 3,305' cpl '7 1 Production 9-5/8" 47 L-80 BTC 8.861 Surf 8,524' 53.5 8.535 8,524' 10,978' Liner 7" 29 N-80 TKC 6.185 10,735' 11,925' TUBING DETAIL 0401 1 fn Tubing 44/2" 12.68 L-80 R216T-M 3.958 Surf ±10,508' 5 1 Ma. , JEWELRY DETAIL 8 6 1 , NO. Depth OD ID Item JI 1 ±10,611' Bottom of ESP 44 2 10,735' TIW SN-6-AT Liner Top Packer ry PERFORATION DETAIL Zone Interval(MD) Interval(TVD) Ft SPF Status f«, - G-1 10,659' 10,677' 8,764' 8,780' 18 5 Open f/Prod i1 ,E: 0-2 10,704' 10,725' 8,803' 8,822' 21 5 Open f/Prod 1 G-3 10,/60' 10,/90' 8,852' 8,8/9' 30 5 Open f/Prod 414' G-4 10,816' 10,885' 8,901' 8,962' 69 5 Open f/Prod V, G-10 G-S 10,974' 11,038' 9,041' 9,098' 64 5 Open f/Prod G-2 G-7 11,149' 11,164' 9,197 9,211' 15 5 Open f/Prod hi;::El ' 2 B-1 11,175' 11,225' 9,220' 9,265' 50' 48 Open f/Prod wa. B-1 11,182' 11,222' 9,227' 9,262' 40 5 Open f/Prod >1,' ¢¢¢ G-3 B-2 11,250' 11,265' 9,288' 9,301' 15' 12 Cmt Sqz ;IV B-2 11,280' 11,310' 9,315' 9,341' 30' 12 Cmt Sqz 1' G-4 G-5 B-3 11,340' 11,400' 9,368' 9,442' 60' 30 Open f/Prod ', Csg Shoe 010978'DIL G-7 B-3 11,350' 11,397' 9,377' 9,419' 47 5 Open f/Prod B-4 11,397' 11,525' 9,419' 9,532' 128 5 Open f/Prod HK-1 CN B-4 11,400' 11,470' 9,422' 9,484' 70' 12 Open f/Prod B-5 11,560' 11,660' 9,563' 9,650' 100 5 Open f/Prod HK-2 B-6 11,699' 11,744' 9,684' 9,723' 45 5 Open f/Prod $1 ' HK-3 Y Updated by:JLL 05/05/14 HK-4 fol 5 HK-5 eat Clean Ott 11,783 HK-6 10/29/13 PBTD=11,834' TD=11,930' MAX HOLE ANGLE=48° Doily Varden Platform .11 D-47 Current 06/20/2013 Hiirnrp Ala.ka.1.lA. Dolly Varden Tubing hanger,CIW-DCB- D-47 ESP,11 X 4'A IBT lift and 16 X 9 5/8 X 4 1/2 susp,w/4"type H BPV profile,5'/4 EN,2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,CIW,4 1/16 5M FE X Cameron internal blanking nut ilioror 4(C, �$ ti\rya c 3 e� Valve,swab,WKM-M, `� •" �cs�<<�' �. ' oQ 41/16 24E,HWO, r j '-i, �\�eti y��1t ,4 P• �III ..1111 Valve,wing,WKM-M, 2 1/165M FE,HWO, �,40' n � 0 +t' ii IT-24 � ai I ,�af s � O ,c Valve,lower master, P",! WKM-M,4 1/16 5M FE, ,TV HWO,T-24 ,..111.1111 AiiMitt IBI "' Adapter, CIW-Toadstool, , 11 5M Stdd X 4 1/16 5M FE, prepped I �= for 5'/4 ESP neck2-'/2 npt �,� ' continuous control line ports Tubing head, CIW-DCB, "'�-; - 13 5/8 3M X 11 5M,w/ _,+m ' I ':._ 2-2 1/16 5M SSO,X- wr II Ill bottom prep, i 1 '/VR profile i #aN"�) ill • '' Valve,WKM-M,2 1/16 5M •i-wl� illif!'-° a■ �� t i *4 FE,HWO,DD -- _ . Qty 2 AR �" DSPO-PP,16%3M X a .„ 13 5/8 3M,prepped for Casing head,CIW-WF r. 9 5/8 casing 16 3/4 3M X 16"SOW, gat------ ru it. Valve,CIW-F,2 1/16 3M FE, w/2-2 1/16 5M EFO r HWO,AA Dotty Varden Platform 2014 BOP Stack(HAK#1) 01/10/2014 Hik4lrp:Uswka.1314; Dolly Varden Platform 2014 Workovers BOP Drawing(HAK#1) Quail Tool Rental Stack tit tit tit tit 111 tit tit tit 3.42' til lir alai lit 111 I fi 111 111 I11 4.54' CI ®U lit lit tit lit lit tit tit:i: nt2.00' 0ii til nl• "r 1LO1I1L Kill Side Choke side 1.00'to 2.00' 21/16 5M w/HCR and Unibolt line 21/16 5M w/NCR and Unibolt line connection 11 INl tit 111'Iil connection Drill deck Riser 11 5M FE X 16.00' 11 5M FE lit lit It tit til Ill lil III III 111 3�, Spacer spool 115M FE X 115M FE lit lit tit tit lit STATE OF ALASKA AL, RECEIVEDA OIL AND GAS CONSERVATION COMMISSION DECD F C 1 2 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate❑ Other CI44IPe un P GC Performed: Alter Casing ❑ Pull Tubing❑l Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weill] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development I] Exploratory❑ 191-011 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ID Service❑ 6.API Number: Anchorage,AK 99503 50-733-20195-02 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594 • Trading Bay Unit/D-47 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): 11.Present Well Condition Summary: L LQ tanr—i 'k 0; , Total Depth measured 11,930 feet Plugs measured N/A feet true vertical 9,885 feet Junk measured N/A feet Effective Depth measured 11,783 feet Packer measured N/A feet true vertical 9,757 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor 398' 33" 398' 398' Surface 3,305' 16" 3,305' 2,948' 2,630 psi 1,020 psi Intermediate 10,978' 9-5/8" 10,978' 9,145' 6,870 psi 4,760 psi Production Liner 1,179' 7" 11,925' 9,881' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schemtic feet APR 2 4 2014 Tubing(size,grade,measured and true vertical depth) 4-1/2" SCANNED 12.6#/L-80 10,508'(MD) 8,634'(ND) Packers and SSSV(type,measured and true vertical depth) N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11,250'-11,265'&11,280'-11,310'/Pumped 17.8 bbls of Class G 15.8 ppg cement. 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: 0 0 0 130 115 Subsequent to operation: 195 33 7264 40 131 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ID • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 s Gas ❑ WDSPL❑ GSTOR ❑ WINJ El WAG El 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: 313-322 Contact Dan Marlowe Email dmarloweCa)hilcoro.com Printed Name Dan MMarlowe ,,-- JJ Title Operations Engineer Signature Y` I � �Phone (907)283-1329 Date 12/12/2013 X, 41-ZZ- it Form 10-404 Revised 10/2012 � ��/� __Submit Original Only i c-7:�,�:� DEL 13 to , McArthur River Field, TBU SCHEMATIC Well: D-47 As Completed: 11/11/13 liar.",Ala.ka.1.1.1; RKB to TBG Head=40.3' Tree connection:4-1/16"5,000# CASING DETAIL A L TYPE SIZE WT GRADE THRD ID TOP BTM. Conductor 33" Surf 398' 3,305' Butt-welded Surf 16" 102 X-56 cpl 14.75 Surf P Production 9-5/8" 47 L-80 BTC 8.861 Surf 8,524' 53.5 8.535 8,524' 10,978' Liner 7" 29 N-80 TKC 6.185 10,735' 11,925' 1. TUBING DETAIL 41 Tubing 4-1/2" 12.68 L-80 R2 IBT-M 3.958 Surf 10,508' 1 9 JEWELRY DETAIL NO. Depth OD ID Item 1 10,508' 6.75 Head Bolt On Discharge 2 10,508' 6.75 Pump (x2) * 1 . 3 10,552' 6.75 Pump Intake 2 3 4 10,553' 7.38 Protectors (x2) o � ' , 4 5 10,571' 7.38 Top of Motor (x2) 6 10,611' 4.5 Bottom of ESP(Phoenix Gauge) kiiimri 5 7 10,735' TIW SN-6-AT Liner Top Packer 6 PERFORATION DETAIL G-1 Zone Interval(MD) Interval(TVD) Ft SPF Status 1. G-2 G-1 10,659' 10,677' 8,764' 8,780' 18 5 Open f/Prod i IT 7 6-2 10,704' 10,725' 8,803' 8,822' 21 5 Open f/Prod 6-3 10,760' 10,790' 8,852' 8,879' 30 5 Open f/Prod G-3 G-4 10,816' 10,885' 8,901' 8,962' 69 5 Open f/Prod ' G-.y G-5 10,974' 11,038' 9,041' 9,098' 64 5 Open f/Prod ';, G-5 6-7 11,149' 11,164' 9,197' 9,211' 15 5 Open f/Prod L Csg Shoe @10978'DIL G-7 B-1 11,175' 11,225' 9,220' 9,265' 50' 48 Open f/Prod - HK-1 B-1 11,182' 11,222' 9,227' 9,262' 40 5 Open f/Prod B-2 11,250' 11,265' 9,288' 9,301' 15' 12 Cmt Sqz B-2 11,280' 11,310' 9,315' 9,341' 30' 12 Cmt Sqz HK-2 B-3 11,340' 11,400' 9,368' 9,442' 60' 30 Open f/Prod • _ B-3 11,350' 11,397' 9,377' 9,419' 47 5 Open f/Prod - HK-3 8-4 11,397' 11,525' 9,419' 9,532' 128 5 Open f/Prod - B-4 11,400' 11,470' 9,422' 9,484' 70' 12 Open f/Prod = B-5 11,560' 11,660' 9,563' 9,650' 100 5 Open f/Prod - HK-4 B-6 11,699' 11,744' 9,684' 9,723' 45 5 Open f/Prod T HK-5 Updated by: 1LL 12/12/13 • Cleanout to a- 11,783'on = HK-6 10/29/13 / ' PBTD=11,834' TD=11,930' MAX HOLE ANGLE=48° Hilcorp Alaska, LLC llileorp ,lo.ka.i.l.(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-47 50-733-20195-02 191-011 9/23/2013 11/11/2013 Daily Operations: 09/23/13-Monday Nipple down tree&nipple up riser spools,flow cross,kill and HCR valves. 09/24/13-Tuesday N/U 13-5/8"5M riser,NU flow cross with kill and choke valves. N/U 13-5/8"5 M double BOP and Annular Preventor.Installed blind& pipe ram. Re-tighten all flanges on riser and BOP's. Make up and run KOOMEY lines. 09/25/13-Wednesday Continue to rig up and install Koomey lines to BOP's.Install flanges and coflex hoses on drilling spool.Install tongs&slips on rig floor and dress both with 4-1/2"dies.Ran elec cable for Koomey unit and hooked up air to same. Filled Koomey with Hyd oil and attempted to hookup remote control cable.(found control wire manufactured wrong/female connections on both ends).PU and MU 4-1/2"test joint. Landed same in hanger.Attempted to test BOP and found leaks at drilling spool flange. Tighten same.Attempt to test BOP's again and found leak at DSA on well head.Re-tighten all bolts on all riser spools and BOP stack. 09/26/13-Thursday Finished torqueing up bolts on BOP stack,spools and valves.Mount choke manifold on choke stand and spot same on rig skid beams. Connect coflex hose to manifold.Closed pipe rams and test lines and rams to 2,000 psi.Pressured up on Koomey and pressure would fluctuate from 2900 to 3400 psi. Pulled cover off of Koomey skid and found all inlet valves on bottles closed,opened same pressured up on Koomey and adjusted regulator so unit kicks in at 2600 psi and kicks out at 3000 psi.MU and land 4-1/2"test joint in hanger. Test BOP's,manifolds&lines to 250 psi low/3500 psi high for 5 minutes. Had leak on unit-bolt connection on kill side of circulating manifold&valve on pump line. Tightened and re-tested ok. Tested annular to 250 psi low/2500 psi high. Attempt to Install V door cat walk into hangers on work platform.Removed any grid hanger pins to fit and start building handrail for same.Install hydraulic hose hangers under work platform and do general house keeping on rig floor and in cellar area. 09/27/13-Friday Emailed Jim Regg with AOGCC 24 hour notice for rig inspection and BOP Test(at 5:00 am).RU 3-1/2"PH-6 test joint&TIW valve,land in and makeup to hanger.Fill Koomey unit. Install lights in Koomey generator shack,pit&pump room&prepare rig and upper deck of platform for state inspection.Test BOP's with 3-1/2"tbg to 250 psi low/3500 psi high and annular to 250 psi low/2500 psi high. RU circ.lines from rig manifold to choke manifold. Run vent lines to north and south ends of platform,finish v-door slide,install shaker screens,service generator&perform general rig maintenance while waiting on state inspector. 09/28/13-Saturday General cleaning of rig and upper decks while waiting for AOGCC rep.Test BOP pipe rams,annular,lines and manifolds to 250 psi low /3500 psi high for 5 mins on chart.Test witnessed by Jeff Turkington,AOGCC.Had failure on manual choke line valve on drilling spool, greased and tested ok. Wing valve on stand pipe capped and took out of service.Seal ring at jars leaked on high test,tighten&retest. LO test joint,pull back pressure valve attempt to set 2 way check and unable to do so due to brake out gas. PU and MU 3-1/2"landing joint. Circulate 160 bbls.Pull landing 3-1/2"jt. Install two way check and test blind rams to 250 psi low&3500 psi high for 5 mins on chart. 09/29/13-Sunday Pull 2 way check valve&break down 4-1/2"and 3-1/2"test assy.Shut down Gen package,install heater and lighting control box on transformer skid. Rig down test lines for cucrc.manifold.Screw into hgr with 4-1/2" landing jt,run out hold down pins,open TIW valve monitor well for flow.Pull hgr free with 190k(pipe wt picking up=190-194K).RU equipment,pull hgr to floor,cut elec&flat pack lines,break out hgr. POOH with 4-1/2"production tbg&ESP.68 jts out of hole=2,176'. 09/30/13-Monday Continue POOH with 4-1/2"production string with ESP&GLM's.Back load full pipe carriers&4-1/2"tbg to work boat(production string).Arrange deck to take on work string.Continue POOH with production string,ESP pump&GLM's(288 jts,=8972'out of hole). Hilcorp Alaska, LLC t,►►eorp Alaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-47 50-733-20195-02 191-011 9/23/2013 11/11/2013 Daily Operations: 10/01/13-Tuesday Continue POOH with 4-1/2"production string. BO&LO ESP pump.Clean rig floor and prepare equipment to RIH with scrapper while back loading 4-1/2 production tbg to work boat. Take on 3-1/2"PH-6 work string and strap same.Back load spoolers,wire spools and work baskets to work boat.PU and MU 9-5/8"clean out assy.Install wiper plate and pipe rubber.BHA=3-1/2"PH-6 box 3-1/2 IF pin, 3-1/2"IF box x 3-1/2"reg box bit sub,casing scraper,junk mill-length=12.44'.RIH with BHA#1 while PU 3-1/2"PH-6 P-110 work string from pipe rack,rabbiting same while RIH. 10/02/13-Wednesday Continue picking up 3-1/2"PH-6 work string off of rack&RIH with BHA#1 to 10,735'.RU up line and break circ in reverse with 17bbls of fluids. Shut down pumping after pumping 50 bbls due to losses of 1 bbl per min. Swap manifold a circulated 900 bbls down drill pipe at 5 bpm total loss=5bbls.Shut down pump monitor well for flow while rigging up to POOH.POOH with BHA#1(9-5/8"junk mill &scraper).Total losses since starting well=337 bbls. 10/03/13-Thursday Continue POOH with 9-5/8"cleanout string.Breakout and layout 9-5/8"scraper&junk mill.Received notification at 10:35 from Phoebe Brooks @ AOGCC that#2 Blind Ram test result was changed to"F".RU up and retest blind rams,rams tested ok.PU and MU test packer.RIH with packer and set same at 10,650'. Space out,set packer. Fill csg with 5 bbls,close rams and test 9-5/8"casing to 1500 psi on chart for 30 mins. 10/04/13-Friday Service rig&equipment.Unset packer&POOH slowly from 10,640'to surface.Break&LID 9-5/8"packer. Clean rig floor.P/U& make up clean out assembly for 7"29#csg.TIH with 3-1/2"P-110 tubing out of derrick.Depth @ 0600 hrs.=10,953'. 10/05/13-Saturday Service rig&equipment.Continue TIH,tag @ 10,954'.Pull 40k over string weight.Unable to pull on up stroke.Slack off&pipe moving in down stroke.Slack off to 10,984'.Rig up circulating hoses&attempt to reverse circulate with no success.Line up&pump down tubing,annulus packed off.Attempt to work string with no success.Install 150 ton elevators&work pipe free with 70k over string weight.Attempt to circulate with no success.Strip over&install adaptor flange with Halls head.R/U power swivel to begin washing. Install&tighten 4"FH by 3-1/2"ID sub to power swivel.M/U pump in sub&pressure up on tubing to 4500 psi,attempting to blow out packed off mill with no success.R/D&lay down power swivel.POOH with 3-1/2"P-110 workstring from 10,664'.Depth @ 0600 hrs=5,112'. BOPE test witness waived on 10/5/03 @ 14:32 hrs by Jim Regg. 10/06/13-Sunday Service rig&equipment. POOH with 3-1/2"P-110 tubing from 5,100'to surface.Rack back 4-3/4"drill collars in derrick. L/D bumper &oil jars.P/U test plug&M/U test joints with equipment to begin testing BOPE.Test BOPE per AOGCC regulations.Test blind&pipe rams,Hydril,kill line valves,choke line valves,choke manifold,choke,circulating manifold,TIW#1,TIW#2,IBOP,upper Kelly valve, test to 250 psi low&3500 psi high,hold all test on chart for 5 minutes.Witness of test waived by Jim Regg,AOGCC. Perform Koomey draw down test. Tested BOP's from remote&function test main Koomey controls.L/D power swivel&all BOPE test equipment. Install wear bushing.P/U 6"Piranha deep throated mill, jars,&drill collars&TIH with same.TIH with 3-1/2"P-110 tubing.Depth @ 0600=2,140'. 10/07/13-Monday Service rig&equipment.TIH with 3-1/2"P-110 work string to 10,639'.Install 13-5/8"x 7"adaptor flange with Halls head spool. Tighten down same.P/U power swivel&R/U hydraulic lines with dual dead man anchor cables.Break circulation in reverse pumping 2 bpm&100 psi.Wash f/10,639' t/10,735'(7"liner top),reverse circulating @ 2 bpm&100 psi.Had 0%solids on returns.Wash& ream inside of 7"29#liner from 10,735'to 10,990'.Milling from 10,990'to 11,145'with 4k-5k weight on mill,pumping 3.5 bpm in reverse @ 500 psi,40 rpm&6k-7k torque.16 bph losses while milling.Circulate bottoms up @ 11,145'. Hilcorp Alaska, LLC Hilcorp Alaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-47 50-733-20195-02 191-011 9/23/2013 11/11/2013 Daily Operations: 10/08/13-Tuesday Milling from 11,145'to 11,204'reverse circulating @ 2.5 bpm&300 psi,40 rpm&8500 ft/lbs of torque.Fluid losses to formation=5 bph.Shale/sand on returns.ROP slowed to 2.5 FPH.Send to Trading Bay facility to displace D-47 well bore with clean fluid.Continue reverse circulating at 5 bph&500 psi&rigging up drain lines to displace well.Rotate&reciprocate pipe while reverse circulating FIW throughout D-47 well bore.Reversed out&shipped total of 800 bbls to Trading Bay facility.Clean sand settlement from shaker& settling tanks.Milling on sand/scale from 11,204'to 11,206',reverse circulating 3.1 bpm&300 psi,5k-7k web,torque off bottom 7000 ft/lbs,on bottom torque=8500 ft/lbs.5 bph losses to formation. 10/09/13-Wednesday Milling f/11,206't/11,214',reverse circulating @ 3.1 bpm&300 psi,5K-7K WOB,8500 ft/lbs torque.Circulating sand/scale mix to surface.Wash&clean hole f/11,214't/11,225'without rotating.Milling f/11,225't/11,302'.Reverse circulating @ 3 bpm&270 psi, 5K-7K WOB,off bottom torque=7500 ft/lbs,on bottom torque=8500 ft/lbs.28 bph losses to formation.Total lost to formation= 623 bbls(last 24 hrs). 10/10/13-Thursday Milling f/11,302't/11,333'.Reverse circulating @ 3 bpm&280 psi,7K-9K WOB,40 rpm with 8700 ft/lbs of torque on bottom,8200 ft/lbs off bottom.Losses increased from 25 bph to 100+bph at 11,333'while circulating bottoms up.Reverse circulate bottoms up @ 3 bpm&100 psi. Mix&spot 16 bbls of n-vis loss circulation material across perforations inside 7"casing.Losses to formation decreased to 3 bph.Prepare to POOH. L/D power swivel&remove stripper rubber.Prepare rig floor to POOH.POOH with 180 stands of 3-1/2"P-110 workstring.L/D(4)4-3/4"drill collars,jars&mill.6"piranha mill was 1/16"under gauge.P/U&make up 7"EZ drill SVB assembly for 29#casing.TIH with 7"EZ drill plug on 3-1/2"P-110 tubing @ 150 fpm inside of 9-5/8"csg.Depth @ 0600 hrs= 7,541'. 10/11/13-Friday Service rig&equipment.TIH with 3-1/2"12.95#P-110 tubing to 8,600'.Incident with blocks contacting beam in derrick. Shut-down held safety stand-down. Contacted Superior Derrick and made recommended repairs. Approval to move forward was given at 1030 hrs. TIH with 3-1/2"P-110 tubing to 11,325'tubing measurements.Set 7"29#EZ drill SVB @ 11,325'tubing measurements.Pull& shear off of CIBP with 203k.Pull off of plug 10'.Slack off&tag top of plug @ 11,320'.Set 20k down.P/U 1.5'off of plug&isolate well. R/U cementers,spot cutting boxes&equipment.Perform balanced plug job with cementers.Test lines to 4000 psi,pump 16 bbls of drill water spacer,mix&pump 87 sacks of class g 15.8 ppg cement with 1.16 yield.Total of 17.8 bbls.Follow by 2.2 bbls of drill water. Displace with 77 bbls of FIW putting top of cement @ 10,785'.POOH with 17 joints of 3-1/2"tubing to 10,800'.Displacement took 6 bbls.Reverse circulate(2)tubing volumes at 3 bpm&250 psi,slip&cut 118'of drill line while waiting on cement. 10/12/13-Saturday Waiting on cement. Slip&cut 107'of drill line. Perform general rig maintenance and housekeeping around rig.TIH slowly&set down on cement with 8k @ 10,838'.Prepare rig floor to POOH.POOH with 182 stands of 3-1/2"P-11012.95#tubing,racking all pipe in derrick. Break&L/D mechanical running assembly.Clean rig floor&area. Prepare to test BOPE per AOGCC regulations. R/U testing equipment,make up test joints with test plug&set same.Open casing valve to monitor while testing BOPE.Test BOPE per AOGCC regulations.Test blind rams,2-7/8"x5"VBR pipe rams,Hydril,choke manifold,circulating manifold to 250 psi low&3500 psi high. Test#1 TIW,#2 TIW,IBOP, hold all test on chart for 5 minutes.BOPE test witness waived on 10/12/13 @ 11:13 hrs by James Regg, AOGCC. Hilcorp Alaska, LLC Hilcnrp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-47 50-733-20195-02 191-011 9/23/2013 11/11/2013 Daily Operations: 10/13/13-Sunday Continue testing BOPE per AOGCC regulations. Test upper Kelly valve,perform Koomey draw down test.Initial psi=3000,psi after closure=1750 psi,200 psi attained=22 sec.Full pressure=90 seconds.Rig down test equipment&L/D test joints with test plug. Prepare rig floor to pick up BHA.P/U 6"mill tooth bit,(4)4-3/4"drill collars,4-3/4"jars&RIH w/same.TIH with 180 stands of 3-1/2" P-110 tubing out of derrick to 10,828'.Monitor well for losses. Install adaptor flange with stripper head&nipple up same.Well remaining static with zero losses.P/U&rig up power swivel with hydraulic lines.Break circulation at 3 bpm&400 psi.Drilling cement f/10,838't/10,891',reverse circulating @ 3bpm&400 psi,WOB=7K-9K,40 rpm&8500 ft/lbs of torque on bottom(8200 ft/lbs off bottom)full returns with no losses. 10/14/13-Monday Drilling cement f/10,891 t/11,032'.Reverse circulating @ 3bpm&400 psi,3K-5K on bit,8700 ft/lbs of torque on&off bottom.Unable to continuously obtain rotation due to maximum torque reached on tubing thread due to friction.Circulate 10 bbl high vis sweep throughout hole,order friction reducer.Circulated one full surface to surface to clean well bore while waiting on friction reducer.Mix &treat fluid system with CFS-520 friction reducer.Displace well bore with 800 bbls of FIW treated with 2%of CFS-520 friction reducer.Reverse circulating @ 3 bpm @ 350 psi&sending returns to Trading Bay facility.Clean solids from shaker&settling tank. 10/15/13-Tuesday Clean settlement from mud tanks&pump lines.Drill on cement f/11,032't/11,322',reverse circulating @ 3 bpm&350 psi,5K-7K WOB,torque on bottom 6000 to 8000 ft/lbs,off bottom=6000 ft/lbs.Circulate bottoms up @ 11,322'(top of CIBP). Monitor well for losses,well static.Drill on CIBP f/11,322't/11,325',reverse circulating @ 3 bpm&350 psi,9K-12K WOB,8000 ft/lbs of torque on bottom.Break thru CIBP&push down hole to 11,332'.Continue milling on CIBP @ 11,332'. 10/16/13-Wednesday Drill and washed from 11,331'to 11,350'.Work on power swivel while continuing to reverse circulate at 4 bpm,350 psi.Continue drilling and washing from 11,350'to 11,390',pumping in reverse at 4 bpm at 350 psi.Pipe plugged at 11,390'.RD power swivel,hyd lines,snub lines,pump lines and swivel.RD stripping head&dsa,install wiper plate,wiper rubber&slips.POOH laying out singles from 11,390'to 10,735'.Pipe pulling wet.Continue POOH with wet string standing back 3-1/2"PH-6 work string.Depth at report time =5,500' 10/17/13-Thursday Continue POOH with 3-1/2 work string and 6"od bit to 65',found last two drill collars plugged with sand and scale.Total fluid lost while POOH=250 bbls. RU 3/8"stainless tbg with crows foot connection and washout drill collars and bit.Clean up rig floor and prepare to RIH with BHA#5.PU and MU BHA#5,6"rock bit,bit sub,4-3/4"oil&bumper jars,(4)4-3/"DC&3-1/2"PH-6 X 3-1/2"IF pin x-over.length=150.75'. RIH with BHA#5 and 3-1/2"PH-6 work string--depth at report time=10,231'. 10/18/13-Friday Service rig.Continue in hole with 6"bit and 3-1/2"PH-6 work string to 11,100'.Install 13-5/8"X 7-1/16"adapter flange and stripping head onto top of annular.Continue in hole to 11,331'.PU and MU power swivel.Install stripping rubber.Rotate and wash from 11,331'to 11,386',pumping at 3 bpm 280 psi,Reverse out 1 bottoms up at 3 bpm 280 psi,fluid loss=6 bph.Rotate and wash from 11,386'to 11,400' pumping at 3 bpm 280 psi,30 rpm 6000 ft/lb torque,fluid loss increased to 30 bph and power swivel started stalling out with 8000 ft/lbs of torque.PU 20'and continue reversing out until returns were clean.Mix and pumped 25 bbl N-Vis pill followed by 70 bbls of FIW,putting 12 bbls outside of work string,closed kill line and squeezed 8 bbls into formation at 1/4 bpm max / pressure=-500 psi.Shut down pump,and monitor well.Had-0-fluid loss in 1 hr. PU 20',open well and circ 1 complete volume while adding NXS lube,losses=2 bbls.Slacked of 20'while rotating at 60 to 80 rpm,2500 to 3000 ft/lb torque to 11,400',attempted to drill deeper w/o success,pipe stalling and bouncing off bottom,set down wt=from 2k to 10 k.RD power swivel and LO same. POOH with BHA#5 depth at 06:00-2,900 ft. Hilcorp Alaska, LLC Hi!carp Alaska,LLC Well Operations Summary Well Name API Number _Well Permit Number Start Date End Date • D-47 50-733-20195-02 191-011 9/23/2013 11/11/2013 Daily Operations: 10/19/13-Saturday Service rig.Continue POOH with 3-1/2"Bit assy.BO&LO out BHA#5.PU and MU 3-1/2"test jt.MU wear bushing retrieving tool and pull same.Test BOP's pipe&blind rams,annular preventer,lines,valves and manifolds to 250 psi low,3500 psi high for 5 min each on chart with 3-1/2" tbg.had(1)low test failure on circulating manifold valve due to stem packing leaking,greased same and retested ok,Annular preventer failed low test,function annular and retested ok.All testing done with BOP remote panel,(function main). State witness waived by Jim Regg,AOGCC.RD BOP testing equipment,set wear bushing and prepare equipment to RIH.MU BHA#6 5- 1/2"junk mill bit sub,bumper sub and jars(4)collars&3-1/2 PH-6 box x 3-1/2 IF pin xover.RIH with BHA#6,depth at 06:00 2,476'. 10/20/13-Sunday Continue RIH with milling assy.Continue in hole to 11,366'.PU and MU power swivel,install stripping head and brake circ in reverse @ 3 BPM 390 psi,reverse 1 tbg volume of 89 bbls.Reamed and washed to 11,398'PU to 11,383'washed back down to 11,403'and pressure increased from 390 psi to 1150 psi and lost returns.Swapped manifold and pressured up on tbg attempting to unplug tbg with 2200 psi w/o success.Attempted to break bridge by working string in 30'stroke with and with out pressure w/o success,stroked tbg 15 times.Attempted to pressure up annulus w/o success,tore down pump and found brass cement in suction cleaned suction lines and pump. Attempted to circulate down tbg and pressured to 1500 psi.RD power swivel and started POOH wet string pulled at total of 49 stds and pipe started pulling dry(3,087'). RU pump in sub and circulated 100 bbls down tbg. 10/21/13-Monday Continue RIH to 11,366'.Install stripping head,PU power swivel,Circ well in reverse at 4 bpm 500 psi.Continued washing down while reversing from 11,366'to 11,405'and pressure increased from 300 psi @ 3 bpm to 659 psi,shut down pump lined up down tbg and found same plugged increased pressuring 3000 psi. Rocked pressure from-0-to 3000 psi 5 times and plug broke loose.11,405'is equal to final wash down depth on last trip.Washed from 11,405'to 11,492' pumping down tbg.PU off bottom every 15'&rev circ 3 BPM 360 psi PU 135K,SO 105 Torq 3-4K. Close Hydril and reverse out at 5 bpm @ 9000 psi. 10/22/13-Tuesday Continued in hole 11,492'.RU stripping head and power swivel,rotated and washed to 11,508'@ 3 bpm/360 psi pumping down work string,Reverse out 3 tbg volumes @ 4 bpm/460psi,Rotate and wash from 11,508'to 11,523 @ 3 bpm/380 psi,Reverse out at 3 bpm and pipe plugged after pumping 5 bbls.Swapped manifold around and pumped down work string and blowed plug attempted to reverse out 3 addition times w/o success.Pumped down work string 82 bbls @ 4 bpm w/500 psi.Reversed at 11,523'180 bbls 3 bpm with 330 psi attempted to work pipe after reversing and had to pull 50 k over PU weight to move same.Mix and pump 10 bbl high vis sweep around with 8.5 ppg FIW @ 6 bpm with 1200 psi pumped a total of 795 bbls while rotating and working work string. Shut pump down swapped manifold around reversed out 5 bbls and pipe plugged,swapped manifold and blowed plug with 800 psi, attempted to PU work string and had to pull 190k(70k over PU weight)to free same. RD power swivel and stripping head,POOH to surface,found outside of DC slicked over with a greasy tar substance. Cleaning and servicing rig. 10/23/13-Wednesday MU BHA(#7)--6"od piranha mill assy&RIH to 11,392'.Install stripping head,PU&MU power swivel,Break circ down tbg with 2 bpm @ 125 psi.Shut down pump and install belt on rod lubricator pump.Break circ down tbg with 25 bbls,@ 3 bpm,360 psi,swap manifold and broke circ down csg with 3 bpm 320 psi,Wash from in reverse from 11,392'to 11,430'found tight spot at 11,398' rotated and wash thru same with 5-7k weight down and 4 to 5k torque,60 rpm. Circ and wash from 11,430'to 11,520' circ down casing with @ 3 bpm 325 psi, at 11,520'found hard spot and unable to wash and mill while reversing,swapped manifold and milled and washed from 11,520'to 11,530"with 7 to 8k wt down,60 to 70 rpm,7 to 6k torque.pumping at 3 bpm 300 psi.Swap manifold from pumping down tbg to down csg and attempted to reverse out w/o success due to pipe plugging.Pumped down tbg at 5 bpm 1100 psi,Reverse out 200 bbls at 3 bpm 320 psi. Hilcorp Alaska, LLC Hikorp:%laska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date 0-47 50-733-20195-02 191-011 9/23/2013 11/11/2013 Daily Operations: 10/24/13-Thursday Continue rev out at 11,534'@ 320 psi,total pumped 252 bbls.Rotate and wash from 11,534'to 11,540'DPM @ 3 BPM,300 psi,60 rpm,3-5K wt down,Circ down tbg @ 5 BPM 1005 psi total pumped 230 bbls.Attempted to reverse out with no success pipe plugged after pumping 5 bbls,mixed and pumped 10 bbl high vis sweep around @ 5 bpm,900 psi total pumped=790 bbls. Mixed 5 bbl high vis sweep and spotted same in tbg,rotate and wash from 11,540'to 11,587'pipe measurements pumping @ 5 bpm,300 psi at 11,587'.Pumped additional 5 bbl sweep and spotted same out end of 3-1/2 PH-6 tbg with 90 bbls of 8.5 FIW.Mixed and pumped additional 5 bbl 140 vis sweep from surface to surface @ 6 bpm 1070 psi total pumped 760 bbls.Continue rotating and washing from 11,578' to 11,783 pumping down work string at 4 bpm,625 psi.Pumped 5 bbl high sweep to end of work string after each connection.Mixed and pumped 25 bbl high 140 vis sweep from surface to surface at 5-/2 bpm,90.0 psi.RD power swivel&LD same prep to POOH to top of liner. Attempt to POOH and found same stuck.RU pump in sub and apply from 500&found tbg plugged increased pressure to 2500 psi&unable to pump out plug.Worked pipe with 40 to 60 k over PU wt and rocking tbg pressure from 500 to 200 psi and unable to pull free. 10/25/13-Friday PU&MU power swivel apply 1500 psi down tbg rotate pipe at 40 rpm for 30 mins and plug broke loose.Circulate well at 3 to 4 BPM. Clean pits&service equipment while waiting on Bariod casing cleaning chemicals.Take on Bariod chemicals,extra storage tanks and line from work boat and spot same on deck.Hook up lines from tanks to pump&mixed casing wash chemicals----40 bbls caustic wash,20 bbls Barascrub,40 bbls Barakleen&40 bbls N-vis spacer.Held pre pumping job JSA.Displace casing wash around with FIW at 3 BPM,460 psi with returns going to Trading Bay total fluid pumped behind chemical sweep=670 bbls of 1150 bbls pumped. 10/26/13-Saturday Cont.displace well with 8.5 FIW @ 4 bbl./min,600 psi--total pumped 1364 bbl. Start out with mill bha--pulling 40k over,rotate and pump---torque @ 8k,pump 40 bbl.NXS sweep and displace with 46 bbl.FIW @ 3 bbl/min 480 psi,rotate and cir.out laying down singles from 11,783'to 11,398'.Attempt to pull from 11,398' --pull 30,000 over while pumping 4 bbl./min---unable to free or verify jar stroke. Rig up power swivel and pump 130 bbl.of NSX while working the pipe free.Cont.cir.out laying down singles f/11,398'to 11,210'. Rig down power swivel and pull stands to 10,707',reverse cir.@ 3bbl/min 340 psi--pump 150 bbl.to clean up @ the top of the liner. Continue out pulling stands from 10,707'. 10/27/13-Sunday Continue POOH with 6"mill assy. BO and LO jars and mill.RU BOP testing equipment,pull wear bushing,land test plug with 3-1/2" test jt. MU TIW and IBOP valves.Test BOP pipe,blind rams,annular preventer lines and safety valves to 250 psi low and 3500 psi high. Chart for 30 mins.Annular failed 3500 high test,cycled annular and increased hyd pressure on Koomey 100 psi &annular tested to 3500 psi ok.Witness of test waived by Jim Regg,AOGCC.Pull test plug,install wear ring,rig down 4.5 test assy. Rig down test equip. Pick up BHA,(mule shoe,2 X/O subs)trip in. BHA no.8 x/o 3.5 ph-6 x 3.5 IF BXP,x/o,3.5 IF, X3.5 X 3.5 ph-6 BXP,3.5 ph-6 mule shoe. 10/28/13-Monday Trip in hole to 10,675'.Slip&cut drlg line-78 ft.Reverse cir.at least 1 tubing volume or until the shakers cleaned up every 60 ft. from 10,675'to 11,313',cir.using 3 bbl./min 230 psi,getting some soft tar,sand and scale back in returns. 10/29/13-Tuesday Cont.to wash and clean the hole from 11,311'to 11,783',reversing out every 60 ft.@ 3bbl./min 350 psi.Tagged @ 11,783'and picked up off bottom 3 ft and attempted to reverse out.Plugged off and pressured up to 750.Pumped down the tubing to unplug. Pick up to 11,750'and cir.2 tubing volumes and cleaned up the hole.Work back down and reverse hole clean @ 11,783'.Pull out of the hole to 10,682'.Wait 1 hour.Trip in to 11,783',cir bottoms up 1 and a half tubing volumes,Hole is clean with no solids coming back.Pull out of 7"liner slow.Continue POOH with 3-1/2"PH-6 And mule shoe @ report time depth=7,239'. Hilcorp Alaska, LLC l,ik.urp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-47 50-733-20195-02 191-011 9/23/2013 11/11/2013 Daily Operations: 10/30/13-Wednesday Continue POOH with 3-1/2"muleshoe to 635'. Cleaned pits recovered 6 bbls of solids.RU pipe tongs,BO x-overs and LO power swivel continue POOH with 3-1/2"mule shoe.Clean rig floor and prepare to PU and MU TCP guns.Held pre job JSA on handling and running of TCP guns.PU and MU 4.5" 5 SPF TCP gun assy.RH with TCP guns on 3-1/2"work string rabbiting same depth @ 06:00=10,700'. 10/31/13-Thursday Continue RIH with 4-1/2"5 SPF,TCP gun assy.to 11,783',tagged bottom&PU to 11,756'DPM. RU a-line and test lubricator to 500 psi. RIH with 1-11/16"GR,CCL&logged from 10.638 to 10,260',found guns less than 1 ft off correct depth.POOH with e-line and rd same.Break circ with 2 bbls,drop 5/8"ball for firing head and circ same on seat with 26 bbls,pressured up to 2800 psi and fired guns. Perfs=10,659'-10,677',10,704'-10,725',10,760'-10,790',10,816'-10,885',10,974'-11,038',11,149'-11,164,11,182'-11,222',11,350'- 11,525',11,560'-11,660',11,699'-11,744' monitor for 5 mins.Found well on slight vacuum.POOH to top of liner(10,735').Monitor well.Continue POOH laying 3-1/2"PH-6 work string well taking 8 bph total fluid loss=100 bbls.At 06:00 hrs L/0 TCP guns. 11/01/13-Friday Continue POOH with TCP gun assy and 3-1/2"PH-6 work string laying out same.All shots fired on 4-1/2"5SPF guns.RIH with 22 sds of 3-1/2"PH-6 work string.POOH&LO same.RD 3-1/2"equipment,clean rig floor,pull wear bushing.RU ESP running equipment,wire spools and spoolers,and handling tools.PU bottom section of pump opened blind rams and coco mat fell in hole.L/D bottom section of ESP pump,R/D equipment. PU wear bushing and install same.Move equipment around on deck and prepare same to take on 3- 1/2"work string,lost 60 bbls of fluid to hole in last 24 hrs. 11/02/13-Saturday Waiting on 3-1/2"PH-6 workstring to arrive.Talked to Jim Regg and requested to test BOP's 24 hrs early and he waived state witness to testing.ND 7-1/16"X 13-5/8"adapter flange from 13-5/8"riser spool.PU and MU wear bushing retrieving tool and pull wear bushing.MU test plug to 3-1/2"PH-6 test jt and land same.MU side entry sud,3-1/2"TIW valves and IBOP to test jt.Attempt to test BOP's W/O success,unable to find any visual leaks,pulled test plug changed seal on same.Landed plug. Attempted to circulate manifold,choke and kill line valves w/o success.Disconnect test pump line from manifold and bull plug same and found pressure bleeding back thru pump(two ball valves bad).RD tri-plex test pump and RU production 10,000 psi diaphragm test pump.Test BOP's, annular,manifolds,safety valves and lines to 250 psi low 3500 psi high on chart for 5 min each with 3-1/2"and 4-1/2"tbg(-0- failures all test good). Witness of test waived by Jim Regg,AOGCC.RD test equipment,pull test plug,flip same and install wear bushing.Cleaned rig floor and prepare to RIH with cutlip shoe and finger basket. Filled hole with 56 bbls of FIW fluid level=790'.RU pipe tongs,PU and MU BHA#8---8-1/8"OD cutlip shoe with finger basket,8-1/8" washpipe pup,8-1/8"canfield bushing,3-1/2"IF box x 4-1/2"IF pin x-over,4-3/4"oil jar 3-1/2 PH-6 box x 3-1/2 IF pin x-over,3-1/2"PH-6 pup jt.---total BHA length=43.96'. RIH with BHA#8 and 3-1/2"PH-6 tbg picking same off of pipe rack reversing bottoms up every 1,000'. 11/03/13-Sunday Service rig.PU and MU 3-1/2"PH-6 work string rabbiting same&continue RIH reverse circulating bottoms up every 1200'at 18:00 hrs depth=6,600'.Continue in hole to 8,000'ft,reversed circulated 2 tbg volumes @ 4 Bpm/360 PSI,getting traces of coco mat across shaker and pressure increased for 360 psi ton 415 psi @ 90 bbls pumped. Continued in hole to 9,920'.Continue in hole with 3-1/2"PK 6 tbg. Hilcorp Alaska, LLC Hilcorp:1lasku.LL(: Well Operations Summary Well Name API Number Well Permit Number _Start Date End Date D-47 50-733-20195-02 191-011 9/23/2013 11/11/2013 Daily Operations: 11/04/13-Monday Continue in hole to 10,739'DPM and tag top of liner with 3-/12"PH-6 cut lip shoe and reversing finger basket.PU to 10,738'while reversing at 4 BPM with 460 psi,Reversed 5 bbls&shut down pump and clean out suction valve,found tie wrap in same.Continue reversing at 5 Bpm 680 psi 150 bbls 1-1/2 tubing volumes with no indication of pressure increase or fish.Shut down pump and observed well(Losses 10 BPH). Total loses last 24 hrs=225 bbls. Pump 15 bbls high Vis pill to end of 3-1/2 work string at 10,738'with 75 bbls monitor well for 45 minutes and well was static. POOH with 3-1/2"PH-6 and Finger basket to surface,broke out basket and found no fish(coco mat). Held trip drill time to secure well=1 min,total time to complete drill all hands in place and valves lined up= 5 min 45 sec.Clean floor.PU&MU BHA#8---6"X 5.75'OD wave shoe with 2 wire strands inside 3'apart,5-3/4"OD wash pipe ext.,5. 3/4"drive bushing,4.75"OD hyd jar,3-1/2"PH-6 box x 3-1/2"IF pin x-over 3-1/2"PH-6 pup total length=33.66'.RIH with 3-1/2"PH-6 to 10,735'running stands from derrick.Continue in hole PU singles from rack depth @ 06:00=11,113'. 11/05/13-Tuesday Service rig and continue RIH with reverse wire basket&burning shoe picking pipe up from rack.Tagged tight spot at 11,354'DPM. Remove air slips,install striper head,spot power swivel in place.RU hoses from power swivel to derrick.PU power swivel,install stripping rubber in head&make up connection.Circulated in reverse @ 3 BPM 300 psi and rotated thru tight spot.Continued in hole picking up 3-1/2"work string from rack&circulated in reverse to 11,376'and pump pressure increased from 300 psi to 460 psi pumping at 3 BPM,and lost all returns. Continued RIH to 11,783'DPM, tagged bottom.PU to 11,781'attempted to reverse,no success with 450 psi.RD power swivel and POOH slow to surface pulling wet string.BO&LO reverse wire basket and recovered coco mat. Fluid loss for the last 24 hrs=89 bbls.Clean rig floor.Prepare to RIH with 3-1/2"PH-6 work string. PU and MU 3-1/2"PH-6 mule shoe&start in hole with same. 11/06/13-Wednesday RIH with 93 stds of 3-1/2"PH-6 work string.POOH,L/0&back load same to work boat.RIH with 93 stds of 3-1/2"PH-6 work string & POOH L/O same. 11/07/13-Thursday Continue POOH with 3-1/2"PH-6 tbg work string,L/0 same and back load tbg to boat.RIH w/4-3/4"D/C,&L/D same.R/D 13-5/8"X 7-1/16"spool.Pull wear bushing. Install 13-5/8"x 11"DSA. R/D 3-1/2"handling tools and RU ESP handling tools.Held pre job JSA. Spot spooler&layout ESP equipment.PU&MU 3 sections of ESP&RI with same.Hang wire sheeves in derrick.Connect flat pac& elec line to ESP and test same.Continue PU/MU last 2 sections of ESP and installed clamps.RD EPS handling tools and RU 4-1/2"tbg handling tools.PU 1st joint of 4-1/2"tbg-NU to pump,started in hole with same and shaft on on wire spooloer broke at drive gear. Take wire spool off of spooler,set same in cradle &stanby for another spooler to arrive. 11/08/13-Friday Change out spooler for electric cable.Splice electric cable,RIH with ESP&4-1/2"Butt prod tbg rabbiting same,installing cannon clamps every second jt.ran.Test flat pack&elec cable. Depth at 06:00=4027'.Total fluid lost last 24 hrs.=120 bbls. 11/09/13-Saturday Continue in hole with ESP and 4-1/2"buttress tbg checking flat-pac&electrical lines every 1,200'&installing clamps every second jt ran in hole.Splice cables for ESP @ 7,860'. Continue in hole with ESP and 4-1/2"buttress tbg checking flat-pac&electrical lines every 1,200'&installing clamps every second jt ran in hole. Hilcorp Alaska, LLC _ Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-47 50-733-20195-02 191-011 9/23/2013 11/11/2013 Daily Operations: 11/10/13-Sunday Continue RIH with ESP&4-1/2"Butt prod tbg installing clamps every second jt in hole&testing lines every 1,200'.Continue RIH to 10,573'with ESP&4-1/2"Butt prod tbg installing clamps every second jt in hole&testing lines every 1,200'. Install hanger,splice lines thru hanger,tests flat pac&elec lines also tested void in hgr to 5000 psi for 5 min (OK).Land hgr,run in hold down pins.Back out landing jt and I/o same.Prep rig floor for nippling down BOP's.N/D BOP's,riser spools&flow lines. BOPE test due today but not needed as tubing hanger was landed prior to midnight. 11/11/13-Monday Continue ND BOP's&NU tree.Test void on tree to 5000 PSI test for 15 test OK.Turn well over to production at 12:00 hrs. STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMISSI~ REPORT OF SUNDRY WELL OPERATIONS ~~~~vE~~~~04 ~llasko Oil ~ Oar Cnns, Commission 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ an~~p~{~out ESP Performed: Alter Casing ^ Pull Tubing ^~ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shultlown ^ Pertorate ^ Re- nter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^~ Exploratory^ 191-011 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^ .API Number: 50-733-20195-02 Property Designation (Lease Number): .Well Name and Number: ADL0017594 (Dolly Varden Platform] Trading Bay Unit D-47 9. Field/Pool(s): McArthur River Field /Hemlock Oil & Middle Kenai G Oil 10. Present Well Condition Summary: Total Depth meas~re 11,930 feet Plugs (measured) N/A feet true vertic~l9,884 feet Junk (measured) 11,512 (fill) feet Effective Depth measured 11,512 feet Packer (measured) N/A feet true vertical 9,520 feet (true vertical) N/A feet Casing Length Size MD ~ ND Burst Collapse Structural Conductor 398' 33" 398' 397' Surtace 3,305' 16" 3,305' 2,948' 2,630 psi 1,020 psi . Intermediate 10,987' 9-5/8" 10,987' 9,052' 6,870 psi 4,760 psi Production Liner 1,179' 7" 11,925' 9,880' 8,160 psi 7,020 psi / 10,704'-10,724', 10,760'-10,790', 10,816'-10,866', 11,175'-11,225', 11,250'-11,265', 11,280'-11,310', 11,340'-11,400', Pertoration depth: Measured depth: 11,400'-11,470' True Vertical depth: g,g02'-8,820', 8,851'-8,878', 8,900'-8,944', 9,220'-9,265', 9,287-9,301', 9,314'-9,341', 9,368'-9,421', 9,421'-9,483' Tubing (size, grade, measured and true vertical depth): 4-1/2" 12.6# L-80 "'-°` " 1'[f;~24' 8,393' Packers and SSSV (type, measured and true vertical depth): N/A N/A N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): ~,y~k s-a Treatment descriptions including volumes used and final pressure: N/A 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 psi 0 psi Subsequent to operation: 304 102 6,771 110 psi 130 psi 13. Attachments: Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development0 Service ^ Daily Report of Well Operations X Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-446 ~ Contact Ronnie Santos 263-7978 Timothy C. Brandenburg Title Drilling Manager Printed Na ~ Phone 276-7600 Date 12/21/09 Signature ~ ~ , ~ ~ ~ Form 10-404 Revised 7/2009 Submit Original Only Chevron • • Trading Bay Unit Well # D-47 -~ As Built 11/21/2009 RKB to TBG Head = 40.3' C a S l n & T u b i n Tree connection: 4-1/16" 5,000# ~~ s g-- sI ~q~ ~~~ q~ S9 ~o ao ~_ ~o ae.~«rt m iis~x~ ee ~rsaroe PBTD = 11,834' TD = 11;. MAX HOLE ANGLE = 48° Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt To 33" Conductor Surf 398' Driven 16" Surf Csg 102 X-56 Butt- 14.75 Surf 3305' 22° 4200 sx Surf welded c I 350 sx To 4550 sx Total 47 8.681 Surf 8524' Bumped Plug 9-5/8" Prod Csg L-80 BTC ~ 12-1/4" 1900 sx Calc TOC @-5400' 53.5 8.535 8524' 978' assmd 20% loss - 11050' TOC 7" Liner 29 N-80 TKC 6.185 10735' 11925' 8-1/2° 400sxs e~~~~prace~~r°u I ncliides (2) sqr. ~clnuu CET 04/91 Tubin 40.3' RKB to Tbg Hngr 4-I/2" 12.6 L-80 BTC 3.833 Surf 10,224' N:SP Cable w/Oat ack 3.7 1 #I bead (.'able Surf 10,295' Spudded D-47 on 02/02/91. Completed on 04/27/91. D-47 was a drill out of D-44 (used the 16" to 3305') Which was a drill out of D-22 used the 33" conductor to 398' . •Hole Section MWT: •A roximate Rotatin hrs: 0 17-1/2" to 3305' 9.2 to 10.2 0 33" 157 hrs 0 12-1/4" to 10978' 9.1 to 10.1 0 16" 931 hrs 0 8-1/2" to 11925' 9.5 to 10.1 0 9-5/8" 77 hrs 0 7" x hrs JEWELRY DETAIL NO. De th ID Item 1 2,493' 4-1/2 SFO GLM #1 2 4,141' 4-1/2 SFO GLM #2 3 5,580' 4-1/2 SFO GLM #3 4 6,687' 4-1/2 SFO GLM #4 5 7,444' 4-1/2 SFO GLM #5 6 7,976' 4-1/2 SFO GLM #6 7 8,516' 4-I/2 SFO GLM #7 8 10,136' 3.813" XD Slidin Sleeve Down O enin 9 10,183' 3.813" "X N" Profile Ni le rofile = 3.813" 10 10,224' NA Crossover Pressure Head 11 10,225' NA Dischaz e Head 12 10,226' NA U er Pum 13 10,243' NA Mid Pum 14 10,262' NA Lower Pum 15 10,281' NA U er Seal Assembl 16 10,288' NA Lower Seal Assembl 17 10,295' NA U er Tandem Motor - 418 HP 18 10,329' NA Lower Tandem Motor - 418 HP 19 10,363' NA Phoenix Sensor XT-1/Anode/Centralizes bottom 10,366' 20 10,735' T[W SN-6-AT Liner To Packer Brief Details & Info: G-2 20 G-3 G-4 sg Shoe !10978' pl PERFORATION DATA Zone Top Btm Amt. Accum SPF last Perf Date Present Condition Notes G-2 10,704' 10,724' 20' 12 11/25/2004 O en f/ Prod a-s/a"TCPO3/o3a 11,oa G-3 10,760' 10,790' 30' 6 to 12 10/30/1969 O en f/ Prod 4-5/8" TC P03/03 8 11,04 shot 10,775' - 10,785' G-4 10,816' 10,866' 50' 6 to 12 6/15/1992 Open f/ Prod 4-s/8" TC P03/03 & 11 A4 (shot 10,830' - 10,860') B-1 11 ,175' 11 ,225' S0' 48 6/15/1992 O en f/ Prod 4191, 692, 10/92, 1/93,9/93, 7/95,4/98, 399 B-2 11 ,250' 11,265' 15' 12 6/15/1992 Open f/ Prod 4198, 399 B-2 11 ,280' 11 ,310' 30' 12 7/1 /1975 Open f/ Prod 4198, 399 B-3 11 ,340' 11,400' 60' 30 7/1 /1975 O n f/ Prod sFJt, 8FJ1, 694, 7F35, 7/96 B-4 11 ,400' 11,470' 70' 12 7/1 /1975 Open f/ Prod 7,ss, 79s D-47 ESP Current Schm 12-21-09.docx CVK: 12/21/09 i Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) D-47 TRADING BAY UNIT D-47 ADL0017594 5073320195 AR4420 106.90 -- Jobs Primary Job Type J~ Job Category Objective Actual Start Date Actual End Date Pump Repair Major Rig Dolly Varden Well D-47, a G-Zone and Hemlock commingled producer, 12/27/2008 Work Over experienced an ESP failure on December 8, 2008 after running for 10 (MRWO) months. It is recommended to workover the well and replace the downhole ESP equipment. Primary Wellbore Affected Wellbore UWI Well Permit Number D-47 507332019502 1910110 _ __ Dal O eratians 10/31/2009 00:00- 41/1/2009 00:00 _ _ _ ___ _ ___ _-- Operations Summary Mobe equipment to Platform 11/1/2009 00:00 - 11/2/2009 00:00 _ _ ___ _ Operations Summary Mobe equipment to Platform __ 11/2!2009 00:00 -111312009 00:00 _ __ Operations Summary Mobe equipment to Platform 11/3/2009 00:00 -.11/412009 00:00 -_._ Operations Summary Mobe equipment to Platform 11/4/2009 00:00 - 11/5/2009 00:00 Operations Summary Waiting on boat due to high winds. -- 11/5/200900:00 - 11/6/2009 00:00 __ _ Operations Summary Waiting on boat due to high winds. 11/6/2009 00:00 - 11/7/2009 00:00 _ _ ___ __ _ __-- - _ -- Operations Summary Mobe equipment and rigging up on platform. _ 11/7/2009 00:00 - 11/8/2009 00:00 Operations Summary Mobe equipment and rigging up on platform. Short crew on platform. 1118/2009 00:00 -11!9/2009 QQ:00 __ _ _ Operations Summary Mobe equipment and rigging up on platform. -_ 11/9j2009 00:00 -1111012009 OOc00 _ _ Operations Summary Mobe equipment and rigging up on platform. - - .. - __ _ 09 00:00 _ 11l10/2005 00:00 - 11111120 . Operations Summary Mobe equipment and rigging up on platform. 11/11/2009 00:00 - 11112!2009 00:00 Operations Summary Mobe equipment and rigging up on platform. IFO session with select crew and service providers in Kenai. Full crew on platform after IFO session. 11112/2009 00:00 -11/13/2009 00:00 _ _ _ ____ Operations Summary Continue rigging up. - ------ 11/13/2009 00:00 -11!14!2009 00:00 _ Operations Summary Continue rigging up. Build FIW and 3% KCL volume. Conduct Pre-Spud meeting with both crews. -- 11/14l2009 00:00 -11/1512009 00:00 __ Operations Summary Skid Rig #77 over well D-47. Continue rigging up and finish building 3% KCL volume. Displace well with 3% KCL taking returns to well clean tank. -- - -- -- - 11115/2008 OOc00 -11/1612008-00:00 - --- Operations Summary Finish displacing well with 3% KCL. Static hole loss = 32 BPH. ND tree. NU BOPE, choke, and kill lines. Mix sized salt pill. Notice given to AOGCC of upcoming BOP test. - - 11l16/2009 00:00 - 11!1712009 00:00 __ Operations Summary Test BOPE to 250 psi low and 3000 psi high witnessed by AOGCC Lou Grimaldi. Spot 90 bbls sized salt pill and squeezed into formation leaving 38 bbls above top perfs. Fluid losses decreased to 3 BPH. Pull and UD tubing hanger. Prep rig & equipment to pull ESP completion. 11117!2009 00:00 -11N8/2009 00:00 Operations Summary POOH with 4-1/2" ESP completion racking back 68 stands of 4-1/2" tubing. RU slickline, RIH through tubing and recovered prong after one failed attempt. Failed to pull the plug body free from the XN nipple. Cut slickline. POOH and RD slickline. Continue to pull ESP completion. Ithevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Deplh (ft) D-47 TRADING BAY UNIT D-47 ADL0017594 5073320195 AR4420 106.90 Dell Q erations - 11/18/2009 00:00 -11119120 0 9 00 :0 0 _ __ _ . . _ _ ____ _ Operations Summary Finished POH and LD ESP completion. RU to run new ESP equipment and GLM. PU upper and lower motors. Check motors for free rotation and fill with oil. PU upper and lower seal assemblies. - - -- ___ _ 11/19/2009 00:00.11/20/2009 00;00' Operations Summary RU flat pack sheave and MU 1/4" control lines to Phoenix gage and anode. Feed MLE through sheave and MU pothead connection to motors. PUMU pump sections. PUMU discharge head, chemical and control lines. Test Phonex gage. RIH and PUMU XN nipple and sliding sleeve. RIH ESP assembly and GLM on rerun 4-1/2", 12.6# L-80 tubing to 4768'. 11!20/2009 00:00 -11/21/2009 00:00 _ ___ - Operations Summary Finish RIH ESP assembly and GLM on rerun 4-1/2", 12.6# L-80 tubing. MU tubing hanger and complete installation of wellhead power cable penetrator and chemical lines. Land tubing hanger with ESP completion assembly bullnose/anode end at 10,366' MD. RD flowline, trip tank, and pitcher nipple. ND BOPE. 11121/2008 00:00 - 11122/2009 00:00 __ __ . _ __ Operations Summary NU production tree and flowlines. Shell test tree to 250/5000 psi for 30 minutes. Power cable MEG test good. Phoenix gage test good. RD other equipment and prepare for load out. - - -- - 11/22/2009 00:00 -11/23/2008 00:00 _ Operations Summary rigging down. _ ____ Continue _ _ _ _ 11/2312008.00:00 -11124/200900:00 _ _ Operations Summary Continue rigging down. 11/24/2008 00:00.-11/25/2009 00:00 _ _ _ _ __ _ _ Operations Summary Continue rigging down. Demobe rig crew. 11/2512009 00:00 - 11/26/2008 OOs00 - __ __ _ Operations Summary Continue rigging down. Demobe rig crew. .11/26/2009 00:00 -11/27/2009 OOAO -- -- - _ Operations Summary Continue rigging down. Demobe rig crew. _ ----- 1112712009 00:00 -11/28!2008 OO:QO _ Operations Summary Continue rigging down. Demobe rig crew. __ _ 11/281200$ 00:00 -11/28/2009 00:00 Operations Summary Continue rigging down. Demobe rig crew. Page 1 af 1 ~ c9l-ott ~ Aubert, Winton G {DOA) Fr~n; Santos, Ronilo [ronniesantos cLDchevron.com] Sent: Wednesday, November 04, 2009 3:14 PM To: Aubert, Wintan G (DOA) Cc: Tyfer, Steve L; Bonnett, Nigel (Nigel.Bonnett); Nash, R Scatt; Hamess, Evan; Kanyer, Christopher V Subject: Sundry No. 308-446 (Trading Bay Unit D-47 ESP Changeout Workover) Mr. Aubert, Please be informed that f assumed the role of project drilling engineer and main contact for this project, replacing Chantal Walsh as indicated on the original sundry application. Following are deviations from what was described in the included documents on the sundry application: • There will be no option to re-splice the first spiice beiow hanger and run back in hole even if the cable below the first splice is good. The cable, chemical lines, and splices will be replaced with different specifications/constructions based on lessons learned from previous failures. • There will be no scraper/cleanout run to the top of 7" liner . • A gage/junk basketlcleanout run is contingent on the amount of bands recovered and LIH. • The tubing will be rerun. • There will be no "Na-Flaw" test within 14 days af cc>mpletian, unless the cleanout contingency is done. I do not see these as exception to the approved sundry, bu# please advise if you will require further documentation or approval. Late last week, we initiated to reactivate the project from where we left off after the boat and volcano incidents earlier this year. We are expecting to move a short crew to the Dolly Varden platform on 11/7i09 and the fuil crew on 11/127~9 fo start the workover operationa Regards, Ronnie Santos 907-306-5857 ~~:~r.r,~.~,~~~~{ ~ ~, ~ _~ ~~ ~C~~~ 1114l2409 • ~ nn ~ ~ ~ '~'~ U SARAH PALIN, GOVERNOR ~~J ~..~ AIrAS~A OW ~ ~5 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOrT COM11II5SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Unocal ©`` PO Box 196247 L~~~~~ ~~~~ ~- ~} 200 ~` • Anchorage AK 99519 Re: McArthur River Field, Hemlock & Middle Kenai G Oil Pool, TBU D-47 Sundry Number: 308-446 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster Commissioner DATED this ~? day of December, 2008 Encl. ,~ ~ `~ ~~ i~~~ 1 i v •~' STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Ext ^ Change approved program^ Putl Tubing 0 ' Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 191-011 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20195-02 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 ^~ Trading Bay Unit D-47 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0017594 [Dolly Varden Platform] 180' AMSL McArthur River Field /Hemlock Oil & Middle Kenai G Oil 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,930' ~ 9,884' 11,512' 9,520' N/A 11,512' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 398' 33" 398' 39T Surface 3,305' 16" 3,305' 2,948' 2630 psi 1020 psi Intermediate 10,987' 9-5/8" 10,987' 9,052' 6870 psi 4760 psi Production Liner 1,179' 7" 11,925' 9,880' 8160 psi 7020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#, L-80 10,330' Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ - Service ^ 15. Estimated Date for 12/14/2008 16. Well Status after proposed work: Commencing Operations: Oil^ . Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ , `; _ ` ' Phone 27600 Date 12/9/2008 ~,_ _- __=i--- . ~,:, COMMISSION USE ONLY Conditions of approval: Notify Commission §o that a representative may witness Sundry Number: Q Plug Integrity ^ BOP Test ~' Mechanical I ntegrity Test^ Location Clearance ^ / ~ ~ t Other: ~'©Ot ~~ ~~. O'V'~-3 W 1 c` ~'`t~~j~C:s~~ ~~ ~'~~ ~ rC~« ~~ O~~ TO 1D~ CC~i\~`~=~, ' . . wc~~c-~0~ Fes: ~c~~~ ~a~~.:c~-~vt-~ ~ t, t ~ ~ ti ~t ~, _ Subsequent Form Required: T APPROVED BY A ~ ~/ d b pprove y: COMMISSIONER THE COMMISSION Date: ~ ~~~ , ~v - ,~-,o.o~ lei o Waiver ^ f Other ^~ t' ensign Rerun ESP ~ Form 10-403 Revised 06/2006 [ ~ ~,~ ~ ~ ~ ~ ~ .~"s4~ ~~~~`_"'~ ~~~"' ~„ ~ ~3 ~d~~ Submit in Duplicate ~..,' ~ °+ Chevron • • Trading Bay Unit Well # D-47 ESP As Comrleted 2/1/08 RKB to TBG Head =40.3' Tree connection: 4-1/16" ~F b°^ 9 $~ ~ HV ( ~~~ :~ ~' i• ~~ ~= ~~ C a s i n a & T u b i n a Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt "1'0 33" Conductor Surf 398' Driven Butt- " 4200 sx Surf 16" Surf Csg 102 X-56 welded c I 14.75 Surf 3305' 22 350 sx To 4550 sx'fotal 47 8.681 Surf 8524' Bumped Plug 9-5/8" Prod Csg L-80 BTC 12-I/4" 1900 sx Calc ToC Q-54oo' 53.5 8.535 8524' 10978' assmd 20/ loss 11050' TOC 7" Liner 29 N-80 TKC 6.185 10746' 11925' 8-I/2" 400 sxs n~~~~,~e ri~~Nmu i~i~~a~s¢iu{, ~.~~~~~s cer aa,en Tubin 40.3' RKB to Tb Hn r 4-1/2" 12.6 L-80 Butt 3.958 Surf 1Q304' ESP Cable w/ (2) 3/S" 3 7 1/OSOLBC 90FB 185 GAL Surf 10,375' Chem inj lines 2.361" x 1.611" JFWF.I.RV 11F.TAII. 3-12 G-2 13 G-3 G-4 :sg Shoe rx10979' pl NO. De th ID Item 1 10,219' 3.813" XD Slidin Sleeve Down O enin 2 10,261' 3.813" "X Line" Ni le rofile = 3.813" 3 10,304' NA Pressure Head 4 10,306' NA Dischar a Head 5 10,306' NA Upper'fandem Pump: 85 stage Model- 538PMSXD, Type - 538P62,S/N 10339219 6 10,334' NA Lower Tandem Pump: 85 stage Model- 538PLSXD H6 6CRC , T e - 538P62SXD, S/N 10339851 7 10,362' NA Upper Tandem Seals: Model - GSB3DB LT EHL HUK 6CRC S/N 10338421 8 10,369' NA Lower Tandem Seals: Model- GSB3DB LT EHL HUK 6CRC , S/N 10338418 9 10,376' NA Upper Tandem Motor: Model# - KMHU (6CRC). 266HP, 1315V, 123Am . S/N 10337613 10 10,399' NA Lower Tandem Motor. ModeUk - KMHL (6CRC). 266HP, 1315V, 123Am . S/N 10271912 I l 10,421' NA Phoenix XT-1 Sensor Gau e 12 10,423' 10 425' NA Aluminum Anode (8 Anodes) w/ bullnose centralizer 13 10,735' TIW SN-6-AT Liner To Packer Rrirf rlrtailc R Infnr Spudded D-47 on 02/02/91. Completed on 04/27/91. D-47 was a drill out of D-44 (used the 16" to 3305') Which was a drill out of D-22 used the 33" conductor to 398' . .Hole Section MWT: •A roximate Rotatin hrs: 0 17-1/2" to 3305' 9.2 to 10.2 0 33" 157 hrs 0 12-1/4"to 10978' 9.1 to 10.1 0 16" 931 hrs 0 8-l/2"to 11925' 9.5 to 10.1 0 9-5/8" 77 hrs 0 7" x hrs PFRFORA'I'InN DATA Zone Top Btm Amt. Accum SPF Last Perf Date Present Condition Notes G-2 10,704' 10,724' 20' 12 11/25/2004 Openf/Prod 4-5/8"TCP 03/03811/04 G-3 10,760' 10,790' 30' 6 to 12 10/30/1969 Open f/ Prod 4-5/8" TCP 03!03 & 11/04 (shot 10,775' - 10,785') G-4 10,816' 10,866' 50' 6 to 12 6/15/1992 Open f/ Prod 4-5/8" TCP 03/03 & 11/04 (shot 10,830' - 10,960') B-1 11,175' 11,225' S0' 48 6/15/1992 Open f/ Prod 4/91, 6/92, 10/92, 1/93, 9/93, 7/95, 4/98, 3/99 B-2 11,250' 11,265' 15' 12 6/15/1992 Open f/ Prod 4/98, 3/99 B-2 11,280' 11,310' 30' 12 7/1/1975 Open f/ Prod 4/98, 3/99 B-3 11,340' 11,400' 60' 30 7/1/1975 Open f/ Prod s/s1, e/s1, s/sa, ~/ss, 7/ss B-4 11,400' 11,470' 70' 12 7/1/1975 Open f/ Prod 7/ss, ~/ss PBTD = 11,834' TD = 11,930' MAX HOLE ANGLE = 48° D-47 Existing ESP Schm (CURRENT) 2-08.doc BCA: 2/10/07 Chevron ~ • Trading Bay Unit Proposed Well # D-47 ESP Conversion 2/1/08 RKB tD TBG Head = 40.3' Tree connection: 4-1/16" xg~ %~^ fi ~$~ M a6~ 1 ~s ~_ ~- Filltagged on 11/06 R 11,19)' PBTD = 11,834' TD= MAX HOLE ANGLE =48° C a s i n & T u b i n 1 Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt'Co 33" Conductor Surf 398' Driven 16" SurfCsg 102 X-56 Butt-welded 14.75 Surf 3305' 22" 4200sx Surf c I 350 sx To 4550 sx Total 47 8.681 Surf 8524' Bumped Plug 9-5/8" Prod Csg L-80 BTC 12-1/4" 1900 sx Calc TOC Q-54oo' 53.5 8.535 8524' 10978' assmd20% loss 11050' TOC 7" Liner 29 N-80 TKC 6.185 10746' 11925' 8-I/2° 400sxs e~~~»aaao~~/a~u Includes (2) sqi rcl nii~s cr:T1 oa/~n Tubin 40.3' RKB to Tb Hn r 4-1/2" 12.75 L-80 Ilydri1503 3.833 Surf 10,280' ESP Cable ~~- n:n puc6 3.7 1#l Lend cable Surf IQ353' 3-9 G-2 10 GJ G~4 g 9~ce 10978' DIL .IFWFI,RY DFTAtI, NO. De th ID Item 1 10,242' 3.813" XD Slidin Sleeve Down O enin 2 10,280' 3.813" "X Line" Ni le rofile = 3.813" 3 10,2966' NA Pressure Head 4 10,297' NA Dischar e Head 5 10,298' NA Pum 6 10,311' NA Pum 7 10,324' NA Pum 8 10,338' NA Seal Assembl 9 10,353' NA Motor - 800 HP 10 10.378' NA Phoenix Sensor XT-I /Anode/Cenlralizcr (bottom (t~ 10,392' IQ73S IIW SN-6-AT Liner Top Packer Rrirf nvtailc R Infn• Spudded D-47 on 02/02/91. Completed on 04/27/91. D-47 was a drill out of D-44 (used the 16" to 3305') Which was a drill out of I}22 used the 33" conductor to 398' . •Hole Section MWT: •A roximate Rotafin hrs: 0 17-1/2" to 3305' 9.2 to 10.2 0 33" 157 hrs 0 12-I/4" to 10978' 9.1 to 10.1 0 16" 931 hrs 0 8-1/2" to 11925' 9.5 to 10.1 0 9-5/8" 77 hrs O 7" X hrS PF:RFORA"PION DATA Zone Top Btm Amt. Accum SPF Last Perf Date Present Condition Notes G-2 10,704' 10,724' 20' 12 11/25/2004 Openf/Prod 4-518"TCP 03/03&11/04 G-3 10,760' 10,790' 30' 6 to 12 10/30/1969 Open f/ Prod 4-5/8"TCP 03/03 & 11/04 (shot 10,775' - 10,785') G-4 10,816' 10,866' 50' 6 to 12 6115!1992 Open f/ Prod a-s/a" TCP 03/03 & 11/04 (shot 10,830 - lo,6so~1 B-1 11,175' 11,225' S0' 48 6/15/1992 Open f/ Prod a/st, s/sz, lo/s2, 1/93, 9/93, 7/95, 4/98, 3/99 B-2 11,250' 11,265' 15' 12 6/15/1992 Open f/ Prod a/sa, 3/ss B-2 11,280' 11,310' 30' 12 7/1/1975 Open f/ Prod 4/98, 3/99 B-3 11,340' 11,400' 60' 30 7/1/1975 Open f/ Prod 5191, 8/91, 6/94, 7/95, 7/96 B-4 11,400' 11,470' 70' 12 7/1/1975 Open f/ Prod 7/ss, 7/ss D-47 ESP Proposed Schm 12-9-08.doc CVK: 12/9/08 Chevron * , .Dolly Varden Platform Well # D-47 12/9/08 OBJECTIVE: • Pull and re-run ESP. PROCEDURE SUMMARY: 1 Mobilize rig onto D-47 2 PJSM - ND Tree - NU BOPE -All LP mud Lines -All HP Mud Lines -Test all lines -TEST BOPE Equipment (PULL & PEEK) Remove BPV. PUMU Landing Joint. BO LDS. PU tbg hanger. Pull tbg to first splice below hngr. 3 Cut cable below splice. Meg cable downhole. If cable megs good, resplice cable below hngr & land same. If cable still shows short downhole, raland tbg hngr and continue with WO. 4 PJSM - RU ESP handling equipment/ (Spooler, sheaves, power washer, ...) 5 PJSM -Circulate well, displace well to inlet water, insure standing column of fluid in well, displace returns to production -Flow check well -Pump salt pill as needed -Flow check well 6 POOH LD 4-1/2" tubing & ESP Equipment 7 PUMU 9-5/8" scraper cleanout assembly on 41/2" tubing. RIH to TOL @ 10,735'. POOH & LD BHA. Stand back tubing. 8 RU Slickline. RIH w/ GR or fluted centralizer to tag bottom. POOH. RD Slickline. Conting_encX * If tag is above 11,400', we will proceed with cleanout contingency. PUMU 7" cleanout assembly on 31/2" DP / 4- 1/2" tubing. Clean out to bottom. POOH. LD cleanout assembly. 9 PJSM - RU Crane & ESP company to run ESP -Run ESP 10 Turn well over to production. 11 Release Rig D-47 REVISED BY: CVK 12-9-08 • • SARAH FALiN, GC~J~P.AJOR 3334V 7!ti.AVEN~;F. Sl!TE iCi~_ .=~~1CHORA:oE.r, %"~S'rv; _S.l_ ~~a SHONE £~t)il? .. 4.._ SAX i9U%, --~ ~ _ 1~~Iarch 12, 2008 Mr. ChYis Myers Field Superintendent linocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flaw Verification Trading Bay Unit D-47, PTD 19]-011 Dear Mr. Myers: On February 1 ~, 2008 an AOGCC Petroleum Inspector witnessed a "no flaw test" at Unocal's Dolly Varden platform, Trading Bay Unit Well D-47. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. The well demonstrated no gas or fluid flow while open to atmosphere, and no pressure build-up during a shut in monitoring period. The subsurface safety valve may be removed from service in Well D-47 l~asecl on this no- flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this ~vcll as required in 2(3 AAA' 25.26. The subsurface safety valve must be returned to sen~ice if the well demonstrates art ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well. will necessitate a subsequent no flow test. Please retain a copy of this letter on the Dolly Varden platform. Sincerely, /' -, _1 Janes B. Regg Petroleum Inspection Supervisor cc: Bob Fleckenstein ~~leyr{~~''~ Francisco Castro Chevron North America Exploration and Production Technical Assistant 909 W. 9th Avenue ~"`'" '>` Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE March 7, 2008 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 NOTES- WELL LOG TYPE SCALE LOG INTERVAL RUN # B-LINE CD ~S' DATE LOGGED PDS, DLIS PDF, ULTRA-SONIC IMAGING TOOL PDS, CORROSION EVALUATION DLIS, TBU D-47 IMAGE 5" 21-Jan-08 200-10676 1 1 1 WCL POSISET PLUG SETTING TBU M-5 RECORD 5" 13-Jan-08 3633-3633 PS 3 1 1 PDS TBU M-5 PSP - GHOST GR/CCL 5" 5-Jan-08 3480-3676 PS 2 1 1 PDS TBU M-5 PERFORATING RECORD 5" 21-Jan-08 3558-3620 PS 4 1 1 PDS ~,~ ~ .._. ~~~- l~ ~tl~ora 10011 1 ~ovra ~~~ ~ `~ ~d~~ l ~o ~ 3 ~~~P~:~~ Please acknowledge receipt by signing and returning one copy of this trans~nittafsor FAX'to'907 263 7828. ~q~-o Received By: `., /' / ~ ~ Date: i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON FHB 2 5 COQ REPORT OF SUNDRY WELL OPERATIONS ~~~~~~ gill ~, Gas Cans. ~ur~missiA!~ Ant:hot~AB 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ ESP CO , Performed: Alter Casing ^ Pull Tubing Q . Perforate New Pool ^ Waiver ^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^~ Exploratory^ 191-011 " 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-733-20195-02 ' 7. KB Elevation (ft): 9. Well Name and Number: 106' AMSL 'rQV D-47 ' 8. Property Designation: 10. Field/Pool(s): ~' ,p y, y?,og Trading Bay Unit/Dolly Varden Platform (ADL 17594) ~ McArthur River Field / G zone & Hemlock 11. Present Well Condition Summary: Total Depth measured 11930 ~ feet Plugs (measured) NOne true vertical 9917 feet Junk (measured) 11512 Effective Depth measured 11512 feet true vertical 9520 feet ~~ FEB ~ ~ 204 Casing Length Size MD TVD Burst Collapse Structural Conductor 357 33 398 398 Surface 3264 16 3305 2947 2630 1020 Intermediate ~ ..,., Production 10937 9.625 10978 9052 5750 3090 Liner 1179 7 11925 9880 8160 7020 Perforation depth: Measured depth: 10704'-10724'; 10760'-10790'; 10816'-10866'; 11175`-11225'; 11250'-11265'; 11280'-11310'; 11340'-11470' True Vertical depth: 8802'-8820'; 8851'-8878'; 8900'-8944'; 9220'-9265 ; 9287'-9301'; 9314'-9341'; 9368'-9483' Tubing: (size, grade, and measured depth) 4.5 L-80 10424 Packers and SSSV (type and measured depth) None ~ None 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 0 0 0 Subsequent to operation: 442 146 4814 124 120 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q ' Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-003 Contact Steve Tyler 263-7649 Printed Name Tim Br rtba•rg.~, Title Alaska Drilling Manager ~ , ~~ Si n t @ j T3r Ph 2 2/25/2 F~ . ~ g ; ,,,,, ~,,. a one 63-7657 Date 008 r R~ ?_ .gin-rr.,sc,~s~a ~ss~ L. r i° ~; ? ~ / ~~~ Z ~ y7•~c$ Form 10-404 Revised 04/2006 /~~ Submit Ori 'n 0~2j/~ Chevron ~ ~ Trading Bay Unit Well # D-47 ESP As Completed 2/1/08 RXB to TBG Head = 40.3' Tree connection: 4-1/16" ~ ~~ g~€ U~~ a ~= y~ U ~+. PBTD = 11,834' TD = 11,930' MAX HOLE ANGLE = 48° Casino 8~ Tuhina Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt To 33" Conductor Surf 398' Driven 16" Surf Csg 102 X-56 B°tt 14.75 Surf 3305' 22" 4200 sx Surt' welded c I 350 sx To 4550 sx Total 47 8.681 Surf 8524' Bumped Plug 9-5/8" Prod Csg L-80 BTC 12-I/4" 1900 sx Calc TOC @-5aoo' 53.5 8.535 8524' 10978' assmd 20% loss 11050' TOC 7" Liner 29 N-80 TKC 6.185 10746' 11925' 8-1i2" 400sxs eu~„aePwrinai Includcs'(2) sqi rc~nuis CETf 04/91) Tubin 40.3' RKB to Tb Hn r 4-1/2" 12.6 L-80 Butt 3.958 Surf 10,304' ESP (`able wi (213x8" 3 7 1/OSOLBC 90FB 185 CAL Surf 10,375' Chem inj lines 2.361" x 1.611" .IF.WF.i.RY DF.TAiI. 3-12 r E G-2 ' 13 G-3 r = G-4 Csg Shoe X10978' dt NO. De th ID Item 1 10,219' 3.813" XD Slidin Sleeve (Dawn O enin 2 10,261' 3.813" "X Line" Ni le (profile = 3.813" 3 10,304' NA Pressure Head 4 10,306' NA Dischar e Head 5 10,306' NA Upper Tandem Pump: 85 stage Model- 538PMSXD, Type - 538P62,S/N 10339219 6 10,334' NA Lower Tandem Pump: 85 stage Model- 538PLSXD H6 6CRC , T e - 538P62SXD, S/N 10339851 7 10,362' NA Upper Tandem Seals: Model - GSB3DB LT EHL HUK 6CRC , S/N 10338421 8 10,369' NA Lower Tandem Seals: Model- GSB3DB LT EHL HUK 6CRC , S/N 10338418 9 10,376' NA Upper Tandem Motor: Model# - KMHU (6CRC). 266HP, 1315V, 123Am . S/N 10337613 10 10,399' NA Lower Tandem Motor: Mode?# - KMHL (6CRC). 266HP, 1315V, 123Am . S/N 10271912 11 10,421' NA Phoenix XT-1 Sensor Gau e 12 10,423' 10,425' NA Aluminum Anode (8 Anodes) w/ bullnose centralizer 13 10,735' TIW SN-6-AT Liner Top Packer Rrirf Ilrtailc R~ Infnc Spudded D-47 on 02/02/91. Completed on 04/27/91. D-47 was a drill out of D-44 (used the 16" to 3305') Which was a drill out of D-22 used the 33" conductor to 398' . .Hole Section MWT: •A roximate Rotatin hrs: 0 17-1/2" to 3305' 9.2 to 10.2 0 33" 157 hrs 0 12-I/4" to 10978' 9.1 to 10.1 0 16" 931 hrs 0 8-1/2" to 11925' 9.5 to ]0.1 0 9-5/8" 77 hrs 0 7" x hrs PF'RFnRATInN DATA Zone Top Btm Amt. Accum SPF Last Perf Date Present Condition Notes G-2 10,704' 10,724' 20' 12 11/25/2004 Openf/Prod 4-5/8"TCP03/03811/04 G-3 10,760' 10,790' 30' 6 to 12 10/30/1969 Open f/ Prod a-s/a" TCP 03/03 8 11/04 (shot 10,775' - 10,785') G-4 10,816' 10,866' 50' 6 to 12 6/15/1992 Open f/ Prod 4-518" TCP 03/03 8 11/04 (shot t0,a30' - 10,860') B-1 11,175' 11,225' 50' 48 6/15/1992 Open f! Prod 4/91, 6/92, 10/92, 1/93, 9/93, 7/95, 4/98, 3/99 B-2 11,250' 11,265' 15' 12 6/15/1992 Open f/ Prod a/sa, 3/ss B-2 11,280' 11,310' 30' 12 7/1/1975 Open f/ Prod a/sa, 3/ss B-3 11,340' 11,400' 60' 30 7/1/1975 Open f/ Prod s/s1, ars1, s/sa, 7/ss, 7/ss B-4 11,400' 11,470' 70' 12 7/1/1975 Open f/ Prod 7/ss, 7/ss D-47 Existing ESP Schm (CURRENT) 2-08.doc BCA: 2/10/07 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~~ ~,r~0~ DATE: P. I. Supervisor ~( February 13 2008 FROM: Chuck Scheve, SUBJECT: Petroleum Inspector No Flow Trading Bay Unit Dol)y Varden Platform D-47 PTD# 1910110 Wednesda Februa 13 2008: I traveled to Chevron's Dolly Varden Platform and witnessed a no-flow test on well D-47. I arrived on location and found the well bled off and opened to atmosphere with no flow of gas or fluid evident. The well was then shut in and observed for three hours with no pressure build up noted and no flow when reopened. I recommend Well D-47 on the Dolly Varden Platform be approved continued no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Well D-47 meets the AOGCC requirements for no flow status. ~~ APR ~ ~.~ 200 • • ~J/~l~[~ L'~ Glis!~'IJI~S!a Az<ASS-A ou Alin c~As COI~TSERQA7`IO2•T CO1~II-~II5SIOI~T Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 ~~;;~~[~ ,~,4N a 2008 SARAH rALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: McArthur River Field, Hemlock/G Oil Pool, Dolly Varden D-47 Sundry Number: 308-003 O ~ ~~~~ Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of January, 2008 Encl. c;r,.o,.oy_. ~~ `~` /~ • STATE OF ALASKA ' ~ t ALASKA OIL AND GAS CONSERVATION COM SION ~ h ~ dyy <'t,r-~ M a-~ i f}~°~,~ ij e~ ~~~~s? APPLICATION FOR SUNDRY APPROVALS ~~ ~ , :,,., , ,,,,~_ ~~n „~~~; .,,:_~ 20 AAC 25.280 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ^ Wa1Ver Other^~ Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ ESP CO Change approved program^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to DriN Number: Union Oil Company of California Development ^ Exploratory ^ 191-011 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 196247, Anchorage, AK 99519 50-733-20195-02 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 ^~ D-47 l 9. Property Designation: r(rlc. !'7 ~ ~$ 10. KB Elevation (ft): 11. Field/Pool(s): ~ Tradin Ba Unit/Doll Varden Platform ~' 106' AMSL - McArthur River Field / G zone & Hemlock 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11,930' ' 9,917' ~ 11,450' 9,465' None 11,450' Casing Length Size MD TVD Burst Collapse Structural Conductor 357' 33 398' 398' Surface 3,264' 16 3,305' 2,947' 2630 1020 Intermediate Production 10,937' 9 5/8" 10,978' 9,052' 5750 3090 Liner 1,179' 7 11925 9,880' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4-'/~' L-80 10,348' Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch Q Exploratory ^ Development^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 1/7/2008 Oil Q Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name La Title Engineering Manager Signature ,,,~..-•' Phone 263-7657 Date 1/3/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ~ Mechanical Integrity Test Location Clearance ^ Other: ~~ e~, ~ ~..~r.~,~ ~ ~ ~~~ t.. ~ ( ~ i ~ry Subsequent Form Required: C..-.` ~ APPROVED BY Approved by: ISSIONER THE COMMISSION Date: ~O !~ ~, ~~ Form 10-403 Revised 06/2006 ~ ~? ~ ~"~ -- Submj~~~f~~~ • Chevron Dolly Varden Platform Well D-47 '08 ESP' Workover OBJECTIVE: Replace the failed ESP assembly currently in Well D-47. PROCEDURE SUMMARY: 1. R/U Slickline. Open Sliding Sleeve above ESP. 2. Circulate oil out of annulus and load well w/ 3% KCL. 3. Activate Dolly Varden Rig. 4. Spot sized salt pill (if necessary) to manage losses and keep hole full while POH. 5. Set BPV and N/D tree on Well D-47. N/U BOPE. Test 13-5/8" BOPE to 250/3,000 psi. 6. Verify well dead. 7. POH w/ tubing, cable & failed ESP. 8. PU 9-5/8" Csg CO Assy. 9. RIH cleaning out 9 5/8" csg to TOL @ 10,735'. POOH. 10. RU Eline. RIH w/ USIT. Log from TOL to surface. 11. RIH w/ Gyro Survey Equipment. Survey well from TOL to surface. RD Eline. 12. P/LT 7" casing clean-out assembly. 13. RIH cleaning out well into the 7" liner as required. 14. Circulate well clean and spot LCM pill as required. 15. POOH w/ CO assembly. 16. R/U to run the ESP completion. 17. RIH w/ replacement ESP assembly on tubing. 18. Install BPV. N/D BOPE. N/U & test tree. AOGCC D-47 ESP WO Procedure Summary.doc 1 of 1 January 3, 2008 • • 3 118" SM DSA Rentals possibly X 2 1116" SM DSA owned by UOCD 3 5/8" 5M by 2 1/16" 5M Kill Lines are 3 1/8" 5M Integral Flanges Dolly Varden Stack up D -47 \0 MEMORANDUM . s. of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (P.I. Supervisor) Petroleum Engineer "I ' ./ f<.e11 311/01 DATE: March 1,2007 SUBJECT: No Flow Test Chevon/Dolly Varden Platform V TBU 0-47 PTD#191-0110 McArthur River Field FROM: Lou Grimaldi Petroleum Inspector I verified the No-Flow Status Chevrons well 0-47 aboard the Dolly Varden platform in Cook Inlet This verification was due to a recent workover. John Lee (Lead Op.) did a good job preparing this well for the test and was accomodating with my requests I arrived to find the well (Tubing/Casing) nearly bled off. As this is an ESP well there was not much gas to deal with and no I fluid production was present The manifold was rigged approximately as I had previously requested, I did have the crew " change the gauge used to check pressure to 5" models which had a better resolution The gauge used was a 60 psi 1/4 psi increment and the flow meter was a 200-2000 SCF ERDCO paddle type I observed the following; Time 1035 1050 1110 1150 1205 1210 1225 1235 1240 1245 1250 1255 13'15 1325 1330 1335 1345 1350 1355 /,.1400 1500 Notes: Flowing to Atmosphere <1 psi, <200 SCF/hour. Flowing to Atmosphere .5 psi, <200 SCF/hour. Flowing to Atmosphere <.5 psi, <200 SCF/hour, Shut well in for buildup. S.I @ 1 psi. S.I @ 1.5 psi. S.I @ 1.5 psi. S.I @ 1.5 psi. SI @ 15 psi. Open to Flow meter, initial flow @ 1000 SCF/hour. Flowing to Atmosphere <1 psi, <400 SCF/hour. Flowing to Atmosphere >0 psi, whisper. Flowing to Atmosphere >0 psi, whisper Flowing to Atmosphere >0 psi whisper Shut-in well. 6) '7 Z007 s: @ 5 i(jANNED MAR .if S.I @.5 psi SI @.5 psi S.I @.5 psi S.I @ .5 psi S.I @ .5 psi. Open to Flow meter, initial flow @ 400 SCF/hour. Flowing to Atmosphere >0 psi, whisper. No-Flow observed No-Flow observed I concluded the test at this point This well appears to be incapable of unassisted flow to surface. Le~- ~ -+v ~YJar- C(Ffrz)V i'~ fG~VtJ.... df SSSv 2007-0301_NoJlow_ TBU_D-47 _Ig.xls a ...- . STATE OF ALASKA ~R 022007 ALAS IL AND GAS CONSERVATION COMMI.N . , . REPORT OF SUNDRY WELL OP~"'ØI~B Cons, COf11l'C\lSSlon Anchorage 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other l:j Replace failed Performed: Alter Casing 0 Pull Tubing 0 . Perforate New Pool 0 Waiver 0 Time Extension 0 ESP v Change Approved Program 0 Opera!. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory 0 191-011 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic 0 Service 0 6. API Number: 50-733-20195-02 - 7. KB Elevation (ft): 9. Well Name and Number: 106 AMSL Dolly Varden D-47 8. Property Designation: r7NÝ ~.S.O? 10. Field/Pool(s): Trading Bay UniUDolly Varden Platform ì hI, McArthur River Field/Hemlock '01c../ /I,(,'J k~ {/ 0((.. 11. Present Well Condition Summary: ~ t·&·ð'7 Total Depth measured 11,930' . feet Plugs (measured) none true vertical 9917' . feet Junk (measured) 11 450' 5~MAR 062007 ' Effective Depth measured 11,450' feet true vertical 9465' feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3305' 16" 3305' 2,947' 2630 psi 1020 psi Intermediate 10,987' 9-5/8 " 10,987' 9,052' 5750 psi 3090 psi Production Liner 1,179' 7" 11,925' 9,880' 8160 psi 7020 pai Perforation depth: Measured depth: See attach Schematic True Vertical depth: See Attach Schematic Tubing: (size, grade, and measured depth) 4-1/2", 12.6# L-80 IBT Mod 10,348' Packers and SSSV (type and measured depth) None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 94 34 1350 1200 454 Subsequent to operation: 416 131 6260 120 125 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory 0 Development 0 I Service 0 Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 306-263 Contact Chantal Walsh Printed Name Timothy C. Brandenburg Title Drilling Manager Z-//'/? ~- " Signature 7v~.;,>·· -.è'~;; Phone 907-276-7600 Date 2/21/2007 "'--- ..--::>"..-). þ' Form 10-404 Revised 04/2006 U 1"< j G I ~ A l RBDMS BFL MAR 0 6 2DD71r."f'5' ~;;;~ t':.Þ'7 ~ . g> if "§ 8" ;:\2 ®~ D-47 Existing ESP Schm 12-06.doc Hole Driven 16" SurfCsg X-56 Butt- 14.75 3305' 22" 4200 sx Slrrf welded c I 350 sx To 4550 sx Total 47 8,681 S\rrf 8524' Bumped Plug 9-5/8" Prod Csg L-80 BTC 12-1/4" 1900 sx Calc TOC @-5400' 53.5 8.535 8524' 10978' assmd 20% loss 7" Liner 29 N-80 TKC 6.185 10746' It 925' 8-1/2" 400 sxs JEWl<:LRY DETAIL -9 NO, DeDt ¡ m Item a, 2496' 3958" 4-l/2" SFO Mandrel w/ dmnmv valve drift ID ~ 3.833" b, 4139' 3.958" 4-1/2" SFO Mandrel w/ dummv valve drift 1D ~ 3.833" c, 5581 ' 3.958" 4-l/2" SFO Mandrel w/ dmnmv valve drift 1D ~ 3.833" d, 6716' 3.958" 4-1/2" SFO Mandrel w/ dmnmy valve drift 1D ~ 3.833" e. 7417' 3,958" 4-1/2" SFO Mandrel w/ dummy valve drift 1D ~ 3.833" f 7998' 3.958" 4-l/2" SFO Mandrel w/ dummy valve drift 1D ~ 3.833") g, 8567' 3.958" 4-1/2" SFO Mandrel w/ dummv valve drift 1D - 3.833") h. 9050' 3.958" 1/2" SFO Mandrel w/ dmnmv valve drift ID ~ 3,833") ~ 9535' 3.958" ]/2" SFO Mandrel w/ dummy valve (drift 1D ~ 3.833") i, 10,292 ' 3.813" XD Sliding Sleeve (Down Ouenim!Ì 1 10,330' 3,813" "X Line" Nipple (profile ~ 3.813") 2 10,346' NA Pressure Head 3 10,347' NA Discharge Head 4 10,348' NA Pump Model HPHVM AR 1-1, SN-10274087 5 10,361' NA Pump Model HPHVM AR 1-1, SN-10274086 6 10,374' NA Pump Model HPHVLT AR I-I, SN-10274088 7 10,388' NA Seal Assembly 8 10,403' NA Motor- 800 HP HMI PN-216009878 9 10,438' NA Phoenix Sensor XT-1/ Anode/Centralizer (bottom (â) 10,442') 10 10,735' TlW SN-6-AT Liner Top Packer Brief l}etaiis &; fnfo: Spudded D-47 on 02/02/9]. Completed on 04/27/91. D-47 was a drill out ofD-44 (used the 16" to 3305') Which was a drill out ofD-22 (used the 33" conductor to 398'), oHole Section MWT: oApproximate Rotatin!! hI's: 0 17-1/2" to 3305' 9.2 to 10.2 ppg 0 33" ]57 hI's 0 12-1/4" to 10978' 9.1 to 10.1 ppg 0 16" 931 hI's 0 8-1/2" to 11925' 9.5 to 10,1 ppg 0 9-5/8" 77 hI's 0 7" x hI's P:¡¡:RFORATION DATA Accum last Present Zone Top Btm Amt. SPF Perf Date Condition Notes G-2 10,704' 10,724' 20' 12 11/25/2004 Open f/ Prod 4-5/8" TCP 03/03 & 11/04 G-3 10,760' 10,790' 30' 6 to 12 10/30/1969 Open f/ Prod 4-5/8" TCP 03/03 & 11/04 (shot 10,775' -10,785') G-4 10,816' 10,866' 50' 6 to 12 6/15/1992 Open f/ Prod 4-5/8" TCP 03/03 & 11/04 (shot 10,830' -10,860') B-1 11,175' 11,225' 50' 48 6/15/1992 Open f/ Prod 4/91,6/92,10/92,1/93,9/93,7/95,4/98,3/99 B-2 11 ,250' 11,265' 15' 12 6/15/1992 Open f/ Prod ,3/99 B-2 11,280' 11,310' 30' 12 7/1/1975 Open f/ Prod ,3/99 B-3 11,340' 11,400' 60' 30 7/1/1975 Open f/ Prod ,8/91,6/94,7/95,7/96 8-4 11 ,400' 11,470' 70' 12 7/1/1975 Open f/ Prod BCA: 2/1 0/07 It Well Name D-47 Primary Job Type ESP Jobs Primary Job Type ESP Objective ../ Pull and replace ESP in Dolly Varden Well D-47 Daily Operations 1/31/2007 00:00 - 2/1/2007 00:00 Operations Summary Mobing rig 2/1/200700:00 - 2/2/2007 00:00 Operations Summary Mobing rig. 2/2/2007 00:00 - 2/3/2007 00:00 Operations Summary Install 4" CIW back pressure valve. Remove production lines. PJSM. Pull tree. Install bell nipple, flow lines, fill up line, check pipe rames. Test BOP to 250 psi low and 3000 psi high. Good test - AOGCC witnessed. Pull test joint and LD, pull BPV and install TWC. Test blind to 250 psi low and 3000 psi high. Pull TWC and install landing joint to secure well. Tighten XO on bottom of IBOP and retest. All tests good. 2/3/2007 00:00 - 2/4/2007 00:00 Operations Summary Mix and ship brine. RU and pump down tbg taking returns to well clean tank. Took 43 bbls to get returns, slight oil cap and then dirty water. ~U tbg . hanger, remove chem lines and disconnect pig tail from penetrator. Check penetrator, OK. Cut cable l' below bottom of lower connector and checked, was bad. Cut cable below splice and checked cable to motor and found it to be good, including info from Pheonix gauge. Tested splice - good. Estimated static losses at 19 BPH. CBU. Had cable cutting drill and mask up drill. Continued to circulate while building sized salt pill. PU pipe and cut cable. Conducted PJSM, pumped 10 bbls satruated salt spacer, 42 bbl sized salt, 10 bbl salt spacer, plus 96 bbls 3%KCL. Shut annular and bullheaded. Static losses <4 BPH. PU tbg, and POOH w/ ESP completion. Stand back tbg. 2/4/2007 00:00 - 2/5/2007 00:00 Operations Summary POOH with ESP completion. Conduct cabel and mask up drill. Static loss <1 BPH. POOH to motor lead. LD pump and motor assembly. One ding in motor lead armour (likely during trip out). Removed discharge head. Pump truned free. LD pump sections. Removed seal section and inspected oil. Looked good - however it was stiff turning. Inspected motor, no visual damage and oil appears in good condition. Recovered all flat guard, 179 cannon clamps and 34 super bands. Left 3 super bands in hole. 2/5/2007 00:00 - 2/6/2007 00:00 Operations Summary Continue to LD ESP motor assembly. RU eline. MU junk basket w/ 8.39" GR. RIH to 334' and set down. POOH. RIH w/ junk basket and 8.25" GR. Same results. Pooh. RIH w/8.2" GR to 334'. POOH. RIH w/5.95" GR to 334'. POOH.RU 4-112" tbg to 455' and saw slight bobble at 334'. POOH and SB tbg. RU eline. TIH w/ junk basket and 8.39" GR, set down at 800'. PU and set down again at 10517'. POOH. Recoved 1 piece offlatgaurd. RD eline. RU slickline. RIH with 8.39" GR to 10660'. POOH, recovered 1 band. RIH to 10639' and recovered 2 pieces of band. RIH with 8.39" GRljunk basket to 10735'. POOH with 2 pieces of super band. 2/6/200700:00 - 2/7/2007 00:00 Operations Summary "137 RIH with 8.39" GR on junk basket 10/~" POOH w/ slickline. No recovery. RD Slickline. Conduct PJSM. Prep ESP equipment for run in hole. PU equipment. Service seal assembly and test motor and Pheoniz guage. RIH installing new motor lead cannon clamps and protectolizers. Run gauge over protectalizers and motor clamps to confirm equipment will drift in 9-5/8", 53.5# casing. MU pump sections install clamps, RIH with completions super bands, protectolizers, pump clamps, motor clamps. Meg cable. Cable splice at 6324'. Meg cable, drift with 3.833". 2/7/2007 00:00 - 2/8/2007 00:00 Operations Summary RIH with ESP completion. Install cannon clamps on every other connection and GLM as required. Test ESP cable every 1000'. At 7926' make splice. Meg and test phoeniz tool. Static loss less than 1 bph loss. After splice, pumped down chem line. Pressured up and discovered chem line crossed and connected to Phoenix tool, pressure discharge sub tied to chern line termination point. Prep to POOH. POOH to first splice. Recovered super bands and clamps. POOH to first splice at 4011 '. POOH with ESP to 2330', stand back GLMs and recover clamps. 2/8/200700:00 - 2/9/2007 00:00 Operations Summary Cont to POOH with ESP completion. Disconnect discharge head, check pump shaft for rotation, verify crossed tuves with port power, check seals, change oil in seals. Pump through chemical injection lines, all good. Megger ESP cable and motor all good. Check Phoenix tool, all good. RIH with ESP completion, making electrical checks every 1000'. Pump through chem lines and meg cable and motor at splices. .. Daily Operations 2/9/200700:00 - 2/10/2007 00:00 Operations Summary Cont. to RIH with ESP. Drift tbg with 3.833" and run tests at each splice. Set pump anode at 10,441' rkb. PU hanger and landing joint and make up same. Space out for pig tail splice to ESP cable. Test. Total of 180 cannon clamps, 10 super bands, 6 Kramer clamps on motor section, 19 full size cannon motor lead clamps, - 1 half size cannon motor lead clamp - 5 protectalizer clamps. Land hanger, perform electrical test.ND BOPE.· Held PJSM and pull and LD riser. NU tree and flow line. Test hanger void. Pull BPV and install two way check. Shell test tree. Pull two way check. Turn well over to production. Well Name D-47 Primary Job Type ESP Jobs Primary Job Type ESP Objective Workover and Replace Failed ESP in Dolly Varden Well D-47 Daily Operations 10/22/200600:00 - 10/23/2006 00:00 Operations Summary Shot tubing punch holes above the ESP equipment 10/23/200600:00 -10/24/2006 00:00 Operations Summary Confirm tubing punch shots fired. Prep rig. 10/24/200600:00 - 10/25/2006 00:00 Operations Summary SIMOPS and PTSM with production. Continue to prep equipment. 10/25/200600:00 - 10/26/2006 00:00 Operations Summary SIMOPS and PTSM. Prep. 10/26/200600:00 -10/27/2006 00:00 Operations Summary SIMOPS. Loading equipment with crane. Prep. 10/27/200600:00 -10/28/200600:00 Operations Summary SIMOPS and PTSM. Prep. 10/28/200600:00 - 10/29/2006 00:00 Operations Summary SIMOPS and PTSM. Prep. 10/29/200600:00 -10/30/2006 00:00 Operations Summary Working H2S system. Prep. 10/30/200600:00 -10/31/2006 00:00 Operations Summary .. PTSM. Moving Kelly from Monopod to Dolly. 10/31/200600:00 -11/1/2006 00:00 Operations Summary SIMOPS. Preping rig. 11/1/200600:00 -11/2/2006 00:00 Operations Summary SIMOPS. Prepping rig. 11/2/200600:00 -11/3/2006 00:00 Operations Summary SIMOPS with production. PTSM. Prepping rig. 11/3/200600:00 -11/4/2006 00:00 Operations Summary Prep rig. 11/4/200600:00 - 11/5/2006 00:00 Operations Summary Mixing FIW and 3%KCL. SIMOPS and PTSM. Prestart safety meeting. 11/5/200600:00 -11/6/2006 00:00 Operations Summary PJSM. SIMOPS. Mixed sized salt pill. Pump 10 bbls of saturated salt, with 60 bbl pill, chased by 10 bbls saturated salt, with no returns. Displaced pill to tbg punch hole with 87 bbls FIW w/ 3% KCL. Circ well to production. Returns cleaned up, circultated 719 bbls. Set ~ and ND tree. Chk tbg hanger. t) O\l 11/6/200600:00 -11/7/2006 00:00 ~nI\ Operations Summary NU BOPS. Function test same. Test BOPE 250 psi low and 3000 psi high. Tested choke valves and pipe rams. 11/7/200600:00 - 11/8/2006 00:00 Operations Summary PTSM Finished BOPE test. Pull test jt and BPV, install 2-way check and test blinds 250/3000/ Test Koomey. Pull 2 way check. Set BPV.BD test joints. RU flow line. PJSM. Circ well. Pulled hanger. Filled hole. Pumped 10 bbls spacer, 51 bbls sized salt pill and 10 bbls KCL space, followed with 95 bbls wI 3% KCL. ~ Daily Operations 11/8/200600:00 -11/9/2006 00:00 Operations Summary LD tubing hanger. RU cable into shieveand hang. PTSM and cable cut drills. POOH w ESP completion, Check for NORM. LDgas liftvalves and stand back and strp 4-1/2" tbg. 11/9/200600:00 -11/10/2006 00:00 Operations Summary POOH with ESP. Recover 179 cannon clamps and 44 super clamps. LD ESP completion. Cable tested good. All but two bands recovered. Motors checked grounded phase to ground. but balanced phase to phase. Top pump was locked up and the remaining two were very stiff. Everything else turned free. Pothead looked good as well as the MLE. All flat guards and protectalizers were recovered. PU BHA. 11/10/200600:00 -11/11/2006 00:00 Operations Summary MU BHA. RIH w/2 jts 5" DP. Pressure test. PU 5" DP and RIH. 11/11/2006 00:00 - 11/12/2006 00:00 Operations Summary Continue to RIH with 5" DP to 8800'. Did not see any obstruction at top of 53.5# 9-5/8" csg. Cont to RIH. Kelly up at 10,936'. Wash down to 11,196' and encountered bridge. Started rotary. Found junk at 11,216. Worked through, Continued to rotary drill to clean out liner to 11,322' 11/12/200600:00 -11/13/2006 00:00 Operations Summary Wash/Ream 11,322' to 11,444'. Pump viscous sweep. Acts like junk is being pushed down hole ahead. Periodically getting junk between bit and bottom junk basket. Work and circulate to 11,450'. Circ well and pump high visc sweep, followed by 3% KCL treated with hypoclorite, Displace well with 3% KCL while taking returns to production. 11/13/200600:00 -11/14/2006 00:00 Operations Summary Trip out, LD 5" DP. Operations curtailed due to high winds. 11/14/200600:00 -11/15/2006 00:00 Operations Summary , LD BHA. Recovered metal (perf guns and possible gun barrel) from junk baskets. RU Centilift, MU ESP motor and pump assy, Test all connections, verify equipmnent will trun freely. Fill seals and motor with oil. Hook-up Phoenix sensor line and chemical lines. RIH banding to motor. Install motor lead to pothead. Test Phoenix tool and perform meg test. RIH installing protectrolizers and flat guard. PU 1 jt 4-1/2" tbg. High winds causing safety concerns. 11/15/200600:00 -11/16/2006 00:00 Operations Summary Waiting on weather. PJSM. RIH with 4-1/2" tbg. Perform megger, OHM and conductivity test every 1000', Splice cable. Conduct electical test before and after. 11/16/200600:00 -11/17/2006 00:00 Operations Summary Pump through each capillary to verify checks are open. RIH w/ ESP completion. installing cannon clamps. Perform electical tests every 1000'. Stop at 8,855', cable good, Test at 9672' cable went to ground, recheck to confirm. POH with 4-1/2" tbg and ESP cable 11/17/200600:00 -11/18/2006 00:00 Operations Summary Continue to POOH with ESP equipment, checking at splice points. Cable to pump continues to be grounded. POOH w/ ESP assembly. Inspect pump and motor lead. Removed flat guard, several dents in motor lead and several broken super bands. Recoved all but 8. Checked Pheonix guage - good. Splice at cable and pothead good. Checked motor for phase and all was good. Found flat motor lead to be bad on middle phase possibly at one of the dents. RU slickline unit. RIH with 8.03" guage ring/junk bailer. ~~~~-~_.._- 11/18/200600:00 -11/19/2006 00:00 Operations Summary RIH with 8,03" GRand junk bailer to 10,600' set down at 5197',6709',7744' and 8239'. POOH recovered 3 super bands with buckles and a partial piece. Second run with GR and bailer, recovered 2 superbands and 2 partial pieces. Did not set down or feel any obstruction while RIH. 3rd run recovered 1 super band. Finished installing motor lead and performed electric test - good. MU 8.375" GR and RIH slow to 10,600' POOH and recovered 1/2 super band. PU motor and pump assembly. MU flat motor lead to pothead and test. RIH installing flat guard and super bands over motor lead. Total 30 bands installed on ESP assembly and 15' pup. Centilift hand found plug in pocket. POOH ESP assembly and found plug was missing on bottom of motor (check valve). Check motor for oil contamination with water. NO. Install plug and RIH. RIH with 4-1/2" tbg and ESP assembly checking electrical every 1000'. .. Daily Operations 11/19/200600:00 -11/20/2006 00:00 Operations Summary RIH with ESP equipment on 4-1/2" tubing to stand 40. Perform electical tests every 10 stands. Perform electrical tests and all OK. Pumped through both chem tubes to verify open - all good. Sand in pits was tested with acid, and shows to be primarily sand. MU tubing hanger. 11/20/200600:00 -11/21/2006 00:00 Operations Summary Made splice at pigtail. Performed all electric checks including Phoenix - all good. Pumped through chem inj lines: Had EMDproblems and shut down EMD #2 and bring on EMD #1. Land hanger, made electical checks and all good. ND riser, clean wellhead and install tree. Test. Turnws well over to produciton. Production started pump at 2200 hrs. Running backwards, change phase and restarted at 2230 hrs with 7500 bpd rate. Pump ran 30 min and reported that VSD went down by production. Research showed motor phase went to ground. 11/21/200600:00 -11/22/2006 00:00 Operations Summary Demobe Re: D-47 Rerunning the ESP completion . . Hi Chantal, It is probably appropriate to continue the work under the original approval. Don't you just hate lemons? Call or message with any questions. Tom Maunder, PE AOGCC \<i\-O\\ Walsh, Chantal-Petrotechnical [contractor] wrote, On 1/15120072:48 PM: Tom, You approved, for Chevron, the rerunning of an ESP completion in the D-47 well, in August 2006 (Sundry 306-263). The procedure was followed and a new completion was run in the well in November 2006. The pump was turned on and ran for less than an hour. We intend to return to the well and pull the completion and rerun another ESP. Attached is the procedure for this work. Please let me know if you would like us to resubmit a 403, or if wè can continue to work under the initial 306-263 sundry. Thank you, Chantal Walsh SCANNED JAN 1 6 2007 I of 1 1/16/20079:27 AM Chevron . Dollv Varde.latform '" \Vell D-47 ESP Workover OBJECTIVE: Replace the failed ESP assembly currently in Well D-47. PROCEDURE SUMMARY: 1. R/U E-Line. Punch holes in tubing above ESP. 2. Circulate oil out of annulus and load well wi 3% KCL. 3. Activate Dolly Varden Rig. 4. Spot sized salt pill (if necessary) to manage losses and keep hole full while POR. 5. Set BPV and N/D tree on Well D-47. N/U BOPE. Test 13-5/8" BOPE to 250/3,000 psi. 6. Verify well dead. 7. POR wi tubing, cable & failed ESP. 8. P/U 7" casing clean-out assembly. 9. RllI cleaning out well into the 7" liner as required. 10. Circulate well clean and spot LCM pill as required. 11. POOR wi CO assembly. 12. RU E-Line. RllI with Casing Caliper Log. RD E-line. 13. R/U to run the ESP completion. 14. RllI wi replacement ESP assembly on tubing. 15. Install BPV. N/D BOPE. N/U & test tree. AOGCC D-47 ESP Workover Summary.doc 1 of 1 August 3,2006 Chevron . . RKB to TBG Head = 41.2' Cas n 9 & Tu b n 9 Tree connection: 4-1/16" 5,000# Size 'I' e Wt Grade Thrd ID To Btm 33" Conductor Surf 398' 16" Surf Csg 102 X-56 Butt- 14.75 Surf 3305' welded c I 47 8.681 Surf 8524' 9-5/8" Prod Csg L-80 BTC 53.5 8.535 8524' 10978' a. b. c. d. e. f. 9 h. 7" Liner 6.185 Trading Bay Unit Well # D-47 ESP Conversion 11-06 Hole Driven 29 N-80 TKC 10746' 11925' 22" 4200 sx 350 sx To Surf 4550 sx Total Bumped Plug Calc TOe @-5400' assmd 20% loss Tubin 4-1/2" ESP Cahle wi (2) 3i8" Chem inj li.n~s ,IEWELRY DETAIL 12-1/4" 1900 sx 8-1/2" 400 sxs Includes (2) sqz NO. Ðenth ID Item a. 2495' 3.958" 4-1/2" SFO Mandrel wi dununy valve drift ill - 3.833" b. 4156' 3.958" 4- 112" SFO Mandrel wi dununy valve drift ill - 3.833" c. 5548' 3.958" 4-1/2" SFO Mandrel wi dununy valve drift ill - 3.833" d. 6665' 3.958" 4- 112" SFO Mandrel wi dununy valve drift ill - 3.833" e. 7416' 3.958" 4-1/2" SFO Mandrel wi dununy valve drift ID ~ 3.833" ( 7986' 3.958" 4-1/2" SFO Mandrel wi dununy valve drift ill = 3.833" g. 8544' 3.958" 4-1/2" SFO Mandrel wi dununy valve drift ID = 3.833" h. 9018' 3.958" 4-1/2" SFO Mandrel wi dununy valve drift ill = 3.833" i. 9524' 3.958" 4- 112" SFO Mandrel wi dununy valve drift ill - 3.833") 1 10353' 3.75" "XN" Nipple (profile - 3.813") 2 ±9250' NA Pressure Head 3 10401 NA ~ischarge Head 4 10402 NA Pump Model HPMT AR I-I, SNI0215961 5 10415 NA Pump Model HPHVMT AR I-I, SNI0215970 6 10428 NA Pump Model HPHVLT AR I-I, SN10215972 7 10442 NA Seal Assembly 8 10456 NA Mo{or- 800 HP HMI 216009878 9 10491 NA Phoenix Sensor XT -II AnodelCentralizer (bottom @ 10497) 10 10735 TIW SN-6-AT Liner Top Packer Spudded 0-47 on 02/02/91. Completed on 04/27191. 0-47 was a drill out of 0-44 (used the 16" (o 3305') Which was a drill out of 0-22 (used the 33" conductor to 398'). oHole Section MWT: oApproximate Rotatillg hrs: 0 17-1/2" to 3305' 9.2 to 10.2 ppg 0 33" 157 hrs 0 12-1/4" to 10978' 9.1 to 10.1 ppg 0 16" 931 hrs 0 8-112" to 11925' 9.5 to 10.1 ppg 0 9-5/8" 77hrs 0 7" xhrs -9 G-2 Brief UetaHs & Info: G-3 G-4 gShoe @1097S' DIL I'J.~RFOR¡\TION nATA Accum Last Present I -1 Zone Top 8tm Amt. SPF Perf Date Condition Notes G-2 10,704' 10,724' 20' 12 11/25/2004 Open f/ Prod 4-518" TCP 03/03 & 11i04 B-2 G-3 10,760' 10,790' 30' 6 to 12 10/30/1969 Open f/ Prod 4-5/8" TCP 03/03 & 11/04 (shot 10,775' -10,785') G-4 10,816' 10,866' 50' 6 to 12 6/15/1992 Open f/ Prod 4-5/8" TCP 03i03 & 11/04 (shot 10,830' - 10,860') B-1 11,175' 11,225' 50' 48 6/15/1992 Open f/ Prod 4/91,6/92, 10/92, 1/93,9/93, 7i95, 4/98, 3i99 Fill tagged on B-2 11,250' 11,265' 15' 12 6/15/1992 Open f/ Prod 4i98, 3/99 11/06@ 11,450' B-3 B-2 11,280' 11,310' 30' 12 7/1/1975 Open f/ Prod 4/98. 3i99 B-3 11,340' 11 ,400' 60' 30 7/1/1975 Open f/ Prod 5/91,8/91.6/94,7/95,7/96 B-4 11,400' 11,470' 70' 12 7/1/1975 Open f/ Prod 7/95, 7/96 PBTD = 11,834' TD = 11,930' MAX HOLE ANGLE = 48° D-47 Existing ESP Schm 12-06.doc CRW: 12/15/2006 . . Dolly Varden Stack up D ~47 To of Rota Table RKB = 40.30' I 4.59' Btm of Trolly beam 11.92' 18.23 To of drill deck A 21/16" 5M HCR Valve 1IIIIIIIwnMmWM B 21/16" 5M Manual gate valve C 21/16" 5M Manual gate Kill line D 21/16" 5M Manual gate Kill line E 3 1/8" 5M Target Tee 18.20 to tbg spool F 2 1/16" 5M Target Tee 22.23 · -, 'i .".=cl /. ;'.::1 ; :! ¡ :! ~·d FRANK H. MURKOWSKI, GOVERNOR A1tASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAù< (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 Re: McArthur River Field, HemlockjG Oil Pool, Dolly Varden D-47 Sundry Number: 306-263 SC.!\N."!EO 1~UG :1 ,1 DG Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person . ay not appeal a Commission decision to Superior Court unless earing has been requested. Sincerely, DATED this If) day of August, 2006 Encl. It:) (-0 tl 1. Type of Request: í/J1. B.~ (){o ~ECE'VED . STATE OF ALASKA Y'''1 ¡ ALA OIL AND GAS CONSERVATION COM ON ~rç AUG 0 4 2006 APPLICATION FOR SUNDRY APPROVAL Alaska Oil & G C 20 MC 25.280 as ons. Commission Operational shutdown Perforate Waiver rage Other.¡ Plug Perforations D Stimulate 0 Time Extension D Replace Failed Perforate New Pool D Re-enter Suspended Well D ESP 4. Current Well Class: 5. Permit to Drill Number: Suspend Repair well D Pull Tubing 0 Abandon Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: Development Stratigraphic 0' D Service Exploratory D D 191-011 . 6. API Number: 50-733-20195-02 PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 106' AMSL 8. Property Designation: Trading Bay Unit 40'- f'7r;;qc/ 11. Total Depth MD (ft): 11,930' 9. Well Name and Number: ~ . '0'" Dolly Varden D-47 . 10. Field/Pools(s): McArthur River Field / Hemlock / I«I'þþ¿4 ~ICAJ~:z. 4 ()I' PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 11,834' 9,849' None Size MD Total Depth TVD (ft): 9,917' Junk (measured): 11,383' Casing Structural Conductor Surface Intermediate Production Liner Length TVD Burst Collapse 3,305' 10,987' 16" 3,305' 10,987' 2,947' 9,052' 2630 psi 5750 psi 1020 psi 3090 psi 9-5/8" Perforation Depth MD (ft): See Attached Schematic Packers and SSSV Type: 1,179' 7" Perforation Depth TVD (ft): See Attached Schematic None 11,925' Tubing Size: 9,880' Tubing Grade: 8160 psi 7020 psi Tubing MD (ft): 10,376' 4-1/2" 12.6 ppg L-80 IBTC Packers and SSSV MD (ft): None 12. Attachments: Wellbore Schematic 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 9/5/2006 13. Well Class after proposed work: Exploratory D Development 0 Service 0 15. Well Status after proposed work: Oil 0 Gas 0 Plugged D Abandoned D WAG D GINJ D WINJ D WDSPL 0 Description Summary of Proposal .¡ o BOP Sketch 0 Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Larry Buster 263-7853 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 907-276-7600 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: t>QOO t;>oS\ ~Y'~c:.~ O-t". ~\o..~~ , ( \-.)o-~\o~ ~~\- "-C~ ~~<t~'ê- '~c...\~"',,(J\j\-~~~*" f.. \cqOO . Approved by: APPROVED BY THE COMMISSION Date: 8"-10- () þ RBDMS BFL AUG 1 0 2006 . -Ob , g--/$/t:6 Submit in Duplicate . . Dolly Varden Platform Well D-47 ESP Workover Chevron . OBJECTIVE: Replace the failed ESP assembly currently in Well D-47. PROCEDURE SUMMARY: 1. Shut off gas lift gas. Bleed down pressure slowly to avoid damaging ESP cable. . 2. R/U E-Line. Punch holes in tubing above ESP. 3. Circulate oil out of annulus and load well wi 3% KCL. 4. Activate Dolly Varden Rig. 5. Spot sized salt pill (if necessary) to manage losses and keep hole full while POH. 6. Set BPV and N/D tree on Well D-47. NIU BOPE. Test 13-5/8" BOPE (see attached diagram) to 250/3,000 psi. 7. Verify well dead. 8. POH wi tubing, cable & failed ESP. ' 9. PIU 7" casing clean-out assembly. 10. RIH cleaning out well into the 7" liner as required. 11. Circulate well clean and spot LCM pill as required. 12. POOH with clean-out assembly and R/U to run the ESP completion. 13. RIH wi replacement ESP assembly on tubing. 14. Install BPV. N/D BOPE. NIU & test tree. AOGCC D-47 ESP Workover Summary 1 of 1 August 3, 2006 RKB to T B G Head = 106.90' Tree connection: 4-1/6" 5,000# 9-5/8" 40,43.5, N-80 & p- Butt 8.68] Surf ] 0,978' 47 lIO LT&C 7" 29 N-80 Butt 6.184 lO,746 11,925' LT&C Tubing: 4- 1/2" 12.6 L-80 Mod. Butt. 3.958 0' 10,361' 2 3 4 5 1 2 3 4 5 6 7 8 9 10 II 2,495' 4,156' 5,548' 6,665' 7,416' 7,986' 8,544' 9,0]8' 9,524 10,329' 10,376' 3.958 3.833 3.833 3.833 3.833 3.833 3.833 3.833 3.833 3.813 N/A 4-1/2" MMM SFO-2 RK 4-l/2" MMM SFO-2 RK 4-]/2" MMM SFO-2 RK Latch 4-1/2" MMM SFO-2 RK 4- 1/2" MMM SFO-2RK Latch 4-1/2" MMM SFO-2RK Latch&R2 4-]/2" MMM SFO-2RK Latch &R2 4- 1/2" MMM SFO-2 RK Latch&R2 4-1/2" MMM SFO-2 RK Latch X Nipple Centrilift ESP Head. 567 HP 562 tandem seals and HC 7000 and GC 6100 pumps. Aluminum Anode Bottom of ESP 6 7 8 9 10 x ]2 10,504 ' N/A Fill Tagged wi a 3.5" GR 08/25/01 @ Fish: 16 foot Energjet Strip Gun Fish: Hydroblaster from CTCO in 97 6" Bit was run to 10900 feet on 2 March 03 07/07/96 02/97 02/03/03 In Rat Hole below Tubing Tail G-2 10704 10724 20' 6 4-5/8" TCP 4 Mar 03 G-2 10704 ]0724 20' 6 4-5/8" TCP G-3 10760 10790 30' 6 4-5/8" G-3 10775 ]0785 10' 6 4-5/8" TCP G-4 ]0816 10866 50' 6 4-5/8" TCP G-4 10830 10860 30' 6 4-5/8" 04 B-1 11,180' 11,220' 100' 6 4/22/9 I PBTD = 11,834' TD = 11,930' B-3 1],340 11,425 85' 6 5120/91 & MAX HOLE ANGLE = 48° B-4 11400 11470 70' 6 7/1/95 · , Table 10.90' 40.23' 15.58' 18.92' A 41/16" 5M Foster HCR Valve B 41/16" 5M Manual gate valve C 31/16" 5M Manual Gate Kill line D 31/16" 5M Manual Gate Kill line 135/8" 5M )( 11" 5M Cross over Spool 22.31' Top of Drill Deck 17.92' ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS U D o 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing 0 Change Approved Program D Ope rat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 106' AMSL 8. Property Designation: Dolly Varden Platform 11. Present Well Condition Summary: Total Depth measured 11,930 feet true vertical 9,917 feet Effective Depth measured 11,834 feet true vertical 9,849 feet Casing Length Size Structural Conductor Surface 3,305' 16" I ntermed iate 10,987' 9-5/8" Production Liner 1,179' 7" Perforation depth: Measured depth: 10,704 to 11,470' True Vertical depth: 8,802 to 9,483' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Rf:: E~~\/ED MAY 19 Z005 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development 0 Stratigraphic D Stimulate U AlaSI(&p@;¡;r&ÆI~,;e¡tHM@P[qjiWnmm()~ Waiver D Time Extension CA.hchorsge Re-enter Suspended Well U' 5. Permit to Drill Number: Exploratory D 91-11 Service D 6. API Number: 50-733-20195-02 9. Well Name and Number: 0-47 10. Field/Pool(s): Trading Bay Unit/Hemlock Pool Plugs (measured) none Junk (measured) 11,383' MD TVD Burst Collapse 3,305' 2 947' 2630 psi 1020 psi 10,987' 9,052' 5750 psi 3090 psi 11,925' 9,880' 8160 psi 7020 psi 4-1/2" 12.6# L-80 @ 10,361' n/a SC.ANNED MAY 2 6 2005 n/a Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 40 2309 1280 78 4680 120 15. Well Class afte¡:....groposed work: Exploratory U Development 0 Service D 16. Well Status after proposed work: Oil0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl 237 257 x Contact Larry Buster 263-7853 Printed Name Timothy C. Brandenburg __ Signature ? y c-y) ~ Form 10-404 Revised 04/2004 Tubing Pressure 420 120 GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 305-047 Title Drilling Manager Phone 907-276-7600 Date 5/19/2005 RBDMs BFL MA \I 2 :i 7005 ORIGINAL Submit Original Only UNOCALe \ RKB to TBG Head = 106.90' Tree connection: 4-1/6" 5,000# z r'- .10 L . . .. . .. .............. . .... . .... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ............ . ... ................ · . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . · . .. ............. . .. ... ...... · .... . .. . . . . . . . . . . . . . . . . . · .. ..... .. .... ... . .. ..... .. ..... .... . . . . .... . ~ 2 3 4 5 6 7 8 9 11 12 ===I~? ~ Z - G3 - - G -4 ~ - B-1 - - B-3 .¡....;...- · . · . · . .. . · . . . · . · . · . ~ PBTD = 11,834' TD = 11,930' MAX HOLE ANGLE = 48° ) ) Trading Bay 0 nit Well # D-47 As Completed 5/13/05 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 16" 102 X-56 14.688 Surf. 3,305' 9-5/8" 40,43.5, N-80 & P- Butt 8.681 Surf 10,978' 47 110 LT&C 7" 29 N-80 Butt 6.184 10,746 11,925' LT&C Tubing: 4-112" 12.6 L-80 Mod. Butt. 3.958 0' 10,361 ' JEWELRY DETAIL NO. DeDth ID Item MD 41' 4-1/2" CIW Tubing hanger. 1 2,495' 3.958 4-112" MMM SFO-2 RK Latch & R2 2 4,156' 3.833 4-112" MMM SFO-2 RK Latch & R2 3 5,548' 3.833 4-112" MMM SFO-2 RK Latch & R2 4 6,665' 3.833 4-112" MMM SFO-2 RK Latch & R2 5 7,416' 3.833 4-112" MMM SFO-2 RK Latch & R2 6 7,986' 3.833 4-112" MMM SFO-2 RK Latch & R2 7 8,544' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 8 9,018' 3.833 4-112" MMM SFO-2 RK Latch & R2 9 9,524 3.833 4-112" MMM SFO-2 RK Latch & R2 10 10,329' 3.813 X Nipple 11 10,376' N/A Centrilift ESP ASSEMBL Y Discharge Head. 567 HP 562 Series motor with tandem seals and HC 7000 and GC 6100 pumps. 12 10,504' N/A Aluminum Anode Bottom of ESP Fill Tagged wI a 3.5" GR 08/25/01 @ 11,383' SLM Fish: 16 foot Energjet Strip Gun 07/07/96 @ 10,735' 07/09/96 Fish: Hydroblaster from CTCO in 97 02/97 In Rat Hole below 6" Bit was run to 10900 feet on 2 02/03/03 Tubing Tail March 03 Clean Out run made prior to TCP Guns. EXISTING PERFORATION DATA ZONE TOP BTM AMT SPF DATE G-2 10704 10724 20' 6 4-5/8" TCP 4 Mar 03 G-2 10704 10724 20' 6 4-5/8" TCP 25 Nov 04 G-3 10760 10790 30' 6 4-5/8" TCP 4 Mar 03 G-3 10775 10785 10' 6 4-5/8" TCP 25 Nov 04 G-4 10816 10866 50' 6 4-5/8" TCP 4 Mar 03 G-4 10830 10860 30' 6 4-5/8" TCP 25 Nov 04 B-1 11,180' 11,220' 100' 6 4/22/91 B-3 II ,340 11,425 85' 6 5/20/91 & 717/96 B-4 11400 11470 70' 6 7/1 /95 REVISED: 5/18/2005, BY: DED '" ) ) Well Name 0-47 Primary Job Type ESP Jobs Lease/Serial ADL0017594 I Primary Well bore Affected Main Hole AFE No. I Larry Buster QC Eng 163567 Daily Operations 5/7/200500:00 - 5/8/2005 00:00 Operations Summary Unload Boat and equipment. 5/8/200500:00 - 5/9/2005 00:00 Operations Summary Continue to unload boat. Spot equipment. General Rig-up. 5/9/200500:00 - 5/10/2005 00:00 Operations Summary Prep. BOPE. General Rig-up. 5/10/200500:00 - 5/11/2005 00:00 Operations Summary Circulate well with 3% KCL brine. Mix and pump 60 bbl sized salt pill. Install BPV. N/D tree. 5/11/200500:00 - 5/12/2005 00:00 Operations Summary N/U BOPE. Test BOPE to 3,000 psi/250 psi. Hold H2S and cable cutting drills. 5/12/2005 00:00 - 5/13/2005 00:00 Operations Summary Circulate well with 3% KCL brine. Pull tubing hanger and POOH standing back 4-1/2" tubing. Losses to hole 1.5 bph. 5/13/200500:00 - 5/14/2005 00:00 Operations Summary Laydown pulled ESP and clean floor. Make up and run Centrilift 570 HP, 213 stage ESP. RIH checking electric cable and Pheonix every 1000 feet. 5/14/200500:00 - 5/15/200500:00 Operations Summary Run new ESP on 4-1/2" tubing. Land and test tubing hanger. N/D BOPE. 5/15/200500:00 - 5/16/2005 00:00 Operations Summary Continue to N/D BOPE. N/U and test tree to 5,000 psi. Start to rig down equipment. 5/16/200500:00 - 5/17/2005 00:00 Operations Summary Continue working on rig de-activation. 5/17/200500:00 - 5/18/2005 00:00 Operations Summary Release rig. STATE OF ALASKA RECE ALA '~OIL AND GAS CONSERVATION COML Ì>ION 'VED REPORT OF SUNDRY WELL OPERATIONS MAR 14 2005 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 106' AMSL 8. Property Designation: Dolly Varden Platform 11. Present Well Condition Summary: Total Depth measured 11,930 feet true vertical 9,917 feet Effective Depth measured 11,834 feet true vertical 9,849 feet Casing Length Size Stru ctu ra I Conductor Surface 3,305' 16" Intermediate 10,987' 9-5/8" Production Liner 1,179' 7" Perforation depth: Measured depth: 10,704 to 11,470' True Vertical depth: 8,802 to 9,483' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 Stimulate U Alaska Oil attw.l.cl..J.ep~~ed..1ijl!~d ESP WaiverD Time Exteni~~1:rnG, l.umnu:l~fOfil Re-enter Suspended WYAI~ age 5. Permit to Drill Number: Exploratory 0 91-11 Service D 6. API Number: . 50-733-20195-02 9. Well Name and Number: 0-47 10. Field/Pool(s): Trading· Bay Unit/Hemlock Pool Plugs (measured) none Junk (measured) 11,383' MD TVD Burst Collapse 3,305' 2,947' 2630 psi 1020 psi 10,987' 9,052' 5750 psi 3090 psi 11,925' 9,880' 8160 psi 7020 psi 4-1/2" 12.6# L-80 @ 10,411' n/a SCß~NNEr)l MAH 2 1.1 2005 n/a Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 247 508 820 314 2979 140 15. Well Class afteÖrOPosed work: Exploratory Development 0 Service 0 16. Well Status after proposed work: Oil0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl 69 338 x Contact Larry Buster Prin::~a::: ~;.A 7 Farm 10-404 Revised 04/2004 Tubing Pressure 1500 800 GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: 304-370 Title Drilling Manager Phone 907-276-7600 Date 3/8/2005 RBDMS BFL IVIAH 1 4 2005 ORIGINAL Submit Original Only ) ) 11/15/04 RU APRS, review perforating checklist, test lubricator to 1000 psi. RIH with 1-11116" 16 shot tubing punch, log on depth, fire gun 10390' - 10394'. 11/16/04 RD APRS. 11/20/04 Mob rig and hold. Spud meeting. Test lines to 2500 psi. Start circulate D-47 with 3% kcl fluid at 6 bpm Start mixing pill 65 bbls. 11/21/04 Ship saturated salt from trip tank to pill pit to increase pill volume from 55 bbls - 85bbl. PJSM. Pump 3% kcl at 6 bpm pressure 100-200 psi. Pump10bbls saturated salt, pump 80 bbls of sized salt pill 4bpm, pumped 10bbls saturated salt spacer zero stks. Set BPV, PU hanger joint. NO Tree. Set 13 5/8" riser in V-Door. 11/22/04 RU and set riser. NU BOPs, install rams in all three cavities. Hook up choke hose, kill line and Koomey lines. Fill up choke and BOP with water. 11/23/04 Testing BOPE, Hold Mask up drill with Crew and Service hands Baker, Weatherford, and Cameron. Went over cable cutting tool WITH Weatherford and Baker. RD Test Equip. PJSM - Pump down Tbg. - take returns to well clean tank at 400bbls swap over to pits put excess pill in upper tanks pump additional 120 bbls clean returns. Mix saturated salt pill. PJSM went over SOP emergency shut in. Procedure Cutting cable class. Pull hanger. POOH 4 1/2tbg. and ESP cable. Monitor well--no losses. 11/24/04 POOH 4" tbg and ESP. RU Schlumberger Wire line unit. PJSM. 11/25/04 Press test, RIH with first run gamma and 10' perf shot. (4" HSD 72 degree phasing 6 spf). Get on depth 10,775'- 10,785' No sign guns fired POOH. Guns did not fire. RIH with 10' - 4 1/2" HSD, 6SPF, 72 degree phasing gun. Perforate the G-3 10,775' - 10,785'. RIH with gun # 2; 30' - 4 1/2" HSD, 6 spf, 72 degree phasing gun. Perforate G-4 10,830' - 10,860'. PU and arm Gun # 3. RIH with gun # 3. 20' - 4 1/2" HSD, 6 spf, 72 degree phasing gun. Perforate G-2 10,704' - 10,724'. RD Schlumberger. Pick up ESP Assy. 11/26/04 RIH 4 1/2" buttress tubing. 11/27/04 RIH 4 1/2" buttress tubing. MU hanger and landing joint. ND BOPs. 11/28/04 Jack rig back over well to pull riser. LD riser, slings. RU to set tree on. Button up tree. Install flow line. Set 2- way check, test tree 5,000 psi. Turn over to production at 06:00. Demob rig. 0-47 (AFE 162870) morning report summary, CONFIDENTIAL: last revised 3/10/2005, Page 1. úNbcALe RKB to TBG Head = 106.90' Tree conne\on: 4·1/6" 5,000# I i X I - I .1TX.'..::::;)..'~C' . . . . --,' - . ( w ~iü_ ~ L 2 3 4 5 6 7 8 9 10 11 12 ===I~? ~ Z - - G -4 ~ - B-1 ~- - B-3 ~ ~ ~ PBTD = 11,834' TD = 11,930' MAX HOLE ANGLE = 48° ) Trading Ba Jnit Well #D-47 As Completed 11/28/04 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 16" 102 X-56 14.688 Surf. 3,305' 9-5/8" 40, 43.5, N-80 & P- Butt 8.681 Surf 10,978' 47 110 LT&C 7" 29 N-80 Butt 6.184 10,746 11,925' LT&C Tubing: 4-1/2" 12.6 L-80 Mod. Butt. 3.958 0' 10,361 ' JEWELRY DETAIL NO. Depth ID Item MD 41 ' 4-1/2" CIW Tubing hanger. 1 2,500' 3.958 4-1/2" MMM SFO-2 RK Latch & R2 2 4,162' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 3 5,553' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 4 6,671 ' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 5 7,421 ' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 6 7,991 ' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 7 8,550' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 8 9,023' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 9 9,525 3.833 4-1/2" MMM SFO-2 RK Latch & R2 10 10,329' 3.813 X Nipple 11 10,372' N/A Centrilift ESP ASSEMBL Y Discharge Head. 600 HP 725 Series Motor with Tandem Seals and HC 7000 and HC 7800 Pumps. 12 10,496' N/A Aluminum Anode Bottom of ESP G3 Fill Tagged wI a 3.5" GR @ 11,383' SLM 08/25/01 Fish: 16 foot Energjet Strip Gun Fish: Hydroblaster from CTCO in 97 6" Bit was run to 10900 feet on 2 March 03 07/07/96 02/97 02/03/03 @ 10,735' 07/09/96 In Rat Hole below Tubing Tail Clean Out run made prior to TCP Guns. EXISTING PERFORATION DATA ZONE TOP BTM AMT SPF DATE 0-2 10704 10724 20' 6 4-5/8" TCP 4 Mar 03 0-2 10704 10724 20' 6 4-5/8" TCP 25 Nov 04 0-3 10760 10790 30' 6 4-5/8" TCP 4 Mar 03 0-3 10775 10785 10' 6 4-5/8" TCP 25 Nov 04 0-4 10816 10866 50' 6 4-5/8" TCP 4 Mar 03 0-4 10830 10860 30' 6 4-5/8" TCP 25 Nov 04 B-1 11,180 ' 11,220' 100' 6 4/22/91 B-3 11,340 11,425 85' 6 5/20/91 & 7/7/96 B-4 11400 11470 70' 6 7/1/95 REVISED: 3/11/2005, BY: DED ~~~' If ¡'öf1\i1F,' Ire, , r r I I 'I t " ' ,I I I r I n)j H i¡ ',11 t~ ~ U' \\ U ~ ) [f1t r e ll~,' \, [,1 ,r¡%,A~, ((ù, P~!/, fA'v~,i' ¡Il¡¡lf 0 II /!J; \~~ !¡ 'Ü1, I I I ! I ~ ì I \ n", \ , \\.J ' I / '.. ¡ !:.::J¡ L '\ ~ ! J ~ 1 I! l' ') /9/- {)l! AI1ASIiA. OIL AND GAS CONSERVATION COMMISSION / / / I FRANK H. MURKOWSKI, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 Re: Dolly Varden D-47 Sundry Number: 305-047 Dear Mr. Brandenburg: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior 0 unless rehearing has been requested. DATED thistEðay of February, 2005 Enc!. 5CANNEt~ MAR 02, 2G05 Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 106' AMSL 1. Type of Request: 8. Property Designation: Trading Bay Unit 11. Total Depth MD (ft): 11,930' Casing Structural Total Depth TVD (ft): 9,917' Length Conductor Surface 3,305' 10,987' Intermediate Production Liner 1,179' Perforation Depth MD (ft): See Attached Schematic 8T A TE OF ALASKA AlAvAA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Suspend U Repair well D Pull Tubing 0 Perforate U Waiver U Other GJ Stimulate D Time ExtensionD Replace Failed Re-enter Suspended Well D ESP 5. Permit to Drill Number: Development Stratigraphic 0 D Service Exploratory D 91-11 D 6. API Number: 50-733-20195-02 9. Well Name and Number: Dolly Varden 0-47 10. Field/Pools(s): McArthur River 1 Hemlock Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11,834' 9,849' Size MD Plugs (measured): None Junk (measured): 11,383' TVD Burst Collapse 16" 9-5/8" 3,305' 10,987' 2,947' 9,052' 2630 psi 5750 psi 1020 psi 3090 psi 7" Perforation Depth TVD (ft): 7020 psi Tubing MD (ft): 10,411' 11,925' Tubing Size: 9,880' Tubing Grade: 8160 psi Packers and SSSV Type: 4-1/2" 12.6 ppg L-80 IBTC None - No Flow Status approved 7/24/2002 Packers and SSSV MD (ft): None 12. Attachments: Wellbore Schematic Description Summary of Proposal GJ 0 BOP Sketch 0 Service D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 4/20/2005 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D WDSPL 0 D D Abandoned D D Plugged WINJ Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Contact Larry Buster 263-7853 Phone 907-276-7600 COMMISSION USE ONLY Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D BOP Test .~"'" Form 10-403 Revised 11/2004 Mechanical Integrity Test D Location Clearance D '\í' (C'\:c- .... ",'-..J \.. 1._. " .~ , COMMISSIONER APPROVED BY THE COMMISSION Date: Submit in Duplicate OBJECTIVE: Replace the failed ESP assembly currently in Well D-47. PROCEDURE SUMMARY: 1. Shut off gas lift gas. Bleed down SIWHP slowly to avoid damaging ESP cable. Turn off cathodic protection system. 2. Perforate tubing above ESP. 3. Circulate oil out of annulus and load well wi 3% KCL. 4. Activate Dolly Varden Rig. 5. Spot sized salt pill (if necessary) to manage losses and keep hole full while POH and while RIH wi tubing and ESP assembly. 6. Set BPV and N/D tree on Well D-47. N/U BOPE . Test 13-5/8" BOPE (see attached diagram) to 25013,000 psi. 7. Verify well dead. 8. POH wi tubing, cable & failed ESP. Visually inspect tubing & LID singles while POH. Send failed ESP equipment & unusable tubing to shore. 8. RIH wi replacement ESP assembly similar to the current failed completion (see attached diagram). 9. Install BPV. N/D BOPE. N/U & test tree. 10. Install flow line and surface facilities & turn well over to Production. Turn platform cathodic protection back on. 11. Startup ESP confirm it is functioning properly. AOGCC D-47 ESP W orkover Summary 1 of 1 February 16, 2005 RKB to TBG Head = 106.90' Tree connection: 4-1/6" 5,000# 16" 102 X-56 14.688 Surf. 3,305' '\ 9-5/8" 40,43.5, N-80 & P- Butt 8.681 Surf 10,978' 47 110 LT&C T' 29 N-80 Butt 6.184 10,746 11,925' LT&C Tubing: 4-1/2" 12.6 L-80 Mod. Butt. 3.958 0' 10,361' 2 . ID E tern 3 4 41' 4-1/2" CIW Tubing hanger. 5 1 2,500' 3.958 4-1/2" MMM SFO-2 RK Latch & R2 6 2 4,162' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 7 3 5,553' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 8 4 6,671' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 5 7,421' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 9 6 7,991' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 7 8,550' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 8 9,023' 3.833 4-1/2" MMM SFO-2 RK Latch & R2 9 9,525 3.833 4-1/2" MMM SFO-2 RK Latch & R2 10 10,329' 3.813 X Nipple 11 10,372' N/A Centrilift ESP ASSEMBLY Discharge Head. 600 HP 725 Series Motor with Tandem Seals and HC 7000 and HC 7800 Pumps. 12 10,496' N/A Aluminum Anode Bottom of ESP ~ ~;;{ 1:1 ,";;::;::;,;3": 1 2 ==I G 2 -;."'1"''''''''''''-''''''''0.."°'''"""",, ~ ~i G3 -- L - G-4 =::::.. - B-1 B-3 ~ ~ PBTD = 11,834' TD = 11,930' MAX HOLE ANGLE = 48° Fill Tagged wI a 3.5" GR 08/25/01 @ 11,383' SlM Fish: 16 foot Energjet Strip Gun 07/07/96 @ 10,735' 07/09/96 Fish: Hydroblaster from CTCO in 97 02/97 In Rat Hole below 6" Bit was run to 10900 feet on 2 02/03/03 Tubing Tail March 03 Clean Out run made prior to TCP Guns. EX~STI;\;G 0-2 10704 10724 20' 6 4-5/8" TCP 4 Mar 03 0-2 10704 10724 20' 6 4-5/8" TCP 25 Nay 04 0-3 10760 10790 30' 6 4-5/8" TCP 4 Mar 03 0-3 10775 10785 10' 6 4-5/8" TCP 25 Nay 04 0-4 10816 10866 50' 6 4-5/8" TCP 4 Mar 03 G-4 10830 10860 30' 6 4-5/8" TCP 25 Nov 04 B-1 11,180' 11,220' 100' 6 4/22/91 B-3 11,340 11,425 85' 6 5/20/91 & 7/7/96 B-4 11400 11470 70' 6 7/1/95 REVISED: 2/17/2005, BY: DED Top of Rotary Table ^ A A It.. 10.90' r 13 S/8" hydril SM "'\ ~, 4.54' 40.23' '- .) 1S.S8' -=r 13.S/8!'Shaffer: 5m.DBL..Gate. ~ ,. WJ ",,;.., !,J,I¡¡,,~,Ii!."'''> ',":~IIi\é~lI'II!I!',j '--~11 4.1,6' t~:!!,:,~1 16.82' ,. 'IF t,,<f>\!J'I¡~" ¡"'ì.,iI!;,':"" r¡;;rr,.~':II!:.:quL'! \. ~I t ./ 18.92' ~ :,:'~-~ ~j--- ~;::A . ,B .",,;; J:,~ ~',-- , - T \ / 3 1/16"SM x 41116"SM DSA 13 5/8" SM Mud Cross 1.74' --~-~- C 'D --~-~- I I A 41/16" SM Foster HCR Valve B 41/16" SM Manual gate valve C 31/16" SM Manual Gate Kill line D 3 1116" SM Manual Gate Kill line I 13-518" 5M I Spacer Spool I 2.13' 13 S/8" SM Spacer Spool 13518" 5M xii" 5M Cross over Spool 2.92' 1.00' I I IIIIIIIIIIU U d Top of DCB Spool .. A 22.31' t Top of Drill Deck "I..".,,,,l:). J-l,'h,,',~'.'I'¡¡¡r;;-:':ß:~-'r.wr;~'-- .. 17.92' 'It '"' REi Dolly V~¡den D-47 Sundry 304-370 " SJj~ject:,'RE,: DoUy V~den D-47 Sllildry 3Q4-370 Fr.om: "Buste~, Larry Wit <lbuster@unoc.aJ.com> , \~ \-'0 \., \ : D~te: Thu, 18,Nov'2004 06:46:17 -0900" , ' ", ' ; " .' Tom, The latest look ahead is for a BOPE test on Sunday (11/21) . I will make sure our Forman contacts your inspectors for ari opportunity to witness the test and give them an update if the schedule changes. Also, I have noted your statement about the 7 day test interval. Thank You and Regards, Larry Buster Drilling Engineer Unocal Alaska Drilling -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, November 17, 2004 3:29 PM To: Buster, Larry W Cc: Jim Regg¡ AOGCC North Slope Office Subject: Re: Dolly Varden D-47 Sundry 304-370 Larry, This acknowledges your message and our discussion. With regard to the pill, the important thing is that you are prepared to use one or more if necessary. I understand the reasoning for preferring a salt pill to CaC03. As we talked, I checked past messages/documents I had on the control station matter. That issue has been discussed previously. As you point out, given the surface pressure of the well an API 3K stack meets the requirements. For a 3K system, only BR and 1 set of PR are required. The additional lower set is there basically as a spacer and can be operated from the koomey unit which is not far from the drillers console. The required preventers for a 3K system can be operated from any control station. This will meet the regulatory requirement. Please be sure that your Drilling Supervisor contacts the Inspectors for an opportunity to witness the initial BOP test. Also, please note that a 7 day test interval is applicable since this is a workover operation. If you can, it would be helpful if you would "reply all" with an estimate of when Unocal might start operations on Dolly. Please call or message with any questions. Tom Maunder, PE AOGCC Buster, Larry W wrote: SCANNED NO\J 1., I} 'to\)4 November 16, 2004 1~2 11/18/20048:07 AM RE:.DoJly Vacden D-47 Sundry 304-370 Dear Tom, Further to our conversation of today's date, I would like to clarify two items on the upcoming Dolly Varden D-47 ESP Workover (10-403 #304-370) . First, to control losses, we are planning to pump a sized salt pill prior to the start of workover operations. We utilized a similar pill on the recent M-25 workover with good results. This differs from our previous standard procedure of pumping calcium carbonate pills which proved difficult to clean~up after the workover. Second, we are permitted to perform this work with a 3,000 psi BOP test and will be in full compliance as per 3,000 psi state requirements. However, we will be nippling up with a 5K BOP stack configuration with a double gate on top (VBR and blind/shears) and a single gate on bottom (pipe rams). You should be aware that the single-gate ram will not be operable from the drillers remote console (either on the drill floor or at the sub-structure level). The koomey unit is located on the drill-floor from which the single-gate ram could be operated. We have successfully performed similar work-over operations with this BOP configuration on the Dolly Varden Platform in the past. Please advise if you require further information herein. Thank You and Regards, Larry Buster 20f2 11/18/20048:07 AM I t¡ I. t) II ~V~VŒ (ID~ ~~~~æ~ AI/ASIiA OIL AlQ) GAS CONSERVATION COMMISSION I I FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Bowen Advising Drilling Engineer Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: McArthur River Dolly Varden D-47 Sundry Number: 304-370 Dear Mr. Bowen: 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 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. BY ORDER OF WE COMMISSION DATED this1 day of October, 2004 Enc!. ~ . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25 280 RFCI='VE~ nrr \1 5 2004 \°k' on - . 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate l!J ~¡Wai\lefEJ'.:¡A.WnI:f;", "';" .Iv". u I Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D AnchorageOther 0 Change approved program D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well D replace failed ESP 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory D 91-11 3. Address: Stratigraphic D Service D 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20195-02 7. KB Elevation (ft): 9. Well Name and Number: 106' AMSL Dolly Varden D-47 8. Property Designation: 10. Field/Pools(s): \r-oD\", 'ßc..'i Ù",\-..4-Ï'1^-1 Trading Bay Unit McArthur River I Hemlock 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): Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3,305' 16" 3,305' 2,947' 2630 psi 1020 psi Intermediate 10,987' 95/8" 1 0,987' 9,052' 5750 psi 3090 psi Production Liner 1 ,179' 7" 11,925' 9,880' 8160 psi 7020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): (see attached) (see attached) 41/2" 12.6 ppf L-80 JBTC 10,411' Packers and SSSV Type: None .. ESP artificallift wI live annulus, No-Flow Packers and SSSV MD (ft): NIA status approved 7/24/2002 12. Attachments: Description Summary of Proposal B 13. Well Class after proposed work: Well bore Schematic 0 BOP Sketch 0 Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oct. 21, 2004 (approximate date) Oil 0 Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jerry Bowen Printed Name Jer~wen /J Title Advising Drilling Engineer Signature /' I /~)- Phone 907-263-7640 Date 1-0ct-04 / ) COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness.. ~ ~ Sundry Number: 3~¥- 37¡) r-" "L',\,~ \ \S~\> ~~ -...ì ,\ \ ~ ~~«.<:J;~ c:.\' Ç>C~\\' \~ - Plug Integrity D BOP Test ¡g¡, Mechanical Integrity Test D Location Clearance D Othe, '>~ ", ~ ~ ~~.. ~ \~ ,,~'iJ. \>,<W \t-;. -\\ "- \tNC..V" '\~'t ~. ~ OpU'~~"':> -\0 bCè. CC,,~UC-~ ç't.,\...J~tu\ ~ ~\~ <J~U().\-\t'~:::5'~ ~I) Subsequent Form Req . ed: ~()'-t RSDMS SF L OCT 0 7 1004 ~proveŒ ~l BY ORDER OF 11)/11 ðl COMMISSIONER THE COMMISSION Date: FO; 1 O-~Revised 12/2003 I ' RSE Submit in Du licate O~\G1W At p UNOCAL8 Trading Bay Unit Well # D-47 CURRENT CONFIGURATION Mar 07, 03 RKB to TBG Head = 106.90' Tree connection: 4-1/6" 5,000# 2 3 4 5 6 7 8 x 9 PBTD = 11,834' TD = 11,930' MAX HOLE ANGLE = 48° SIZE 16" 9-5/8" 7" Tubing: 4-1/2" NO. 1 2 3 4 5 6 7 8 9 10 G2 11 G3 WT 102 40,43.5, 47 29 12.6 Depth TVD 41 2,370' 3,412' 4,192' 4,917' 5,355' 5,772' 6,160' 6,555' 8,516 8,555' 8,626' CASING AND TUBING DETAIL GRADE CONN ID X-56 14.688 N-80 & P- Butt 8.681 110 LT&C N-80 Butt LT&C L-80 Mod. Butt. JEWELRY DETAIL Depth ID Item MD 41 ' 2,502' 3,981 ' 5,065' 5,969' 6,508' 7,016' 7,491 ' 7,969' 10,370' 10,413' 3.958 3.833 3.833 3.833 3.833 3.833 3.833 3.833 3.813 N/A ACTUALCURRENT ACTUAL D-47schematic 10 MAr 03.doc 10,499' N/A Fill Tagged wi a 3.5" GR Fish: 16 foot Energjet Strip Gun Fish: Hydroblaster from CTCO in 97 6" Bit was run to 10900 feet on 2 March 03 TOP BTM. Surf. 3,305' Surf 10,978' 10,746 11,925' 0' 10,411' 6.184 3.958 4-1/2" CIW Tubing hanger. 4-1/2" MMM SFO-2 RK Latch & R2 4-1/2" MMM SFO-2 RK Latch & R2 4-1/2" MMM SFO-2 RK Latch & R2 4-1/2" MMM SFO-2 RK Latch & R2 4-1/2" MMM SFO-2 RK Latch & R2 4-1/2" MMM SFO-2 RK Latch & R2 4-1/2" MMM SFO-2 RK Latch & R2 4-1/2" MMM SFO-2 RK Latch & R2 X Nipple Centrilift ESP ASSEMBLY Discharge Head. 600 HP 725 Series Motor with Tandem Seals and HC 7000 and HC 7800 Pumps. Aluminum Anode Bottom of ESP Assembly 08/25/01 @ 11,383' SLM 07107/96 02/97 02/03/03 @ 10,735' 07/09/96 In Rat Hole below Tubing Tail Clean Out run made prior to TCP Guns. EXISTING PERFORATION DATA WNE TOP BTM AMT SPF DATE G-2 10704 10724 20' 6 4-5/8" TCP 4 Mar 03 G-3 10760 10790 30' 6 4-5/8" TCP 4 Mar 03 G-4 10816 10866 50' 6 4-5/8" TCP 4 Mar 03 B-1 11,180' 11,220' 100' 6 4/22/91 B-3 11,340 11,425 85' 6 5/20/91 & 7/7/96 B-4 11400 11470 70' 6 7/1/95 REVISED: 10/112004 BY: J.I.M. UNOCAL8 Dolly Varden Platform Well D-47, AFE 162870 ESP Workover OBJECTIVE Replace the failed ESP in well D-47 & re-perforate G-Sand intervals. PROCEDURE SUMMARY 1. Activate rig. 2. Shut off gas lift gas and slowly de-pressurize the tubing and casing slowly to minimize damage to the ESP cable. 3. Load well wi 3% KCl. Circ oil out of annulus. Spot sized salt pill, if necessary, to manage losses and keep hole full while POR or RIR wi tbg & ESP cable. Punch circ hole in tbg above ESP before pumping sized salt pill. 4. Set BPV. ND tree. NU & test 13 5/8" 5m BOPE to 250/3000 psi as per attached diagram. 5. Verify well dead and FL can be maintained at surface. Circ well clean to verify no oil has entered tbg or annulus. 6. POR wi tbg, cable & failed ESP. Inspect tbg while POR & stand usable tbg in derrick. LD GL V s and ESP equipment. 7. RU E-line unit. Re-perforate the following G-zone intervals with 4 Y2" RSD (6 SPF): G-4 G-3 G-2 10,830' - 10,860' DIL (30') 10,775' - 10,785' DIL (10') 10,704' - 10,724' DIL (20') 10. RIR wi replacement ESP assembly as per attached diagram & 4 1/2" completion string. 11. Install BPV. ND BOPE. NU & test tree. 12. Install flowline and surface facilities & turn well over to Production. Turn platform cathodic protection back on. Startup ESP as per separate startup procedure and confirm that ESP is functioning properly. 13. Deactivate rig & backload equipment. AOGCC D-47 ESP Workover Summary. doc 1 of! October 1,2004 Dolly Varden Stack up D -47 To of Rota Table 17' 1.15 Top of drill deck A 41/16" 5M Foster HCR Valve B 41/16" 5M Manual gate valve C 3 1/16" 5M Manual gate Kill line D 31/16" 5M Manual gate Kill line 18.60 to tbg spool 2.0 spacer spool 2.0 spacer spool 1.5' 135/8" x 11" xo spool 23' UNOCAL DOLLY VARDEN Platform D-47 slot #A2-8 McArthur River Field TBU, Cook Inlet, Alaska SURVEY LIS TIN G by Baker Hughes INTEQ Your ref: MSS <10913-11930'> Our ref: svy5305 License: Date printed: 12-Feb-2004 Date created: 4-Nov-1991 Last revised: 29-Jul-1996 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 48 20.815,w151 38 22.052 Slot location is n60 48 28.184,w151 37 59.266 Slot Grid coordinates are N 2490829.393, E 208379.369 Slot local coordinates are 748.40 N 1130.40 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North UNOCAL DOLLY VARDEN Platform,D-47 McArthur River Fie1d,TBU, Cook Inlet, Alaska Measured Inc1in. Azimuth True Vert Depth Degrees Degrees Depth 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2050.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3387.00 3483.00 3572.00 3666.00 3760.00 3860.00 3954.00 4047.00 4141. 00 4233.00 4324.00 4418.00 4512.00 4605.00 4697.00 11. 32 13.30 15.70 18.63 22.30 25.90 28.00 30.03 34.02 38.05 42.43 43.62 42.02 42.58 43.25 44.00 44.63 45.15 45.82 46.45 45.00 46.25 47.50 47.00 46.75 46.00 46.00 45.30 46.40 45.70 45.10 44.60 44.40 44.00 43.30 0.00 0.92 0.87 0.28 0.35 0.00 102.50 89.19 37.50 14.50 0.17 2.67 4.15 5.83 7.30 127.11 266.30 274.20 278.20 285.31 7.35 7.60 8.48 8.97 9.63 301.11 314.50 325.90 335.31 342.61 345.20 347.61 348.70 349.70 351. 00 351.31 351.11 351.11 351. 90 352.11 352.20 350.00 347.31 346.31 346.20 346.61 346.20 346.11 346.00 345.50 351. 30 351. 00 355.30 1.40 3.40 12.90 14.30 17.00 20.30 24.70 0.00 100.00 199.98 299.98 399.98 499.98 599.94 699.76 799.38 898.72 997.92 1097.08 1196.10 1294.94 1393.63 1491. 96 1589.66 1686.47 1782.00 1875.68 1966.94 2011.51 2055.23 2140.00 2220.85 2297.16 2370.27 2443.63 2517.59 2590.83 2663.21 2734.76 2805.61 2875.72 2945.02 3005.78 3072.91 3133.77 3197.61 3261. 87 3.00 1. 40 2.80 6.40 8.50 3330.86 3396.16 3461.17 3526.66 3590.51 R E C TAN G U LA R COO R DIN ATE S 0.00 N 0.17 S 0.34 S 0.13 S 0.36 N 0.57 N 0.33 N 0.45 N 1.44 N 3.84 N 8.82 N 16.76 N 27.51 N 40.70 N 55.76 N 73.23 N 93.96 N 118.46 N 147.45 N 181. 92 N 222.27 N 244.66 N 268.62 N 321. 06 N 379.30 N 443.28 N 510.68 N 577.31 N 642.83 N 708.97 N 776.03 N 843.94 N 912.46 N 981. 67 N 1051.54 N 1112.50 N 1180.30 N 1244.77 N 1313.70 N 1382.24 N 1454.51 N 1522.08 N 1588.53 N 1655.74 N 1721.41 N 1785.05 N 1849.48 N 1912.91 N 1974.33 N 2032.97 N 0.00 E 0.78 E 2.32 E 3.23 E 3.45 E 3.65 E 1.44 E 4.49 W 13.13 W 24.29 W 35.89 W 46.09 W 54.94 W 62.33 W 68.09 W 73.09 W 78.07 W 83.19 W 88.70 W 94.52 W 100.79 W 104.26 W 108.01 W 115.82 W 123.99 W 132.81 W 143.38 W 156.72 W 172.08 W 188.26 W 204.47 W 220.90 W 237.79 W 254.97 W 272.72 W 285.27 W 295.83 W 303.55 W 305.55 W 302.68 W 298.64 W 296.04 W 293.61 W 288.18 W 279.60 W 267.59 W 252.01 W 234.24 W 213.52 W 189.24 W Dogleg DegllOOft SURVEY LISTING Page 1 Your ref: MSS <10913-11930'> Last revised: 29-Jul-1996 Vert Sect 0.00 0.92 0.21 0.73 0.14 0.00 0.12 0.51 1. 03 1. 57 3654.42 3721.07 3788.12 3854.80 3921.38 0.44 2.80 1. 55 1. 72 1. 67 1. 83 0.82 -1.18 -3.32 -5.04 2.01 1. 76 1. 82 1. 51 1. 35 -4.51 -0.70 6.19 15.90 27.93 1. 75 2.05 2.42 2.95 3.69 42.49 60.09 81.18 106.32 136.47 3.60 4.20 4.07 4.01 4.03 171.96 191.66 212.72 258.97 310.50 4.38 1. 91 2.43 0.88 0.67 367.18 426.43 483.97 539.76 595.84 0.80 0.69 0.52 0.67 0.73 652.76 710.40 768.46 827.04 886.05 5.05 1. 32 3.80 4.79 1. 58 938.58 998.20 1055.72 1119.45 1184.54 0.80 1.22 1. 31 2.99 1. 81 1253.53 1317.61 1380.59 1445.34 1509.78 3.50 1.18 2.02 2.51 3.39 1573.53 1639.30 1704.90 1769.67 1833.12 All data is in feet unless otherwise stated. Coordinates from slot #A2-8 and TVD from wellhead (106.20 Ft above mean sea level). Bottom hole distance is 5713.21 on azimuth 21.95 degrees from wellhead. Vertical section is from wellhead on azimuth 20.81 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ . , UNOCAL DOLLY VARDEN Platform,D-47 McArthur River Field,TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 4791.00 4886.00 4982.00 5077.00 5170.00 5263.00 5358.00 5452.00 5547.00 5638.00 5733.00 5827.00 5921. 00 6016.00 6112.00 6206.00 6292.00 6385.00 6479.00 6572.00 6665.00 6759.00 6853.00 6947.00 7039.00 7133.00 7226.00 7318.00 7410.00 7502.00 7596.00 7682.00 7773.00 7855.00 7955.00 8048.00 8131. 00 8233.00 8327.00 8420.00 8503.00 8596.00 8684.00 8783.00 8880.00 8973.00 9067.00 9159.00 9252.00 9345.00 41.70 39.90 39.60 36.90 36.30 36.60 36.80 36.80 36.90 36.40 36.10 35.40 35.00 34.90 34.80 34.50 35.20 35.00 35.30 35.20 35.00 35.10 35.00 34.90 34.80 34.70 34.80 34.70 34.60 34.50 34.20 33.80 33.50 33.10 33.80 33.60 34.30 32.90 32.70 33.50 36.80 37.40 36.90 36.70 35.70 36.00 36.40 36.00 36.00 36.50 30.10 31. 30 31. 90 34.20 35.20 35.40 35.30 35.00 35.20 36.00 35.60 36.10 36.10 35.40 35.60 35.80 35.50 35.80 36.10 36.20 36.70 36.70 36.50 37.20 38.10 38.50 38.40 38.80 39.80 40.30 41. 40 42.40 41. 30 40.40 38.70 39.10 36.70 35.30 33.70 32.60 29.80 30.40 31. 50 30.20 30.40 31.10 25.70 25.60 26.00 25.90 3990.71 4062.62 4136.43 4211.03 4285.69 4360.50 4436.67 4511.94 4587.96 4660.97 4737.58 4813.87 4890.68 4968.55 5047.33 5124.66 5195.23 5271.32 5348.18 5424.13 5500.21 5577.17 5654.12 5731.17 5806.67 5883.90 5960.32 6035.91 6111. 59 6187.37 6264.97 6336.27 6412.02 6480.56 6564.00 6641. 37 6710.22 6795.18 6874.19 6952.10 7019.96 7094.14 7164.28 7243.55 7321. 83 7397.21 7473.08 7547.32 7622.56 7697.56 RECTANGULAR COO R DIN ATE S 2089.33 N 2142.71 N 2194.99 N 2244.30 N 2289.88 N 2334.98 N 2381.28 N 2427.32 N 2473.94 N 2518.10 N 2563.67 N 2608.18 N 2651.96 N 2696.13 N 2740.79 N 2784.19 N 2824.12 N 2867.58 N 2911.39 N 2954.73 N 2997.74 N 3041. 02 N 3084.36 N 3127.45 N 3169.08 N 3211.12 N 3252.64 N 3293.62 N 3334.10 N 3374.04 N 3414.16 N 3449.95 N 3487.51 N 3521.56 N 3564.07 N 3604.22 N 3640.80 N 3686.45 N 3728.41 N 3770.94 N 3811.82 N 3860.35 N 3905.93 N 3956.84 N 4006.30 N 4053.11 N 4101.91 N 4150.89 N 4200.10 N 4249.55 N 160.08 W 128.40 W 96.24 W 64.20 W 32.64 W 0.71 W 32.14 E 64.56 E 97.32 E 128.94 E 161. 80 E 193.96 E 225.88 E 257.68 E 289.54 E 320.72 E 349.36 E 380.53 E 412.30 E 443.96 E 475.73 E 508.00 E 540.18 E 572.48 E 604.59 E 637.79 E 670.76 E 703.47 E 736.60 E 770.17 E 804.86 E 836.98 E 870.62 E 900.07 E 935.16 E 967.56 E 996.02 E 1029.21 E 1058.05 E 1085.81 E 1110.52 E 1138.65 E 1165.98 E 1196.39 E 1225.29 E 1253.14 E 1279.51 E 1303.04 E 1326.83 E 1350.89 E Dogleg DegllOOft SURVEY LISTING Page 2 Your ref: MSS <10913-11930'> Last revised: 29-Jul-1996 Vert Sect 4.24 2.07 0.51 3.21 0.91 1896.16 1957.31 2017.61 2075.08 2128.90 O. 35 0.22 0.19 0.16 0.76 2182.40 2237.36 2291.91 2347.12 2399.64 0.40 0.81 0.43 0.44 0.16 2453.90 2506.94 2559.21 2611. 79 2664.85 0.34 0.84 0.28 0.37 0.12 2716.50 2764.01 2815.70 2867.94 2919.70 0.38 0.11 0.16 0.44 0.57 2971.19 3023.11 3075.06 3126.81 3177.13 0.26 0.12 0.27 0.63 0.33 3228.23 3278.75 3328.68 3378.29 3427.55 0.73 0.80 0.75 0.78 1.17 3477.37 3522.24 3569.30 3611. 60 3663.79 0.32 1. 82 1. 57 0.95 1. 08 3712.84 3757.14 3811.61 3861.08 3910.69 4.42 0.75 0.94 0.81 1. 04 3957.68 4013.05 4065.36 4123.75 4180.25 0.55 3.42 0.44 0.25 0.54 4233.90 4288.89 4343.03 4397.49 4452.26 All data is in feet unless otherwise stated. Coordinates from slot #A2-8 and TVD from wellhead (106.20 Ft above mean sea level). Bottom hole distance is 5713.21 on azimuth 21.95 degrees from wellhead. Vertical section is from wellhead on azimuth 20.81 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL SURVEY LISTING Page 3 DOLLY VARDEN Platform,D-47 Your ref : MSS <10913-11930'> McArthur River Field,TBU, Cook Inlet, Alaska Last revised : 29-Jul-1996 Measured Inclin. Azimuth True Vert R E C TANGU LA R Dogleg Vert Depth Degrees Degrees Depth COO R DIN A T E S DegllOOft Sect 9437.00 36.40 26.00 7771.56 4298.70 N 1374.81 E 0.13 4506.69 9529.00 35.60 26.90 7845.99 4347.11N 1398.89 E 1. 04 4560.51 9622.00 34.60 27.00 7922.08 4394.78 N 1423.12 E 1. 08 4613.68 9716.00 33.30 26.70 8000.05 4441.62 N 1446.84 E 1. 39 4665.88 9839.00 33.20 31. 00 8102.93 4500.65 N 1479.36 E 1. 92 4732.62 9932.00 32.90 30.90 8180.88 4544.15 N 1505.44 E 0.33 4782.55 10024.00 33.40 32.10 8257.91 4587.04 N 1531.73 E 0.90 4831.98 10119.00 32.60 34.70 8337.59 4630.24 N 1560.19 E 1.71 4882.47 10211.00 31.70 35.50 8415.48 4670.29 N 1588.34 E 1. 08 4929.91 10332.00 32.20 36.60 8518.15 4722.06 N 1626.02 E 0.63 4991. 68 10426.00 31.90 36.40 8597.82 4762.15 N 1655.70 E 0.34 5039.71 10523.00 30.90 36.30 8680.62 4802.86 N 1685.65 E 1. 03 5088.40 10913.00 27.50 39.50 9021. 03 4953.09 N 1802.25 E 0.96 5270.26 11153.00 26.50 42.50 9234.88 5035.33 N 1873.67 E 0.70 5372.51 11585.00 29.25 45.00 9616.73 5181.05 N 2013.45 E 0.69 5558.38 11930.00 29.75 47.00 9917.01 5299.03 N 2135.65 E 0.32 5712.08 All data is in feet unless otherwise stated. Coordinates from slot #A2-8 and TVD from wellhead (106.20 Ft above mean sea level). Bottom hole distance is 5713.21 on azimuth 21.95 degrees from wellhead. Vertical section is from wellhead on azimuth 20.81 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ AI,ASILA O~ ~ GAS CONSERYA~I~iON COP~IISSION FRANK H. MURKOWSKI, GOVERNOR 333 w. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson UNOCAL Field Superintendent PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification TBU Well D-47 PTD 191-011 May 15, 2003 Dear Mr. Johnson: On July 24, 2002 AOGCC Petroleum Inspector Lou Grimaldi witnessed a "no-flow" test on Well D-47 at UNOCAL's Dolly Varden Platform, Trading Bay Unit, McArthur River Field. Mr. Grimaldi arrived on Dolly Varden Platform and observed the well flowing to flare at 20 psi making no fluid. The well was directed to the clean up tank and observed for 75 minutes. At the end of the observation period, there was 0 pressure and the gas rate was below the meter threshold of 180 scf/hr. The well was shut in for 60 minutes and opened to flow for 5 minutes for 2 cycles. In the first cycle the SITP was 5 psi while in the 2® cycle the SITP was 2 psi. In each cycle when opened to flow, the well quickly died. At the end of the 2nd cycle, no flow was confirmed using a "bubble bucket". Throughout the observation periods, no liquid flow was observed and only a slight gas flow was noted. The observed performance of TBU well D-47 (191-011) demonstrated that the well is incapable of unassisted flow of hydrocarbons to the surface. It has been concluded that TBU well D-47 (191-011) meets the criteria of a "no-flow" performance test and as such, is considered incapable of unassisted flow to the surface. The well's performance meets the criteria at 20 AAC 25.265 (b). Therefore the well is not required to have a fail-safe automatic SSSV, however, the pilot and SSV must be maintained in satisfactory operating condition. If for any mason the well again becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well file on board Dolly Varden. Sincerely, Thomas E. Maunder, PE Sr. Petroleum Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: x Pull tubing: x Alter casing: Repair well: Other: Add G-Zone/Run ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 106' RT above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface Leg A-2, Conductor 8 8. Well number 748' FSL & 1130' FWL Sec. 6, T8N, R13W, SM D-47 At top of productive interval 9. Permit number/approval number 506' FSL & 2169' FEL Sec. 32, T9N, R13W, SM 91-11/303-045 At effective depth 10. APl number 50- 733-20195-02 At total depth 11. Field/Pool 767' FSL & 2450' FEL Sec. 32, T9N, R13W, SM McArthur River Field 12. Present well condition summary Total depth: measured 11,930' feet Plugs (measured) true vertical 9,884' feet Effective depth: measured 11,383' feet Junk (measured) true vertical 9,411' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 3305' 16" 3,305' 2947' Intermediate 10987' 9-5/8" 1900 sx 10,987' 9,052' Production Liner 1,179' 7" 400 sx 11,925' 9,880' Perforation depth: measured 10704'~10724', 10760'-10790', 10816'~10866', 11,180'-11,220', 11,3402,1~'_ true verticalnECEIVED 8,802'. 9483' Tubing (size, grade, and measured depth)APR 2 9 200.3 4-1/2" 12.6# L-80 BTC MOD to 10411' Packers and SSSV (type and measured depth) Alaska 0il & Gas Cons. Commission none 13. Stimulation or cement squeeze summary Aflchorage none Intervals treated (measured) none Treatment description including volumes used and final pressure none 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 268 650 3207 870 140 Subsequent to operation 834 383 2778 112 105 15. Attachments: Schematic X 16. Status of well classification as: Copies of Logs and Surveys run: .................. Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: '~--~__ ' ~GANNED ~A¥ 0 5 2003 Sig ~ Title: Drilling Engineer ..... Date:. 4125/2003 Form 10-404 Rev 06/15/88 ,OR16i'NAL SUBMIT IN DUPLICATE ~.~ Unocal Alaska Business Unit Drilling Department Dolly Varden Well D-47 ESP Conversion Daily Summary 2/20/03 Skid rig to the D-47 slot. R/D the flow lines and N/D tree. N/U BOPE and start to test. 2/21/03 Continue testing BOPE to 250/3000 psi OK. M/U landing joint and unseat tubing hanger and work pipe attempting to pull seal assembly out of packer - unable to do so. R/U E-Line and RIH with tubing cutter. Fire cutter at 10,682'. POOH. 2/22/O3 Finish out of hole and R/D E-Line. Work pipe and pull and L/D 4-1/2" tubing. 2/23/03 Finish pulling tubing out of hole with seal assembly. Note: The tubing cutter didn't sever the tubing but had the effect of jarring the seal assembly loose. M/U 9-5/8" packer milling BHA. 2/24/O3 RIH with packer milling BHA on 5" drill pipe. Mill on packer while circulating 3% KCL brine (8.6 ppg) at 10,706'. Twisted off drill string at 260'. 2/25/O3 M/U overshot to engage drill pipe tool joint.fish. Engage fish and perform string shot back off at 513' leaving box looking up. RIH and screw into the box and recover drill string. 2/26/03 Continue pulling out of hole checking drill string for over torqued connections. M/U new packer milling BHA and RIH. 2/27/O3 Mill on packer at 10,720'. POOH with no recovery. M/U spear to catch packer and RIH. 2/28/O3 Engage packer and POOH with full packer fish recovery. M/U storm packer and set same at 1,438'. 3/1/03 Release from storm packer and POOH. N/D BOPE and tubh~§~6'ol.' N/1Zl-~'~bing spool and N/U BOPE. SCANNED 0 5 200] Unocal Alaska Business Unit Drilling Department Dolly Varden Well D-47 ESP Conversion Daily Summary (Continued) Page 2 3/2/03 Test tubing spool and BOPE to 250/3000 psi OK. Recover storm packer. M/U clean-out BHA and RIH to 10,902' while circulating 3% KCL (8.6 ppg) brine. 3/3/03 POOH. M/U TCP gun assembly and RIH. Correlate with E-Line. 3/4/03 Drop the bar and perforate G-2, G-3 and G-4 zones. L/D TCP assembly and R/U to run ESP. Circulate the well clean and POOH. 3/5/O3 M/U ESP assembly and RIH on 4-1/2" tubing. 3/6/O3 Continue running ESP assembly. P/U tubing hanger. 3/7/O3 Land and test tubing hanger. N/D BOPE and N/U and test tree. Release rig. T nical Schematic Dolly Varden Platforrn, D-47 last revised 4/25/03 by Diane Dunham, Unocal Alaska RKB to TBG Head = 106.90' Tree Connection: 4-1/6" 5,000# Casing and Tubing Detail SIZE WT GRADE CONN ID TOP BTM. 16" 102 X-56 14.688 Surf. 3,305' 9-5/8" 40, 43.5, 47 N-80 & P-110 Butt LT&C 8.681 Surf 10,978' 7" 29 N-80 Butt LT&C 6.184 10,746 11,925' Tubing: 4-1/2" 12.6 L-80 Mod. Butt. 3.958 0' 10,411' Jewelry No. D'epth ID Item 41' 4-1/2' CIW Tubing hanger. I 2,492' 3.958 4-1/2 MMM w/16 port 2 3,972' 3.833 4-1/2 MMM w/20 port 3 5,065' 3.833 4-1/2 MMM w/20 port 4 5,960' 3.833 4-1/2 MMM w/24 port 5 6,499' 3.833 4-1/2 MMM w/24 port 6 7,007' 3.833 4-1/2 MMM w/24 port 7 7,482' 3.833 4-1/2 MMM w/24 port 8 7,961' 3.833 4-1/2 MMM w/32 port 9 10,411 3.813 X Nipple 10 10,413' N/A Centrilift ESP Assembly (end of Assembly = 10,500') G-3 G-4 B-1 i PBTD @ 11,834' TD @ 11,930' Max Hole Angle = 48 degrees G-2 Fill Tagged w/a 3.5" GR 08/25/01 @ 11,383' SLM Fish: 16 foot Energjet Strip Gun. 07~07~96 @ 10,735' 07~09/96 Fish: Hydroblaster from CTCO in 97 02/03/03 Perforations Zone TOP BTM AMT SPF DATE G-2 10704 10724 20' 6 4-5/8" TCP 4 Mar 03 G-3 10760 10790 30' 6 4-5/8" TCP 4 Mar 03 G-4 10816 10866 50' 6 4-5/8' TCP 4 Mar 03 B-1 11,180' 11,220' 100' 6 4/22/1991 B-3 11,340 11,425 85' 6 5/20/91 & 7/7/96 B-4 11400 ~ ~tl,47~0, 70'~ ......... 6 7/1/1995 RE: D-47 Subject: RE: D-47 Date: Fri, 14 Feb 2003 09:39:09 -0800 From: "Mosley, Jim I" <mosleyj@unocal.com> To: "'Tom Maunder'" <tom_maunder@admin.state.ak.us> Good eyeballs sir. Thanks, ..... Original Message ..... From: Tom Maunder [mailto:tom maunder~admin.state.ak.us] Sent: Friday, February 14, 2003 6:38 AM To: Jim Mosley Subject: D-47 Morning Jim, I did get your procedure. Very complete. Just a few questions. 1--Would you check the APl number. I show 733-20195-02.2--You indicate cleaning out to PBTD, but your new drawing shows the fill/fish still remaining. An existing drawing would be nice to have. 3--I know you want to achieve underbalance to shoot. Is it 1500 psi on the Hemlock or the G?? The depths and numbers you give didn't compute. Thanks. Talk to you later. Tom 1[--~D-47 ESP Cony WO Proc.doc Name: D-47 ESP Cony WO Proc.doc Type: WINWORD File (application/msword) Encoding: base64 I--~ 10403 Sundry Notice.xls 10403 Sundry Notice.xls Name: Microsoft Excel Worksheet (application/vnd.ms-excel) l Type: Encoding: base64 SCANNED MAR ! 0 2003 1 of I 2/14/2003 8:49 AM DATE: TO: FROM: SUBJECT: 10 Feb, 03 Mr. Tom Maunder P.E. Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission Tom Maunder~admin.state.ak.us Jim Mosley Advising Drilling Engineer Unocal MosleyJ~l Jnocal.com Workover Conversion to ESP for Dolly Varden D-47 Tom~ Unocal would like to convert the Dolly Varden D-47 well from Gas Lift to Electric Submersible Pump. In the process we will eliminate the down hole packer and the subsurface safety valve. At the present time the D-47 well is a Hemlock only producer. We intend to add "G" zone perforations as per the attached program. I have enclosed the proposed work over program, the BOP schematic, an existing well bore schematic, a proposed well bore schematic, and a waiver request letter for completing without a SCSSSV and without a packer. The well has a documented no flow filed with your office. We will perform the NO FLOW test again shortly after completing the well with the additional perforations in the "G" zone. Please find the enclosed Form 10403 requesting permission to perform this work. Should you need additional information, please do not hesitate to contact me at 263-7679. Sincerely, ~F)O ~' Jim Mosley PE Sr Advising Drilling Engineer Unocal Alaska CC: Well File, J.I.M. RECEIVED o 2003 iklaska 0ii & Gas Cons. C01itinissi0n Anchorage Page 1 of 1 02/10/03 " .' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: No Flow, Install ESP 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X RT above MSL 106 feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well number Dolly Varden Platform, Leg A-2, Cond #8, 748' FSL, 1130' FWL, Sec 6-8N-13W-SM Dolly Varden D-47 9. Permit number 91-11 10. APl number 50- 733-2~'~0'1~ B'f~L~.5-O'~ 11. Field/Pool McArthur River/Hemlock Pool 12. Present well condition summary Total depth: measured 11,930' feet true vertical 9,884' feet Effective depth: measured 11,383' feet Tagged Fill (measured) true vertical 9,411' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 3305' 16" 3305' 2,947' Intermediate 10,987' 9-5/8" 1900 sx 10,987' 9,052' Production Liner 1179' 7" 400 sx 11,925' 9,880' Perforation depth: measured 11,180'- 11,220'; 11,340'- 11,470' true vertical 9,220' - ...................................................................... 9,483' Tubing (size, grade, and measured depth) 4-1/2" 12.6~ ppf L-80, mod btc, 10,799' Packers and SSSV (type and measured depth) Baker SB-3A H 9-5~8" Pkr @ 10,712' & Camco 4-1/2" TRDP-4A SCSSV @ 322' 13. Attachments Description summary of proposal: X Detailed operations program: X BOP sketch: X__ 14. Estimated date for commencing operation 15. Status of well classification as: 3~22~2003 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: ESP Conversion 17. I hereby l~ertify that the foregoing is true and correct to the best of my knowledge. Signed: ~ Jim Mosley Title: Sr Advising Drilling Engineer Date: 2/10/2003 FOR COMMISSION USE ONLY Conditions o~' approval: Notify Commission so represe~n[:ative may witness '~ ~} (~ t"~.~'\ ~'~i..~ ~) ~--~,.~ ~- IApproval No. Plug integrity_~_ BOP Test ~ Location cleara0ce ~'' - ' ~, ~.= .~,,1~ , ~ ~ ~ ~-~ Mechanical Integrity Test__ ,.~u~)seque~'~rm required 10- ~-~(~).~'~, H t il b ! V ~ L~ ORIGINAL SI~ ~ Approved by order of the Commissioner ~ L. ~ Commissioner Form 10-403 Rev 06/15/88 RBDMS BF L AFE #149470 SUBMIT IN TRIPLICATE Dolly Varden D-47RD Workover to Add G-Zone Perfs & Convert to ESP Unocal Alaska requests Sundry Approval to add G-zone perforations to the existing Hemlock perforations during the upcoming ESP conversion workover of Dolly Varden Well D-47RD. Specifically, Unocal Alaska requests permission to run a 4 %" ESP completion without a; 1. subsurface safety valve (20 ACC 25.265) 2. production packer (20 ACC 25.200). Justification: 1. The current gas lifted Hemlock completion passed a No-Flow test on Sept 5, 2001. 2. The G-Zone is known to be partially depleted and is expected to be a thief zone with a SIBHP of 2595 psi at -8850'SS. The well is expected to produce _+7000 BFPD with a high watercut (+/- 90 to 95%) after the ESP is installed. Therefore, reservoir pressure in the vicinity of the subject wellbore is predicted to decline, thus the potential for unassisted flow is predicted to decrease. UNOCALe (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 TABLE OF CONTENTS OBJECTIVE ................................................................................................................................................................. 3 WELL HISTORY & STATUS ...................................................................................................................................... 3 SPECIAL HAZARDS ................................................................................................................................................... 6 WELLHEAD CONDITION .......................................................................................................................................... 6 WELLHEAD DRAWING ............................................................................................................................................. 7 PRE-WORKOVER PREPARATION ........................................................................................................................... 8 SOP'S, QAQC, SIMOPS, H2S CONTINGENCY PLAN, MOC DOCUMENTS ........................................................ 9 WORKOVER PROCEDURE ....................................................................................................................................... 9 BOPE SCHEMATIC ................................................................................................................................................... 10 FISH EXISTING COMPLETION .............................................................................................................................. 11 D-47 DPC PERFORATING PROCEDURE ............................................................................................................... 13 RUN ESP ASSEMBLY .............................................................................................................. 17 PROPOSED WELLBORE SCHEMATIC .................................................................................................................. 17 GAS LIFT DESIGN .................................................................................................................................................... 19 ESP CONFIGURATION ............................................................................................................................................ 22 D-47 ESP Conv WO Proc.doc 2 02/10/03 UNOCAL (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 OBJECTIVE Recover the original gas lift completion, change tubing head spool, TCP perforate the G-Zone, and install a new tubing string with Gas Lift Valves and ESP. WELL HISTORY & STATUS Well D-47 was completed in 1991 and is one of the newer wells on the platform. It has been perforated numerous times and has a history of having fish and fill in the hole. Coiled Tubing work done in 1997 experienced a lot of stuck coil events. Although the CTCO was completed without adding any fish to the well, there are several fish in the rathole below the packer. Slickline work indicates that the tubing is relatively free of scale. A 3.7" Guage Ring was run in the well to 1120' and stopped in January of this year. A 3.5" GR was run to 11240' with out difficulty. A DB 6 Lock is set in the SCSSSV and must be pulled prior to doing any wireline work. This DB6 lock has a history of getting scaled in, however, it was pulled recently and reran after the slickline work was done. Additional well information on perfioration history and current condition of the well are as follows: SIGNIFICANT EVENTS IN THE HISTORY OF DOLLY VARDEN WELL D-47 ITEM MD SAND TVD DATE GUN SPF INTERVAL INTERVAL SHOT SIZE PERF # 1 11180-11220 HB-1 9228-9264 04/22/91 3-3/8 6 PERF # 1 11340-11398 HB-3 9372-9423 04/22/91 RePerf # 2 11370-11398 HB-3 08/31/91 3-3/8 6 RePerf # 2 11340-11370 HB-3 08/31/91 3-3/8 6 RePerf # 2 11210-11220 H B- 1 9228-9264 06/06/92 3-3/8 6 RePerf # 2 11190-11210 HB-1 06/06/92 3-3/8 6 RePerf# 3 11210-11220 HB-1 10/17/92 3-3/8 6 RePerf # 3 11190-11210 HB-1 10/17/92 3-3/8 6 RePerf # 4 11200-11210 HB-1 01/24/93 3-3/8 6 RePerf # 4 11180-11200 HB-1 01/24/93 3-3/8 6 RePerf # 5 11190-11220 HB-1 09/20/93 3-3/8 6 TAGGED FILL (~ 11567 With Slickline 05-31-94 RePerf # 3 11340-11398 HB-3 06/05/94 2-1/8 4 RePerf # 6 11180-11220 HB-1 07/01/95 3-3/8 6 RePerf # 4 11340-11380 HB-3 07/01/95 3-3/8 6 PERF # I 11400-11470 HB-4 07/05/95 3-3/8 6 TAGGED FILL ~ 11483 With Slickline 06/07-96 RePerf # 5 11425-11391 HB-3 07/06/96 2-1/8 4 D-47 ESP Conv WO Proc.doc 3 02/10/03 UNOCAL (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 RePerf#5 111356-11340 IHB-3 I 107/06/96 12-1/8 14 TAGGED FILL ~ 11426 With Slickline 07/06/96 TAGGED FILL ~ 11334 With Slickline 05/18/97 using a 3.5" GR. I I I I I I CTCO Cleaned out Well in February of 97 To a Depth of 11438'. A Hydro-blaster was lost in the well at this time. It is in the rathole at the present time. Ran TDT Log from 11300' to 10400'. 20 May 97 RePerf # 7 11198-11222 HB-1 05/20/97 3-3/8 6 RePerf # 7 11178-11198 HB-1 06/05/97 2.5" HC 6 PERF # 1 11250-11265 HB-2 04/02/98 3-3/8 6 PERF # 1 11290-11310 HB-2 04/02/98 3-3/8 6 PERF # 1 11205-11225 HB-2 04/02/98 3-3/8 6 RePerf # 8 11185-11205 HB-1 04/02/98 3-3/8 6 RePerf # 8 11175-11185 HB-1 04/02/98 3-3/8 6 Tagged Fill at 11429' with 3.5" GR 1/31/98 but had tight spots in Tubing ~ GLM's Tagged Fill with 3.5" GR at 10420' 2/2/98. Ran 2.875" Dummy Gun to 10350' ok. Tagged Fill @ 11355' With Slickline 03/02/99 using 3.0" GR RePerf # 2 11280-11310 HB-2 03/15/99 2-7/8 6 RePerf # 2 11250-11265 H B-2 03/15/99 2-7/8 6 RePerf # 2 11175-11225 HB-2 03/15/99 2-7/8 6 Ran 3.75" GR to 10787' "XN" tubing nipple 01/15/00 Ran 2.54 GR to 11395' and tagged Fill 01/16/00 Ran 3.5" GR to 11383' and Tagged Fill 08/25/01 Ran 1.25" Gauges to 11350' 3/3/02 Had lots of trouble with DB 6 Lock in May 02. Pulled DB lock with Braided line and lots of trouble 07/15/02 ReRan DB6 Lock on Slickline to 325' on 07/18/02 Pulled and Reran again on slickline on 08/27/02 Ran 1.9" Swedge to 10800' and POOH 11/16/02 The well has been perforated numerous times and has a long history of obtaining more production after the reperforations have been made. The increases generally have lasted some 6 months or so. The CTU Clean Out done in 1997 experienced stuck coil several times. Other than scaling, it is thought that the casing and tubing on this well are in fair shape considering that the well was installed in 1991. Slickline operations have had the unfortunate experience of having great difficulty with the DB-6 Lock presently run the Camco TRDP-4A SCSSSV. The ID through this lock is 2.13". In the past the lock was removed only after fighting the setting and removal process. Braided line was required during the last two times that the DB6 Lock was D-47 ESP Cony WO Proc.doc 4 02/10/03 UNOCALe (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 run. Apparently, Scale is a significant problem in this well and has been throughout the wells life. There are numerous documentations of restrictions in the tubing. Most notably, is the use of smaller guns during several of the reperforation jobs. The tubing was blasted clean and the well cleaned out during 1997 via coiled tubing. During this job, numerous stuck Coil incidents occurred including losing a HydroBlaster down hole. It is recommended that the DB lock be left in the tubing string and that any anticipated wire line work be conducted first via string shot and back off below the SCSSSV in order to remove this tubing ID restriction. The current tubing scale condition is such that a Chemical cutter run is unlikely to be successful because of reduced ID and scale in the tubing. This reduced ID could preclude the use of a jet cutter as well. A series of slickline work will be done to determine if a jet cutter or chemical cutter can be used on the well. Summary on Existing Perforations HB-1 Shot 8 times HB-2 Shot Twice HB-3 Shot 5 Time HB-4 - Shot one time only/ The ESP justification includes shooting the "G" intervals. The assumptions in the economics of this ESP installation assume that some 30% of the oil will come from the "G" zones. There is not an openhole log on the interval across the "G" Zones. The below perforation intervals have been picked using a TDT log that was run in 1997. These intervals will be added via TCP guns after the packer is fished from the well. Proposed Perforations "G" -2 From 10704 to 10724' for a Gross 20' "G" - 3 From 10760 to 10790' for a Gross 30' "G"-4 From 10816 to 10866' for a Gross 50' All of the above additional proposed perforations are measured from TDT log Run 20 May 97. The Hemlock currently produces approximately 3200 BFPD with a 95% watercut (177 BOPD) on gas lift. Currently, there are no G-zone perforations. One objective of this workover is under-balanced TCP of the G-zone, for commingled Hemlock/G-zone ESP production in the range of 7000-9000 BFPD. The reservoir pressure of the Hemlock and G-zone are estimated to be 3841 psi at - 9350' SS and 2595 psi at -8850' SS, respectively. The pressure gradients are estimated to be _+0.40 and _+0.29 psi/ft BRT, respectively. However, the pressures and gradients in each sub-layer are not likely to be uniform. Since the G-zone has not been produced at this location, it is possible that the G-zone could have a relatively high oil- cut with higher than expected O/VV and GOR ratios. D-47 ESP Cony WO Proc.doc 5 02/10/03 UNOCALe (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 SPECIAL HAZARDS The mixture of produced gas and gas lift gas coming from well D-47 has an H2S concentration of around 600 ppm. The Dolly Varden Platform is designated as an H2S facility. The site-specific Dolly Varden H2S Drilling & Workover H2S Contingency Plan should be reviewed during the pre-spud meeting. NORM contamination may be present on Well Components. Sealing thread protectors will be utilized on the used tubing, and wooden boxes will be available to transport joints having corrosion holes, to prevent spills. A No-Flow Test was witnessed by the AOGCC in Sept 2001. The typical result of the NOFLOW tests is that the AOGCC will give approval to produce without a SSSV or packer. This No-Flow Test will no longer be valid once the G-zone perforations are added. Extra care should be taken to maintain a fluid level and monitor the well after perforating the G-zone. The G-Zone is known to be partially depleted and is expected to be a thief zone with a SlBHP of 2595 psi at -8850'SS. The well is expected to produce _+7000 BFPD with a high watercut (+/- 95%) after the ESP is installed. Due to the much higher production rate, the reservoir pressure in the vicinity of the subject wellbore is expected to continue to decline, thereby reducing the available reservoir energy and the potential for unassisted flow. WELLHEAD CONDITION Tubing Hanger: 11", CIW, FBB 4-1/2" Armco Seal Lock Threads with CIW 4" Type H BPV Profile Tested to 5000 PSI. Held OK Tubing Spool: Type F CIW 13-5/8", 3M by 11", 5M Casing XO Seal: 13-5/8" 3M by 16-3/4", 3M DSAF Pumped approximately 2 gallons of oil and was able to pressure void to 1200 PSI. The void then bled off to 300 PSI very quickly. Injected plastic into XO Seal, tested again with same results. It appears that the XO seal is holding and the test fluid is going past the primary seal on top of the casing hanger. We came to this determination due to the fact that we were not able to maintain gas lift pressure in the void with our test fluid. This tree is the same as the others and we will have to address the trim issues. The tubing spool will be removed and probably replaced during the workover. At a minimum the casing slab seals will be replaced. Casing Spool: CIW Type WF 16-3/4", 3M by 16", 3M SOW with 9-5/8" Casing and Slips in Place. D-47 ESP Conv WO Proc.doc 6 02/10/03 UNOCALe (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 WELLHEAD DRAWING Dolly Varden D-47 Swab 4 1116" 5M Tree, Block 11" 5M x 4 1116" DBL MSTR X 3 118" Wing x 4 1116" 5M STD Tubing Hanger, ClW FBB, 11' x 4 %" Armco Sealock Top & BTM, 4' CIW H BPV prep for control line, Tubing Spool, CIW Model F, 13 5/8" 3M x 11" 5M WI2-2 1116" 5M outlets ~ DSA 16 %" 3M x 13 518' 31~ Casing head CIW WF 16 ~/~" 3M x 16" SOW With 2 2" LP outlets 9 518" 3 %" D-47 ESP Conv WO Proc.doc 7 02/10/03 UNOCALe (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 PRE-WORKOVER PREPARATION Production Four days prior to skidding rig, shut off gas lift gas and slowly bleed casing to 0 psi. After 9 5/8" pressure is 0 psi, bleed 13 3/8" casing to 0 psi and monitor build up rate. It is recommended that injection wells D-34, D-45, D-9 & D-1 be shut-in approximately one week prior to nippling down the X-mas tree. Slickline Work Recent slickline work was done to confirm that the tubing was open and free of serious obstructions. A 3.6" guage rign was run to the end of the tubing in January of 2003. The DB6 SCSSSV lock was rerun and is in the well. The DB6 Lock has a small ID and will need to be pulled if cutting tools are required. Plan to use the specially made Pollard tool to hold open the SCSSSV if slickline or Eline work becomes necessary. Centriliff All Centrilift supplied equipment, including all of the primary and back-up ESP equipment, all required protectolizers, flat cable guard, flat cable, centralizer and anode, should be pre-assembled at Centrilift's Anchorage warehouse and fit tested prior to load out. The pre-assembly should be verified at least ten days prior to shipment to the well site. The work over is scheduled to start February 21st. The back-up and primary equipment should then be clearly labeled, disassembled into convenient sections (which can be handled safely and without risk of damage), and loaded into the aluminum transport basket. The back-up equipment should be placed on bottom and the primary equipment of top, to avoid confusion on-site. The fully loaded basket should be available at OSK at least one week prior to the start of operations to allow convenient shipping of the equipment offshore without an extra dock worker call-out. When the equipment arrives offshore, it should be preassembled and hung in the derrick prior to the beginning of the work over. It is suggested that the ESP equipment be hung during the well kill and circulate time frame. Prior to starting the work over, the X-mas tree and the tubing head spool bolts should be worked (or replaced one at a time) to minimize the risk of critical path downtime. The lock down pins should also be worked. D-47 ESP Cony WO Proc.doc 8 02/10/03 UNOCAL (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 SOP'S, QAQC, SIMOPS, H2S CONTINGENCY PLAN, MOC DOCUMENTS The following Unocal Alaska Drilling Department Standard Operating Procedures have been prepared to minimize HES risks, streamline operations and ensure job quality. The Drilling Foreman must verify compliance with the following documents pertaining to ESP workovers: 1. SPS 7.24 Simultaneous Operation Policy & Checklist 2. Management of Change (MOC) For Drilling Operations Procedure A.) MOC Form 5 Unexpected Change or Occurrence at the Well Site Checklist (if required) B.) MOC Form 6 ESP Workover Checklist 3. SPS 7.11 H2S & the Unocal Alaska Drilling Department's Site-Specific H2S Contingency Plan for the Dolly Varden Platform ESP QAQC Checklist Drilling Dept. SOP - ESP Workover Pre-Rig Arrival Procedure Drilling Dept. SOP - ESP Workover Pill Setting Procedure Drilling Dept. SOP - ESP Workover Rig Startup Procedure Drilling Dept. SOP - ESP Workover NU BOPE Procedure Workover Tripping Pipe & Cable Procedure Workover Emergency Shut-In Procedure 5. 6. 7. 8. 9. Drilling Dept. SOP - ESP 10. Drilling Dept. SOP- ESP WORKOVER PROCEDURE 1. Mobilize crews & activate rig as per Standard Operating Guideline - ESP Workover Rig Startup Procedure. 2. Skid over & prep well D-47 as per Standard Operating Procedure - ESP Workover Pre-Rig Arrival Procedure. Note: The well should be bled to 0 psi & confirmed dead prior to ND/NU operations. Bull head kill the well at 4 BPM down the tubing and fill the annulus as necessary with 3% KCL water. If the tubing has hole in it, then be prepared to circulate hydrocarbons out of well w/3% KCI. Take returns to the production separators. If well will bullhead kill without circulating, then plan to lubricate the annulus full of fluid prior to nippling down. Determine loss rate to Hemlock perfs. If loss rate is manageable, no CaCO3 LCM pill will be spotted at this stage. 3. Install 4" Type "H" BPV. NU & test 13 5/8" 5m BOPE to 250/3000 psi as per attached diagram & as per Standard Operating Procedure - ESP Workover NU BOPE Procedure. SEE BOPE SCHEMATIC ON FOLLOWING PAGE. Once BOPE is nippled up, remove BPV and install two way check. Test BOPE. SCANNED, ~I~ ~ 0 2003 D-47 ESP Conv WO Proc.doc 9 02/10/03 UHOC&L (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 BOPE SCHEMATIC Dolly Varden Stack up D -17 of Rotar Table A 41116' SM Foster HCR Valve B 41116' 5M Manual gate valve C 31116" 5M Manual gate KiHline D 31/16# 5M Manual gate Kill line Btm of Trolly beam 17' 23' 1.15 Top of drill deck 1860 to tbg spool 20 spacer spool 20 spacer spool 1.5' 13 5/8" x 11' xo spool D-47 ESP Cony WO Proc.doc 10 02/10/03 UNOCAL (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 Note: Although only a 3m double ram configuration is required, a 13 5~8" 5m triple ram stack will be utilized, with a 3000 psi test (refer to diagram). Make certain Sundry Notice is approved prior to starting to nipple down and perform subsequent well work. FISH EXISTING COMPLETION 4. Verify that the landing joint crossover ID will swallow the BPV after it is installed in the tubing hanger such that full tubing make up can be effected on the tubing hanger. Install landing joint with TIW valve. 5. Verify well dead. If the tubing proved to have integrity, then plan to try and pull the seals out of the packer. If the tubing had obvious holes, then the tubing integrity will be highly suspect and the weight of the tubing should be picked up and cuts made above the packer. Discuss options with drilling Supt. Pick up on the tubing hanger and attempt to pull seal assembly out of packer. Note: Do not exceed 50% of tubing yield strength without first discussing with Superintendent. If seal assembly comes loose, jump to step # 9. 6. If necessary to cut tubing, pull 30k over string weight and set slips. RU & test APRS lubricator on top of landing joint & full opening TIW valve made for the Tubing ID. RIH w/3.6" jet cutter and SCSSSV Hold Open Device and cut 4 W' tubing in middle of first full exposed joint above packer. Pooh and RD APRS E-line unit. 7. Circulate bottoms up (long way) to ensure well free of oil. POH & L/D 4 ~" gas lift completion. Note: Check for NORM while POH as per attached guidelines. Install sealing thread protectors. If NORM above maximum guideline detected, seal joints with corrosion holes in crates. Note: Send in Gas Lift Mandrels and/or pup joints for possible refurbishment. catch tubing stub and attempt to jar same out of hole. BHA#1: 8 1/8" 150 Overshot w/Double Bowl wi4¼ Grapple & MCP 8 1/8" Top Extension 6 1/4" OD Bowen Bumper Jar 6 1/4" OD Bowen Oil Jar 6 1/4" Drill Collars If tbg was jet cut, RIH w/BHA and 5" drill pipe as recommended by Baker to 11 02/10/03 12 D-47 ESP Conv WO Proc.doc UNOCALe (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 T.I.H. to top of tubing stub. Establish all up, down, and rotating weights. Engage fish with O'shot and jar seals lose at the packer. Note: It will be necessary to dress flared jet-cut tbg stub before overshot can engage tubing stub. 9. Pull out of hole with tubing stub and seal assembly. Lay down overshot and prepare to burn over packer. Note: When seal assembly was recovered from packer with tubing. RIH w/BHA # 2 as per Baker recommendation and burn over packer. BHA#2 3 12 8 1/2" MM Mill w/4 ¼ PRT Spear w/4 % Grapple w/5.3' of Ext. Tripple Conn. Sub 7" OD Boot Collar Baskets 4 1/2" Reg Box x 4 1/2" IF Box Sub 6 1/4" OD Bowen Bumper Jar 6 1/4" OD Bowen Oil Jar 186 1/4" OD Drill Collars 6 1/4" OD Bowen Acc Jar T.I.H to top of Packer, establish all string weights before milling packer. Mill packer per standard BOT packer milling procedures. After packer drops, circulate bottoms up to remove any trapped gas. POOH w/packer. 10. Lay down packer and fishing tools. Pick up 8-1/2" Bit, 8-1/2" string mill and boot baskets. RIH and clean out to PBTD. Note that there are fish in the hole. Pull out of hole and lay down all excess tools. 11. M/U hurricane plug (Baker Retriev-a-matic w/storm valve on top) on top of fishing string. RIH to 2000'. Set packer. Pressure test above packer to 1250 psi. 12. ND BOPs & remove tubing spool. Change out DSAF for DSPO. Reinstall the tubing head spool or install replacement tubing spool as needed. NU & test BOPE. Recover storm packer. Note: Confirm preferred final orientation of tubing hanger, casing valve and ESP cable (wi respect to gas lift gas inlet) with Production Foreman before installing the new oriented tubing head. 13. M/U & RI H w/Halliburton TCP assembly & champ packer as per attached TCP diagram to approximate firing depth. Position packer to place guns on depth with drill pipe measurements. Prepare to rig up wireline and run correlation log. Note: Fill D-47 ESP Conv WO Proc.doc 12 02/10/03 UNOCALe (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 tubing while RIH to provide 1500 psi underbalance at G-zone (2595 psi @ -8850' TVDSS). (reference D-47 TDT Log): G-2 10704-10724' G-3 10760-10790' G-4 10816-10866' (80'net, 162'grossinte~al) D-47 DPC PERFORATING PROCEDURE Hold pre job safety meeting with crews before P/U perforating guns. Review H2S risks, spill prevention, and well control. While making up the guns make sure that only essential personnel are present on the rig floor. Radio silence is not required with the Halliburton system described below. While picking up and running the perforating guns and associated tools (firing heads etc.) there should be only essential personnel on the rig floor (driller, floorhands, perforating crew and packer hand). All other personnel will stay off of the dg floor until the perforating equipment is below the rotary table. Perforating guns will be run with hand slips (not air slips). It is imperative that all slip dies be inspected prior to running the guns. (Dies that are dull will tend to let the guns slip and catch causing the charges within to shift and possibly rotate out of the scalloped area of the gun). Use a dog collar on the first 10 guns to go in the hole, along with a safety plate which will be used on all the guns that are run. 4. M/U Perforating assembly in the following order: · · · · · · · · · · · · · · Perforating guns & blanks, as per production specs 4 5/8" 6spf Guns Model liD Bar Drop Firing Head 1 jt. of 2 7/8" EUE 8rd Tubing Bar Pressure Vent 1 jt. of 2 7/8" EUE 8rd Tubing Crossover 2 7/8" EUE 8rd. Pin X 3 W' IF Box 1 Stand of 3 W' Drill Pipe RA Marker Sub Drill Pipe Spacer to above the liner top Below Packer Safety Joint 9 5/8" Champ IV Packer Big John Jars Drill Pipe to Surface ;~CANNEb ~AR ~i 0 2003 D-47 E SP Conv WO Proc.doc 13 02/10/03 UNOCALe (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 Notes: Halliburton will provide BHA detail diagram. Big John Jars will be clamped in the un-cocked position to prevent the possibility of cocking the jars while making them up in the tool string. Caliper all tool lengths and OD's. Note drift of the casing. Ensure that the packer setting depth will not be in an area that exceeds 70° of inclination or an area of high dogleg severity. RIH filling the drill pipe from the top to a designated depth of 2000 ft. Ensure the pipe is full at this point and continue in the hole with dry pipe to achieve the calculated under-balance pressure of 1500-psi. Position Perforation assembly by logging on depth, and picking up to place the guns on depth. Caution: Be aware of the Bar Pressure Vent during e-line operations. 7. Set the Champ IV packer with 1/4 turn (at the tool) to the right, and 20K down weight. 8. R/U the head pin & surface equipment with the ability to reverse to the rig pit system, and pressure test all surface lines to 3000-psi. Test annulus to 500 psi. Prepare to drop the bar to activate the bar pressure vent and fire the guns. Caution: In the event that there is not a good indication of the guns firing, then it is recommended that the bar be fished with slick line. This procedure is recommended to prevent inadvertently shooting the guns off depth when pulled off bottom. 10. Monitor the guns firing by a sound recorder, or blow in the bubble bucket. 11. P/U & strip through the annular preventer with 500 psi on the backside to see the packer bypass open, and reverse out. Unseat the packer, monitor well for flow or losses and allow the packer elements to relax prior to pulling out of the hole. 12. Determine rate of losses. If loss rate is manageable, jump to step #14. 13. Circulate 25 bbl CaCO3 down tbg into annulus. Close annular before pill exits tubing and bullhead base of pill to top G-zone perf. Stop pumping and keep hole full. Monitor rate of losses over time. Spot second pill if necessary. Verify loss rate is manageable and circulate hole clean before proceeding with step#14. Note: Do not stop pumping with pill inside tubing to minimize risk of plugging. D-47 ESP Cony WO Proc.doc 14 02/10/03 UNOCAL (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 14. POOH and monitor fill-ups closely, when the first gun is to surface have a short safety meeting reiterating to the crew that the guns could possibly have trapped gas and that extreme caution is needed when breaking connections (especially the blanks between spent guns). 15. LID perforating guns and establish that all guns have fired. If they haven't, then again only essential personnel will be on the rig floor to dismantle the guns. 16. R/D perforating equipment and lay out guns for removal. Inspect and report all shots fired or misfired. D-47 ESP Conv WO Proc.doc 15 02/10/03 (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 'HALL~BU~TON Acc°u.,.... ,-,~c. d 1 ¢907) 275-260~ Ib/~al lt. De~rees Ib/,~al Air 4 5/8" 6spf DP Vann~un 7", 29# 9 5~8", 47# 2 Bi,cI John Jars 2.250 5.000 5.15 8848.65 4 Below Packer Safety Joint 2.250 5.000 11.20 8862.30 12 Safety S~)acer N/A 4.625 2.00 10702.00 ~ 7 14 4 5~8" 6spf DP Vann Guns N/A 4.625 30.00 10760.00 Spacer Gun N/A 4.625 26.00 10790.00 ~ 8 15 4 518" 6spf DP Vann Guns N/A 4.625 50.00 10816.00 10866~65 D47 ESP Conv WO Proc.doc 02/t0/03 UNOCAL (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 RUN ESP ASSEMBLY M/U new ESP assembly as per attached diagram, and in accordance with ESP QA/QC Checklist. PROPOSED WELLBORE SCHEMATIC D-47 ESP Conv WO Proc.doc 17 02/10/03 RI(B tO TBG Head = t06.90' Tree ~onnection: 4-tl6" 5,000~ 2 3 4 5 6 7 8 9 10 12 13 14 16 PBTD = 1t,834' TD = 1t,930' MAX HOLE ANGLE = 48° D47 ESP Conv WO Proc.doc (Version 3) SIZE Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/14/03 CASING AND Ti BING DETAIL WT GIL&DE CONN ID TOP BTM. 16" 102 9-5/8" 40, 43.5, 47 7" 29 Tubing: 4-1/2" 12.6 NO Depth 41 I 322' X-56 14.688 Surf. 3,305' N-80 & P- Butt 8)681 Surf' 10,978' 110 LT&C N-80 Butt 6.184 10,746 11,925' LT&C L-80 Mod. Bun. 3.958 0' 10.799' JEWELRY DETAIl. 4-t/2" CIW Tubing hanger. 3.813 44/2" Cra,nco TRDP-4A SCSSV, 3.813" profile w/DB-6 lock 2 2,187' 3.833 3 3,947' 3.833 4 5,429' 3.833 5 6,562' 3.833 6 7,469' 3.833 7 8,191' 3.833 8 8,874' 3.833 9 9,422' 3.833 10 9,9t6' 3.833 11 10.315' 3.833 12 10,655' 3.833 13 10,712' 4.00 4.00 4.00 14 10,744' 3.813 15 10,78T 3.725 16 10,799' 4.00 (LOCK ID 2.13") 4-1/2' Danials 2A 4-1/2" Danials 2A 4-1/2" Danials 2A 4-1/2" Danials 2A 4-1/2" Danials 2A 4-1/2" Danials 2A 4-1/2" Dania{s 2A 4-1/2" Danials 2A 4-1/2" Danials 2A Mandrel #1 w/ 1.5" side pocket w/RK latch Mandrel #2 w/1.5' side pocket w/RK latch Mandrel #3 w/1.5" side pocket w/RK latch Mandrel #4 w/1.5" side pocke! w/RK latch Mandrel #5 w/1.5" side pocket w/RK latch Mandrel #6 w/t.5" side pocket w/RK latch Mandrel #7 w/1.5" side pocket w/P~ latch Mandrel #8 w/1.5" side pocket w/RK latch Mandrel #9 w/t.5" side pocket w/RK latch 4-1/2" Danials 2A Mandrel #10 w/1.5" side pocket w/RK latch 4-1/2" Danials 2A Mandrel #11 w/1.5" side pocket w/RK latch Baker SB-3A Pkr w/11.5' Seal Assy Crossover sub 6' Millout ext. Otis "X" Nipple, 3.813 Otis "XN' Nipple, 3.8i3 Baker Shearout ball seat w/WL Re-entry Guide EXISTING PERFORATION DATA ZO___ N_[ TOP B-1 11,180' B-3 11,340 B4 11400 BTM AMT SPF DATE 11,220' 40' 6 4/22/91 ll,425 85' 6 5/20/91 & 7/7/96 11470 70' 6 7/1/95 Fill Tagged w/a 3.5" GR 08/25/01 @ 11,383' SLM FISH: 16 foot Energjet Strip Gun Probably left below the packer since later slickline got below packer Fish: Hydroblaster from CTCO in 97 DB6 Lock and sleeve in Camco TRDP SCSSSV 07/07/96 @ 10,735' 07/09/96 Feb 97 In Rat Hole below Tubing Tail 08/27/01 @ 322' WLM 02/14/03 UNOCAL (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 RKB to TBG Head = 106.90' Tree connection: 4-t/6" 5,000~ G2 G3 G4 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 16" 102 X-56 14.688 Surf. 3,305' 9-5/8" 40, 4~.5, N-80 & P- Butt 8.681 Surf 10,978' 47 110 LT&C 7" 29 N-80 Butt 6.184 10,746 11,925' LT&C Tubing: 4-1/2" 12.6 L-80 Mod. Buit. 3.958 0' 10,799' JEWELRY DETAIL NQ. Depth Depth I,~D Item TVD MD 41 41' 4-1/2" CIW Tubing hanger. 1 2,350' 2.492' 3.833 4-l/2" MMM w/16 Port 2 3,400' 3,986' 3.833 4-l/2" MMM w/20 Port 3 4,200' 5,088' 3.833 4-1/2" MMM w/20 Port 4 4,900' 5,960' 3.833 4-1/2" MMM w/24 Port 5 5,350' 6,511' 3.833 4-1/2" MMM w/24 Port 6 5,750" 7,000' 3.833 4-1/2" MMM w/24 Port 7 6,150' 7,489' 3.833 4-1/2" MMM w/24 Port 8 6,550" 7,974' 3.833 4-I/2' MMM w/32 Port 9 10,712' 4.00 Centriliff ESP ASSEMBLY Fill Tagged wi a 3.5" GR 08/25101 @ 11,383' SLM Fish: 16 foot Energjet Strip Gun 07/07/96 @ 10,735' 07/09/96 Below the packer in rathole 07/07/96 In Rat Hole below Fish: Hydrobiaster from CTCO in 97 02/97 Tubing Tail DB6 Lock and sleeve in Camco TRDP SCSSSV 08/27/01 @ 322' WLM EXISTING PERFORATION DATA ZONE T~Y~ BTM AMT SPF DATE B-1 11,180' 11,220' 40' 6 4/22/91 B-3 11,340 11,425 85' 6 5/20/91 & 7/7/96 B-4 11400 11470 70' 6 7/1/95 PROPOSED PERFORATIONDATA ZONE TO~P BTM AMT SP~F DATE G-2 10704 10724 20' 6 TBD G-3 10760 10790 30' 6 TBD G-4 10816 10866 50' 6 TBD D47 ESP Conv WO Proc.doc 18 02/10/03 UNOC&L (Version 1) Dolly Varden Platform Well #D-47 ESP Couversion Workover Procedure 02/06/03 GAS LIFT DESIGN 1000 4000 5000 80 1 O5 Unocal Dolly Varden D-47 Gas Lift Design 1 2-10-02 ESP @ 10500'MD Temperature (degrees F) 130 155 180 Objecth,~ Tubing pre~sure: Q liq = 4500.000 STB/day Temperature: Q liq = 4500.000 STB/day Maximum Ca~ing Prmsum, 1250.000 p~ g Operating Ca~ing Pre.~ure, 1183.840p~g Unloading sequence Design operating va lye Unloading Ca~Jng PressJrgs 6000 7000 8000 9000 o 2~ 1~00 26'00 22'00 24'00 2600 2800 640 8~0 ldO0 12'00 14'00 16'00 Pressure (psig) UNOCAL ) (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 Pollard Wireline PRESSURE VALVE GAS LIFT DESIGN CALCULATIONS CLIENT: UNOCAL FIELD · DolLyVarden WELL # D-47 Dec. 10, 2002 LEASE · VALVE DEPTH DEPTH PORT PD AT Set NO. TVD MD TV SIZE R DPC PT PSC PVC OP PSO 60F PTRO Press 1 2350 2492 149.6 16 0.066 55.6 817 1220 1289 1323 1251 1068 1143 1145 2 3400 3986 157.8 20 0.103 86.8 947 1210 1310 1351 1248 1068 1190.4 1190 3 4200 5088 163.3 20 0.103 109.6 1006 1200 1322 1359 1233 1067 1189.6 1190 4 4900 5960 167.3 24 0.147 129.2 1125 1190 1332 1368 1222 1067 1250.6 1250 5 5350 6511 169.5 24 0.147 141 1150 1180 1334 1365 1208 1064 1247.4 1245 6 5750 7000 171.4 24 0.147 151.3 1153 1170 1334 1365 1197 1061 1243.4 1245 7 6150 7489 173.1 24 0.147 161.6 1153 1160 1334 1365 1187 1057 1239.7 1240 8 6550 7974 174.6 32 174.8 Orifice Valve Orifice Valve 4 1/2" MMM Mandrels from Unocal Stock Max OD: 7.063" Drift ID: 3.833" TV: Temperature of Valve TCF: Temperature Correction Factor R: Ap/Ab PT: Tubing Pressure @ Depth PSC: Closing Pressure at Surface PVC: Closing Pressure at Depth OP: Opening Pressure at Depth PSO: Surface Opening Pressure PD AT F: Bellows Pressure at Base Temperature PTRO: Test Rack Opening Pressure D-47 ESP Cony WO Proc.doc OP= (PVC - PTR)/(1-R) OP= PSO+DPC PVC = PSC + DPC PD AT F = TCF X PVC PTRO= (PDATF)/(I-R) 20 R-2 Pressure Valves RK Latches 02/10/03 UNOCALe (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 CENTRILIFT EQUIPMENT QUOTATION Centrillft 824~ ~,NDLEWOOD PLACE SUITE 102 ' ANCHORAGE, AL,~,SKA 995~7 * (~);)7) 349-3731 DATE 01)1,~2003 Cusla~er: Unocal Oil & Gas Corporation QUOTATION NO. 961103-032~-A Cust~nrer Si~lnalure: Dale: PRESENTED BY Robert de Lon~l AFE or PO Number:. RequeBled Deli~ry Date: 02/*15~0~ CAPACITY TOTAL HEAD FREQUENCY KVA ATFN. Jim Mosl~ 61,81 6'1S4 60.5 557 WELL NAME Doll;y Varden D-47 5925 S478 56 4A~ FIELD NNdE Cook Inlet 4928 4279 48 2-~, LOCATION Dol~ Varden Platform 33 APl PERFS SE'I'rING DEPTH B.H.T. 18S PRIMARY VOLTAGE 41 ~ REQ SURFACE VOLTAGE 4250 REQUIRED KVA Sb'/' 4.5" THREAD AB ~ SURFACE PSI 98 FRICTION LO~i~ T.D.H. 64~1 PUMP STAGES '-~'§"-TYPE '~MODEL '~~r~LENGTH 33 20~ $ 124,808.45 ~PUMP ~ ~ ~ I'~PUMP DS~RG. SERIES 675 MODEL HPD~ LEN~H ~NN. 31 $ 1,147.~ ~G~ 5EPA~TOR 5ERIES NfA MODEL LENGTH ~SE~ SE~ION SERIES 675 MODEL HST3 HLG I"mPOWER~BLE AWG ~O TYPE CEB~ LEN~H ~0,700 ARM~ GALV. ~8~ $ 22a,a73.~ ~F~T C~ 5EEIES 725 TYPE CEE 5 ~ LEN~H 110' ARM~ M~EL 23~ ~ 2.ga3.~ ~PUMP AD~R SERIES MODEL LEN~H ~LOWER POWER CONNECTOR TYPE BIW $KV 1~ AMP PART ~ 61726 ~ $ ZS10~ ~POWER ~EE~THRU M~DREL TYPE BIW 5KVI~ ~P PART · 61ZZ~ '15 ~ 5,~.~g 3~ ~TO ~STA~ D UGHTNINQ ARRE~ / ~V~L~ FE~JENCY CONTROLLER: T~NSFORMERS ~ TYPE ~ PRIMARY T~S SE~N~ff~ T~S : . LESS D IS~UNT 8 2~4,353~ ~SS TR~E-IN ~a~~m=~=am~~=l~U~ ~m~aH=~=~=~zo,'~. ~Ee~ 41,632 ~ Zs?,gB~.67 D-47 ESP Cony WO Proc.doc 21 02/10/03 UHOCAL (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 ESP CONFIGURATION Dolly Varden D-47 D-47 ESP Conv WO Proc.doc 22 wyooo 02/10/03 UNOCALe (Version 1) Dolly Varden Platform Well #D-47 ESP Conversion Workover Procedure 02/06/03 14. RIH w/ESP assembly & refurbished or new SPMs (refer to attached gas lift design & proposed completion schematic) on new 4 W' 12.6 ppf L-80 IBTC x 3 W' 9.2 ppf L-80 IBTC tubing string as per Standard Operating Procedure - ESP Workover Tripping Pipe & Cable Procedure. Position base of ESP between 7815' & 7785' (within 0.50 to 0.61/100' DLS interval). 15. Make up tubing hanger. Splice ESP cable to BIW hangar penetrator pig tail. Make up chemical injection lines to upper check valves and to hanger. Monitor conductivity of the ESP cable while landing hanger in tbg head. Note: Be aware of final ESP cable & hanger orientation with respect to gas lift inlet valve, and work ESP cable & cable clamps to opposite side of tubing near surface if possible, to avoid rotation of hanger and string. 16. Install BPV. ND BOPE & NU X-mas tree as per Standard Operating Procedure - ESP Workover NU BOPE Procedure. 17. Recover BPV and set TWC valve. Pressure test tree & void area to 3000 psi. Recover two way check. 18. Install flowline and surface facilities & turn well over to Production. The Asset Team will provide a procedure to bring well on-line. Note: Discuss flowback of CaCO3 pills with Production Foreman in advance. Make arrangements with Foreman to inject __2 drums of bleach into flowline during first 6 hours of pump operation to break polymer. D-47 ESP Conv WO Proc.doc 23 ~~[~;0~]~0~ 0 200~ ./ ALASKA OIL ANrD GAS CO~SERYATIO~/COMMISSION~ November 20, 2001 TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 Re: No-Flow Verification TBU Well D-7RD2 TBU Well D-47 Gentlemen: On September 5, 2001 AOGCC Petroleum Inspector Chuck Scheve witnessed "no-flow" tests on Wells D-7RD2 and D-47 at UNOCAL's Dolly Varden Platform, Trading Bay Unit, McArthur River Field. Mr. Scheve arrived on Dolly Varden Platform and observed both wells shut in with 0 tubing pressure. The wells remained SI while safety valve tests were conducted. After several hours, the tubing of each well was opened to atmosphere. No liquid flow was observed and only a slight and diminishing gas flow was noted. The observed performance of TBU wells D-7RD2 (192-155) and D-47 (191-01) demonstrated that the wells are incapable of unassisted flow of hydrocarbons to the surface. Therefore, these wells need not be equipped with a commission approved fail-safe automatic surface-controlled subsurface safety valve ("SSSV") system. However, these wells must be equipped with fail-safe automatic surface safety valve ("SSV") systems capable of preventing uncontrolled flow and maintained in proper working condition. If for any reason any of the wells become capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well files on board Dolly Varden. Sincerely, Thomas E. Maunder, P.E. Sr. Petroleum Engineer ~KA OIL AND GAS CONSERYA~ON COHHISSION September 7, 2001 Dwight Johnson, Superintendent Chris Meyers, Superintendent UNOCAL Field Superintendents 260 Caviar Street Kenai, Alaska 99611 TONY KNOWLES, GOVERNOR 333 W. 7r" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 RE: No-Flow Verifications TBU Well D-7RD2, PTD 192-155 TBU Well D-47, PTD 191-011 Gentlemen:' On September 5, 2001 AOGCC Petroleum Inspector Chuck Scheve witnessed a "no flow tests" on Unocal's Trading Bay Unit Wells D-7RD2 and D-47. Mr. Scheve arrived on Dolly Varden Platform and found the wells shut in and depressurized as requested. While testing the safety valve system the wells remained shut in for several additional hours. When safety valve testing was concluded, each well was opened to atmosphere. Neither well produced any fluid with only a slight but diminishing gas flow noted. Therefore, it is determined; that TBu Well D-7RD2 (PTD 192-155) and TBU Well D-47 (PTD 191-011) need not be equipped with a commission approved fail-safe automatic surface-controlled subsurface safety valve ("SSSV") system. However, the wells must be equipped with fail-safe automatic surface safety valve ("SSV") systems capable of preventing uncontrolled flow and maintained in proper working condition. If for any reason either well becomes capable of unassisted flow of hydrocarbons, the SSS¥ must be returned to service. A coPy of this letter should be maintained in the respective well files on board Dolly. Sincerely Thomas E. Maunder, PE Sr. Petroleum Engineer cc: Bob Fleckenstein TEM:\jjc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor, C~ DATE: Chairman Tom Maunder,. ~J~--~~~\- P. I. Supervisor %~ THRU: FROM: Chuck Scheve, SUBJECT: Petroleum Inspector September 5, 2001 No Flow Trading Bay Unit Dolly Varden Platform D-7RD2, PTD192-155 D-47 PTD 191-011 Wednesday, September 5, 2001: I traveled to Unocal's Dolly Varden Platform and witnessed no-flow tests on wells D-7RD2 and D-47. I arrived on location and found both wells shut in with 0 psi on the tubing. Both were observed for several hours, while testing Safety Valve Systems. The tubing was then opened to atmosphere and observed, no fluid and only a very slight and diminishing gas flow (probably gas breaking out of wellbore fluids) noted. I recommend Wells D-7RD2 and D-47 on the Dolly Varden Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. ,SUMMAR,Y: Wells D-7RD2 and D-47 meet the AOGCC requirements for no flow status. Attachments: X Unclassified Classified Unclassified with Document Removed MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan seamOunt, /'~. Commissioner rT//~cz~ Blair Wondzell, ~ P. I. Supervisor "~ (~I '~ FROM: John Crisp? ~ C. SUBJECT: Petroleum In~gtector DATE' June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due to header valVe leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc .cc; NON'CONFIDENTIAL SVS Dolly Pit. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit~ad: McArthur Ry./Dolly Varde Separator psi: LPS 110 HPS 6/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE D-01 1670800 110 80 85 P 4 OIL D-02ARD 1750380 110 80 65 P 5 OIL D-03RD2 1830810 110 80 80 P P OIL D-04RD 1820410 110 80 80 P P OIL D-05RD 1800650 110 80 100 P P 43 OIL D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P OIL D-11 1680730 110 80 80 P P P OIL D-12RD 1800820 110 · 80 '75 P P 43 OIL D-17RD 1810230 110 80 80[ 'P P 43 OIL D-18 1690040 800 700 700 P P P GAS D-20 1690950 110 80 901 P P OIL D-25RD 1780870 110 80 100 P P OIL D-26RD 1981290 110 80 75 P P * OIL D-27 1750240 110 80 60 P P OIL D-28 1760360 110 80 100 P P OIL D-30RD2 1880980 D-31RD 1760740 110 80 70 P P 43 OIL D-32 1-700370 110 80 75 P P P OIL D-40RD 1820830 110 80 80 P P OIL D-42 1830530 110 80 70 P P OIL' D-43RD 1853110 110 80 70 P P P OIL D-46 1890610 110 80 60 P P P OIL ~} 1910110 110 80 70 P P 9 OIL D-48 1921540 110 801 80 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [-i ~0 ray Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page 1 of 1 SVS Dolly Pit. 6-22-00jc 1 '~. STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COiv, MlSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging ,--- Perforate X Pull tubing After casing Repair well Pull tubing Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory __ 106 KB above MSL feet 3. Address Stratigraphic __ 7. Unit or Property name P.O. BOX 196247 ANCHORAGE, AK 99519 - 6247 Service Trading Bay Unit 4. Location of well at surface Leg A-2 Cond. #8 8. Well number 748' FSL, 1,130' FWL, Sec. 6, T8N, R13W, SM D-47 At top of productive interval I~AL 9. Permit number ec' OR G At effective depth 10. APl number 50-733-20195-02 At total depth 11. Field/Pool 767' FSL, 2,450' FELt Sec. 32, T9N, R13W, SM Hemlock 12. Present well condition summary Total depth: measured 11,930 feet Plugs (measured) None true vertical 9,882 feet Effective depth: measured 11,834 feet Junk (measured) None true vertical 9,805 feet Casing Length Size Cemented Measured depth True vertical depth Structural 398' 33" Exist 398' 398' Conductor 305' 16" Exist 3,305' 2,933' Surface Intermediate 10,978, 9-5/8" 1,900 SX 10,978' 9,042' Production 11,925' 7" 400 SX 11,925' 9,877' Liner Perforation depth: measured B-1 11,180'- 11,220' B-3 11,340' - 11,398' true vertical B-1 9,228' - 9,264' B-3 9,372' - 9,423' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Butt. Tbg w/Mod Butt couplings @ 10,799' Packers and SSSV (type and measured depth) Baker SB-3A Pkr wi11.5' seal assem. 4.0" I.D., 6' millout ext. @ 10,712' 1 ~-.~, ;,,"', ..... 3. Stimulation or cement squeeze summary 'i"::'.~. ti'" Intervals treated (measured) ~ r~ ~.r.~ /.:~t"i, Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Datat.,,~,.,t.,~.-,~:~ ..... ],,~ ~.~, .,.x OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing P,~¢Jt;~ Prior to well operation 709 126 2373 1085 150 Subsequent to operation 395 18 2528 1090 130 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Oper,,ations Oil X Gas Suspended Service 17. I hereby certify that the for~ilc jrt! ~ tr, i~e ~nd ~c~t to the best of my knowledge. Signed G. Russell Schmidt '('~¢-- t~'~''~v''~-~ Title Drilling Manager Date r~.__ 4~'~ A~A ~"~.. ~'~l~_14J~lO~ ~F '~ d~lql ll'liall'~' I1~1 r'lr~l II~r~l I~ A'r'i--' Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL( March 20, 1996 Alaska Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Douglas: Re: Dolly Varden Platform Well D-47 APl Number 50-733-20195-02 On June 6, 1994 the following interval was perforated in Well D-47: BENCH TOP (MD) BOTTOM (MD) FEET HB3 11,340 11,380 40 Very truly yours, G. Russell Schmidt Drilling Manager Attachment ' -' STATE OF ALASKA "-'- ALASKA ~.~IL AND GAS CONSERVATION CC .~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Pull tubing __ Alter casing__ Perforete X Plugging __ Repair well __ Pull tubing __ Other__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 5. Type of Well: Development X Exploratory Stmtigraphic Service Location of well at surface Leg A-2 Cond. #8 DollyVarden Platform 748' FSL, 1,130' FWL. Sec. 6-8N-13W-SM At top of productive interval 506' FSL, 2,169' FEL, Sec. 32-9N-13W-SM At effective depth At total depth 767' FSL, 2,450' FEL, Sec. 32-9N-13W-SM 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-47 9. Permit number/approval number 91-11/93-232 10. APl number 50 -733-20195 -02 11. Field/Pool Hemlock feet 12. Present well condition summary Total depth: measured true vertical 11,930' feet Plugs (measured) None 9,882' feet Effective depth: measured true vertical 11,834' feet Junk (measured) None 9,805' feet Casing Length Structural 398' Conductor 3,305' Surface Intermediate 10,978' Production 11,925' Liner Perforation depth: measured true vertical Size Cemented Measured depth 33" Exist 398' 16" Exist 3,305' 9-5/8" 1,900 sx 10,978' 7" 400 sx 11,925' B-1 11,180'-11,220' MD 9,228'-9,264' TVD B-3 11,340'-11,398' MD 9,372'-9,423' TVD B-4 11,400'-11,470' MD 9,416'-9,478' TVD True vertical depth 398' 2,933' 9,042' 9,877' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Butt. Tbg. w/Mod Butt couplings @ 10,799' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Baker SB-3A Pkr. w/11.5' seal assem. 4.0" I.D. 6' millout ext. @ 10,712' Intervals treated (measured) Treatment description including volumes used and final pressure OCT Alaska Oil & (~as Cor~s. Commission Anchorage 14. Prior to well operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 223 296 879 1,045 Tubing Pressure 130 Subsequent to operation 725 214 4,274 1,081 150 15. Attachments Copies of Logs and Surveys run -- Daily Report of Well Operations __ 16. Status of well classification as: Oil X Gas __ Suspended __ Service 7. I her c~er that ~e~f~¢g,e~ng is tr.,u,p~and correct to the best of my knowledge. Signed/0L' Title Drilling Manager Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Unocal Energy Resourc' WlsIon Unocal Corporation 909 West 9th Avenue, P.O. box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOr. October 5, 1995 Alaska Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Douglas: Re: Dolly Varden Platform Well D-47 APl Number 50-733-20195-02 On July 1, 1995 the following intervals were perforated in Well D-47: BENCH TOP (MD) BOTTOM (MD) FEET HB1 11,180 11,220 40 HB3 11,340 11,380 40 HB4 11,400 11,470 70 TOTAL 150 Attachment Very truly yours, · ¢ Candace Williams oCT 't v i995 Li~l & G~ts Cons. Commission Anchorage Marathon Oil Company Alaska ,ion Domest,u ~roduction P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 10, 1994 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Dolly Varden Platform Well D-47 Dear Mr. Wondzell: Attached for your approval is the AOGCC "Application for Sundry Approvals" to reperforate Dolly Varden Platform Well D-47 HB #1 and #3. Should you have any questions regarding this application, please contact me or Mr. Ed Oberts at (907) 564-6436. L. C. Ibele Operations Engineering Supervisor LCI/EVO/cah Enclosure RECEIVED MAY 2 3 1994 Alaska Oil & Gas Cons. Commission Anchorage H:\wp\Sundry Gas Cons, Commissio~ Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALA~,-,A OIL AND GAS CONSERVATION COMI~,,,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Operation Shutdown__ Re-enter suspended wellm Alter casing Repair well __ Plugging B Time extension Stimulate Change approv'"'~d program__ Pull Tubing__ Variance__ P'-'~rforate__X Othe"~' 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL (Marathon Oil Company - Sub Operator) Development X 106' KB above MSL feet Exploratory ~ 3. Address Stratigraphic m 7. Unit or Property name P.O. Box 196247 Achorage, AK Service~ Trading Bay Unit 4. Location of well at surface Leg A-2 Cond. #8 Dolly Varden Platform 8. Well number 748' FSL, 1,130' FWL, Sec. 6-8N-13W-SM D-47 At top of productive interval 506'FSL, 2,169'FEL, Sec. 32-9,-13W-SM p~CIEiVIE0 9. Permit number/approval number 91-11 At effective depth 10. APl number 1994, 50-733-20195-02 At total depth 767' FSL, 2,450' FEL, Sec. 32-9N-13W-SM A~sk3 [iii & Gas Gonm, I~0mmisst0~ ~' Field/Pool Hemlock 12. Present well condition summary Total Depth: measured 1 1,930' feet Plugs (measured) None true vertical 9,882' feet Effective depth: measured 1 1,834' feet Junk (measured) None true vertical 9,805' feet Casing Length Size Cemented Measured depth True vertical depth Structural 398' 33" Exist 398' 398' Conductor 3,305' 16" Exist 3,305' 2,933' Surface Intermediate 10,978' 9-5/8" 1,900 sx 10,978' 9,042' Production 11,925' 7" 400 SX 11,925' 9,877' Liner Perforation depth: measured B-1 11,180' - 11,220' MD 9,228' - 9,264' TVD B-3 11,340' - 11,398' MD 9,372' - 9,423' TVD true vertical Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Butt. Tbg. w/Mod Butt couplings @ 10,799' Packers and SSSV (type and measured depth) Baker SB-3A Pkrw/11.5' seal assem. 4.0" I.D.. 6' millout ext. @ 10,712' 13. Attachments Description summary of proposal X.~ Detailed operations program ~ BOP sketch Estimated date of commencing operation 15. Status of well classification as: May 22, 1994 If proposal was verbally approved Oil X Gas B Suspended Name of approver Date approved Service 17. I hereby/~e,rtify~at~,~?//the'~r"e"rg°in'~l i~rrect- _(, )0 ~,, 0,,,'"~ to the best of my knowledge. Signed .]~.. !~,~ .,~,~:;;~:~'~ Title'~t ~.,,L.L.t¢,,~C....~. ~'~k~C..~f.~ Date Plug integrity__ BOP Test__ Location clearance__I Mechanical Integrity Test__ Subsequent form required 10- ~ Approved Copy Original Signed By Returned Approved by order of the Commision David W. Johnston £- ~.r../_ ~) c( Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE '~) PROCEDURE DOLLY VARDEN PLATFORM WELL D-47 OBJECTIVE: Reperf HB #1 and #3. 1) Hold operational and safety meeting with platform personnel and service company prior to RU. 2) Lock open TR SCSSV with auxiliary pump on platform and regulate pressure at 4,000 psi. 3) Pressure test BOP's and lub to 2,500 psi. Function test BOPS with 1,500 psi on lub. 4) RU E-Line unit. 5) RIH and reperforate the following intervals underbalanced with 3-3/8" HC, 6 SPF, 60° phase' HB #3 11,345' - 11,365' DIL 20' Existing Zone Test well for 12 hours obtaining water cuts every three (3) hours: Selectively reperforate the following zones. HB #3 11,365' - 11,398' DIL 33' Existing Zone HB #1 11,180' - 11,220' DIL 40' Existing Zone 6) RD E-Line. 5/9/94 EVO h:\wp\Sund~\D-47 MARATHON OIL CDNPANY.-.. TRADING BAY UNIT D-47 16% IOPO X-56 Butt. Csg. @ 3,305' 9-5/8' 40. 43.5, 47~, N-80 8< P-il0 Butt Csg Compteted 4/27/91 A~t measurements cr`e RKB to top o-F equlpment, 41' CIW 4,5* Tbg H(~nger 31?P' Camco 4,5' TRDP-4A SCSSV 3,813" w/ DB-6 took Comptetlon String: 0'-10,799' 4.5' 1P.6~, L-80, Butt -tbs w/ Mod. Buttress Couptings, G(ls LiFt Mandrets (ire 4.5' DanieL's GLM 2A w/l.5' Side pockets, RK Latch, 2,187' 01 3,947' 02 5,429' 03 6,562' ~4 7,469' ~5 8,191' 06 8,874' 07 9,422' 08 9,916' 09 10,315' 010 10,655' 011 TBL 7' @ 10,746' 9-5/8' Cs9 @ 10,978' 7' 29~ N-80 Liner set @ 11,925' B-1 B-3 10,712' 10,744' 10,787' 10,799' Baker SB-BA Pkr. w/ 11.5' sect (lssembty 4.0' I.D. 6' Mit(out ext. BTIS 'X' nlppte 3.813' I.D, BTIS 'XN' nlppte 3.7P5' I.D. Shear'out BoLt Se<it Sub/A/L Re-entr`y guide, (Fracture Stimulated 4/91) Per`¢orations HB 01 11,180'-11,220' (BIL) 6 SPF HB ~:3 11,340'-11,398' 6 SPF Fill @ 11,571' WLM 5/50/92 4/22/91 5/20/91 RECEIVE[) MAY 't 1 1994 Alaska i]11 & Gas Cons. 6ommiss.),~ Anchorage PBTD @ 11,834' TD ~ 11,930' Revision Bate: 10/5/93 Revised By~ JDH/evo Reason: Update Pr`evious Revlslom 8/26/95 DOLLY VARDEN PL,~TFORM Wireline Lubricator w/Associated BOPE - GREASE HEAD (Hydraulically Activated) ,, LUBRICATOR MANUALLY OPERATED BOP · 4':.~z~.S~.'Sooo .~ CHISTMAS TREE POSITIVE CHOKE RECEIVED MAY 11 1994 Ai~ska 0~1 & Gas Cons. Commissior,: Anchorage --~, 2' 5000 _--- 2' 3000 psi 13 3/8' CASING STATE OF ALASKA AL,,~ ~,,-,,A OIL AND GAS CONSERVATION COM~,,,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operations Shutdownm Stimulate__ Plugging__ Perforate ~ Pull Tubing __ Alter Casing __ Repair Well m Otherm 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL (Marathon Oil Company - Sub Operator) Development X__ 106' KB above MSL feet Exploratory 3. Address Stratigraphic m 7. Unit or Property name P.O. Box 196247 Anchorage, AK 99519 Service-- Trading Bay Unit 4. Location of well at surface Leg A-2 Cond. #8 Dolly Varden Platform 8. Well number 748' FSL, 1,130' FWL, Sec. 6-8N-13W-SM D-47 At top of productive interval 9. Permit number/approval number 506' FSL, 2,169' FEL, Sec. 32-9N-13W-SM 91-11 /93-232 At effective depth 10. APl number 50- 733-20195-02 At total depth 11. Field/Pool 767' FSL, 2,450' FEL, Sec. 32-9N-13W-SM Hemlock 12. Present well condition summary Total Depth: measured 1 1,930' feet Plugs (measured) None true vertical 9,882' feet Effective depth: measured 1 1,834' feet Junk (measured) None true vertical 9,805' feet Casing Length Size Cemented Measured depth True vertical depth Structural 398' 33" Exist 398' 398' Conductor 3,305' 16" Exist 3,305' 2,933' Surface Intermediate 10,978' 9-5/8" 1,900 sx 10,978' 9,042' Production 11,925' 7" 400 SX 11,925' 9,877' Liner Perforation depth: measured B-1 11,180' - 11,220' MD 9,228' - 9,264' TVD B-3 11,340' - 11,398' MD 9,372' - 9,423' TVD true vertical Tubing (size; grade, and measured depth) 4-1/2", 12.6#, L-80 Butt. Tbg. w/Mod Butt couplings @ 10,799' Packers and SSSV (type and measured depth)RECEIVED Baker SB-3A Pkrw/11.5' seal assem. 4.0" I.D.. 6' millout ext. @ 10,712' 13. Stimulation orcement squeeze summary DEC ! ( Intervals treated (measured) Atgska Oil & Gas Cons. Commission Anchorage 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 483 ..,..-.~10 2,168 1,080 140 Subsequent to operation 51 I"- 91 2,670 1,160 130 15. Attachments 16. Status of well classification as: Copies of Log and Surveys run Daily Report of Well Operations X Oil X Gas Suspended__ Service Signed /~ . Title X~ (~., [. t,..i,.,/~ ~..~ ('~L,~ ~C...~(~ ~. Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICAT.~ DA~LY ~ELL OPERATZONS D-47 9/19-20/93 RU E-line. PT lub to 2500 psi. Good. RIH w/ 3-7/8" HC, 6 SPF, Flowed well to obtain underbalance and perforated the following: RD. RUN BENCH i HB-1 Returned well to production. DEPTH (DIL) 11,190' - 11,220' 60° phasing. RESULT F i red H: \wp\WE L LOPS\D47 REC£%V£D DEC 1 7 I99~ U~t & Gas Cons. Commission Anchorage STATE OF ALASKA AL,...,A OIL AND GAS CONSERVATION COb .... :SSION APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation shutdown Re-enter suspended well Alter casin"'~ Repair ~ Plugging -- Time extension Stimula-'~' Change appr~'~'ed program__ -- Pull Tubing ~ Variance__ -~rforate X.~ Oth~.__~'~,~ · Type of Request: 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface Leg A-2 Cond. #8 Dolly Varden Platform 748' FSL, 1,130' FWL, Sec. 6-8N-13W-SM At top of productive interval 506' FSL, 2,169' FEL, Sec. 32-9N-13W-SM At effective depth At total depth 767' FSL, 2,450' FEL, Sec. 32-9N-13W-SM 6. Datum elevation (DF or KB)J.~ 106' KB above MSL \ feet Unit or Property name Trading Bay Unit Well number D-47 9. Permit number/approval number 91-11 10. APl number 50- 733-201 95-02 11. Field/Pool Hemlock 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate ~ Production Liner Perforation depth: measured true vertical 11,930' feet Plugs (measured) None 9,882' feet 1 1,834' feet Junk (measured) None 9,805' feet Length Size Cemented Measured depth 398' 33" Exist 398' 3,305' 16" Exist 3,305' 10,978' 9-5/8" 1,900 sx 10,978' 11,925' - 7" 400 sx 11,925' B-1 11,180' - 11,220' MD 9,228' - 9,264' TVD B-3 11,340' - 11,398' MD 9,372' - 9,423' TVD Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Butt. Tbg. w/Mod Butt couplings @ 10,799' 13. P EEEIV£D True vertical depth 398' 2,933' s EP - 199) Packers and SSSV (type and measured depth) A 0il & Gas Cons. Baker SB-3A Pkr w/11.5' seal assem. 4.0" I.D.. 6' millout ext. ~ 10,71LPlaska'n,~hnmna C0m~'tSS't0t~ Attachments Description summary of proposal X~ Detailed operations program ._..' ......... " BOP sketch 9,042' 9,877' Estimated date of commencing operation Sept. 7, 1993 If proposal was verbally approved Name of approver Date approved 15. Statis of well classification as: Oil X Gas Service Suspended 17. to the best of my knowledge. Title %~'~..~,t,.,g (./~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commision Original Signed By David W. Johnston IApproval N.~..~w...' ~,~._=~ ~ Approved Copy Returned Commissioner Date.q/,¢/~.....,__ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE(~ PROCEDURE WELL D-47 · · · · · · Obtain a well test w/ 4 W.C.'s. Test tree valves and ensure operational and holding. Conduct safety/environmental meeting. Ensure adequate lighting for night operations. Skid rig 77 over D-47. Disconnect SCSSV from manifold and lock open SCSSV w/ auxiliary pump at 4000'psi. Monitor control line pressure to ensure pressure does not bleed off. RU E-line unit. HU platform PA in unit. Pressure test lubricator & BOPE to 2500 psi. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify logistic support and establish communication black-out. Re-establish communication black-out when guns are at 1000' when POOH. SI well. RIH w/ 3-3/8" select fire-carrier guns 6 SPF, 60° phasing and perforate the following interval underbalanced. RUN BENCH INTERVAL (DIL) FOOTAGE HB-1 11,190' - 11,220' 30' NOTE: The bottom 10' of the 30' gun will be fired, recorrelation performed and the top 20' of gun fired. Flow well for cleanup approximately 15-20 minutes after perforating each interval. SI well. POOH. RD E-line unit. Return well to production and obtain a 24-hour well test after cleanup. NOTE: Limit shut-in time to absolute minimum to reduce affects on platform production and stabilization period. Previous work on this well {10/92) with prolonged shut-in required several days to stabil i ze. H: \wp\WLPRO\D47 RECEIVED S EP - 1993 Alaska Oil & Gas Cons. Gomm'tss'to~ Anchorago 16', 102# X-56 Butt. Csg. @ 3,305' 9-5/8' 40. 43.5, 47t~, N-80 & P-110 Butt Csg Completed 4/27/91 NARATHBN DIL CDHPANZ., TRADING BAY UNIT D-47 Ali mecsurements one RKB to top oF equipment. 41' CI~ 4.5' Tbg Honger 322' C~mco 4.5' TRDP-4A 3CSSV 3.813' I.D. Comp(etlon String: 0'-]0,799' 4.5' 1P.6t~, L-80, Butt tbg w/ Hod. Buttress Couptings. Cos LiFt Mondpets ope 4.5' D~niet's GLM 2A w/1.5' :Side pockets, RK t~tch. 2,187' 3,947' 5,429' ~3 6,562' 7,469' 8,191' ~6 8,874' q7 9,422' ~8 9,916' 10,315' ~lO ].0,655' ,11 TOL 7' 10,746' 9-5/8' Csg 10,978' 7' 29~ N-80 Linen set @ 11,925' B-1 B-3 lO, 71P' 10,744' 10,787' 10,799' Bo. ken SB-3A Pkr. w/ 115' secit cissemloty 4.0'~ I.D. 6' Mittou-t ex-t. OTIS 'X' nippte ,3.813' I,rj, OTIS 'XN' nippte 3.725' I.D, ?,hecir'out B(l[t ~ecit i~ub/¥/L Re-entry guide. PenFopotions HB ~1 II,180'-ll,E~O' (DIL) HB ~3 11,340'-11,398' 6 SPF 4/22/91 6 3PF 5/~0/91 Fill (~_ l l,jTl WLM 5/30/9°_ ~ PBTD @ 11,834' TD ¢_ 11,930' RECEIVED S E P - 3 t993 Alaska Oil & Gas Cons. comm~sSm~ Anchorag~ Revlsion Dote: 8/26/93 Revised By: AP/evo keelson; New CompLetion Previous Revision: 5/15/91 "~':DOLLY VARDEN ir'~iATFORM .. Wireline Lubricator w/Associated BOPE · GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP · 4"I1.-1.6 "-.-" 5000 psi CHISTMAS TREE POSITIVE CHOKE RE(EIVED S EP - ~ 199,t ~'- Alaska Oil & Gas Cons. GommisSio" Anchorage ~ 2' 5000 psi _-- 2' 3000 pal 13 3/8' CASING Unocal North Amer~-~ 011 & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 t~ Alaska Region UNOCAL RECEIVED APR 2. O 1993 Alaska 0it A Gas Cons, Commission Anchorage DOCUMENT TRANSMITTAL April 16, 1993 TO' Larry Grant LOCATION: 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM: Kirk Kiloh LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANS~G AS FOLLOWS TRADING BAY UNIT 1 blueline and 1 sepia Logs from specified wells listed below 5~0--0~--. D-5RD Perforating Record '7'7-"~;Z-- -' D-7RD Perforating Record -.-D-il. Perforating Record 'Perforating Record · Perforating Record .Perforating Record Completion Record &~--qS' -- D-20 Completion Record 10-18-92 10-19-92 11-30-92 11-22-92 11-29-92 12-04-92 6-29-92 6-16-92 8:~'-~11 D-43RD ~1~11 D-47 qO-l~ M-28 qt'" ~.'1 Completion Record Perforating Record Perforating Record Perforating Record Perforating Record Perforating Record Continuous Gyro Tool Cement Bond Tool Perforating Depth Control 6-20-92 11-21-92 11-25-92 10-17-92 12-03-92 12-18-92 7-24-92 7-24-92 8-12-92 M-29 TUbing Patch Record 11-13-92 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRA~SMITT~xL. TltANK YOU DATED: STATE OF ALASKA ALA~r~A, OIL AND GAS CONSERVATION COb~vllSSION REPORT OF SUNDRY WELL OPER TION : 1. Operations Performed: Operations Shutdown Stimulate Pull Tubing __ Alter Casing __ Repair Well Plugging 2. Name of Operator UNOCAL (Marathon Oil Company-Sub-Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 5. Type of Well: Development X Exploratory ~ Stratig raphic ~ Service ~ 4. Location of well at surface Leg A-2 Cond. #8 Dolly Varden Platform 748' FSL, 1,130' FWL, Sec. 6-8N-13W-SM At top of productive interval 506' FSL, 2,169' FEL, Sec. 32-9N-13W-SM At effective depth At total depth 767' FSL, 2,450' FEL, Sec. 32-9N-13W-SM Perforate X._~. ~ Other m ~ 6. Datu?, elevation (DF or KB)~,~'~, 106 KB above MSL ~,~-~feet 7. unit or Property name ~ Trading Bay Unit 8. Well number D-47 9. Permit number/approval number 91-11 / 93-026 0. APl number 50- 733-201 95-02 1. Field/Pool Hemlock 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 11,930' feet Plugs (measured) 9,882' feet 11,834' feet Junk (measured) 9,805' feet Length Size Cemented 398' 33" Exist 3,305' 16" Exist 10,978' 9-5/8" 1,900 sx 11,925' 7" 400 sx Bench 1 Bench 3 11,180'- 11,220' MD 11,340' - 11,398' MD None None Measured depth True vertical depth 398' 398' 3,305' 2,933' 10,978' 9,042' 11,925' 9,877' 9,228' - 9,264' TVD 9,372' - 9,423' TVD 13. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Butt. Tbg. w/Mod Butt couplings @ 10,799' Packers and SSSV (type and measured depth) Baker SB-3A Pkr w/11.5' seal assem. 4.0" I.D.. 6' millout ext. @ 10,712' stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure /Xlaska Oil & ~as Cc~.~s. (;ommissior~ 14. Prior to well operation 1/17/93 Subsequent to operation 1/29/93 Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcr Water-Bbl. Casing Pressure 954 515 1,608 1,010 636 443 2,146 1,180 Tubing Pressure 135 170 15. Attachments Copies of Log and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service -- 7. I hereby ce~ify that the~foreg, oing is tr..ue~nd correct to the best of my knowledge Signed Form 10-404/R;v 06/15/88 Date SUBMIT IN DUPLICAI~ DAILY WELL OPERATIONS D-47 1/24/93 Pressure test lubricator to 2500 psi. Good test. Establish CBO. Arm 30' 3-3/8" carrier, 6SPF, 60 degree phasing. Select fire. RIH w/ perf gun. Flow well for underbalance. Correlate, fire gun to reperforate HB-1, 11,200' - 11,210'. Re- correlate. Fire 20' section to reperforate HB-1, 11,180' - 11,200'. Good indication of gun firing each time. POOH. Establish CBO w/ gun at 1000'. Continue OOH. All shots fired. RD. Return well to production. H: \wp\WELLOPS\D47 STATE OF ALASKA 4LASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS I. Type ot Request: ~oanaon __ Suspend __ Oaerat~on snutclown __ Re-enter suspended well __ Atter cas, ng __ Repair we~t __ Ptugg~ng __ Time extension __ ~;timutale ~ Cnange adorned program __ Pull tubing __ Vanance __ Pedorate __ O.ner __ 2. Name of Operator ] 5. Type of Well: X UNOCAL (Harathon 0il Co - Sub 0peraf. or) Develooment__ Exploratory __ 3. Address Stratigraomc_ p. r~. Box 190247 Ar~choraqe, AK 99519 Sea,ce__ 4. Locatlon of well at surface Leg A-2 Cond. #8 Dolly Varden Platform 6. Datum e~evat~on (DF or KB) 10(~' KB above HSL 7. Unit or Property name Tradin~ Bay Unit 8. Well numoer feet 748' FSL. 1.130' FWL, Sec. 6- 8N- 13W- SM At top o~ productive ~nterval 506' FSL, 2,169' FEL, Sec. 32 - 9N - 13W - SM At effective depth ,At total depth 767' FSL~ 2,450' FEL, Sec. 32- 9N- 13W- SH fl-47 9. Permit number 91-11 10. APt number 50-733-20195-02 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical E ~ec[ive depth: measured true vertical Casing Lengtn Structural Conductor Surface 398' Intermediate 3,305 ' Production 10,978' 11,925' Liner Perforation depth: measured true vertical 11 930 ' feet Plugs (measured) ' ~eet 9,917' 11,834' 9,805' Size feet Junk (measured) feet Cemented NONE NONE 33" Exist 16" Exist 9-5/8" 1900 sx 7" 400 sx MeasuredL~P~ ~ E I ~ ,~ ~'cai clepth Alaska Oil & £~as Cons. Cor.qmissio~" Anchorage Bench i 11,180' - 11,220' MD 9,228' - 9,264' TVD Bench 3 11,340' - 11,398' MD 9,372' - 9,423' TVD Tubing (s~ze. grade, ana measured depth) 4-1/2", 12.6#, L-80 Butt. Tubing w/ Mod Butt couplings (a 10,799' PacKer§and SSSV (type and measured depth) Baker SB-3A Pkr w/ 11.5' seal assem. 4.0 ID, 6' millout ext. @ 10,712' , 13. Attact~ments Description summary of proposal _~X Detailed opera, ohs program ~ BOP sketch 14. Estimated date for commencing operation 1/z3/93 16. If propo_sal was.verbally apl~roved Oil BI air Wondze~ · ]./Z2/93 Name of~pprove~ Date approved Service Y ,L ( I Signed //~ q~ FOR COMMISSION USE ONLY Conditions of approval: Notify Comm~saon so representative may witness Plug integrity _... BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subseauent form required 10- 15. Status of well class~tication as: Suspended __ Approved by order of the Commission Origin~ :-~.~,,-tn~d By David W. johnston CommiSaoner Form 10-403 Rev06/15/88 SUeMn'~N'mIPUC~TE ~ PROCEDURE NELL D-47 lo ,1, e Obtain a well test w/ 4 W.¢.'s. Skid rig 77 over D-47. RU E-line unit. HU platform PA in unit. Pressure test lubricator & BOPE to 2500 psi. Disconnect SCSSV from manifold and lock open SCSSV w/ auxiliary pump at 4000 psi. Monitor control line pressure to ensure pressure does not bleed off. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify logistic support and establish communication black-out. Re- establish communication black-out when guns are at 1000' when POOH. SI well. RIH w/ 3-3/8" select fire carrier guns 6 SPF, 60° phasing and perforate the following interval underbalanced. RUN BENCH INTERVAL (DIL) FOOTAGE I i 11,180' - 11,210' 30' NOTE: The bottom 10' of the 30' gun will be fired, recorrelation performed and the top 20' of gun fired. SI well. POOH. RD E-line unit. Return well to production and obtain a 24-hour well test after cleanup. NOTE: Limit shut-in time to absolute minimum to reduce affects on platform production and stabilization period. Previous work on this well (10/92) with prolonged shut-in required several days to stabilize. H: \wp\WLPRO\D47 .AIaska Oil & Gas Cons. Anchorage DOLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE , GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP 4' ~1Z:1.6~. '50 0 0 psi CHISTMAS TREE POSITIVE CHOKE ---- 2" 5000 psi ---- 2' 3000 13 3/8' CASING MARATHON Fl CDMPANY TRADING B~Y UNIT D-47 Comp(eted 4/27/91 16", 1020 X-56 Butt, Csg. @ 3,305' 9-5/8' 40. 43.5, 47~, N-80 & P-110 Butt Cs9 AU measucements ace RKB to top oF equipment. 41' CIW 4.5" Tb9 Hanger 3PP' Camco 4.5" TRDP-4A SCSSV 3.813' I.D. Comp(etlon Stnlng: 0'-10,860' 4.5' 12.60, L-80, Butt tbg w/ Nod. Buttness Couptings. Gas LiFt Handpe(s ope 4.5" Danle['s GLH 2A w/1.5" Side pockets, RK (arch. 2,187' ~1 3,947' ~2 5,429' ~3 6,562' fi4 7,469' ~5 8,191' ~6 8,874' ~7 9,422' ~8 9,916' ~9 10,315' ~10 10,655' ~11 TBL 7~ 10,746' 9-5/8' Cs9 10,978' 7" 290 N-80 Linen set @ 11,925' B-1 B-3 10,712' Baker SB-3A Pkn. w/ tl,5' sect assemb(y 4.0' I.D. 6' MiLtout ext. 10,744' []TIS 'X' nlpp[e 3,813" I.D. t0,787' BTIS 'XN' nlppte 3.725' I.D. 10,799' Sheanout Ba[[ Seat Sub/WL Re-entry 9ulde. PepFonations HB 0i ll,180'-ll,PPO' (DIL) 6 SPF 6 SPF 4t22191 5120/91 PBTD @ 11,834' TD @ 11,930' Revision Dote: 5/15/91 Revised By: JDM/evo Reason: Proposed Comp(etlon Previous Revision: 4/16/91 OIL AND GAS CONSERVATION COMt ~ION REPON, SUNDRY WELLOPERATIONS 1. Operations Denormea: ©~erat,on snutaown ~ Stimulate ~ Plugg,ng ~ ~utl tul3tng m Alter camng m ReDmr welt m · Sub ~JS.~Type pt Well- 2. Na~(~[;O~[era'~larathon 01] Co - 0pera~or] O~mem ' t Ex~°~o~ 3. Address ]_ Str~graDmc P. 0. Box o247, ..... 4. Locatiogof~tlatsudace L~ ~--L ~UIIU. FO UUII] Voluc~ , ,u~,v,,,, 748' FSL, [,[30' FNL, Sec. 6 - 8N - [3N - SH At tod of DroOuct~ve mter~ 506' FSL, 2,[69' FEL, Sec. 32 - 9N- [3N- SH A~ effective ~eot~ Pedorate ~ Other xtt FP L, 2,450' 12. Presem welt conoition summary Total cleptn: measured true vertlcat Effective (:leD[n: measure(3 true vemcat FEL, Sec. 32 - 9N - 13W - SM ,, 11,930' fee~ 9,917' feet feet 11,834' 9,805' Casing Lengtn Structural Concluctor Surface 398' 3,305' Intermecliate 10,978' Production 11,925' Liner Perfora[~on clepm: measured Size 33" 16" 9-5/8" 7" Plugs (measured) true veraca~ JunK (measurea) 6. Datum elevatIon (DFor KB) 106' KB above HSL TT~,Ur~it or Pr rty m aalng ~e.~ 8. wu~i numner D-47 9~ P_erm~t number/approva numl~er -11/92-175 AP ~o. so~SP~n_u~O 195_ 02 NONE feet NONE Cementea Exist Exist 1900 sx 400 sx Bench i 11,180' - 11,220' MD 9,228' - 9,264' TVD Bench 3 11,340' - 11,398' MD 9,372' - 9,423' TVD Tubing (s~ze, graae, ana measureo aepm) 4-1/2", 12.6#, L-80 Butt, Tubing w/ Hod Butt couplings 0 10,799' P~qct~ers ancL~SSV (~e and m~ur~ d~ ] uaKer 5U-SA PKr W/ ~z.3' sea assem. 4.0 ID, 6' millout ext. ~ 10,712' 13. Stimulation or cement squeeze summary Intervals treatea (measureO) Treatment description including volumes useO ancl final pressure 14. Representative Daily Average Procluction or InjecUon Data OiI-Bbl Gas-Mcr Water-Bbi Casing Pressure Prior to well operation 809 '"" ..... 580 1707 1080 Subsequent to operation 1007/" 456 2277 1130 , 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ._. Daily Report of Well Operaaons _~ Oil ~ Gas ~ SusDenclecl ~ 17. I hereOy certify that me foreg~ng iS true and correct to the best of ~ knowledge. Service Tubing Pressure 130 150 SUBMITIN DUPUCATE DAILY WELL OPERATIONS D-47 6/6/92 Safety meeting. Lock open SCSSV w/ auxiliary pump. O.K. PSI test lubricator to 2500 psi. Good test. Establish communications blackout. Arm 30', 3-3/8" carriers, 6SPF, 60 degree phasing. Select fire. RIH. Flow well to obtain underbalance. Perforated the following intervals: RUN #1 HB-1 11,210' - 11,220' HB-1 11,190' - 11,210' RUN'#2 HB-1 11,190' - 11,210' RD. Return well to production. Fi red Misfired F i red H:\wp\WELLOPS\D~7 STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION COM MISSION REPONT OF SUNDRY WELL OPERATIO 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ~ Perforate .~X Pull tubing __ Alter casing __ Repair well ~ 2. Name of Operator I 5. Type of Well: , · Development A UNOCAL (Marathon O~l Co - Sub OperatJor) ExploratoryZ 3. Address ] Stratigraphic_ P. O. BOX 190247 Anchorage, AK 995]19 Service__ 4. Location of well at surface Leg A-2 Cond. #8 Dolly Varden Platform Other 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number feet 748' FSL, 1,130' FWL, Sec. 6 8N- 13W- SM At top of productive interval 506' FSL, 2,169' FEL, ,Sec. 32 - 9N- 13W- SM At effective depth At total depth 767' FSL, 2,450' FEL, Sec. 32 - 9N - 13W - SM D-47 9. Permit number/approval number 91-11 / ~ 10. APl n~Jmber 5°733-20195-02 11. Field/Pool Hemlock 12. Present well condition summary Total depth' measured true vertical 11,930' feet 9,917' feet Plugs (measured) Effective depth: measured 11 834 ' feet Junk (measured) true vertical ' feet 9,805' Casing Length Size Cemented Structural Conductor Surface 398' 33" Exi st 3,305' 16" Exist Intermediate 10,978' 9-5/8" 1900 sx Production 11,925' 7" 400 sx Liner Perforation depth: measured Bench I 11,180' - Bench 3 11,340' - true vertical NONE NONE Measured depth True vertical depth RECEIVED N 0V - 6 1992 Alaska Oil & Gas Cons. Gomm'tssiOn Anchorage 11,220' MD 9,228' - 9,264' TVD 11,398' MD 9,372' - 9,423' TVD Tubing (size, grade, and measured depth) p~s2a'~¢s~v¢¢pe&~C~Qea~g~deJN~bing w/ Mod Butt couplings 0 10,799' _.__J3.AJ(er gR-AA PkY' w/ ll_g' ,~¢,al a,~,~c,m_ 4,8 ID, 6' millout ext_ @ !0,7!__' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1022 491 1737 1070 1062 //638 2190 1120 Tubing Pressure 160 140 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _.~ Gas ~ Suspended Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Signed %88~ Form 10-404 Rev 0 Date SUBMITIN DUPLICATE ~.. DAILY WELL OPERATIONS D-47 10/17/92 Hold operations/safety/environmental meeting. RU E-line unit. Psi test lubricator & BOPE to 2500 psi. Apparent swab valve leak. Tested again after closing master valve. Good test this time. Bleed down lubricator. Establish CBO. Arm 30' section 3-3/8" carrier, 6SPF, 22 g charges. RIH. Open choke slowly to bring well on production and obtain underbalance. Correlate to CET. Make 4' correction. Perforate HB-1 11,210' - 11,220' Good indication gun fired. Recorrelate. Perforate HB-1, 11,190' - 11,210' 'Good indication top 20' of gun fired. POOH. Close swab & master valve. BleJd lubricator. All shots fired. Return well to production. H: \wp\WELLOPS\D47 RECEIVED V -- 1992 Alaska OiJ & Gas Cons. ¢o~lrnissioi~ Anchorage MARATHON OIL COMPANY TRADING BAY UNIT D-47 10; 10~# x--c~ Butt. Cs~. @ 3.30~' 9-5/8' 40. 43.~ 47#, N-80 & P-IlO Butt Csg Conpleted 4/~7/9! Att ~easureemnts are RKB to top of' equ~ent. 4l' ClV 4.5' Tho Hanger 322' C~Mco 4.5' TR~-4A SCS~V 3.8i3' I.E ~-t0,8~' 4.5' ]~.61, L-~, ~utt tb9 ~/ ~d. ~ttress C~pGngs. $~e pockets. RK ~,187' #l 3,947' #~ 5,4~)' #3 6,562' #4 7,469' #5 8,191' .6 8,874' #7 9,422' #8 9,916' 119 10,315' #10 10,655' #il TOL 7' @ 1~746' 9-5/8' Csg @ 10,978' 7' 29# N-80 Line# set e ILgeS' B-I B-3 10,712' 10,744' 10,787' 10,799' HB #1 HB #3 PBTD @ TDe Baker SB-3A Pkr. u/ ILS' seal asse~ioty 4.0- I.D, G' M.liout ext. OTIS 'X' nipple 3~13' I.D. OTIS 'XN' n~f~e 3.7L:~5' I.D. Shear~t Bott Seat Sub/VL Re-entPy 9uide. ILISO'-II~DO' CDIL) 6 SPF 4/22/91 11,340'-11,398' 6 SPF 5/20/91 1L834' 11o930' RECEIVED NOV - G 1992 Alaska Oil & Gas Cons. Corrxmissio~ Anchorage Reviswn Date: 5/15/91 Revised 9y, JDH/evo Reason, I~oposed C~plet;on Prev~us Revis~m 4/16/91 STATE OF ALASKA 0 ~ ! 6 I N A~ASKA PI L AND GAS CONSERVATION COMM,dSiON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair wen __ Cr~ange approved program __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon Oil Co- Sub Opera~or) eecv~,o~..e.n,t' __..X 1 3. Addr_ess _ ! StraUgraphlc- P. O. Box 190247 Anchorage, AK 995~9 Serv,ce~ 4 m Locatlon of well at sudace Lug A-Z Cund. #8 boily Varaen Piatfon, 748' FSL, 1,130' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 506' FSL, 2,169' FEL, Sec. 32- 9N- 13W- SM At effective depth Operat,on shutdown __ Re-enter suspended well __ Plugging __ Time extension __ ~t~muiate __ Pull tubing __ Vanance __ Pedorate ~ Other At total depth 767' FSL, 2,450' FEL, Sec. 32- 9N- 13W- SM 6. Datum elevation (DF or KB) 106' KB above HSL feet 7. Unit or Property name Trading Bay Unit 8. Well numOer D-47 9. Permn number 91-11 10. APl numUer 5o-733-20195-02 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical Effecwe depth: measured true vertical Casing Length Structural Conductor 398' Surface 3,305' Intermediate 10,978 ' Production 11,925' Liner Perforation depth: measureO true vertical 11,930 ' feet Plugs (measured) 9,917' feet 11,834' feet Junk(measured) 9,805' feet Size Cemented 33" Exist 16" Exist 9-5/8" 1900 sx 7" 400 sx NONE NONE Measured~6 E ! F~ 6rt'ca' depth OCT 2 7 1992 Alaska 0ii & Gas Cons. Gommission Anchorage Bench i 11,180' - 11,220' MD 9,228' - 9,264' TVD Bench 3 11,340' - 11,398' MD 9,372' - 9,423' TVD Tubing (s~ze, grade, and measured depth) 4-1/2", 12.6#, L-80 Butt. Tubing w/ Mod Butt couplings ¢ 10,799' Packers and SSSV (type and measured depth) Baker SB-3A Pkr w/ 11.5' seal assem. 4.0 ID, 6' millout ext. @ 10,712' 13. Attachments Description summary of proposal X__ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 10/17/92 16. If proposal was verbally approveci Hi ke [.-ii nder 10/16/92 Name of approver Date approved~ Service 17. I hereby certify that the foregoing is trug. ap~orrect to the best of my knowledge. Signed ..~'4¢~ --~~//t~ OkA;S~tle 0perations Enaineerin~ Supv. // ~' I ~'~,,,'~ ~ ¥OR COMMISSION USE OI~.Y Conditio6s of approval: Notify C~'~mission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- 15. Status of well classification as: Oil ...~X ~ Gas ~ Suspended Date Approved by order of the Commission Form 10-403 Rev 06/15/88 UE!G,NAL $tBNED BY q!~$~ELL A. DOUGLAS8 i Approval No. Commissioner Date SUBMIT IN TRIPLICATE PROCEDURE 0-47 · e · · Obtain well test w/ 4 W.C.'s. Skid rig 77 over D-47. RU E-line unit. HU platform PA in unit. Pressure test lubricator & BOPE -~ to 2500 psi. Disconnect SCSSV from manifold and lock open SCSSV w/ auxiliary pump at 4000.psi. Monitor control line pressure to ensure pressure does not bleed off. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify logistic support and establish communication black-out. Re- establish communication black-out when guns are at 1000' when POOH. SI well. RIH w/ 3-3/8" select fire carrier guns 6 SPF, 60° phasing and perforate the following interval underbalanced. RUN BENCH INTERVAL {DIL) FOOTAGE I i 11,190' - 11,220'/ 30' NOTE: The bottom 10' of the 30' gun will be fired, recorrelation performed and the top 20' of gun fired. SI well. POOH. RD E-line unit. Return well to production and obtain a 24-hour well test after cleanup. H: \wp\WLPRO\D7 RECEIVED OCT 2 7 1992 A/aska Oil & Gas Cons. Gommission Anchorage X-56 Butt. 9-5/8' 40. 43.~ 47#, N-80& P-1]O Butt Csg Conl~eted 4/87/91 MARATHON OIL COMPANY TRADING BAY UNIT 0-47 Att neosureMnts are RKB to top oF eclu~nent 41' CIV 4.5' Tbg Hanger 382' Camco 4.5' TR~-4A SCSSV 3.813' I.~ 0'-10,860' 4.5' ]8.61, L-8~ Butt th9 =/ Hod. Buttress CouptmBS. Gas LiFt Handrets are 4.5' Donwl's GLH 8A -/].5' S~le pockets, RK tGtCPL 8,187' #l 3,947' #8 5,4~9' #3 6,562' #4 7,469' #5 8,191' #6 8,874' #7 9,48~° #8 9,916' #9 10,315' #lO 10,655' #11 TOL 7' @ 11~746' 9-5/8° CsO @ 10,978' 7' 89! N-80 L~er set z~ B-1 B-3 10,718' 10,744' 10,797' 10,799' HB #1 HB #3 PBTD @ TD · Baker SB-3& lake. w/ 11.~5' seat osserMoty 4.0' I.D. 6' Mittout ext. OTIS 'x' rapture 3.813' I.D. OTIS 'XN' fl~e 3.7~* i.D. S~er~t Bott Seat Sub/~ Re-entry 9uade. perForot;ons ILISO'-I1,;~L~O° CDIL) 6 SPF IL340'-IL398' 6 SPIr 4/22/91 5/L~0/91 RECEIVED 0 CT 2 7 Alaska Oil & Gas Cons. (3ommission Anchorage 11,834' 11,930' Revismn Date: 5/15/91 Revised By, JDN/evo Reasom Proposed Co,~ptet;on Prevmus Re~s~m 4/16/91 '~)OLLY VARDEN Pt~TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) LUBRICATOR 3 1/8'. 5000 psi CHISTMAS TREE POSITIVE CHOKE Naska 0ii & (~as Cons. 'Anchorage ---- 2' 5000 p.i ]_-- 2' 3000 psi 13 3/8' CASING STATE OF ALASKA ALAbKA OIL AND GAS CONSERVATION COMMISbi©N 0 R APPLICATION FOR SUNDRY APPROVALS 16 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator ~ 5. Type of Well: UNOCAL (Marathon Oil Co - Sub Ol:)era~or) De._vel,opm. ent.z~_ - ! ~- xp~ora[ory __ & Address ! Stratigraphic_ P. 0. Box 190247 Anchorage, AK 995J19 Service__ 4. Location of well at surface Leg A-2 Cond. t~ L)ol ly Varden Platform 748' FSL, 1,130' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 506' FSL, 2,169' FEL, Sec. 32 - 9N - 13W - SM At effective depth Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate .,~ Other __ At total depth . 767' FSL, 2,450' FEL, Sec. 32 - 9N - 1314 - SM 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Welt number D-47 9. Permit number 91-11 10. APl number 5o-733-20195-02 11. Field/Pool Hemlock 12. Present well condition summary Total depth' measured true vertical 11,930' feet Plugs(measured) NONE 9,917' feet Effective depth: measured 11,834 ' feet Junk (measured) NONE true vertical 9,805 ~ feet Casing Length Size Cemented Measured depth True vertical depth ~t~%~tuU;ta~r R E C E IV E D 398' 33" Exist Surface 3,305' 16" Exist JUL - 6 1992 Intermediate 10,978' 9-5/8" 1900 sx Production 11,925' 7" 400 sx Alaska Oil & Gas Cons. CommiSsior~ Liner Anchorag~ Perforation depth:measured Bench i 11,180' - 11,220' MD 9,228' - 9,264' TVD Bench 3 11,340' - 11,398' MD 9,372' - 9,423' TVD true vertical Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Butt. Tubing w/ Mod Butt coup'lings @ 10 799' Packers and SSSV (type and measured depth) ' Baker SB-3A Pkr w/ 11.5' seal assem. 4.0 ID, 6' millout ext. Ia 10,712' 13. Attachments Description summary of proposal __ Detailed operations program X_._ BOP sketch 14. Estimated date for commencing operation 6/7/92 16. If proposal was verbally approved Oil X Gas __ 6/5/92 Name of approver Mi ke Mender Date approved i Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ FOR COMMISSION USE ONLY - ._) Conditions of'~prov~l: Notify Commission so representative may witness Plug integrity __ BOP Test __ Mechanical Integrity Test __ Approved by order of the Commission Form 10-403 Rev 06/15~88 15. Status of well classification as: Suspended__ Date ! Approval N o. Location clearance ~ I Subsequent form required 10- ¥¢~ ' ~pproved Copy Returned Original Signed By 7' ,,~1- ~1"~ David W. JohnstOn Commissioner Date '7/IO/C~ 2 SUBMIT IN TRIPLICATE TBU WELL D-47 PROCEDURE TO REPERF HB-1 1. Conduct safety meeting. 2. Disconnect SCSSV from manifold and lock open with auxiliary pump. 3. 'R/U E-line. Pressure test lubricator to 2,500 psi. Follow C.B.O. procedures. 4. RIH with 3-3/8" hollow carriers, 6 SPF, 60 degree phasing, and perforate o underbalanced as follows: RUN BENCH i HB-1 INTERVAL (DIL) 11,190' - 11,220' FOOTAGE 30' SI well, POOH. R/D E-line. Return well to production. H: \wp\w t pro. D47 RECEIVED d U L - 6 1992 Alaska Oil & Gas Cons. Commission Anchorage BARATHFIN 8'I'L TRADING BA, _,NIT D-47 X-56 Butt. Csg. @ 3,305' 9-5/8' 40, 43,5, 4~'' N-80 & P-Il0 g £s9 Comp(eFed 4/87/9i All meosurements ore RKO to top oF equipment, 4]' CIW 4.5' Tbg H~nger' Co, taco 4,5' TRDP-4A SCSSV 3813' I,D, Compietlon String: 0'-10,860' 4.5' 1~.6~, L-80, Butt tb9 w/ Mod. Buttress Couplings. Gas LiFt Mandre(s are 4.5' DanieL's GLM ~A w/l.5' Side pockets, RK torch. 2,187' ~1 3,947' ~2 5,489' ~3 6,562' ~4 7,469' ~5 8,874' ~7 9,422' :~8 9,916' ~9 !0,315' ~10 10,655' ~11 TElL 7' 10,746' -=/8' Cs9 ~78' 7' 29fl N-80 Liner set 1~ il, 925' B-3 lO, 71P' 10,744' 10,787' 10,799' HB t41 HB ~3 PBTD e TDe Baker SB-3A Pkr. w/ 11.5' seal assembly 4.0' I.D. 6' NitLout ext. OTIS 'X' nlpp[e 3.813' I.D. OTIS 'XN' nlppte 3.725' I.D. Shearout B~IL Seat Sub/WL Re-entry guide, PerForations 11,180'-11,220' (DIL) 6 SPF 4/22/91 11,340'-11,398' 6 SPF 5/20/91 11,834' 11,930' Revision Date: 5/15/91 Revised By: dDH/evo Reason: Proposed Comptetion Previous Revision: 4/16/91 DOLLY VARDEN P~.ATFORM Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) , LUBRICATOR MANUALLY OPERATED BOP · 4'~1~%-1.6"..-"~ '5000 pal CHISTMAS TREE POSITIVE CHOKE .---- 2' 5000 psi _.- 2' 3000 pal 13 3/8' CASING 5. STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend m Alter casing __ Repair well Change approved program __ Operation shutdown ~ Re-enter suspended well __ Re pe rf HB- 3 Plugging __ Time extension __ Stimulate __ Pull tubmg__ Variance m Pedorate X Other __ 2. Name of Operator / 5. Type of Well: UNOCAL (Marathon Oil Co - Sub Oper~or) D~VxeJ~toe?¢ 3. ~ ....... / Stratigraphic P. 0. Box 190247 Anchorage, AK 995~9 Serv~ce~ 4. Locahon of well at surface Leg A-2 Cu.d. #8 uo~- 'iy Varde. Piatfun. 748' FSL, 1,130' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 506' FSL, 2,169' FEL, Sec. 32 - 9N- 13W - SM At effective depth At total depth 767' FSL, 2,450' FEL, Sec. 32- 9N- 13W- SM 6. Datum elevation (DF or KB) 106' KB above HSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-47 9. Permit number 91-11 10. APl number 50-733-20195-02 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 398' Sudace 3,305' Intermediate 10,978 m Production 11,925 ' Liner Perforation depth: measured true vertical 11,930' feet 9,917' feet 11,834' feet 9,805m feet Size 33" 16" 9-5/8" 7" Bench 1 Bench 3 Plugs (measured) Junk (measured) Cemented Exist Exist 1900 sx 400 sx 11,180' - 11,340' - NONE NONE Me~,ur~d~e~h I V E Crue vertical depth SEP 1 9 t991 Alaska 0il & Gas Cons. 6ommission Anchorage 11,220' MD 9,228' - 9,264' TVD 11,398' MD 9,372' - 9,423' TVD Tubing (size, grade, ano measured depth) 4-1/2", 12.6#, L-80 Butt. Tubing w/ Mod Butt Packers and SSSV (ty~)e and measured depth) Baker SB-3A Pkr ~/ 11.5' seal assem. 4.0 ID, couplings ~ 10,799' 6' millout ext. 0 10,712' 13. Attachments 1, 2 Description summary of proposal &2 Detailed operations program BOP sketch Y,._ 14. Estimated date for commencing operation G/31/91 16. If proposal was verbally approved 4' Johnstone ame of approver 9/4/91 Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ('~ ~ '~, ~ c,,,.,~% Title ~-, ~e.~ ONE-'~ --(~ G FOR COMMISS~ U~ * ~%' Conditions of ~provaE Notify Commission so representative may witness Plug integrity __ BOP Test __ L~ation clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev O6/15/88 ORIGINAL ,.SIGNED BY LONNIE 6. SMITH SUBMIT IN TRIPLICATE Attachment # 1 Wel 1 D-47: Reperforate HB-3 1) Obtain a 24-hour well test with a minimum of four (4) WC's. 2) Skid rig #77 over D-47 {leg A-2). 3) RU E-Line unit. Hook up platform communication system in unit. Pressure test lubricator and BOPE to 2500 PSI. 4) Apply 4000 PSI control line pressure to the SCSSV with the auxiliary pump and monitor for any leak off prior to RIH. Pump to be located near lower wellroom entry door. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT USING THE PERFORATING CHECK LIST. RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE ~ 1000' WHEN POOH. 5) RIH with 3-3/8" carrier guns, 6 SPF, 60 -Degree phasing and perforate the following intervals underbalance. RUN BENCH INTERVAL (DIL) FOOTAGE HB #3 11,340' - 11,370' 30' HB #3 11,370' - 11,398' 28' 6) RD E-line unit. Return well to production and obtain a 24-hour well test w/ 4 WC's. Test well for 12-hours every other day with WC's taken every 8-Hours for 5-days. \docs\oe56\ 16 .doc RECEIVED SEP 1 9 t99i Alaska Oil & Gas Coils. Commission Anchorage Attachment #2 MARATHDN DIL CDHPANY TRADING BAY UNIT D-47 16', 102# X-56 3u~t. Csg. 8 3,305' 9-5/8' 40. 43.5, 47~, N-BO & P-il0 Butt Csg Compteted 4/27/91 All measurements ore RKO to top oF equipment. 41' CIW 4.5' Tbs Hanger 328' Camco 4.5' TRDP-4A SCSSV 3.813' I.D. Compte~c;on String. O'-//;WB64~. 4.5' 12.6#, L-80, Butt tb9 w/ Mod. /0~ ~ Buttress CoupLings. Gas Ll?t Mondrets ore 4.5' Danlet's GLM 8A ~/1.5' Side pocke~s, RK [~ch. 8,187' #1 3,947' #2 5,429' #3 6,562' #4 %469' #5 8,191' #6 8,874' #7 9,422' #8 9,916' 10,315' #10 10,655' #11 TOL 7" 10,746' 9-5/8' Csg 10,978' 7' 29~ N-80 Liner set lB 11,925' B-1 B-3 10,712' 10,744.' 10,787' 10,799' HB #1 HB #3 PBTD 8 TD @ Baker SB-BA Pkr. w/ 11.5' sea~ ossembty 4.0' I.D. G' M;llout ext. OTIS 'X' nlppte 3.813' I,D. OTIS 'XN' nipple 3.725' I.D. Shearout Bolt Seat Sub/WL Re-en~cry guide, PerForations 11,180'-11,220' (OIL) 6 SPF 4/22/91 11,340'-i1,398' 6 SPF 5/20/91 RECEIVED S EP 1 9 t991 Alaska Oil & Gas Gong. tomrnissiOn Anchorage 11,834' 11,930' Revision Da~e. 5/15/91 Rev;ged By, J]]H/evo Reason, ~ew~°roPo=e-~ Compte~ion Prev;ous Rev;s;on, 4/16/91 Attachment · · . DOLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) LUBRICATOR · 4'*'11:1.6~.5000 psi CHISTMAS TREE Anchorage POSITIVE CHOKE RECEIVED S E P 1 9 t991 "" Alaska Oil & Gas Cons. Commission 13 3/8' CASING STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS '~ SUSPENDED ~ ABANDONED ~ SERVICE 2. Name of Operator ~/~.~[l:lrr..~ 7. Permit Number UNOCAL (Marathon Oil Co. Sub-operator) s~.[~...'~'~,-~ 91-11 3. Address ~. H.~ I' $. APl Number P. O. Box 190168 Anchorage, AK 99519 ~ ,,~o- 733-20195-02 4. Location of well at surfaceLeg A-2, Cond. #~ uoi iy Varden Pia[forml, 9. Unit or Lease Name 748' FSL, 1,130' FWL, Sec. 6 8N-13W-S~i Trading Bay Unit At Top Producing Interval I ~//TE x2I 10. Well Number 506' FSL, 2,169' FWL, Sec. 32 9N-13W-SMJ--~:-~-~-~-~ii D-47 At Total Depth 11. Field and Pool 767' FSL, 2,450' FWL, Sec. 32 9N-13W-S~ McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB above MSLI ADL 17594. ,Heml°ck Zone 12. DateSpudded 13. DateT.D. Reached 14. DateComp.,Susp, orAJ~and. 115. WaterDepth, ifoffshore 116. No. of Completi°ns 02/01/91 04/10/91 ~ </'//~//,7/I ~128feetMSL1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey ' I 20. Depth where SSSV set I 21. Thickness of Permafrost 11,930' - 9,917' 11,834' - 9,805' YES[~[ NO[![ 322feetMD,N/A 22. Type Electric or Other Logs Run gl~. Phaser. LSS. FDC. CNL. CAL. RFT, SP, CBT, CET · 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 33" $,,rf 3qR' Fxisting 16" !02# X-56 S~rf AAllE' Fxistino o_c/~,, J'~/K~ K~ m-Mn n' in q7R' 12.2.~; 1900 sx Class G 200,000# ""'7" '29.0# i-An !0,746' 11,q?.~' 8.5 400 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 (MD) 4..~ 10.7qg 10.712' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. B-1 11,180' - 11,220' 9,228' -9,264' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED B-3 11,340' - 11,398' 9,372' - 9,423' 11,180-!1,220' Fracture- Treatment: All Perfs are 6 SPF 22,600# 7~1/4~1 Carhnlite in !20 bb!~ x-linked ge! 27. PRODUCTION TEST Date First Production ! Method of Operation (Flowing, gas lift, etc.) 5/21/91I Gas Lift · I Date of Test Hours Tested PRODUCTION FOR el L-BBL ~' '~AS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 5/21/91 24 TEST PERIOD~ 2397 968 771 N/A 404 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press140 980 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. No Core Taken ' ~,.: . -- !-' Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. NAME HEMLOCK BENCH TOPS HB-1 HB-2 HB-3 HB-4 HB-5 HB-6 GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 9,228 9,291 9,371 9,425 9,563 9,679 FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Il,180 11,250 11,340 il,400 11,556 11,690 HEMLOCK INTERVAL HB-1 HB-2 HB-2 HB-3 HB-4 HB-5 HB-6 DEPTH (DIL) 11,198' 11,270 11,305 11,356 11,440 Il,610 11,722 PRESSURE (PSIA) 3,475 3,889 3,929 3,445 3,624 3,830 3,714 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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. ~tem 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. ~tem 21: Indicate whether from ground level (GL) or other elevation (D.F, 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 16; 102# X-56 Bu.tt. C$g. 8 3,305' 9-5/8' 40. 43.5, 47#, N-80 & P-110 Butt Cs9 4/27/91 MARATHON OIL COMPANY TRADING BAY UNIT D-47 All Me~suremen.ts are RKO to .top o? equipment. 41' CI~¢ 4.5' Tb9 Hanger 322' CaMco 4.5' TRDP-4A SCSS¥ 3.813' I.D. Completion Strlng~ 0'-10,860' 4.5' 18.6#, L-80, Butt tho w/ Mod. Bu.ttress Coupt;ngs, Gas L;?t Handrel$ are 4.5' DanleVs GLM 8A w/1.5' 2,187' #1 3,947' #8 5,429' #3 6,562' #4 7,469' #5 8,19i' #6 8,874' #7 9,428' #8 9,916' #9 10,315' #10 10,655' #11 TDL 7' @ 10,746' 9-5/8' Csg @ 10,978' 7' 29~ N-80 Liner se.t @ 11,925' B-1 B-3 10,712' 10,744' 10,787' 10,799' HB #1 HB #3 PBTD @ TD 8 B0.ker SB-3A Pkr. w/ 11.5' seat assembty 4.0' I.]). 6' Mltlout; ex't. OTIS 'X' nlppte 3.813' I.D. OTIS 'XN' nlppte 3.785' I.D. Shearou.t Ball Seat Sub/WL Re-en.try guide. p~,r?oratlons 11,180'-11,22O' (OIL) 6 SPF 4/22/91 11,340'-11,398' 6 SPF 5/20/91 11,834' 11,930' Re~;.~jo~8~¢~/tS/91 Revised By~ Reosom Proposed Co~ptet;on PPev;ous Revlslom 4/16/91 WELL D-47 Summary of Daily Well Operations 02/02/91 N/U and tested BOP's. Ran freepoint - g-5/8" csg free to 1,800'. 02/03/91 RIH and cut 9-5/8" csg at 1,800'. Speared and retrieved csg to 1,800'. Cut csg at 2,000'. Speared csg and started POOH. 02/04/91 L/D 200' csg. Cut at 2,205'. Speared csg and POOH. L/D 205' csg. Cut csg at 2,410'. 02/06/91 POOH with bit. RIH with casing cutter, cut casing at 2,830'. Tripped for casing spear. Attempted to latch casing at 2,610' failed. Tripped for tapered mill. Dressed off top of 9-5/8" casing at 2,610' tripped for spear. Attempted to latch casing failed. Tripped for casing cutter. Cut casing at 2,641'. POOH. RIH with casing spear. 02/07/91 Finished RIH with casing spear. Latched casing at 2,610' POOH laid down 32' casing. Top 2,641'. RIH with spear. Latched fish jarreJ. Spear released. POOH. RIH with bit. Washed 2,610'-2,640' Circulate. Tripped for spear. Latched casing at 2,641'. Jarred. Spear ~eleased. Could not re latch. R/U shale shaker for milling casing. 02/08/91 Finished rigging up flow trough and cuttings slide. BHA, picked up casing mill. Modified flow trough. RIH with casing mill. Circulated. Milled 9-5/8" casing 2,641'-2,650'. Circulated and conditioned mud. Milled 9-5/8" casing 2,650'-2,700'. 02/09/91 Milled 9-5/8" casing 2,700'. Pipe hung up. Worked pipe free. Circulated. POOH with casing mill. Set inflatable packer. Tested BOP released packer. Tested surface equipment. RIH with bit and underreamer. Washed and reamed 2,434'-2,701'. Circulated. POOH. Laid down underreamer. Picked up casing spear and RIH. Well D-47 ' : ' Summary of Well Operations Page 2 02/10/91 Finished RIH with casing spear. Latched pipe several times. Spear kept slipping out of fish. Tripped for casing mill. Milled g-5/8" casing 2,703'-2,825'. Casing started spinning. Circulated tripped for casing spear. Tagged fish at 2,825'. POOH. 02/11/91 Finished POOH with casing spear. No recovery. Modified spear. RIH with casing spear. Tagged fish at 2,828'. POOH. Recovered fish. RIH with casing mill. Milled casing 2,829'-3,000'. 02/12/91 Milled casing 3000'-3,139'. Pipe hung up at 3 105', 3,135', and 3,139'. Circulated. Milled g-5/8" casing 3,139'-3,147) Hole packed off. Circulated hole clean. Tripped for underreamer. Washed a~d reamed hole 2,701'-2,800'. Circulated and conditioned mud. 02/13/91 Washed and reamed 2,800'-3 147'. .Circulated POOH. RIH with casing mill. Milled g-5/8" Casing 3,147:-3,270' Circulated. POOH. 02/14/91 RIH with mill. Mill casing 3270'-3300' CBU. POOH. RIH with underreamer. Clean out to casing stub at 3300'. CBU] POOH. RIH with mill. Mill casing 3300'-3337'. 02/16/91 POOH and L/D metal plugged joint. RIH and set 250 sx cement plug from 3559'-3239'. Reverse out and WOC. Attempt to test casing. Bled from 1000 psi to 700 psi. RIH and tag TOC at 3239'. POOH. 02/17/91 POOH with drill pipe. Ran packer to 2098' and inflate. Test casing on backside to.1500 psi. OK. Release from packer and POOH. N/D BOPandR~nsert, casing spool N/U and test BOP 250/3000 psi. Annular 250/2000 psi- H to retrieve packer. Unable to get over to latch. Falling beside. POOH. 02/18/91 POOH. RIH with stabilizers on drill pipe. Latch packer and test casing to 1500 psi. Release and POOH with packer. RIH and dress cement plug to 3315'. POOH. BHA. RIH with steerable mud motor. Orient and drill 3315'-3332'. , Well D-47 . Summary of Wel 1 Operations Page 3 02/19/91 Sidetrack and drill to 3492' Pull into casing and displace hole with polymer mud. Clean pits° RXH. Driil to 3651'. 02/20/91 Drill with mud motor 3651'-4120'. Short trip to casing shoe. Drilled to 4313'. Drilled with steerable motor 4,313'-4,805'. Short trip to casing shoe drilled to 4,805'-4,830'. 02/22/91 Drilled with steerable motor 4,805'-5,186'. POOH for BHA and bit. 02/23/91 Finished POOH. Changed out BHA. RXH. Drilled 5186'-5518'. Ran check survey. Drilled 5186'-5690'. 02/24/91 Rotary drilled 5690'-5866'. Surveyed with NWD D. Short tripped 27 stands. Rotary drilled 5866'-6170'. Surveyed with RWD D. 02/25/91 Rotary drilled 6170'-6276' Surveyed with RWD D. Circulated. Dropped survey. POOH. Tested 8OP. RXH. ~otary drilled 6276'-6514o Surveyed with RWD D. 02/26/91 Drilled 6514'-6908'. S/T to shoe. Tight 6110'-5959'. Tagged bridge at 6783'. Reamed 6780'-6908'. Drilled 6908'-7121'. 02/27/91 Drilled 7121' to 7400'. S/T to 5500'. Drilled 7400' to 7617'. 02/27/91 Drilled 7617'-7677'. CBU - Dropped survey° POOH. R/U mud motor. RIH. Drilled 7677'-7765' 'Well D-47 ~ Summary of Wel 1 Operations Page 4 03/01/91 Drilled with mud motor 7765'-8055'. S/T to 5781'. Drilled with mud motor 8055'-8086'. 03/02/91 Drilled with mud motor 8036'-8301'. S/T to 7336'. 03/03/91 Finished RIH. Drilled 8301'-8385'. Dropped survey. POOH. Tested BOP's. RIH. 03/04/91 RIH. Reamed 8120'-8385'. Drilled 8385'-8697'. 03/05/91 Drilled 8697'-8716' - MWD failed. Circ high visc sweep. POOH. Changed out MWD, jars and bit. RIH - reamed 8400'-8500'. Drilled 8716'-8777'. 03/06/91 Drilled 8777'-8932'. Short tripped to 7500'. Drilled 8932'-8955'. 03/07/91 Drilled with steerable motor 8955'-9210'. Surveyed with MWD D. 03/08/91 Circulated. Short tripped 25 stands to 6847' Drilled with steerable motor 9210'-9335' Surveyed with MWD circulated bottoms up. Dropped survey. POOH. Hole tight ~750', 6700', 5945' and 4620'. BRA. Retrieved survey, laid down mud motor. 03/09/91 Finished laying down mud motor. Tested BOP. RIH with rotary drilling assembly. Slipped drill line. Finished RIH washed and reamed 9250'-9335'. Hole tight 9300' and 9326'-9335'. Drilled 9335'-9469'. 03/10/91 Tripped for MWD. Reamed 9428'-9469'. Drilled 9469'-9596'. Surveyed with MWD D. Summary of Well Operations Page 5 03/11/91 Rotary drilled 9596'-g716'. Surveyed with MWD Do Short tripped to 7800'. Rotary drilled 9716'-9764'. Surveyed with MWD D. 03/12/91 Rotary drilled 9764'-9778'. Surveyed with MWD D. Tripped for mud motor. Drilled with mud motor 9778'-9848'. 03/13/91 Drill 9848'-9960' with motor. ST to 8050'. Drill 9960'-9972'. 03/14/91 Drilled with steerable motor 9972'-10,107'. POOH. 03/15/91 POOH. Tested 80P's. RIH w/rotary assembly. Drilled 10,107'-10,158'. 03/16/91 Drilled 10,158'-10,317'. POOH looking for washout. 03/17/91 POOH - Found washout in heavy weight. RIH. Drilled 10,317'-10,480'. Lost 500 psi pump pressure. POOH looking for washout. 03/18/91 POOH. Jet cracked in bit. RIH. Drilled 10,408'-10,597'. 03/19/91 Drilled 10,597'-10,693'. CBU. Short tripped 20 stands. Drilled 10,693'-10,760'. 03/20/91 Drilled 10,760'-10,790'. Repaired broken chain. Drilled 10,790'-10,911. Short tripped to 9450'. Drilled 10,911'-10,937'. 03/21/91 Drilled 10,937'-11,000'. Circulated. Short tripped 25 stands to 8600' circulated. POOH. Hole tight 6104'-5,397' Pipe hung up at 5,430' Worked pipe free. POOH 30'. Pipe hung up. AttemPted to work pipe ~ree. ~arring down with no success. 'Well D-47 ~ Summary of Wel 1 Operations Page 6 03/22/91 Worked stuck pipe at 5428'. Retrieved single shot survey. RIH with string shot. Backed off heavy weight drill pipe at 4432' DPM. Circulated. 03/23/91 Finished circulating. POOH with drill pipe. RIH with screw in sub, could not locate top of fish. POOH. RIH with 12-1/4" bit, tagged top of fish at 4436'. Circulated. POOH. RIH with screw in sub with 11-3/4" skirt to 4436' worked over fish and screwed into fish. Jarred on fish. 03/24/91 Jarred on fish. RIH with freepoint. Jarred. Freepoint, fish 78% free at 4445', 0% at 5015'. Jarred on fish. Freepoint, fish O~ free at 5015', 59~ at 4936' POOH. RIH with string shot. Backed off fish at 4946' WLM. POOH with wireline. Circulated. POOH. Recovered 17 joint HWDP (513'). RIH with screw in assembly. Jarred on fish. R/U wireline. 03/25/91 RIH with freepoint. Tool failed. Rewired head. RIH with freepoint. Stuck below screw in sub. RIH with string shot. Attempted back off at 4949'. Pipe backed off high. Attempted to screw back into fish. POOH with drillpipe. Backed off at 4265'. RIH with screw in assembly. Screw into fish. Jarred on fish and circ. RIH with string shot. Attempt back off at 4949'. Failed. RIH second string shot. 03/26/91 RIH with string shot. Pipe backed off while working left hand torque POOH with wireline. POOH with drill pipe. Hole tight 4102'. Left screw in sub in hole. RIH with wash pipe. Washed over fish 4947'.-5064' POOH. RIH with screw in assembly. Screwed into fish. Jarred on fish. RiH with free point. Fish stuck below drilling jars. Jarred fish free. 03/27/91 Jarred fish free. POOH with wireline. Worked pipe up to 5333' (bit depth). Pipe stuck. Worked pipe. Ran freepoint. Pipe free at 4625'. POOH with wireline. RIH with string shot. Backed off pipe at 4592'. Recovered 44 stands, a single, and 14 joints HWDP. RIH with screw in assembly. 03/28/91 Screwed into fish. Jarred on fish and knocked free. Able to go down but not up. Worked through tight spot 5333'-5270'. Pulled free 5270'-5140'. Tight 5140'-5126'. Worked/backreamed 5126'-5125', making 1' in 10 hours. Gradually lost most pump pressure. Sunanary of ~el 1 Operations Page 7 03/29/91 Worked/backreamed 5125'-5123'. RIH w/freepoint tool - fish came free. POOH to 5020' and hit tight spot - attempt to work through and hung up. Worked stuck pipe w/o jar action. Ran freepoint stuck in lower drill collar. Attempted backoff at 4223' w/o success. Backed off at 4123'. Recovered 2-collars and accelerator jars. 03/30/91 Washed over fish 4133'-4276' POOH. RIH and screwed into fish. Jarred fish free. Worked/backreamed 5021~'-4750' (bit depth). 03/31/91 Worked/backreamed fish 4750'-4600' - fish came free. POOH. L/D fish - full recovery. Tested BOP's. RIH to shoe. 04/01/91 RIH to shoe. Repaired drawvorks brakes. RIH - hit tight spots at 4636', 6480', 8725' and 10,155' - worked through each until clean. Washed/reamed 10,155'-10,400'. 04/02/91 Washed reamed 10,400'-10,989' (corrected T.D.). Circ and cond mud. POOH - tight at gg20', 9800', 5422'. R/U to run csg. 04/03/91 R/U to run csg. RIH w/256 its 9-5/8" csg to 10,978'. Circulate and condition mud. R/U cementers. 9-5/8" Casing Detail From: To: KB Elevation i Jt g-5/8", 47#, BTC, L-80 197 Jts 9-5/8", 47#, BTC, L-80 55 Jts 9-5/8", 53.5#, BTC, L-80 Float Collar 2 Jts 9-5/8", 53.5~, BTC, L-80 Float Shoe 0 42.88' 42.88' 73.22' 73.22' 8,523.56' 8,523.56' 10,891.24m 10,891.24' 10,891.99' 10,891.99' 10,976.02' 10,976.02' 10,977.83' 04/04/91 Circulated and conditioned mud. Rigged up cement lines. Mixed and pumped 30 bbl 11.0 ppg scavenger cement, 140 sx 12.5 ppg lead cement, and 500 sx 15.8 ppg tail cement. Displaced with 792 bbl 10.1 ppg mud. Bumped plug with 2000 psi. WOC. 'Well D-47 Summary of Well Operations Page 8 04/05/91 WOC. Nipple down flow line. Picked up BOP stack. Set slips, Hade rough cut on 9-5/8" casing. Nippled down BOPE. Made final cut on 9-5/8" casing. Nippled up tubing spool. Tested to 3000 psi. Nippled up 8OPE. Test BOPE. 04/06/91 Test BOP. Laid down 8" drill collars. RIH. Tagged at 10,885' Circulated. Tested casing to 2275 psi. Drilled cement to 10,g55'. Circulated Tested casing to 2275 psi. Drilled cement and 5' new formation to 11,005;. Circulated. Test shoe to 1840 psi, EMW 13.8 PPG. Drilled 04/07/gl Rotary drilled 11,054'-11,164'. 04/08/gl Rotary drilled 11,164'-11,185'. Tripped for bit and BHA. Rotary drilled 11,185'-11,277'. 04/09/91 Rotary drilled 11,277'-11,540'. Short tripped to casing shoe at 10,978'. Drilled 11,540'-11,630'. 04/10/g1 Rotary drilled 11,630'-11,638'. Tripped for bit. Rotary drilled 11,638'-11,774'. 04/11/gl Rotary drilled 11,774'-11,g30'. Short tripped to shoe. Circulated and conditioned mud. POOH. R/U to log. 04/12/gl Ran open hole logs. Run #1: GR Phazor LSS AMS (SP tool failed), Run #2: FDC CNL GR CAL AMS, Run #3 RFT, Run #4 GR SP Phazor. R/D Schlumberger. Started testing BOP's. 04/13/91 Tested BOP's. RIH. Reamed go' to bottom. CBU. Short tripped to shoe. Circ and conditioned mud. POOH. RIHw/7" liner. 'Well D-47 ~ Summary of Wel 1 Operations Page g 04/14/91 RIH with liner. Circ and conditioned mud. Cemented liner w/400 SXS while rotating and reciprocating. Bumped plug and set liner hanger: 7" shoe at 11,g25', top of liner hanger at 10,746'. POOH 10 stds. CBU. POOH. RIH w/bit. 7" Liner Detail From: To: TIW Liner Hanger 25 Jts, 7", 29#, TKC, L-80 TIW Landing Collar, TKC i Jt, 7", 2g#, TKC, L-80 TIW Float Collar, TKC I Jt, 7", 2g#, TKC, L-80 TIW Float Shoe, TKC 10,746.02' 10,765.39 10,765.39' 11,831.07 11,831.07' 11,831.90 11,831.90' 11,875.92 11,875.92' 11,877.74 11,877.74' 11,922.10 11,922.10' 11,925.00 04/15/91 RIH with 8-1/2" bit to 10,000'. WOC. RI" tagged liner top at 10,746'. CBU- had cement contaminated mud. Tested liner lap to 2500 psi. POOH.RIH w/6" bit. 04/16/91 RIH. Cleaned out liner to 11,834'-25'. Tested liner and lap to 2500 psi w/150 Psi bleed off in 15 min. POOH. RIH w/test tools. Set pkr at 10,500' Dry tested liner lap to 700 psi for 1-hr w/steady blow to bubble bucket. ~/I for 2 hrs. Reversed out. Tested lap to 2500 psi - lost 400 psi in 15 min. POOH. RIH w/scrapers. 04/17/91 RIH w/bit and scrapers. CBU. POOH. Ran bond log from PBTD - 10,500'. Began Gyro survey. 04/18/91 Finish running gyro survey- RIH w/ casing scrapers and displace hole w/ FIW - POOH laying down drill pipe. 04/19/91 string - dress top of liner. POOH.P/U and RIH with liner top isolation packer. Well D-47 . Summary of Wel 1 Operations Page 10 04/20/91 RIH and set liner top packer. Test liner and casing to 2500 psi POOH. Test BOPE. RIH with dry test assembly. Set packer at 10,692' and perform negative test on liner top. Shut in for pressure buildup. Reverse out test with no indication of influx. 04/21/91 Finish reversing out dry test. No influx. POOH. RIH with tandem 7" and 9-5/8" scrapers. Displace with 34 KCL and filter fluid. POOH. 04/22/91 POOH w/ scrapers. RIH with tubing conveyed guns and perforate 11,180'-11,220'. Reverse out and POOH. RIH with frac packer and assembly. 04/23/91 RIH w/ frac string testing to 7000 psi. Set packer at 11,041'. R/U and test surface lines. Perform datafrac. R/U E-line and RIH to retrieve downhole pressure data. 04/24/91 Latch pressure recorder and download dowhole data. Work tool loose from profile. Ran GR/temp log across perfs. R/U and frac Hemlock Bench 1 with 22,600# proppant and 8730 psi max pressure. Allow gels to break. R/U slickline to tag top of sand. 04/25/91 RIH with W/L bailer and tagged sand at 11,650' R/D W/L. Unset RTTS packer. POOH - L/D drill pipe. Started RIH with 4-1/2~' production string. 04/26/91 RIH with 4.5" completion string. Set packer at 10,712'. Pulled seals out of pkr. Started pumping 34 KCL w~corrosion inhibitor. 04/27/91 Pumped corrosion inhibitor and displaced with tbg volume KCL. Landed hanger. Set BPV. N/D BOP's. N/U and tested tree. Released rig at 00:01 hrs 4/27/91. \docs\dvp\d47. doc Energy Systems Technology 15G~ Broadway, Suite 9~1 Denver, Colorado 802~2 (3~3) 861-2424 * ES-LOG True Vertical Depth Results * * True Vertical Depth Data - Full Report * * Terminal Angle Method PROJECT NAME : TBU Operator MARATHON OIL COMPANY Well Name D-47 FLD/UNIT MC ARTHUR RIVER, TBU County KENAI PENINSULA BOROUGH State ALASKA .... , ,' Project TBU ~"~ ..... Comments DATUM IS M.S.L. OPEN HOLE LOGS ~OR RUN #1 NOT OBTAINED DUE TO Date_ HOLE PROBLEMS. C.A.U. G/91. Project: TBU ---- Measured Depth (feet) 12~F. 22~. 32~. 42~. 528. 6 2 ~. 72~. 112~. 122~.~ 1 fi 2~. 172~.~ 1 ~ 2~. 2228. 222 ~. 242~. 252~. 262~. 272~. 282~. 292N. 2~2~.~N 212~. 222~. 222~. 242~. ~52 N. ~ ~62~ .~ 272~. 282~. 412N. 422~. 432~. 442~. 452~. 472~. 492N. 5~2~. 522~. 532~. 552N. Drift Angle (decimal deg) 0.32~ 0,328 0.74~ 0.66~ l.l~ 3.~5~ 4.588 6.868 7.65~ 7.66~ 7.98~ 8.79~ 9.158 1~.~4~ 11.64~ 13.738 16.45~ 19.34~ 22.97~. 26.72~ 30.720 34.95~ 39,19~ 43.858 42.998 41.98~ 42.71~ 43.39~ 44,14~ 44.78~ 45.618 46.~1~ 45.32~ 45.67~ 47.428 47.598 46.84~ 46.13~ 46.24~ 46.44~ 46.28~ 46.5~g 44,659 45.279 44.618 44.73~ 44.~1~ 4~.77~ 41.~99 39.12~ 36.57~ 36.71~ 37.25~ 37.13~ 37.51~ Drift Direction (decimal deg) 317.99~ 318.9~ 291.87~ 297.52~ 269.758 264.858 269.6~g 278.198 285.22~ 38~.180 314.148 324.418 334,828 34~.368 344,798 347.~ 349.648 349.38~ 35~.93~ 351.978 351.64~ 352.790 352.288 351.52~ 35~.152 347.82~ 347.12~ 347.818 347.869 346.648 346.618 346.722 346.929 349.12~ 351.54f 356.138 358.928 ~.76N 2.23N, 5.168 7.27~ 19.61~ 12.35~ 16.94~ 19.47~ 24.26~ 29.842 2~.56~ 32.8~9 35.58~ 36.448 36.358 36.21~ 36.80~ Well: D-47 Page: 1 Depth Interval (feet) True Vertical Dog Leg Depth Severity (feet) (deg/10N fi) 0..080 ~.~80 g.~ N 119.998 ~.833 ~.498 N 219.997 1.S~ 8.919 N 319.988 1.888 1.383 N 419.982 1.08~ 1.915 N 519.963 1.~g 1,987 N' 619.822 1.~81 1.355 N 719.592 1.088 1.38~ N 818.786 1.~1 3.~1 N 917.896 1.~80 6.496 N 1817.~f4 1.~1 13.181 N 1116.~36 1.ggl 22.849 N 1214.861 1.g~0 35.276 N 1313.589 1.~8~ 49.667 N 1412.~57 1.~g~ 66.~86 N 151~.g~i 1.8gg 85.556 N 1687.143 1.~N1 1~8.682 N 1783.O5~ 1.~1 136.538 N 1797.4~7 I.~1 I69.888 N 1889.478 1.g~2 2~7.625 N 1978.799 1.802 252.147 N 2~64.767 1.O~2 382.689 N 2146.732 1.~83 359.522 N 2224.238 1.~83 422.139 N 2297.313 1.~2 ,489.656 N 237~.461 1.~gg 556.838 N 2444.799 1.~81 622.219 N 2518.278 1.~8~ 688.341 N 259~.948 1.~88 755.28~ N 2662.712 1.~N~ 823.152 N 2733.792 1.~N 891.588 N 28~3.745 1.~g~ 961.1~5 N 2873.199 1.ggg 1831.128 N 2943.513 1,880 11~.'387 N 3~13.392 1.8~g 117~,634 N 3~81.~54 1.8~1 1243.466 N 3148.497 1.N~2 1317.132 N 3216.9~1 1.~1 139~.~63 N 3286.2~4 1.NS~ 1462.149 N 3355.367 1.~ 1534.367 N 3424.279 1.88N 1686.778 N 3493.493 1.~81 1678.661 N 3562.329 1.~8~ 175~.616 N 3633.47~ 1.~81 1819.692 N 3783.847 1.~ 1889.891 N 3775.837 1.Ng2 1956.271 N 3846.~8~ 1.~8~ 2~22.624 N 3918.~2 .1.~2 2885.966 N 3993.736 1.gg4 2142.611 N 4~69.1~4 1.8N8 2199.2E6 N 4146,687 1.~81 2252.241 N 4227.ggg 1.ggl 23~8.698 N 4387.167 1.~ 2348.787 N 4386.767 1.8~ 2397.538 N 4466.493 1.8~ 2446.242 N 4545.818 1.80S 2494.998 N 12f.g~g Rectangular Coordinate (feet) (feet) ~.449 ~ W E E E ~.816 2.O21 3.842 4.962 1~.254 ,18.239 3E.862 42.987 54.439 64.4~2 73.295 8~.861 85.92N 91.214 96.553 1~1.645, I~7.749 113.9~'1 12~.182 127.6N9 134.799 143.287 153.353 165.~18 179.12~ 194.25~ 2~9.692 225.286 241.54~ 258.~88 274.615 29~.7~7 3~4.289 315.841 32ff.~25 321.4~ 32~.519 319.561 316.741 31~.25~ 381.071 288.131 272.926 252.474 229.N16 2~.469 167..976 134.559 lf~.380 65.714 3~.208 5.669 41.328 77.8~2 4-0UN-91 g9:3~ Measured Drift Depth Angle (feet) (decimal Project: TBU Drift Direction deg) (decimal deg) ~ell: D-47 Page= 2 36.810 36.24~ 37.5~0 36.42~ 36.86~ 37.210 36.63~ 37.g4~ 37.24~ 37.45~ 38.15~ 38.g3~ 38.14g 38.42N 39.27~ 39.960 39.64N 4~.~lN 41.25~ 41.38~ 42.68g 42.45g 41.36g 4~.32~ 38.89N 37.57~ 36.170 35.36~ 34.153 31.8N~ 31.330 31.11~ 31.N8N 29.89g 28.~2~ 25.58g 26.65g 27.18~ 26.87~ 27.93~ 27.61~ 28.68g 3~.38~ 34.87~ 34.46g 36.39~ 36.87N 37.44~ 38.6g~ 38.4NN 39.g7~ 39.72~ 48.64~ 41.16~ 41.61~ 43.12~ Depth Interval (feet) lgg.gg~' lgg.gg~ lgg.ggg l~O.gg~ l~g.~ lgg.~g~ True Vertical Dog Leg Rectangular Coordinates Depth Severity (feet) (deg/100 ft) (feet) (feet) 1.~g~ 2543.~7~ N 113.777 E 4625.786 4796.554 ,.~::.~ 1.~'0~' 259g,625 N 4787,3.0'2 ,~: 1.~'~'~' 2637.425 N 4868,642 ~'~u:~' 1,~gS 2684.234 N 495~.215 '~ 1.~g 273~.514 N 5~31.~ ~ 1.~N 2776.513 N' 5113 6I~";. .... " :~:~ -1.~N~ 2822 715 N 5195 4:.99J~ ~.~; ~ ~ ' ,,~,;:~ ....~' ~g 2868.533 N ::j~ ~N~ 3N5~. 854 N 56~4. ,;~NN 3~96 .Eg~ N 5686.~g) ~ ...... j~j;Z~g~ 3141.174 N 5849 5~.5~ ~?~l.~gg 3229.892 N 5931, lg9 ='~.:~:1 ,~. 3274 · 413 N 6~12,833 ::?-~1 .~8~ 3318,553 N 6894,578 1.~8~ 3361.859 N 6176,343 l.g~g 34~5,~58 N 6258,894 1,gg~ 3446,549 N 6341,839 1,~8 3488,628 N 6424,821 1,~8~ 353~,513 N 65~6,492 1,~gg 3573.632 N 6588,964 1.~8 ,3617.652 N 6671,357 1,~ 3662,568 N 6754.241 1,8~ 37E7,734 N 6837,61~ 1.8~ 3752,77g N 692~.514 1.g~g 3799,g45 N 7~.451 I .~Z 385~, 11~ N 7879,263 1.8g~ '39~2.687 N 7158,577 1.8~ 3954,832 N 7238,167 1,~ 4~g6..684 N 7318,667 1,~ 4~58,12~ N 7398,761 1.~8 411~,976 N 7479,268 1,~g 4164,489 N 7559,573 1.g~ 4217,74~ N 7639,979 1,Sgg 427~,629 N 772~.~g~ 1.8~ 4324. 126 N 7891,g66 1.~g~ 4375.858 N 7883,26~ 1,g~ 4426,329 N 7966,184 1.~ 4475,362 N 885~,~13 1.~ 4522,398 N 8133,459 1.g~l 4567,61~ N 8217,~11 1.8~ 4612,915 N 83E1 ,~67 l.~g~ 4656,522 N 8385,519 1,8~8 4699,364 N 8469,998 1,~ 4741,85~ N 8554.664 1,~g 4783.438 N 8639,946 1.~ 4824.362 N 8726.286 1,~8~ 4863.533 N 8813,672 1.~ 49~,929 N 89E1,521 1.Sg~ 4937,183 N 899~,~68 1,~ 4972,168 N 9~79,192 1,8~g 5~6,~78 N 9168,537 1,~ 5~38,863 N 148,634 E 184,545 E 219.~80 E 253,778 E 288.7~6 E 323,~56 E 357,632 E 392,559 .E 427,662 E 463,181 E 498,632 E 534,152 E 569,911E 696,181E 643,349 E 68~,232 E 717,283. E 755.26.1E 793,319 E 831,579 E 87E,071E 9E6,945 E 943,539 E 979.g45 E 1013.598 E 1~46.618 E 1~78.576 E 11~9.969 E 1141.631E 1173.636 E 12~5.104 E 1236.358 E 1265.923 E 1294.051E 1319.667 E 1346.391E 1373.549 E 14g~.655 E 1428.~80 E 1454.477 E 1481.3gg E 15~8.874 E 154~.379 E 1571.469 E 16~3.697'E 1635.739 E 1668.269 E 17~1..468 E 1733.905 E 1765,7~3 E '1796.772 E 1827.89~ E 1858.474 E 1888.59~ E 1919.292 E 4-JUN-91 Measured Drift Depth Angle (feet) (decimal deg) 11220.6~ 26.616 1132g.00~ 26.16N 1142~.690 27.31~ 1152~.6~g 28.81g 1162N.6~6 29.68g 11720.6~ 36.13~ 1182~.0~ 29,600 11837.6~N 28.86~ 1192~.6~ 28.6~N Project: TBU Well: D-47 Depth True Vertical Interval Depth (feet) (feet) Drift Direction (dectmal deg) 44.52S 44.96~ 45.82S 46.78~ 47.298 48.56~ 49.346 49.15~ 49.1NN Page~ 3 9257.94 Dog Leg Rectangular Coordinates Severity (de9/166 it) (feet) (feet) lgS.gg6 9347.761 16~.g~6 9436.555 1E~.~ 9524.177 166.6~6 9611.~58 166.N~6 9697.547 l~g.6~ 9785.~g9 17.ggN 9799.897 93.~ 9881.55~ 1.D~D 5D7~.868 N .195D.698 E 1.g6~ 51gl.997 N 1981.851E 1.~6g 5133.971 N 2614.754 E 1.g~ 5166.972 N 2049.872 E 1.~6~ 52~g.558 N 2686.256 E 1.66~ 5233.786 N' 2123.886 E 1.g66 5265.369 N 216~.663 E 5.882 527~.736 N 2166.876 E 1.675 5299.884 N 22~0.519 E 4-0UN-91 FINAL CLOSURE Distance (feet) 5738.559 ProJect~ TBU INFORMATION= Azimuth (decimal deg) ====================== 22.548 A GYRODATA DIRECTIONAL SURVEY DOLLY VARDEN PLATFORM , WELL NO. D-47 McARTHUR RIVER FIELD , COOK INLET FINAL SURVEY RESULTS DATE : 17 APRIL 1991 (SLOT 20) , ALASKA :: AF:,C ho c ~ '-' e, ~;c..~0~.5) oc ¢°07 26~ 2U86) ( 907 ~':'~""" " , ~ '" -'=;'F.~x.~ - t 907 266 '-'30~ ~ for HA~ATHCN OIL COHPANY DOLLY VARDEN, SLOT 20, {{£LL NO. D-47 HCARTHUR RIV£R FI£LD, COOK INLET, ALASKA Date Run: 17-APR-91 02:35:00 Job Number: Surveyor: TOH STODDARD I MI Calculation tlethod: ffltlI.,~s. CURV^TUI~£ Survey Latitude: '60.8058dog N Azimuths are Relative +.o T~UE NORTH Proposed {:ell Azimuth: 20.8000de8 · ~. · Vertical Section Calculated from {{ell Head Location Closure Calculated from ~ell Head Location .,.--~-.-Horizontai Coordinates Calculated from Local Horizontal Reference ,. .. .:. - ; -: !..-- .,:..-. rodata 9irectlonal MEAS INCL AZIMUTH DEPTH ft de~ d~g DOG-LEG VERT VERT SEVER i TY DEPTH SECT ! ON deg/!O0' ft '* C L 0 S U R £ H 0 R I Z 0 N T ^ L DISTAHCE AZiHUTH C 0 0: D ft ,~ f~t .0 120.0 220.0 320,0 420.0 .00 .00 .00 .0 .0 .32 317.99 .32 318.90 .74 291.07 .66 297.52 520.0 !.!0 269.75 620,0 3.05 264.05 720.0 4.58 269.60 820.0 6.88 273.!9 920.0 7.85 285.22 1020.0 7.66 300.10 1120.0 7.98 3!4.14 1220.0 8.79 32t.41 1320.0 9.15 334.82 1420,0 10.04 340.38 1520.0 11.64 3~4.79 1~20.0 13.73 347.00 1720.0 16.45 349.64 1820.0 19.3~ 349.38 1920.0 22.97 350.93 2020.0 26.72 351.97 2120.0 30.72 351.64 2220.0 34.95 352.79 2320.0 39.19 352.28 2420.0 43.05 351.52 iLL DEPTHS REFERENCED TO R.K.B. .0 .0 .ON .27 ,~n 0 ~ ~ =" ~ .3 N .00 220.0 .48 320.0 .6 !.8 30~.8 !.I H .II t20.0 .6 3.0 302.8 1.6 N .60 520.0 .3 ~.~ 295.2 !.9 N 1.96 819.9 -1.2 7.7 23:.£ t.6 ~.I !.57 719.7 -3.8 !4.3 275.1 :.3 N 1.19 918.4 -8.5 35.8 277.3 4.7 N 1.98 1.93 1,70 1.68 !.80 2,81 2.90 3;67 10!7.5 -8, i 49.8 281.3 9,8 1215.5 2.7 ?4.? 292.8 2~.0 1314.3 12.5 B?.6 298.9 ~2,1 .. 1a12.9 '~:' ~ fol,i 30a.8 :? ~ 15!!.1 39.4 118.8 310,5 75.8 !808.~ 5?.4 135.0 '315.~ 97, i 1705.2 79.4 157.6 32!.0 122.6 1800.4 t05.7 185.2 325.5 152.8 ,~o~ 6 '~6.7 ~,8.5 329.5 !~q i 3.77- 198~.3 4.00 :07:.0 **-a.27 2156.0 · 4.26 2235.8 :'3.8~:.-~_~,- 2311.1 ...-~. :.~ ':: .... <_. 173.4 258.0 333.0 229,9 N 215.4 303.9 335.9 277.5 N 2~2.0 356.2 338.3 331.2 N 316.1 414.9 3~0.4 390.9 N 373.6 ~79.5 ~' ~,1.9 456.0 H .OE .2~ .6~ 1.4~ 2.5Y 4.OW 7.6 14.2 36.4 48.6 59.4 68.8 76.7 83.0 88.5 93.9 99.1 104.7 !10.8 117,0 123.9 131.2 139.0 lt~8.3 Pa~e DEPTH ft deg de~ DOG -LEG VERT VERT SEVER I TY DEPTH ~ECT I ON deg/lOO' ft ff. CLO ~ L"EE HOR [ ZONTAL STANCE AZ!HUTH C 0 0 R D ,+ .~=~ feet 2520.0 42.99 350.!5 2~20.0 4!.98 347.~2 2720.0 42.71 347.12 2520.0 43.39 347.01 2920.0 44.14 347.06 3020.0 44.70 346.64 3120.0 45.6! 346.61 3220.0 46.0! 346.72 n'~ 45.32 ~0.0 3~20.0 45.67 349.12 .94 238~.2 ~..'=~ ~ 1.87 2~53.0 ~0.1 .87 2531.9 546.4 .H8 2~05.0 603.2 .76 2677.2 660.7 547.~ c4~.0 681.5 344.1 749.H 2~4.3 818.8 2~4.6 .63 2745.~ 71~.7 ~89.7 3~4.7 .90 2819.1 777.4 959.6 3~4.9 .4' ~: 835.7 1031 ~ ~5.0 3520.0 ' '" ;:~ 5~ 2.~8 22'57.5 "'~; 3620.0 47.59 356.13 3.38 3165.2 I'384.2 3720.0 46.84 358.92 ~.~ 19 ~..no~3.1 ..,,.,"c~; 3820.0 46.13 .70 1.47 35~2.0 121'~.3 3920.0 46.24 .76 .12 3371.2 !2H7.! 4020.0 46.44 2.23 1.08 3440.2 !355.~ 4120.0 46.20 5.16 2.'~ ::n~ : ,~, 4220.0 46.50 7.27 1.55 3579.3 !494.5 4320.0 44.65 I0.61 ~.~ Ol 364~.3 .~=..':~* ~ 4420.0 45.27 12.~: ..' ~8 ?,o 1 .~.~.'=~'~' .... ~ 3~6.0 !39!.2 14~I,9 2;7.3' 1532.2 !H02.O 3~8.5 3.30 3789.9 1704.3 1940.8 3.43 3932.5 1844.4 2065.7 354.0 4.96 4006.4 Ig!!.3 2122.6 355.0 .57 4082.0 1976.0 2!76.4 356.~ ; --; . 4520.0 44.61 16.94 4620.0 44.73 19.47 4720.0 44.01 24.26 4820.0 40.77 29.84 4920.0 41.09 30.56 523.4 )l IEg.2 55'2.6 H 172.1 655.4 N 186.7 721.9 N 202.0 ~o 3 N ~'~ 5 ~57.5 N 233.4 ~26.5 N 249.8 9~5.2 H 268.4 !CE5.9 N 282.7 !!25.6 )i 297.5 1250.5 N 317.5 '~;: ~ N 320.7 I ~26.3 N 32!. 0 !498.4 N 320.0 1570.7 N 318.2 16~2.9 !~ 3i3.5 1714.8 N 305.7 1785.4 N 29~.6 '~;.' 5 ~ 2~0.5 1922.9 N 262.7 205~.5 N 214.7 211~.6 N 184.2 217!.3 N i51.2 ."..L:..~.THO,~i .OIL CC.'i?^NY }'::LY VAE?);, £L~T 20, 'YILL )~9. ,.%4'7 XCARTHUR ~iVE! FIELD, COCK !HLET, Job Number: F~.~oda ta Directionai HEAS I~C',, ~ AZl"~',u DEPTH ft ~..ao8 de( DOG-LE~ VE~T VEET SEVERITY DEPTH SECTION deU!O0' ft ft CLOSURE HOR ! ZC)ITAL DISTANCE AZIMUTH C 0 0 R D ft deg feet 5020.0 39.12 32.80 2.44 ~!58.5 20~9.2 · 5120.0 o~.~i 35.56 ~.v 4237.~ .... q "8 ' 20~8.9 5220.0 36.71 36.44 .54 ~317.7 2156.5 5320.0 37.25 38.35 .5~ 439?.5 2214.4 54~0 0 37. Iq 38.21 14 ~477.2 ~ ? 5520.0 37.5! 36.80 .52 455E.7 233!.1 5620.0 36.90 36.81 .61 4636.4 2389.2 5?20.0 36.!3 38,24 .8~ 47!6.? 5620.0 ~6.15 3?.50 .74 ~797.5 2503.! 5920.0 35.57 38.42 .86 ~878.5 2559.~ 6120.0 35.28 37.2! .22 5041.6 2870.7 6220.0 35.15 36.63 .36 5123.3 2726.! 6320.0 35.03 37.04 .27 5205.! 278!.3 6~20.0 35.25 37.24 .25 5286.9 2838.6 6520.0 35.26 37.45 .12 5368.6 2891.9 5620.0 35.!0 38.15 .q4 i;:O.] 25-17. J 6?~'~ ^ ~ '~ 3~ ,":' '~' ~S';'.' 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COOK INLET, ALASKA ~o):) Number: AKOaglG219 D~e~t~ona! ~EAS INCL AZIMUTH ft deg deg DOG-LE~ VE:T VERT SEVERITY D?TH SECTION aox/mn, ft ft 7520.9 35.!5 al.~ 08 ~,~= n ~ ~ 7720.0 34.77 42.45 .43 6350.~ 3544.0 ?~20.0 33.92 41.36 1.05 6433.1 3596.7 ?920.0 34.44 40.32 .?8 65!5.9 3649.4 8020.0 8120.0 8220.0 8320.0 ~420.0 34.44 38.89 .81 6598.3 3703.0 34.52 37.57 .75 66~0.8 3757.0 34.02 36.17 .94 67E3.~ 3811.! 33.5~ 35.36 67 ~: 34.00 3q.15 .83 6929.7 8620.0 37.99 3!.33 1.10 ?090.5 4035.2 8720.0 37.52 31.11 .49 7!E9.6 4095.4 8~20.0 37.28 31.08 .28 T2;9.0 ~55.~ ~920.0 36.39 29.89 1.12 7329.1 42!4.2 9020.0 36.78 28.02 i.18 7~09.3 9120.0 36.39 25.5~ i.51 7;~.5 9220.0 36.57 26.65 .66 7570.1 9320.0 36.48 27.18 .33 T650.~ 9~20.0 36.85 26.87 .42 7730.6 .9520.0 35.84 27.93 9620.0 34.72 27.61 9720.0 33.98 28.68 9820.0 33.04 30,38 9920.0 33.44 34.87 1.19 1.1~ .95 1.33 2.49 7811.2 7~92.~ 7975.4 8058.8 . . 8142.4 ~32.5 439!.7 ~50.8 45!0.3 q569.1 "~.4 4682.3 4736.9 4790.5 347!.2 12.~ 3570.8 !3.7 3~20.6 14.2 3670.9 !~.6 3722.2 3776.3 3526.T ~a?a 0 ~0.5.9 ~105.~ ¢280.7 4398.3 4~57. 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I 18.7 ~899.4 !3.9 ~950.7 19.1 5001.6 !9.2 5052.2 19.4 5102.1 19.6 5150.6 19.8 5197.~ 20.0 52~2.6 20.2 5£~6.7 E3£U.6 20.5 537!.8 20.? 5a!2.8 2o.g .,94.0 2!.~ 5536.7 2!.5 55:.~.8 11.7 5625.6 2!.9 5677.0 ~o ~ 4590.~ N 1556.0 E 4678.3 N 1619.7 E 4720.9 N 1852,0 E 4763.0 N 1684.9 E J,80~,. 2 .~ 1717.7 E ~,84~,. 3 N 1749.9 E 4882.8 N 1781.3 E agSS.,j H I~43.2 E 4989.5 N !873.6 5022.8 N 1904.0 505~.9 N !93~.8 ': 1~55.~ 5117.9 )1 1997.9 5!50.4 N 2031.9 E 5163.? N 2067.7 E 52!7.! H 2104.7 E 5249.5 N ~' 525~.9 H 2!¢8.! E ~i-~.~ MARATHON OIL COMPANY *~.~ *.~ DOLLY VARDEN F'i ;;',~t 'F o r'.rr, *~ .~..~ McAr-thur'- River- Fie!d., Cook In'let, Ak *~. C: 1 e r.~ r- a. n c e R e F' O r- t ( S r.;, h e r. _i. c,~ 1 P't e t h o d ) E]]i~:.'.'se (:limens.i. ons I"4OT inc'tuded in c,-~]cu]a, ti,:)ns C ;~ s i n s-1 cli m e n s i o n s tx! O",r' i n c '1 u d e d i n c a. ] c u '1 ~..~ t i c, n s P r. o ::< i m i t '¥' r. ,z d i u s i s :3 O("). ~ e e t . r',.EFEF.EN_.E WELl_. 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()0 ":"=,";' '7(::) N :B .1..4., :2:6 W :3508,75 :B 145.92: 3!538.22 :}:: 167.07 .... ,':5'-' =~':', . 5 ..::,._ ,::,/ ...... ::2: I. 88 .1. :'::!:=]9/., '"" '= :3209 I 1 .1.,/-/", l.a N 118,!,, 18 N 1206.1,'.'.'.', N .1.226,06 N .1. 2:.'47 '='.':"] N 1267. :31 N ! 287 ,, :3("~ tq 1:307,, v,...:,.-, N .1. 1 :B. 00 W 204,, :36 S81 .4.9E i _t. 7.40 W :204.25 '::1: :=;:=: i23E 121 79 W ';:' C):=: 7'.';:' .::: S 8 ('3 ..... ::, E :L 26. 16 W 2C, 2,99 <: S 80 :;;'7 E I ::::0.8::.:.:: W :;::'o .... :L ,, o' .::,"'" .::: '::;:::o ..... ;iii ;~) 135,, 25 W 199,92 4 S 79 !:.54. lie I'::':':' ........ 66 N 197 87 4' ,-.:.-.:,o:.,.,., 2,'.'--,E :L 44 ,, 1 ::'-': N :L '-':,, '=._, , 4. 4. < r=; .... .'7.-9 5 E : 7 :B 3 ,, 86:3 :;.240,, 00 ! 36 :B, 02 N :B 2:3,, 34 W :'762.7'7 :':: 2,'=, 0.0 (":.' :L 38 :B. :=: 9 N :3.':;:: 4. ~:~:2.: W : 791 ,, c'.:, 4 3 :;;:.:',E: 0.00 .1. 4. 04 ,, 70 hi :324. :35 W :E:20. 4:3 :3:300, 00 i 425.4.1 I".4 :324, ::.::::ii: W I :B:,-3'7.6 7 N 1:3 4'7 ,, 5 5 lq 1 :=: 6'7.8 5 N ! :3 8'7.6 2 N 14.07. :B:B N i 4.26, ':"/' N n ." 14-/.1.'7. () 6 N i 4,'::,6.55 N 16,'.":,, 41 W .1. '78. 14- < .':2;'76 .1. ! E 17 (). :!:: :7 W 173.7 ::2': <."..:," .... / ._,'= ._'2 '::_ E 175.4:B W !68,96 .:.': S'74 41E 179.94 W 1 ,_/-,._,':'. ::: ::2: 'C :=; ..... 7 :':: .... , r.. i: 9,'3:},': .., 9 t 3400,, 00 1528 ,, 1:2: N 318,83 W !: 9 ?.':/2.5:B 3420. (')C, 1548, .,t.',:: N :3 :L 6, ,.:'::,6 W ,L C, 21 ,, .1.. ,:':~ :B 44.0, (:)(} l ':.f' i. ,,'-,,.--,":? ,, 72. lq :2,14. 1. 6 M f-() 4 9 /-,'"' :-:.: 4,"_", 0 C, (") .1. ='''' ":' =' lq ..... . ...... ::,:3. :....., :':: I i. 29 W 1485.97 N 1505.22 N 1524.45 N · _,4.=,. ,"_',4 N 40. :::_ 2,. 13 T-,.5,.5,:.~,".' 2: 4- -,.1.109.0'!;: :356':.:~..t. 4 41:2: 6,. 44 :B 5 8','-2:. 3 I 4 ! 6:3. '70:2:607.42 1-221 ~ c, :.=: ,=~ :=: ;-.; ,"3;"., 1 '70 Ei:. '~:' 4 N 2 E:6 -: '= W . .~ ..- _.._ _ -.- ~ ._ ._. .. . ~ ? -.j · !. :;;it .,'-i-9 ,, 8 '7:7::.. 6, 0. ,:") . ;">... ;3... .1. 7 2 :=: .7 2: N .-.."':' ,..,'=' ]. . 4 2. W "7[5 J. :,7: '2;'"' ',[': 4 ~:, :?, ~, 2_ (':'.. 0 0 1 7 ,.I-E: 4 '=' .l"'J ,:: ...../? .._ ~'= . : ._ M.. ~ .- n "".-~ 4-1';',:') :=:a :=:6.,26 4- :- · . ~ ... , -'-~/. ~- .- ._ 4217, '72'. .=,,=, 4 4- 244-, 7 C.' ::2: 6, E, 4.2'. 2'. 42 7 ]... 59 ::2: 6, E:::2',. 0:3 /=,:2:8.2:E: N 657.09 I".4 675.88 N 694. ,"'--,0 N ERSTMRN CHRISTENSEN C a Li:::t.,.lf.... A'i" :[ 0l"'4 0 F L. E (~, t:.i;T ]:i ]: F.:.; T A i:'.iCli:.": DETNEE::N NELL. S F::' c, s i t i c, n o n ~.~ e I t D- 4'7 ( D 4.q ..... 2.1. ) MD .... '' _ 1 Y D N S E W C t ,:, s e s t P ,:, s i t i o r', ,:, r', uJ e t i D-.'.-I. 0 R D MD 'TVD N'S EW :30'7, 1:3:3,S 40,, 00 ! '768, 06 N 26'!;', 7 :'"!: W :3:35. ::':.::,.:l. :366 (). 00 .1. 78'7.64 I'4 2 ,'.'.:, :3, :7:: 4 W :7: 6,4. ~:q 9:3680. C, 0 180'7. I '7 N 25/:,. `5, ("D W 3 ? :3. ::.:.: 8 -':ii:'700. ,:":, 0 I :ii!: 2,f--,. ,'5, 2 N 24 'ii:'. 5 :L W 17:7::2.0:7.: N 2.'.':39.75 W 1 '7 .... .=-~,:"D. 64 N 24:3. ""/._.'"5 W 17;.':,9,, 17 N 2,:t-'7.74 W 4.4()4,96 3776.38 44:3 't., .~:."".j ':= :3'7'P 4. '7 :t 4457.4.'2: :7::::::: ~ 2., 5)7 44.8:3. !150 38:3 i..1. 4 _1 '78'7, "'~, ....':::; N ,~"':' =';... I ,, 74 W 180/~.,...I. ,,:.,_ N .~.'-'._, =:'._., '=' , 7 ~=; W .1. 82,:4 ,, 50 N 259. '75 W 1842,,'76 N 263.7.:2 W ,::,,5,..~ 66 N 26'7 ,, '7 i W i878.70 N 271.89 W 1896.6`5, N 276.05 W 19.1.4.5:3 N 280. i8 W .5`5, 7,2 .'.-t. :'-] 820.00 1941. 'ii:' 2 N 1 ,..7., 9. :7:3 W !. 59`5, ~ 4. ,,5, :384. O. 00 .1. 'ii:, 60 ,, 'i;, .1. N .1. :i'.:: 9,/:,'7 N · `5, 25. '74 :::_:: 86 (), 0 () .1. 975:,, 80 N 179.64 N 45:3Zl,,, 80:38`5,6,82' 45,'.'::,CD./.1.:3 ::3884.63 4585, 94:3902, :35 ,-5,84. `5,2:7::9()(). 00 2() 1 '7.4.4 N :[ 58.44 N 7 :t 4.19:392.0 ,, 00 :2:036..1. 3 N .1. 47.2/:, N 743. ,:,'"' ,:, '"'' ::ii: 9 .q.,:}. 0 () .,_";' 0.. 'q... 4 ,, '7'7 N.1...:, ''"'....,':::' .69. W 4611. ::ii: 8:7::919. 'ii:"7 4 ,'.5., :B,'5, ,,/:, 2 :B 9 :B '7.4 () 46 ,'5, :t.. 7:7:: .:,'-' '"~:: ='._,.4 . 7:7:: 468`5,. 75 39'7 :Z'. 00 i932.40 N 1 ,:7.,50. 18 N .1. 967.8'7 N I985.49 N F:;.'.,'? 'F 1-7 '7:3 ,, 68:3 !i;' 60 ,, 00 2 ()'7 :3 . .':ii: 4 N 123 ,, 7 ':;:' W i80:3. :57:35'80. 00 2091 ,, 8 :t. lq i :1_ 1. :36 W I-8:33. :;.::.' 7 4000.00 2. ]. O'ii;'. 9'7 N 99,, 04 W .L :::: .... A .."::'.._, ';= ..., '=' 4020. () 0 ':..:: .1. 2'7. ,'5, :F: lq 8'7. (':, 4 W 4712. `5,`5, 398'F/. 81 4737.45 4006.78 4762.. C, 4 4o23.6,2 478,/_",. :34 4040.2,5, '.7003.82 N :2021.4.:3 N 2' ('D :'-':::: ':'"', N 2056. i5 N i, ::'.:'!;' 1. ~ 4 4 4 () ...... 40,00 ':::' 14. 4, ':.'.._'q N '~'/._.r4 ::: 4 W l-919. .5:`5, 40`5, 0. o. (). ,."-' 1 `5,1 . -:,/-_, N63 . '::.'.....':' N i. 94 :F:. 1 :':.: 4- 080.00 2 .1. 78.18 N 52.79 W i.'..:.,7rq ,:.,-z 4100 cx-~ "'-'I'.-.--'4.21 N 41 ':.":' W . ,. · 1. . ,' u .- ._, 481 I. `5,2:4057.54 48:35.46 407:3.'79 4859.04 4089.87 4:_-_.::5:2. :7::8 4105.78 2074.15 N 20':.-'-' i. 17 lq 2108.01 N 2124.67 hi D i s t a. n c e D :i_ r-e ,::: t i, Betmeen Betu.~een We ! t s Wet t s 89.3'7 -:C S31 49E 85.60 .-'.'.' S23 OE 82. 'ii;'O .:.'1 'S ! 2 48E :F:I. r--;'2_. <: ':'._, iL 46E 284 :':: ~'1 W .1. '""'"", '7 ! S`5, 0 5 W u - - .-', 288. !5 4 W 151. 1 `5, S,5,2 40 W ,::.'-'"'.::,~.'-', 70 W16.q ...... ..... ':'"'", S,5, 4 ':=;'I.W 29,'_':,. :_:,'4 W .1. 78.31 S/:.,6 44W :7::CD I 1 i W .1. 92.84 S 68:3`5, W 305. 1!5 W 207.91 S'70 2W :_.: O'ir,'. i 7 W 22. :3.0 8 S 7 .1. .1. 9 W 31:3. 14 W 2:7::8. () 1 S 72 27 W HRISTENSEN C A L C L.f L. A"f' I 0 N 0 F L.. E A S T D ! S T A N C El BETWEEN WEL_L.S R e 42 : '.::;0/:.:,62227,7 M A r::'osition on u Jell D-4.7 (344-2i) MD TVD NS EW C 1 ,::, s e s .I: F',:, S i t i 0 r': ,:, n ~.~ e t 't D- 4-0 R D !dD TVD Iq:..'-:; EM Di st,ir:ce Dir. ecti Betueer, Betu.~een We ] ] s We t ] s 2410. 78 :2:0 2().00 1129.01 N 2 91.08 W ;24 4 0.6 4 30 4 0.0 C.~ :I. :I. 5 0.6 4 N 2 95.9 4 W ', 4-'7 0 ,, :2:9 :B 0 6 0.0 0 I i '7 2, 2 0 itl :2: () 0, 4 0 W ....... .': ..... ,,:,.. 1 084. 7,:"} N 222418,11 308(),19 1105, 12 N 9 9.8!5 W :B 4 4 7,8'7 3 _t. ,:"~ 1.8 0 1 ! 2 5, _!..-!. N ! 0 4, 1 6 W 3 4'7 7, !1523:31 223, :3 3 I 1 4 5 ,, 0 8 N :L 0 :iii:. 4 4 W 20(), 2226 SF':3 ! 22 20!,89 S82 5:BE '203. t () F:;8 2 ::.:-]6 E :2 ():3,9 -'..1. ._' :' ':',_, 1 5 8 IL-.. :: 500. 0 .1. :B 080. C)() 1193 ~ 66 N :2:04 ,,/-t.'7 W :.'::.:';::' 9 5 4:2: :L 0 0 ...... 0 0 ! ':::' '~ '='':, , 0 7 N :2:0 8. ]. ':::' W 25 5 8, 9 8:312 0, 0 0 1 2 3,/.,, 4-':..:' N :B 1 1.4.'"25 W 252F28, :3:2::3 i 4. 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';:"7 W 1 9 2, A Fi .::] ,-"--" ,-, ::: z~. E .... · ') / ::: _ : 189. ~=~4 .:.'.' S78 C~E ! SA. 1 0 -{ S 7'7 2223 E 182.27 ..':" S76 542 :84 "::~. 20 :B :}': 2,."). () 0 1446,. 09 N :31.:.' :3.9 ,.'.1- W :877.9::ii: :2::340.00 1466. '7(.'.3 N :2:23. i 9 W :9()6,, 6 :I. :B:B6C). 00 148'7.2:3' N :2:22.09 W :':""::'=- 22'7 '-"-'""'", 0 · -,. ..:, ..:, ,:, ~.. 15C, 7, '70 N :::22C~ 64 W ":"::"::'/' '::' i :2:41:2:4..1 3915.71 343:3.65 394.3. '72 :'::453.26 1407.:33 N .1. 66.41 W 142/.::. 96 N I '70.8:2: W 14.4'7.06 N 1'75.43 W t 466.55 N 17'.T.'. 94 W i'78.14 .C '.E;'76 tIE 1'73.73 .::: S75 232 .1. 6.2,:::: 'T.,6 -':: '"'"'"' 4 . . .::,, -'-1. 1 E 1,_/-,._.":'. 8:2: .C F:; 7:2:4 2.' Ii-_-' :: .;:,/_., :2:, ,:.? 1:34 () 0.00 · =i"'"'"" :I ..... ::.,::,, 1 :B N :318. :-3 :'-': W 9 9. s,,.,, F--'; .... :':: :':: 4 2 0 , ('3. ,:'",.. 1 .'=~_ 4 ::::... 4,_,':' t',.I :2:1 6 . ..... L/. W · 02!.1("} 344Q.00 1568.72 N 3.1.4..1.6, W · 049.69 23460.00 i588.9!5 N 311.229 W 23971.6 4:3 4 7 2. :--.: 1 2 .... 9 9 9 . .:,'-' '"':,s :2:4 ,.T¢ 2 . 1 ::: zt.c~27.0¢) 3511.5'!;' 4054.61 22',52220,95 1485.97 N 184.4-:3 W 1505.22 N 188.83.? W 1524.45 N 1 ,.:.:,:2:. :2:4 W 154.'_::.64 N 1'.-.-,7.'78 W 1 58, R =' _ ._ ._, .::7. S'7 2. :_:..:.=s E 152. ?9 <: S 7 1 14 7.2,:-I- .::: 'S 6 9 141.232 <.' S623 142 :l (:)78.27 34,80.00 1609.1 :B N 30:'_-':. 07 W · 10 6.8 5 2225(}cz:'. 0("~ t 6 29.2 0 N 22204.5 .I. W ; 1:2:5. 4' 2:2:520. 0'3 1 ,':':,49. 2:2: N 3':]) 0../_', 0 W !64 c)2 '-'=" c', 66':::', 296 · . . .:,.:,.'.,[ .¢ 0~.:} i 2 .1. N .22223 W 4082. 1:2:3550.24 410 '.-.--'. C)? 3569. 14 ,.'i. 1 ::: 6.4 4 "-" =~':":'. :E: 1 416:3.7 (] :2:,'!, 0'7.42 !562.'76 N 202.2i W 1581.50 N 206.50 W 1 ,/_-,00. 5:2: N 210.76 W 1619.49 N 2i5. '.")1 W !235.24 .::] S66 212 :I 29.08 -::: S6 4 2222 i 22.92 -C '.E;61 :'::2 E t 1/.:,,, 75 <] S58:332 .: .... ,'.:-,,._¢ C) 0 1 ,/" ':":::' 1 i N ":":.' 1 71 W · 2' 2 1. 1 9:3 5 8 0.0 0 1 '7(:.: 8.9 4 N 2 8,5.7 5 W · 2 4 9, ::3 :;:2:3 60,:".~, 0 0 1 '7 2 8. '7 2 N 222': 1.4- 2--_' W · ::3'7:.-:_'.:, 4/_*, :::,':..:,20. ,::x:} 1 748, 4:::: 1'.4 275.75 N 4190,84, :36 26.4 6 42.1. 7.72 23645, :30 4244.70:3664,2;2 4.:-2 7 t. 5'? 2226 83. ()8 163:--:.38 N 219.25 W !657.09 N 22:2:.:38 W 1/.-L=]. · ......_. ...... 8 8 N ,',..'/.?]1 W 1 ,"_-, 9 4.6 0 N 2 :E: i, 6';::.' W 1 10./-',4 -C S55 OE 1 c) 4.. 7 2 'C :-'.:,._, = 0" 4 :B E '.T.,9 1 1 .::: '..--.';4-5 '-' =--'- . -,3 ._i '-':'":' ':;:':-: '::'. ':;q'::' 212 ERSTMRN CHRISTENSEN P o s i t ± c, n o n w e I 1 D- 4. 7 ( [il ,4. ,.'.l ...... 21 ) MD 'T'V[) J"~J ~:5~ EW Closse'.st Po:'.:~it:ion on uel I D-4()Ri] PI]El TVi] N~B EW f"I i ~:...'. t' a n c e D i r'-e c t i, B e t' ~;.e e I] B e t bJ':-2' ~i:: r'~ Wet I s 1,,.Je I t .s i, :307. 1:3:3,":: 4. 0.00 ! 768, 0/:, N 269, 7:3 W · :B :B 5.84 3660.00 ! 787.64 N 26 :iii:. :B..I. W i, :ii: 64.59:3680.0 () 180'7. ! 7 N ::ii: 56. ,':::, 0 W · :39:3.._,":' ,_,':' :'::_ 7 ('). r,.... 0 () i ,:,'-' x."" c:,/' . ,._,/- .6.'":' N 249 . !""11 W ........ :,:~ .-:,o:.i 7 i W 4298 :B 6 :::: / 01 c:,~.=~ I '71:7.: ~: ..... N ........... # u s_~ ._ ." :1 u 4:325 ,, 24 3720,65 :L ';7 :B 2.0:3 N 2 :B9, '75 W /'-'~::i . "q'7"::'::). . . ¢.:,._ ! E:,:!: ........ 26 :L 750 ;.':, 4 N i:.' 4:2:, "7.~::i N 43'78, ._,,_,':' o :B'757 ,, 80 1 .v, ,.,/. o,., 17 N 24'7 ,74 W 81,, 63 S c',... 2'7 W o.-:, 5:9 S :2(') fl])W :.:!:6 = -"'-' c:,c; :::,,:, S ......1 '7 W 9 ;.2. C) 2 S :3'7 '-'"' ..... S4:3 :::}W'~ 7 ,'-",. / / 107.02 'S48 56W 116 5:2: ':'~'::; '~' 21 W t: ._s ...._s . !./:,55. 14 :B880.00 1998.66 N 169.23 W · /:,84.62:3900.00 2017.44 N t58.44 W !- 714 .t. '::' :.5::92(') () 0 .-,r -':,/- ...... z..) ........ 1:2: N I -q. 7..,.9/._, W !'74.3.88 394,:}. O0 2054., 77 iq 1:2:5.69 W 4611.38 3919.'ii-"7 I732.40 N 284.35 W 46:36.62.'-' 39:2:'7.40 1950. 18 N 288.54 W 466, .1.. / .:: 7:'.? 54. / :3 1 9/-, 7.87 N '-'" ..... ........... ... _ ..-. ::;L-'. 70 W ,.t. ,'5, :2: 6. -".,' ._, ~': 3'P'7:2.00 i ":~:: ,:,'- .... ...:,. 49 tq 296. ::5:4 1,4 1 ':"::'. 7 t. '::;/-, (') r'"'l ........... :) 15i.16 S62 40W 164.37 S64 51W 1'78. :B ! :566 44W l.'7'73,68 39/}.,0.00 207:B, 34 hi 1 :;;:::.3':, 72 W ......... ~:.)::..t. 81 N 11i :36 W ~::5:0 ::ii:. ':-i" , . · . 7 5:19 I::1(") , C) C) .... '(' l ::~_ ,.... ,'R'7 27 40 ¢.:) 0 . ,:"~. '.'-~.. 21 ""~...9. 'ir.' 7 N c',......c.' 0,-1- 1,4 · ',B62. .... ':::;"-':',, 4020 ,0() 21:27. ,..,z,::,,_, N 87.. 04 t,4 471:2.66 '3';:' 89.81 ?:: 00:3, :-5:2 N :2:01, 11 W 4'73'7. 455 4006.7:3 202!, 4:2.!: N :BO5. 15 W 4'76':?, 04 4 02:2:. 62 207:8.89 N :B 09, 1 '7 W 4'786:2:4 .,.I.,.'") 40 26, :205 E, 1 '= 1'4 5:1:2:. 14 W i92.84. S68 36.,W 207.91 ::5;70 2W 223.08 S71 19W 2' ::: ::5:01 "'"" "" . .:,, .,-' :271,,.i t. 891,,44 4040,,00 2144.,93 Iq 7Si,34 W k'i.':' :t 9, '.::':'6 4.060, 00 2 :L 6 :t. 76 N 6::::, 92 W [. 948. ]. :':.: .,-1. 0 ::5: 0.0,:7.) 217 :..7..:..1. E: N El; 2.79 1,-4 ' ':"7 '= 9 .00 2 ! '.? 4.21 N 41 ':;':' ....... ,. 7 410(:) ....... W ,,1-811.6,:Z': 4 C}!57.54 2074. 15 N :B .I. 7. z..~.'-"-" N 252 ./_",4 S7:3 ; '~ /.t. 8 :::5, 46 4 C) 7:B. 7'P '20'? 1. 17 N :2:2 :t. 0:2 W 2 E, 6.97 ::5; 74 .... - 4-::5:59. o,.'.r 4. 089,87 210:::. (:) i N :'::24.78 W 2::5: .1.. 07 ':::;75:2:;-it W 48::5:2. :::8 ,q. 1 '" = 7:3 212:4 /'. 7 . 294 c,=-- S 7/:, 22W u ......... 1'4 :2:2::5:50 I,,4 . ;.._, ERSTMRN CHRISTENSEN B E"I" W E: E:- N W E L_ L. S Re.F "-' C],:,sest I:.~,:;sition or, ,~elt D-11 MIl '!"VD NS EW Distance Direct i Be t~.~een Be t"~a, ee n Wel !:s Wel !s ~.:3:30.90 ::3 () 0("). 0 () :!:4.10.78:3020.00 344-,:7). 64:2: () 40.00 !:470. :39:306c.~. OO C)7,4:1. N 285.89 W 29. ('.~.t. N :29 :[~ ()8 W 50.64 N 295.94 W 72.2() N :300.40 W -:::._ ~..9 ,::,.. ::::_. 48 .~."::' 9. :::_ :I. . 46 .1. _'142. ':'"-:,_ o... N ':::'.. 05 .4 '7 W 3:3:27,92:3004.4.6 1161.06 N :2(38, 19 W :'::: :2: 5"7' "'" '= :".:~ (') 27, ' '~ .... 4._ 117':::' 2 ::: N 2-:: 10 '::, 1 W :2::386.70 3050. :B 8 I 197. :F: 4 lq 21 ::ii:. 61 W 89.83 N66 llE 90. :22 N6:3 5 .1. E ':".:'C), 58 N71 252 90.8'7 N 73 50 E ii: 6 i 7,5'? :2:160.00 i:646, '75:2:1:3(}. (}0 :: 675.8,'L-, :B 200, C) 0 i: 704,8::3 ::32:::i'. 0.00 119:2:. ,S 6, N 1215.0'7 N 19'":,/.. 4 2. N 1:25'7, 70 N 12'78.88 N 1 ::30 O, ,.'2:3 N .1.32.1.. 10 N t..:,..C::, o:::: N :':.: 0,.I. ,, 47 W 308. 15 W :2:11.45 W. 314. :36 W ::ii: .I. 6.91 W :319, 0'7 W 32:0, :2:5 N .:,"-"-',....~:. 28 W 91.05 N'76 9 E 91.10 N78:222 91.00 < N80 352 90.81 'C N:.33:362 9o. ,,_..,4 .::: 90, 4.5 .C N89:3:3 E 90.2,"_", <: $87 272 9 .... o. 07 <: F; :::: 4 "",~._.~i I::.- i: 7:2:3,8 ;.'.':, :3 ::.24 O, 00 !:762, '77 ::'.-.'::;liE,(). 00 i:'791,64 .'3:280.00 i:8:20, 4:3 3:30 C). 00 .1. :36:3, 02 N 1:2:82!:. E 9 N 14(')4.70 N 1425.41 N '""-"-' :::4 · g) ~:..-",, W ::324.03 W :B24, .35 W ":'24 '-' .... 3645.82 3258.52 i:349.76, N 236.39 W :2:6'74. ! 6:3281.._'q,..,':::' 1:36 ~'-,_ .0:2: N ~.'":'._:':',_,':', 82 W :B 702 4:2: ::: :::(") 4. '=;':.' 1 '-"-' ..... ::'.'% ~.._, W ............. :,,:, ~ .... N 241 ,, ":' =' :37:30.61:3:327,5:3 13'.:.".'8. ,.%4 I\t 243, 67 W 89.88 .C S81 202 :39,69 <: S78 102 F:,,:, =~ 9 .::] S7.4 =;'-' - .., ..' . .- .~- ... 89. :.'::9 <.' S 71 31 E !i:849,20 :B ::32 C). C) 0 il 8'77, 9 ::ii: 3:34. 0.00 !!: 90,'.':.. 6, ! :B :360.00 'z ~'" ""'~ t::,7 :, .".~.:,._,. :27:2: :2: :2:0,00 144.6, 09 N I466.70 N 148'7. :;.2:3 N i 507. '70 N :32-!::3.94. W ::323. ! 9 W :2::22:. C) 9 W :2:20.64 W :_"-.':758,74 2:BE;,:.'). 4.3 14. i4.59 N 246.08 W :3'784, :30 3371.62 lZl. 28,66 N 248,31 W :3:2:11.9:3 3:2:94,96, .I. 4.4:2:, 26 N 250.75 W :3:3:39.5 :t :341 :.'::. 25 1457.82. N ':.253. 19 W :39,74. S 6, :3 4 t2: 90.80 S58 212 92.20 S5:3:31 E i:963.91:3400.00 .,..:" :;':.'.. 2 . :-'q :':: :34:2 C) .0 c). :I. 0':::: :[..1. 0 :'::: 44 0.00 I. 04.'!..".', 6, 9:3460.00 318.83 W :2:16.66 'W 314. i E, W ::::11.29 W :B 867.0:3:34. 41 .4-9. 1. 472. F:_ 5 N z.'-' =._, =._, . 6, 2 W :3894.4:!3 3464, 6,7 1486.85 N 258, 04 W :'-'~ 92: .1., 8.4:34-8'7,78 _i. 50 i, :2:0 N 26, 0.46, W :39-4.9. 16 3510.85 i5121,7:3 N 262.88 W 9:3.95 '.E;4:2:34. E 96.07 '.34:3 o,:, .~] =: 'S :2:8 ..* s..~ ~ ._ ...~ C) 1.4.5 S:2::7 2:2:E t. 07 8.2'7:2: 4. 80, (')0 i- i. c.',./-.,_. ,:,'-' ._, =- :3 F.; (') 0. () () I, .1. ":-'._,....=i. zi. 2:3.. ~. ~.) .00 i- 1 E,,.'.l-. 02:3!540, 00 1609.13 N t629.20 N 1649.23 N i 6,6'iF-'. :2 ! N 308. C)'7 W :2:C',4.51 W :300.60 W z. :.',::,. 3:3 W :3976.42 353:B,, 8'.:2: 1530. 12 N ';i:65.29 W 400:':: 6(') '-' =- =; ' ':":' '--' -'- '"'' /-, 9 W . . .:.._,._ c,. 1 .~-] 44. 4. 8 N 4 (") 9 ::: 22 :::.~q T ? ,:":; 1 ~ = '~ (') 6 N 9,.'.. ,:., 6. 8 W 4C)55. ! 9 :'::6C, 0. 'F~S:' 1570.8:3 N 2'7 i. 87 W I. i 9:2.59 :."-'[56,0. 00 I. 22' 1, 1 '.:.::' :358 c). 00 1, 5'.' 49, :2: 2.:: :B 600, 00 t. 2'78./4. 6:2:6::-20.00 1689..1.1 N !708.94 N .1. 7:2:2:. 7 ':.2 N 1748.4:3 N 291.7i W 286. '75 W '.7:2:1,42 W 275. '75 W 40:_::2. 10 3624.02 !584.. 56 N 274-. (])4 W 4 ! C):2: 'F.' 4 ::: 647. ;') ;") 1 '= '''"''-' ..' ,' ,'",. ~ 1 W ......... .:. ,:,. 27 N "" '"'''''' '-' 4 .1. :35,7:3 :::669. 'F.':3 1611. 'P4. N 278. :::8 W .4. i 62.4-6 :'-':6,92. :2: .1. 1625..59 tq 2:2:,.'2). 54 W ERSTMRN CHRISTENSEN C: A L. F: U L A T I Oiq 0 F' L.. E A S T D I S T A N C: E BETWEEN W[.::':L.L..S F' o s~ i t i o n o n t~ c, l i D- 47 ( D 44 - 2 ii. ) MD 'TVT't NS E:W Ct,::,s.e!~.t F'c, sition on ~.¢.~el i D-11 MD 'T'VD 1:3,.':}'7, .t. :3:364 (). 0 () 1768. ,'3/z, 1"4 269. '7:3 W '1..._,._,._"::'":' =;, t:? 4:3. 6,.. 60 .0 () ~. '7 A.. '7 .64 N 26:3, :34. N :l. :36 4 N':::, :q,,':., ~:::~ C:, 0 () 1 ''"'; ...... . .... ........ :,J/,17 N 2 5/", 60 W :l- ::ii: '.:.:' :3 , :38:3700, ':]:".':) :[ 82,'.":,. 62N 248', 51 W 4 t 8 $:',, t I :3'715, /::, :3 _t./::, 3 S",, 2 0 N 4:7' ! *.1.. 5 ::::~... :37:3 '7 . =i._ ._,'-':' i/:, 5_ 2_. 0 4iq 424 t, 12 3'7,'.":,('.~. 37 ! 665.41 N 4267.59:378:2;. I .~'-1.. 16 '78. -"/..., '= N :1. 42:2.:: ..................... :2' 0 ":,' 7 ?,"') () 0 1 :q 4 ~i, 98 N 24 ::it ,'"~ ..../- W : '= ,:) S:~ ,2,,") ........ ]. 4..., i :3'74. 0 .t. ""' '":' "::' '::, .::~ z~ 24 ......... :::,o....,.._, _1. N N ,:,,:~.¢ .'.::,7 N :i. 4. 80.0:3 376 O. 00 .t ''"'''''' ~ ,, '" 2';ii: 6, O,S N t. 509, ()2 2780.00 190:3. '7:3 N 21 '7.52 W :[692.06 Iq !'705.34 N t'718.59 N 1 '7:iii: 1.80 lq 1 '744 ':'"':' N ~, .," ,.,., 1 '758. ! 4 N I771.:7'7 N. 1784. :35 N :t, 6. 51; 5 ,, 14 3 8 8 C,, ,:::, 0 15:"!-';,' 8. ,<:, 6 N 16, 9,2 3 W I. 6 8 4.6 2 3 9,:1),:".~. 0 c:, 2 0 i 7.4 4 lq 15 8.4. 4 W 1.714. ,, :t.'.:;' ::::92C~, O0 2 (') :}.': ,:'.:, . 13 N .1. 4'7.26 W 178'8. :'1':'._._, N :[811.69 N 1824.82 N R e 'I: : .-", J(:,..., / I 7 M A EW Distance Dir. ecti Be t u.~e e r, Be, t me e r, Wel I s Welt s 290.6C) W "':":'";' 5';' .~:......~.~ ~, . · .-, ,"', ~ m:~ '7 .,i ::" ~'. .... W :29,S, 5 4 W 2'F:.'8.5 :t. ~ :300.4~--~ N :q02.44 W .... '/- =: 4:3 S 24 25 W ~: ...,._t . .... :;::'77 .. 15 '...F.;:36 OW '":":":~ 21 S :2:7:32 W ERSTMRN CHRISTENSEN AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PERMIT # ~ t - ~ t WELL NAME -'['l~)b~ .... ~-,,1~-7,, COMPLETION DATE L~ !_ ~'7. / ¢~ j CO. CONTACT ~heck off ~r iist data as it, iS ,receiv. ed.*l!,S,t rec~iv, ed ldate i~r 407.. if, not requilred list ~S I[IR' ' "'~407 ["~"~/ZZ~J/drilling history, V' surveY[ Z[ wellteSts ~:>[coredescriptio~A~ cored inte~al~ coreanalysis ..... dry ditch Intervals digital data I Il I I I I II II I Il I llll I ill , ,lin, u Il Il Ill I q~q I ~' IIIII I I III II I IIII I II I t iii I I I II ii I il iiii i I I I I I I I , . I i i ii i ii ii ii i ~1 i ii ii1~ iiiiii iiiii iiiii i i III I I I I II I II ~11 ii i iiiiiiiii iiiiii i i i i I iii i Jl II ! I I , _ ~ iii i iii iiii ii iiii iiiiiii i i ii . ii ii i ii i I i Jl I IIII I iiiii LOG TYPE RUN · INtERvALs SCALE NO. Ito the nearest foot) [inchl100'l ii jL i .._ ji .i .. i ILl II IlL I I I II II I IIIIII ~1 L",~%.,C., ............ ~ t oq ~-it~o? '~ ~-$ ii iii I i I I Jlllll i I I iii I q PfC '! ~i'c [~oP ,,, i ............... Ic?q,,~,~---(t'~o~ ,,, S · iii i ,, ii i iii ,1, II i II II ii I 131 I ii iiiii iiiiiiii i i i i lull I I IIII J I I I .7 . I ii i 14! ~61 iiii i i i i j ii I I I II I II ii I I i iii ii 17! __ljlll..L . . I I I I I II II I I II I I I I Ill I I , ,,,,, , ,,, ,,, ,, I Ill II I I I I I I I I III III I I I J I I GEORGE'S ZIP [] ONE HOUR -~IgI~E HOUR $ ...:-~ SAME DAY $ ~ 24 HOUR OTHER $ TOTAL $ RECEIVED BY DATE ! / TIME Memorandum UNOCAL DOCUMENT TRANSMITTAL May 22, 1991 GEORGE'S COURIER TO: John Boyle FROM: Bob Warthen Kirk Kiloh LOCATION: 3001 Porcupine Drive Anchorage AK 99501 ALASKA Oi,L & GAS CONSERVATION COMMISSION LOCATION: Alaska Region P. O. Box 190247 Anchorage AK 99519 Transmitting as Follows= Trading Bay Unit - McArthur River Field - Dolly Varden D-47 1 blueline and 1 sepia as follows: Phasor Induction Log/GR/SP ~CBT \CET Repeat Formation Tester ~Long Spacing Sonic Log ~Compensated Neutron Litho Density ~Open Hole Tape ~yrodata directional survey PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF ~,c~,zv.~ ~. ~~~//~/~ FORM 1-0C03 (REV. 8-85) PRINTED IN U.S.A, THRU: FROM: ME MORANOUM State of Alaska A~S~ OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi~r// DATE: March 29, 1991 Commissioner/ ~ FILE NO: LG329 - 9_ TELEPHONE NO: SUBJECT: RIG/BOPE Inspection Unocal/Marathon D-47 Dolly Varden Platfrm CK Inlet McArthur Rv Permit No. 91-11 Louis R. Grimaldi~A Petroleum Inspector ~-:_Saturda¥.3Z16991: I performed a RIG/BOPE Inspection on the Dolly Varden platform. Their rig is being operated by Parker Drilling Company drilling well %D-47. Externally, the platform and rig are in need of scrubbing and painting but I found all blowout prevention equipment to be operating satisfactorily. I found the following items not to be in compliance with state regulations: There was not a check valve in between the accumulator and nitrogen back-up system. There is no allowance for bypassing the poorboy gas separator coming from the choke manifold. The kill line has a minimum of four 90 degree turns that were not targeted along with two hammer unions in line. Pursuant to a conferance with Vic Rudolph, Marathon representative, Marathon is presently designing a new choke manifold and kill system. Kent Kelly of National Oilwell, was on the platform performing other duties. His company was building the new choke manifold, I met with him to discuss the ~problem with the separator bypass. This was incorporated into the design. The drilling foreman asked if the kill line targets and line could be repaired when the choke system was changed. I asked Vic Rudolph to submit a timetable to the commissioners that would explain repairs and define time limits. Vic Rudolph agreed to do this. I found all other RIG/BOPE functions satisfactorY. In summary: The rig on the Dolly Varden platform has a large repair job planned on the choke manifold and kill line assembly. I believe a return inspection either during or after repairs are completed is warranted. Attachment. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 · OPERATION: Drlg. / Wkvr UIC Operator U~) ~/./,~ ~'t'~/~x] Permit Location: Sec ,_/_~ _. T ~ AJ R /~CJ M Drlg contrI F~'~--~ Rig# ~. '~. Location (gert'l) ~/~/' Well sign. .(I'~ STAT~ OF ALASKA ALASKA 01L AND GAS CONSERVAT ION COMM ISS BOPE Wa]k-Thru Inspection Report DATE: ~--j~ Representative Well name ~_~/ IN COMPLIANC~ yes n_~o ~n/a A. DIVERTER 1. ( ) ( ) (Iq) line sz & length line conn& anchored bifurcated & dwn wind 906 targeted turns vlvs: auto & slmul taneous aQnular Pack-off condition 2.() () ( 3.() () 4.() () ( 5.() () ( 6.() () 7.() () ( B. BOP STACK 1. (/~ ( ) ( ) wellhead flg wkg press 2 ~ ( ) ( ) stack wkg press 3 ( ) ( ) annular preventer 4 ( ) ( ) pipe rams 5. (2(~ ( ) ( ) blind rams 6 ~/~ ( ) ( ) stack anchored 7 ~ ( ) ( ) chke/kill line sz 90° turns targeted (chke & kil.__]_l ln) HCR vlvs (chke & kill) manual vlvs (chke & kill) connections (flgd__._, whd~, clm_~) drl spool flow nipple flow monitor control lines fire protected 8.() 9.(y () 10.~ ( ) 11, (~). () 12. ( ) 13., () 1~. ~ ( ) 15. ( ) C. CLOSING UNITS wkg press fluid level oprtg press press gauges sufficient vlvs regulator bypass q-way vlvs (actuators) blind handle cover driller control panel remote control panel 1. () () 2 ~ (1 ) () () 6.(x~ (1 7. (~) ( ) 8.(~ () 9.(XJ () 10. () () RECORDS Date of last BOP inspection.' Resulting failures: IN COMPL IANCn~a 11 ( ) ( ) firewall · CW£c~ 12. ( ) ~ ( ) nitrogen power source (back-up) 13. ~ ( ) ( ) condition (leaks, hoses, etc) D. MUD SYSTEM 1. ()~ ( ) ( ) pit level floats installed 2.~ ( ) ( ) flow rate sensors 3. ~ ( ) ( ) mud gas separator ~. (~x) ( ) ( ) degasser ~5. ( ) ~ .( ) separator bypass 6. (~<D ( ) ( ) gas sensor 7. ~) ( ) ( ) chke In conn 8. ( ) ( ) ~ trip tank () 2.~ () 3.' () ( ) 5.() () 6. (X:) () .0o () 3. (~ () ~'~~~) () s. () 6. () 7. {~ () 8.() () () E. RIG FLOOR ( ) kelly cocks (upper,lower,IBOP) ( ) floor vlvs (dart vlv, ball vlv) ( ) kelly & floor vlv wrenches ( ) driller's console (flow monitor, flow rate indicator, pit level indicators, gauges) ( ) kill sheet up-to-date ( ) gas ~etection monitors (HS & methane) ( ) hydr chke panel ( ) chke manifold F. MISC EQUIPMENT flare line vent line 90 ° turns targeted (dwn strm choke lns) reserve pit tankage personnel protective equip avail all drl site suprvs trained _for procedures HZS probes rig housekeeping Date of last BOP test:. Failures not corrected & why: Date corrections will be completed: BOP test & results properly entered on daily record? Kill sheet current? ALASKA OIL AND GAS CONSERVATION COMMISSION January 29, 1991 STEVE COWPER, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501.3192 PHONE: (907) 279.1433 Gary S. Bush Regional Drilling Mgr. UNOCAL P. O. Box 190247 Anchorage, AK 99510-0247 re: Trading Bay Unit D-47 UNOCAL Permit No. 91-11 Sur. Loc. 748'FSL, l130'FWL, Sec. 6, TSN, R13W, SM Btmhole Loc. 988'FSL, 2463'FWL, Sec. 32, T9N, R13W, SM Dear Mr. Bush: 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. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, C) ' Alaska Oii'-~nd Gas Conservation Commission BY ORDER OF THE COMMISSION dlf:Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. January 28, 1991 I- WA II'ER 1o HICKEI., GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192. PHONE: (907) 279-1433 Telecopy No. (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 80.57 Re: The application of Union Oil Company of California, operator of the Trading Bay Unit (TBU), to drill and complete the TBU D-47 well as part of the pressure maintenance project approved by Conservation Order No. 80. Mr. Gary S. Bush Regional Drilling Manager UNOCAL Corp. P. O. Box 190247 Anchorage, Ak 99502-0247 Dear Mr. Bush: Your application of January 7, 1991 for a permit to drill the TBU D-47 requires exceptiOn to spacing requirements set forth in Conservation Order No. 80. The drilling and completion of the TBU D-47 well is expected to provide additional oil recovery from the Hemlock Oil Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU D-47 well pursuant to Rule 5 of Conservation Order No. 80. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION dlf: RAD. 01 / 28/91 STATE OF ALASKA ALASKA _, AND GAS CONSERVATION CO~,...,'IlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill iX1 Redrill I~I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNOCAL (Marathon.Oil Company - Suboperator)106~'~KB above MSL feet McArthur River Field 3. Address P.O. Box 190247 6. Property Designation Hemlock Pool Anchorage, AK 99510-0247 ADL17594 4. Location of well at Platsf°~. ' surface748 'FsL,T~g A-21130,COndFwL,#8 secD°llY6, 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) Varden .'T8N, R13W, . . Trading Bay At topofproductiveinterval600'FSL. 2200'~L 8. Well nu,mber Number 5194234 Sec~32, T9N, R13W S.M. @ 9231'TVD D-47 At total depth 988'FSL. 2463'FWL Sec 32, T9N 9. Approximate spud date ,Crc Amount $200,000 R13W, S.M. @ 9912'TVD ' ~ a/.f/~ 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 12045 MD property line 3500 feet At ConductOrs - 6 feet 9912 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2>) Kickoff depth 3305 feet Maximum hole angl~4;.,Z~;,. Maximum surface 2440 psig At total depth (TVD) psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 33" Existing 16" 102 X-56 73 73 3305 Existin~ 12-1/4 9-5/8" 47 N-80 BTC 11045 73 73 11118 9150 1800 8-1/2 7" 29 N-80 BTC 10845 10918 8985 12045 9912 260 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate JAN 24 ]99! Production t,.Ga Cons. Liner Perforation depth: measured -'~'~~~1.~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch.~ Diverter Sketch [] Drilling program [] Drilling fluid program E~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements r~ 21. I hereby certify ,t~t the foregoing is true and correct to the best of my knowledge, Signed(' ~(_~ ~.~, ~~Z~v,.. Title ~,~.,.~ ,~¢-, ~'~,~v-, Date _91 Permit Number I APl number _ I Ap..p. roy~l~di~t_.e, cover letter I -I u z I · for other requirements Conditions of approval Samples required [] Yes zl~ No Mud log required L-] Yes ~i~ No Hydrogen sulfide measures [] Yes '~ No Directional survey required ~' Yes [] No Required working pressure for BOPE []2M; ,l~ 3M; [] 5M; [] 10M; [] 15M by order of Approved -- Commissioner the commission Date./ '-orm 10-401 Rev. 12-1-85 Submit in triplicate DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: D-47 LEG: A-2 SLOT: 8 (RECOVER D-44) FIELD: AFL No: TYPE: Trading Bay Unit, Dolly Varden Platform 8201-1 Hemlock Producer REVISION NO.: 0 DATE: 12/7/90 SURFACE LOCATION: TARGET LOCATION: BO'i-rOMHOLE LOCATION: 748FS L, 1130'FWL, Sec.6,T8N, R 13W, S. M. 600'FSL, 2200'FWL, Sec.32,T9N,R13W, S.M.@ 9231 'TVD 988'FSL, 2463'FWL, Sec.32,T9N,R13W, S.M.@ 9912'TVD KB ELEVATION: 106 ft. GL ELEVATION: 0 ft. MSL FORMATION ESTIMATED FORMATION TOPS DEPTH(MD) POTENTIAL DEPTH(TVD) CONTENT G-Zone Hemlock 10671 11216 8781 oil/water 9231 oil/water TYPE SIZE CONDUCTOR: 33" SURFACE: 16.00 CASING PROGRAM WT. GRADE SET SET THREAD FROM TO Surf 398' 102.00 X-56 BTC Surf INTERMEDIATE: 9-5/8" 47.0 N-80 BTC PRODUCTION: (Liner) 7" 29.0 N-80 BTC SIZE WEIGHT GRADE CASING DESIGN sE'l-rING FRAC GRD DPTH,TVD @ SHOE 9150 N/A 9912 N/A 9-5/8" 47# N-80 FORM PRSS 4000 4OOO 7" 29# N-80 HOLE SIZE Existing 3305' Existing Surf 11118' 12-1/4" 1O918' MASP 12045'8-1/2~" _ .RECEIVED 2 zt 1991 DESiG~.~Gas Col~s, TENS COLL B~R~tl0rag8 2440 2.98 1.23 1.62 N/A 36.1 1.65 1.97 Page1 ~WOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 3000 psi Hydril type GK annular preventer and a 13-5/8" x 5000 psi Cameron Type U double gate ram type preventer outfitted with pipe rams in the bottom and blind rams in the top. The riser will be rated 13-5/8" x 5000 psi. The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster ,and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. The blowout preventers, choke manifold and associated equipment will be pressure tested to 250 psi and to 3000 psi with the exception of the annular which will be tested to 250 psi and to 2000 psi. The BOPE will be tested every seven days and whenever a flange or seal is broken on the stack. MUD PROGRAM DEPTH DEPTH WEIGHT VISC. WATER FROM TO ppg sec/qt LOSS MUD TYPE 3305' 11,118' 9.2-9.8 60-80 < 15cc's PHPA 11,118' 12,045' 9.2-9.8 40-50 < 10cc's PHPA SPECIAL CONSIDERATIONS: Mud discharges will be monitored and reported per EPA requirements. MUD EQUIPMENT The solids control equipment consists of an Brandt dual tandem shale shaker, a 2-cone desander and a desilter. STARTING HEAD: TUBING SPOOL: WELLHEAD SYSTEM 16" SOW X 16-3/4" 3M W/2 flanged outlets 13~5/8" 3M X 10" 5M w/x-over double studded adapter Page 2 CEMENTING PROGRAM INTERMEDIATE: 9-5/8" @ 11118 ft. LEAD SLURRY: Class "G" w/3% D-20 prehydrated gel + .2% D-46 defoamer WEIGHT: 12.40 ppg. YIELD: 2.16 cu.ft/sk WATER REQ.: 12.40 gal/sk PUMPING TIME: 4 to 5 hrs:min EXCESS(%): 30.00 % SLURRY TOP: 2800 ft. EST. QUANTITY: 1500 sx TAIL SLURRY: Class "G" w/.25% D65 dispersant, .25% D59 fluid loss additive, .2% D46 defoamer WEIGHT: 15.80 ppg. YIELD: 1.16 cu.ft/sk WATER REQ.: 5.04 gal/sk PUMPING TIME: 3-4 hrs:min EXCESS(%): 30.00 % SLURRY TOP: 10350 ft. EST. QUANTITY: 300 sx RUNNING 1 2 3 4 5 6 7 8 9 10 11 12 13 14 AND CEMENTING DETAILS: Remove thread protectors and visually inspect connections. Pickup shoe joints. M/U float shoe and float collar. (Baker-lok all connections to top of float collar) Rig up to circulate and check floats. Run remaining casing. Circulate and condition mud. Pump 10 bbls. fresh water spacer. Mix and pump 30 bbls. of 11.0 ppg scavenger slurry. Mix and pump 1500 sx. lead slurry. Mix and pump 300 sx. of tail slurry. Reciprocate casing as long as possible. Displace cement. Check floats. P/U BOP stack, set slips, and make rough cut on 9-5/8". N/U tubing spool and BOPE. Page 3 CEMENTING PROGRAM LINER: 7" from 10,918'to 12,045' SLURRY TYPE: Class G w/1 gps D600 latex, .1 gps D135 stabilizer, .25% D65 dispersant, .05 gps D47 defoamer, .1% D800 retarder WEIGHT: 15.80 ppg. YIELD: 1.16 cu.ft/sk WATER REQ.: 3.89 gal/sk PUMPING TIME: 3-4 hrs:min EXCESS(%): 100 % SLURRY TOP: 10918 f. EST. QUANTITY: 260 sx RUNNING 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. AND CEMENTING DETAILS: Remove thread protectors and visually inspect connections. Pickup shoe joints. M/U float shoe and float collar. (Baker-lok to top of float collar) Rig up to circulate and check floats. Run remaining liner. Make up liner hanger. Run liner in hole on 5" drillpipe. Circulate and condition mud before going into open hole. Run liner to TD. Circulate and condition mud. Reciprocate liner while cementing. Pump 10 bbls. fresh water spacer. Mix and pump 20 bbls. of 11.0 ppg scavenger slurry. Mix and pump 260 sx. slurry. Displace cement. Set liner hanger. Release liner setting tool. POOH. WOC 12 hours. Page 4 DIRECTIONAL PLAN NORTH EAST DESC MD TVD INCL AZIM COORD COORD RKB 0 0 0 N0.0W 0 0 Existing Pile Kickoff - turn 3400' 3013' 48.12 N13.5W 1121 -289 turn @ 2.5 deg / 100' End of turn 4800' 3978' 48.12 N34.1E 2090 -113 drop @ 2.0 deg / 100' End of drop 5349' 4389' 34.40 N34.1E 2389 90 hold Top of Hemlock 11216' '9231' 34.40 N34.1E 5132 1950 hold Total Depth 12045' 9912' 34,40 N34.1E 5519 2213 VERTICAL SECTION 0 978 1913 2265 5490 5945 POTENTIAL INTERFERENCE: D-47 will cross 2 existing wells as follows: WELL TVD TVD on D-47 Distance Direction D-40RD 3758' 3700' 82' S 2 E D-11 3350' 3320' 89' S 58 E INTERMEDIATE: LINER: COMPLETION: LOGGING GR/SP/Cal/DIL/LSS from 11118' to 3305'. FDC/CNL/Cal/GR 11118' to 3305'. GR/SP/Cal/DIL/LSS from T.D. to 11118'. FDC/CNL/Cal/GR from T.D. to 11118'. A Cement Bond log (CBL/GR) and a directional gyro- survey will be run prior to perforating. CORING PROGRAM No cores are planned for this well. TESTING PROGRAM No open hole tests are planned for this well. Page 5 DRILLING PROGRAM SUMMARY FOR WELL D-47 D-44 ABANDONMENT: Cut and pull and/or metal munch 9-5/8" casing to 3330' Lay a balanced plug from 3330-3100'. INTERMEDIATE: Polish plug to 3315'. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill 12-1/4" hole from 3315' to 11118' per the directional program. Run E-logs. Run 9-5/8" casing to 11,118' and cement with 1800 sx. WOC. Land casing as cemented and nipple up BOPE. Test BOPE, choke manifold, and casing to 3000 psi. LINER: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill 8-1/2" hole from 11118' to 12045' per the directional program. Run E-logs. Run and cement 7" liner with 260 sx. WOC. Test BOPE, choke manifold, and casing to 3000 psi. COMPLETION: Cleanout casing to PBTD. Run gyro and CBL. Perforate the Hemlock sands with TCP guns. Kill well, POOH. Set permanent production packer. Run and land 3-1/2" tubing with SSSV. Nipple down BOPE. Nipple up tree. Page 6 (~) 3" Howco Lo Torque 5000 psi Valve All F~ange$ are 3' 5000 psi Remote Adjus.table Choke MARATHON OIL COMPANY DOLLY V ARDEN PLATFORM CHOKE MANIFOLD Targeted Tee Vent Line Targeted Tee Targeted Tee Targeted Tee ~ Targeted Tee Stop Cock Valve (To Be Left Open) Pressure Sensor Rig Floor 3/4' Manual Choke I 1/2' Manual iChoke 3~ Targeted Tee 3" Bull Plug 2' Blind Flange 6' to Shaker Choke Line 3" 5000 psi MARATHON OIL COMPANY DOLLY V ARDEN PLATFORM BOP STACK Flowline 13 5/8'x 5000 psi Annular Preventer U Kill Line 3' 5000 psi Pipe Rams Blind Rams .,~___~---~- Clamp Connector 0 13 5/8' 5000 psi Double Rams Choke Line 3' 5000 Drill Deck Floor o o Spool Pieces to Casinghead Iz ~ I I . i . $ + + MARATHON OIL COMPANY McARTHUR RIVER ~ ? ATHON 0xl Compar y Dolly Varden Platform Well · D-47 Field : Trading Bay Unit Location · Cook Inlet, Alaska Ireated by : jones For: B ROY ate plotted : 7-Dec-90 lot Reference is D-47 version t5. oordinotes ore in feet reference slot #A2-8. rue Vertical Depths ore reference wellhead. I-~IIEASTMAN IZ/Z/]IIC H RISTEN S E N N 34 DEG 9 MINE 5¢90' (TO TARGET) ~ 20OO ~ 1000 .. C/) 1000 4000 _ 5000 - 6ooo 7000 8000 900O Tmd= 11216 Dep=~490 North 5152 East 1950 KOP / Tie-In Point Tvd=3013 Tmd=3400 Dep=94.5 No~h 1121 West 289 ........ East -- > 2000 10DO 0 1000 200O 3000 Sec. 32, TgN. R 3W ;~Oc,.£M LO<~ LocoUen: emtock 10000 11000- Surfoce LocoUon: 748' FSL~I150' F'WL Sec, 6. TSN. R13W OP Tvd=3012 Trnd--3400 Dep=94§ 2.5 Deg/aOODogleg ) FtFt 4'~'5~3~'x7.50~ End Turn / Begin Drop Tvd=3978 Trod=4800 Dep=191,:3 .... '%.~, End Angle Drop 4-9 Dap=2265 AVERAGE ANGLE 5¢ DEG 24 MIN , ~/~,, c, TO / 7 U~- 915 Trnd=12045 Dep=5945 vl~7_.~ I I I I I I I I I I I I I I I I I I I I I I I I 2000 1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Scale 1 ' 500.00 Vertical Section on 20.81 azimuth with reference 0.00 N. 0.00 E from sial JLA2-8 9000 8O00 7O00 1 900 1850 1800_ 1750 _ 1 700 1650. 1 600 _ 1550 1 500 1 450 1400 400 I ~50 300 5100 41 O0 5000 4000 4900 4800 I I I 4700/ I t I ! I I I I I ! 390~1 I /' 3600 I I 3800 3700 250 200 150 1 O0 50 0 I I I I i I ! ! / 700 I 3800 I I I I 3700 D-44 3400 3300 I 3600 I I I 4500 I I 3500 4400 . 3400 3300 3600 .RECEIVED ;JAN 24 1991 I I I I I I I I I 400 350 300 250 200 150 1 O0 50 0 _ 1 900 _ 1 850 1800 1750 _ 1700 _ 1 650 _ 1600 _ i 550 _ 1 500 _ 1 45O _ 1 400 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__/' Suspend __ Alter casing __ Repair well __ Cl~ange approved program __ Na rater 5. ype of Well: I ~, 2. rr~l~t~(~ (Marathon 0il Co - Sub 0pera~:or) Deve, opment__ . ! Exploratory __ 3. Addr ss ' Stratigraph~c P. 0. Box 190247 Anchorage, AK 995~L9 Service-- / 4. Locatlon of well at SurfaCe · Leg A-7 gond. #8 Dolly Var'den Plattonii 748' FSL, 1,130' F14L, Sec. 6- 8N- 1314- SM At tom of Lpur.~d~ctive interval 2,550 FSL, 350' FWL, Sec. 31 - 9N- 1314- SM At eff~c/~o~Pt~NL, 291' FEL, Sec. 31 - 9N - 13W- SM Operation shutdown __ Re-enter suspended well __ Plugging __ Time exlens,on __ Stimutale __ Pull tubing __ Vanance __ Pedorate __ Other __ Attot~l,~, FNL, 215' FEL, Sec. 31 - 9N- 13W- SM CnDca~tu~..elevQtion (DF. 9.r[~ B) uo F,U above Mb feet fUn~t or Property raa~ ng ~ay 8. Well number D-44 9. Permit number 85-122 10. APl b r 5o~-~019S-01 12. Present well condiUon summary Total depth: measured true vertical 13,070' 13,070'-12,981' cement 9,990' feet Plugs(measured) 12,745' PX Plug feet 12,432' -12,465' BP & Cement Effective depth: measured 12,432 ' feet Junk (measured) true vertical 9,530 ' feet None 13. Casing Length Size Cemented Measured depth True vertical depth Structural Conductor · - Surface 3,305' 16" 4,550 sx 3,305 ' 2,942' Intermediate 11,218' 9-5/8" 2,300 sx 11~.218' 8,675' Production 2,151' 7" 505 ~~~,OZO'~'F~' ~ 9,990' Liner ./~t~_EVE~ Per;oration depth: measured (;El See A1;~'achment #1 U true ve~ical ' / 3-1/2" 9.2~, N-80 Tbg at 11,958' { · Packers and SSSV (type and measured depth) ~ ~ ' Otis WBR Pkr'. e 11,904'; Otis WD Pk~ e 12,725'i Otis 3-1/2" S~ies 10 BV e302' Attachments Description summary of proposal __~.....DetaJled operations.9~gram __ BOP sketch __ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approVed 15. Status of well classification as: Oil __ Gas __ Suspended __ Service 1Z I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed (/~ a¢.,-~ ~ (~b ,.,...~,,, Title (~e_,~ . '~ ,r \,~, ''i~ ~ ' FoR'COMMISSiON USE ONLY~ ' conditions 6LApp'roYal: Notify Commission so representative may witness Date Plug integrity, __ BOP Test __ Ia3c_.~tion clearance __ Mechanical Integrity Test -- Subsequent form required 10- ~ ~ OOP'~ Approved by order of the Commission J Approva, No. a~U~,~,iAL- SIGNED ~3Y LONNIE C. SMITH proweO d Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Bench 1 Bench 2 Bench 3 Attachment #1 Well D-44 Perforations 12,108' - 12,148' MD 12,175' - 12,208' MD 12,240' - 12,290' MD 12,308' - 12,326' MD 12,350' - 12,380' MD 9,301' - 9,329' TVD 9,347' - 9,371' TVD 9,393' - 9,429' TVD 9,442' - 9,454' TVD 9,472' - 9,493' TVD \doc s\dvp\d44 rd. doc Attachment #2 Wel 1 D-44 ~'~' Plug and Abandon Procedure 1. Skid Rig to Well D-44. 2. Kill well. Fill and test 9-5/8" x 16" annulus to 1000 psi. 3. Close ball valve. Set BPV. 4. ND tree. NU and teSt 13-5/8" BOP stack to 250/2500 psi. . Pull tubing and LD same. If unable to pull, make cut at 11,700' and pull tubing. 6. Run cement bond log 3500' to surface to find top of cement, 7. If top of cement is not seen or annulus fails to test in Step~, perf 3200 - 3202' with 2 SPF. Squeeze 16" ~annulus through perfs after Step .... 10, if perf. is necessary 8. Make 7" bit and scraper trip. 9. S~r_e_tajmer_a~O.'. Down squeeze production perforations. ~-Leave 75' cement above packer. 10. Set 9-5/8" CIBP at 10,850'. 11. Set CIBP at 3500'. Make cut in 9-5/8" casing above top of cement or at 3400'. 12. PU BOP Stack. Remove tbg spool. Tack slips to casing. Hang stack from substructure. 13. Spear casing and remove slips. NU and test BOPE. Spear and recover g-5/8" casing. 14. Mill 9-5/8" casing to 3400". 15. RIH with plug.cutter and set cement plug 3500 - 3100~'f..,,~ \docs\dvp\d44 rd. doc Attachment # 3 MARATHON OIL COMPANf- DOLLY VARDEN PLATFORM BOP STACK Flowiine 13 S/8'x 5000 pal Annulet Preventer , U o o ..__---------- Clamp Connector Drill Deck FIoM ~ " Spool Ple~e& lo - Casinghiad ~ 3' Howco Lo To/qua SO00 psi Valve All Flanges i~e 3' SO00 psi CHOKE MANIFOLD 3' Vent Line Pfc llU~e Senior Remote Choke ' 3/4' Manual 3' I 1/2' Manual Choke Stop Cock Valve (To Be Left Open) Bull Plug 2' Blind Flange 6' to Shaker _ ~ . RII Fleet -%~ Choke Une 3' SO00 pit (2) Loc ,~£~ 8~-~ (2 thru (8) (3) Admin ~ ~ //~.~/~ / ........... (9-~hru 'i3) " (10 and 13) (i4'th~' 22) ~ , , (23 thru 28) 2. Is well to be located in a defined pool , ............................ 3..IS well located proper distance from property line. ................. 4, IS well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is Wellbore plat included ... ............. 7. Is operator the only affected party .............. . .................. 8. Can permit be approved before fifteen-day wait ....... ............... 9. Does operator have a bond in force ................... ' ............... 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ................................... 12. Is the lease number appropriate ..................................... 13. Does the well have a unique name and number ......................... 14. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 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 conductorand surface . ........ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked~off froman existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ..e.e.ee.eeee.eeee.....e.eee ,, Is a diverter system required e..eeee.eeee.eeeeeeee.eeee.eeeesee.eee. Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of ~~ BOPE attached. Does BOPE have sufficient pressure rating - Test to ,~~ psig ~_ Does the choke manifold comply w/API RP-53 (May 84).~ .............. Is the presence of H25 gas probable ................................. O ~O (29 th~u 31) Geology: En~eering: DWJ rev: 11/30/90 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. ' INITIAL ....... GEO. UNIT '" ON/OFF POOL CLASS STATUS AREA NO. SHORE 5.2.0 Izo Oou I-o,'/ .zo t:z'o 70 o,O Additional Remarks: ,0- ~' ~o 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 =------* ****************************** STATE : STATE API NUMBER : 50-733-20195-02 REFERENCE NO : 74505 IS TaDe Ver~fication [.isting ChlUmberger Alaska Computing Center 23'APR-1991 21:56 SERVICE NAME : EDIT DATE : 91/04/23 ORIGIN : FLIC REEL NAME : 74505 CONTINUATION # : PRE¥IOUS REEL : COMMENT : MARATHON OIL COMPANY,MCARTHUR RIVFR,D-47,50-733-20195-02 DATE : 91/04/23 ORIGIN : FLIC TAPE NAME : 74505 CONTINUATION # : 1 P~EVIOUS TAPE : COMMENT : ~A~ATHO~ 015 COMPANY,MCARTHUR RIVER,D-47,50-733-20195~02 **** FILE HEADER **** FILE NA~E : EDIT ,001 SERVICE : FL!C VERSION : 001A06 DATE ~ 91/04/23 MAX REC SIZE : ~.024 FILE TYPE : LO LAST FILE : PAGE~ SCHLUMBERGER WELL SERVICES COMPANY NAME: MARATHON OIb COMPANY WELL: D-47 F~ELD~ ~cARTMUR RIVER BOROUGH~ KENAI BOUROUGH STATE: STATE AP1 NUMBER~ 50-733-20195-02 bOCATION~ 748' FSL & I~30' FWL SECTION: 32 TOMNSHIP: 9N RANGE: 13w PERMANENT DATUM~ MSL ELEVATIONt 0 LOG ~EASURED FROM K,B,~06.2 ABOVE PERMANENT DATUM IS TaLe Verlftcatlon I..istinq chlumberger AlasKa Computin~ Center 23-APR-1991 21:56 PAGE{ ELEVATIONS KB: 1o6.2 DF: i05,2 DATE LOGGED: ~UN NUMBER: TD DRILLER: TD LOGGER: 12-aP~-1991 ONE 11930 11910 CASING 1: 9 5/8" @ DRILLER'S DEPTH OF 10978 AND LOGGER DEPTH OF 10952 BIT SIZE 1: 8 I/2" TYPE FLUID IN HOLE: FRESH GEL MUD DENSITY: 9,8 VISCOSITY: 40 PN: 9,5 FLUID LO$S~ MUD RESlSTIVITY~ FILTRATE RESISTIVITY:' MUD CAKE RESISTIVITY: 2 74 ~ 48 2[28 ~ 48 2 84 ~ 48 TISE CIRCULATION ENDED: 0130 4-11-91 ~IXIMU~ TEMP ~ECORDED: 175 LOGGING DISTRICT= LOGGING ENGINEER: WITNESS= KENAI AK, b. HA6GARD, C, UNDERWOOD TOOL NUMBERS: SGC 660 CNC 239 ORS 2981 TCCA 115 NSC 907 TCM 535 DATE JOB STARTED: 20-APR-g1 JOB REFERENCE NO: 74505 LDP/ANA: $, DEES FILE - ED!T.O01 ~ARATMON OIL COMPANY MCARTHUR RIVER D-47 50-733-20!95-02 MAIN PASS LOG DATA FOR LITE FROM FIELD FILE .041 ~AIN PASS LOG DATA FOR DSS FRO~ FIELD FILE .002 ~AIN PASS LOG DATA FSR LDTD FROM FIELD FILE .017 ~AIN PASS LOG DATA FOR CNTH FROM FIELD FILE .017 11900 TO 10954 11874 TO 10954 11907 TO 10954 11891 TO 10954 IS Tare Verification I,Istl, n~ chlumberger AlasKa_ ComDutJ. nq CeDter 21:56 DAIA SAMPLED EVERY -.5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME DIT-E .DTE LDT .bDT CNT-A/D/H ,CNL [,SS .LSS PHAMOR DUAL INDUCTION SFL LITHO DENSITY COMPENSATED NEUTRON bONG SPACED SOMIC ****************************************************************************** PAGE: 3 TABLE TYPE t CONS TI)NI VAbU DEFI CN FN SECT TOW~ RANg COUN STAT NATI bAT! LONG WIT~ SON PDAT EPD EKB EDF TDD TDL BLI TLI DFT DFD DFpH DFV DFL ~ST MFST FT FT FT FT FT FT FT FT FT G/C3 CP F3 OHMS OEGF DEGF MARATHON OIL COMPANY MCARTHUR RIVER D-47 50-733-20195-02 SLOT 9N KENAI BOUROUGH STATE USA C UNDERWOOD 99 25 11 !0 10952~ FRESH GEB MUD 9,800001 2,74 2'28 48, Company ~ame Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Latitude Longitude Witness' Name Service Order Number Permanent datum Elevation of Perm, Datum bog Measured From ABOVE PERMANENT DATUM Elevation O~ ~ellyBushin~ Elevation of ~erric~ Floor Elevation o~.~round Bevel Total PePth Drlller Total DePth - 5oGger' Bottom Log Interval Top Log Interva~ Drilling Fluid Type Drilli, no Fluid DenSity Drillin~ Fluid Ph Drillind Fluid Viscosity Ortlltng Fluld Resistt9it¥ of ~Mud Sample Mud~Sample Temperature Resistivity of"mud filtrate MUd Filtrate Sample Temperatu IS Tape Yerification Listing chlumberger AlasKa Computing Center 23-APR-199i 21:5B PAGEI 4 TUMI VALU DEFI R~CSMcST DEGFOH~M ~ ~ 4 Resistivity o~ MUd Ca~e Sampl .~ ~ud CaKe Sample Temperature TC$ 0~30 4-11-91 Time Circulation Stopped · STEN DEGF -999.25 Surface Temperature BHT DEGF 175. Bottom Hole Temperature T~BLE TYPE ~ CURV DEPT ClOP IDPH CIMP IMPH CtbD ILD IFRE IOOF IIRD IIXD IIXN SFLU TENS ~RES HTEN DPHI RHOB DRHO PEF LITH SSI SS2 $$HV S1R~ LSR~ LUR~ CALI Depth Channel Name INDUCTION DEEP PHASOR CONDUCTIVITY INDUCTION DEEP PHASOR RESISTIVITY INDUCTION MEDIUM PHASOR CONDUCTIVITY INDUCTION ~EDIU~ PHA$OR RESISTIVITY Deep Induction Standard Processed Conductivity Deep Induction Standard Processed Reststlvttv ~edium Induction Standard Processed COnductivity Medium Induction Standard Processed Resistivity Induction Calibrated FreouencX IDQF DEEP INDUCTION ~UAibiTY F CTOR IMDF ~ED INDUCTION QUAbITY FACTOR Deep Induction Real Intermediate Conductivity Deep Induction Quad Intermediate Conductivity ~edlum Induction Real Intermediate Conductivity ~edi~m Induction Ouad Intermediate Conductivity SF5 Resist~vit¥ (unaveraged) Spontaneous Potential Gamma Ray Tension Mud Temperature MUD Resistivity Head Tension Densit Porosity Bulk D~nsity Delta Photoelectric Factor Quality control of long spaclngpin for LDT Quality control on short s c ~g for LOT Long Spacing COmputed CountaRate (LL+LU/~) Long UPper 1-2 Window Count Rate Long bower Window Count Rate Ltt~olog Window Count Rate Short Spacing 1 window Count Rate Short Spacing ~ Window Count Rate [~ong Spaci 1 age Output na High vot Short Spa !fig High V ltage 5oop Output ~pacc o . Short ln~ 1 Density Long S~acin RHOB (Uncorrected) Long ubper- Caliper IS Tape Verification Listing chlumberger AlasKa Computing Center 23-APR-199! 21:56 PAGE: D£FI GR Gamma Ray TENS Tension MTE~ Mud Temperature PRES ~UD Resfstivlty HTEN Head Tension NPHI Neutron Porosity RTNR Raw Thermal Neutron Ratio TNPH Thermal Neutron Porosity TNRA Calibrated Thermal Neutron Ratio NPO~ Neutron Porosity Output From an APpliCation Program RCNT RCNT RCFT RCFT CNTC CNTC CFTC CFTC GR Gamma Ray CALI Caliper TENS Tension ~RE$ MUD Resistivity ~TE~ Mud Temperature HTE~ Head Tension DT DELTA-T' DTL DE~TA-T LONG SPACING TTI TRANSIT TIME 1 TT2 TRANSIT TI~E 2 TT3 TRANSIT TIME 3 TT4 TRANSIT TIME 4 SP Spontaneous Potential GR Gamma TENS Tension ~TE~ ~ud Temperature ~RE$ ~UD Reslstiv~ty HTEN Head Tension ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE V~LUE ! 66 0 2 66 0 3 73 292 4 66 ! 5 66 6 73 7 65 g 65 11 66 3 IS TaPe verification Listing cblumberger Alaska Computir~g Center 23-APR-1991 21:56 PAGEI mm#mmmmmmmmmmmmmmm~mmmmmmmMm~m TYPE REPR COD. VALUE 12 68 13 66 0 14 65 FT ~5 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API AP1 API API FIBE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ bOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 381485 O0 CIDP DTE M~HO 381485 00 IDPH DTE OH~M 381485 O0 CIMP DTE MMHO 381485 00 INPH DTE OHMS 381485 O0 CILD DTE ~MHO 381~85 O0 IbD DTE OHMM 381485 00 CILM DTE ~MHO 381485 00 IbM DTE OHMS 38~485 00 IFRE DTE HZ 38i485 00 IDOF DTE 381485 00 I~OF DTE 381485 O0 IIRD DTE MMHO 381485 O0 iIXD DTE MMHO 381485 00 IIR~ DTE MMMO 381485 O0 IIX~ DTE M~HO 381485 00 SFLU DTE OH~M 381485 00 SP DTE MV 38~485 O0 GR DTE GAPI 381485 O0 T~NS DTE LB 381485 00 MTE~ DTE DEGF 38~485 O0 MRE$ DTE OHMM 381485 00 HTEN DTE LB 381485 00 DPHI LDT PU 381485 00 RMOB LDT G/C3 381485 00 DRMO 5DT G/C3 381485 00 PEF bDT 381485 00 OLS LDT 381485 O0 ~SS LDT 381485 00 LS LDT CPS 381.485 O0 LU bDT CPS 381485 O0 L5 bDT CPS 381485 O0 LITH LDT CPS 38~485 00 SSI bDT CPS 381485 00 $$2 LDT CPS 381485 00 LSMV,LDT V 381485 00 SSHV LDT V 381485 00 S1RH LDT G/C3 381485 O0 LSRH bDT G/C3 381485 O0 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 ! 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 ! t 1 4 68 0000000000 000 O0 0 I t 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 I 1 I 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 ! 1 4 68 0000000000 000 O0 0 i 1 I 4 68 0000000000 OOO O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 I I 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 i 1 I 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 000 O0 0 1 ! i 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 IS Tape Yerlficatlon Listinq chlumberger AlasKa Computlnq Center 23-APR-1991 21:56 PAGE~ .A~E SER UNIT SER¥IC APl APl ~PI AP1 L NUmB N MB SIZE REPR PROCESS ID ORDER ~ hOG TYPE CLASS MOD NUMB SAkP EDEM CODE (HEX) '"'"'"",,','"'"""~u,. ~ c~,4~s ..... oo'"'",'"'"'"'""'"'"'"'"'"""','"'"'"ooo o o t ~ ~ 4 ~, ooooooo CALl LDT IN 381485 00 000 00 0 1 1 I 4 68 0000000000 ~ ~ ~ ~4~ oo ooo oo o ~ ~ ~ ~ MTEM LDT DEGF 381485 OO 000 00 0 1 1 1 4 MRE$ LDT OH~" 381485 O0 000 O0 0 1 1 I 4 ~... c~ ~ ~4~ ooooo oo o ~ ~ ~ 4 RCFT CN5 CPS 38i485 O0 000 O0 0 I I ! 4 CNTC CN5 CPS 381485 O0 000 O0 0 1 1 1 4 c-c c~ c.s ~,~,~ oo ooo oo o ~ ~ ~ 4 ~. c.~ ~ ~,4~ oo ooo oo o ~ ~ , 4 TENS CNL LB 381485 00 000 000 I 1 1 4 ..~s c.~ 0.~.~4.5 oo 000 oo0 ~ ~ ~ 4 ~ c~ ~ ~.,4~5 0 ~, ~ ~ 4 .~s~ c~ ~ ~8~4.~ 0 ~ ~ ~ 4 DT LSS US/F 381485 0 1 I 1 4 0 1 ~ I 4 TT TT4 LBS US 38'485 0 I I 1 4 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 OOOO000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 DATA D~PT, IMPH,DTE Ib~.DTE SFLUoDTE MTE~ DTE RNOB BDT 0S$ LDT LITH LDT SSHV LDT CALl LDT MRES LDT !2000,500 7,645 7,523 109,875 7 188 175 888 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 CIDP UTE CIbD UTE IFRE UTE IIXO UTE SP DTE MRE$ UTE DRHO bDT LS.LDT SS 1 . bDT SIRH,LDT GR bDT H ,,, EN, 12 38 IDPH,DTE 4I 1 IIR~.,DTE -62 1 GR,DTE 0 788 HTEN,DTE -999 250 PEF'LDT -999 ~50 LU,LDT -999 50 SS2~LDT -999 250 LSRH,LDT -999 ~50 TEN$~LDT -999 50 NPMI.CNb 8 195 CIMP,DTE 8 039 CILM'DTE 3 000 IMOF,DTE 125 500 IiXM,DTE 40 ~844 TENS~DTE -32768 000 DPHI.LDT -999 250 OLS,.LDT '999 250 LL,LDT -999 250 LSHV'LDT -999 250 LURH,LDT -999 250 MTEN.LDT -999 250 RTNR,CNL ~o ~o 13~ 875 000 '9 742 ~i~s ooo -999 '999 56 '999 290 '999 250 '999 · -999 50 m999 50 IS Tape verification Listing chlumberger Alaska Computing Center TNPH.CNL -999.250 TNRA.C~4L RCFT CNL -999.250 CNTC.C~L CALI:CNL -999 250 TEHS.CNL HTE~.CNL -999:250 DT.LS$ TT2.LSS -999,250 TT3.LSS GR.LSS -999,250 TENS.hSS HTEN.LSS -999.250 DEPT. I~PH DTE IL~ DTE IIRD DTE SFLU DTE ~TE~ DTE RHOB LOT QSS LDT LITH LOT SSHV LDT CALl LOT ~RES LDT TNPH CNL RCFT CNL CALI CNL HTEN CNL TT~.LSS HTEN.LSS 12000 000 7 645 7 523 109 875 7 !88 175 888 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999,250 -999.250 -999.250 :999 250 999:250 -999.250 CIDP.DTE CILD.DTE IFRE.DTE IIXD.DTE SP.DTE MRE$.DTE DRHO.LDT L$,LDT SSI~LDT SIRH.LDT GR.LDT HTEN.LDT TNRA.CNL CNTC.CNL TEN$&CNL DT.LSS TT3.LSS TEN$.LSS DEPT IL~,DTE IXRD.DT~ SFLU,DTE MTEM,DTE RHOB,LDT OS$.LDT LiTM.LDT SSHV,LDT CALI.LDT MRES'LDT TNPH.CN5 RCFT,CNL CALI.CNL HTEN~CNL TT2.LSS 11900 000 7 730 7~35 109 38 8.523 175~775 0 80 95 625 1665 000 lO 688 0 861 ~4,4~4 1093,629 10,688 575.000 737,000 31,813 1137,000 CIDP DTE C!LD DTE IFRE DTE IIXD DTE SP.DTE DRHO LOT L~i LDT SS1, LDT S1RH,~DT GR LDT HTEN bDT TNRA CNb CNTC CNb TENS CNL DT.LS$ TT3.LSS TEN$,L$S DEPT, I~PM.DTE IL~,DTE IIRD.DTE SFLU,DTE MTEM,DTE RHOB,LDT 11800,000 10.555 9.992 95 188 2 178 CIDP.DTE CILD,DTE IFRE.DTE IIXD.DTE SP.DTE MRES,DTE DRMO,bDT 23-APR-IS9! 21:56 -999.250 NPOR.CNL -999.250 CFTC.CNL ~999.250 MRES.CNL .999.250 DTL.bSS 999.250 TT4.LSS -999.250 MTEM,LSS 1~ 000 41.031 "62, 3 "999 ~5050 '999 5O '999 ~5 ' 999 0 5O '999 0 '999 ~50 -999 '999 ~50 '999 50 IDPH,DTg ILD,DTE IDOF,OTg IIRM,DTE :GR,DTE HTEN.DTE PEF,LDT ~U,LDT SS2,bDT LSRH,bDT TENS,LOT NPHI,CNL NPOR CNL CFTC CNL ~RES CNL TT4 bSS MTE~ 122.125 124,125 20.000 52.938 '52~063 0,789 ~8 600 27 500 98 6 ,9~ 57 000 o? 8255 0 10420 000 838 000 IDPH,DTE ILD,DTE IDOF DTE II.RS DTE HTEN DTE P~F LDT ~U bDT SS2 LOT 5SRH.LOT TENS .bDT NPH! CNL NP.OR,CNL CFTC,CNL MRE$.CNL DTL,LSS TT4'LSS MT:EM,LSS 99.813 104'563 20,000 -3 656 0.765 0,142 IDPH.DTE ILD.DTE IDQF,DTE IIRM,DTE GR.DTE HTE~,ETE PEF,LDT -999.250 RCNT CNL -999 250 GR:CNb -999 250 MTEM,CNL -999 250 TT1.LSS -999 250 8P.LSS -999 250 MRES.LSS 8.195 CIMP.DTE 8 039 CILM.DTE 3 000 IMOF.DTE 125 500 IIXM.DTE 40 -32768 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 844 TENS DTE 000 DPHI LOT 250 OhS bDT 0 LSHV.LDT 250 LURH,LDT 250 STEM,bDT 250 RTNR CNL 250 RCNT CNL 250 GR CNL 250 STEM CN~ 250 TT1 LSS 0 SP 8 180 CINP.DTE 8 055 CILN DTE 0 125 54 -117 4 ]54 2 8255 23 23 i044 0 76 895 173 000 I~OF 313 IIXM 219 TENS 625 DPH! 582 OLS 750 240 LURH 000 ~TEM 494 RTNR DTE DTE DTE LDT bDT bDT bDT bDT LOT 418 RCNT CNL 613 'GR,CNL 861 MTEM,CNL 125 TT'I,L$$ 500 SP.LSS 125 MRES*LSS 10 016 CiMP.DTE 9 555 CILMiDTE 0 000 IMOF'DTE 94 688 IIXM'DTE 375 TENS'DTE 11 625 DPHI'LDT '116 094 OLS'LDT PAGE~ -999250 -999:250 -999.250 -999,250 -999,250 -999.250 130 750 132 875 2 000 · -9 742 ooo ~999,250 999~ -999250 -999.250 -999250 -999,250 -999 250 -999 250 :999,250 999250 29,250 32' 625 o,o00 2!, 766 8440' 000 20~ 6~5 624'i 1 .-~ 000 884;0O0 '3., O~ 94,688 .!00,063 0 00o 2 893 8205 000 28 -0 07~ IS Tape Verification Listlno chlumberger AlasKa Computing Center ' OSS LDT -0.011 LS.LDT LITH:LDT 114,375 SSI.LDT SSHV.LDT 1665.000 SIRH.LDT CALI.LDT t0,594 GR.LDT ~RES LDT 0,833 HTEN.LDT TNPH:CNL 30,648 TNRA.CNL RCFT,CN5 928,709 CNTC.CNL CALI.CN5 10,594 TEN$,CNL HTEN.CN5 1~1.000 DT LSS TT2.LSS ,,3.000 TT]:LSS GR.LSS 116.938 TENS.LSS HTEN.L$$ 1126,000 DEPT. ILM DTE IIRD DTE SFLU DTE MTE~ DTE RHO8 5DT 055 LDT ~SHV LDT CALI LDT .~ES LDT TNPM CNL RCFm CALI HTEN GR HTEN 11700.000 33.438 29,094 6,938 17 6~3 2.326 0 O55 118 188 1~6~ 000 8 4~0 ~97! 200 8 430 666 0 46 375 i086 000 ClDP,DTE ClLD.DTE IPRE DTE IIXD DTE SP DTE MRES DTE DRHO~LDT SSI~SDT SIRH LDT- GR LDT HTEN LDT TNRA CNL CNTC CNL TENSCNL DT,LSS TT3,LSS TENS.LSS DEPT. I~PH.~TE IL~'DTE IIRD.DTE SFLU.DTE ~TE~,DTE RHOB;LDT LZTH.LDT SSHV.LDT CALI~LDT MRES,LDT TNPH.CN5 RCFT,CNL CASI.CNL HTEN.CNL TT2,L$S GR~L$S HTEN,5SS il600 000 9 797 9 734 106 875 ~5 281 t75 2 48 o o~$ 91 938 !666 000 8 281 0 821 ! 218~ 624 8 28! 454 25O ,000 t103,000 CIDP DTE CILDDTE IFRE DTE IIXD.DTE SP DTE MRES DTE DRHO LDT DS LDT SSi LDT SIRH,LDT GR,LDT HTEN,LDT TNRA.CNL CNTC.CNL TENS,CNL DT LSS TT3 LSS TENS LS$ 23-APR-1991 21:56 548.'500 283.000 1 757 750 11 2 896 2581 453 9440 000 77 875 109 000 792~ 000 LU.LDT S$2.LDT LSRH.LDT TENS bDT NPHI CNL NPOR CNb CFTC CNL MRES CNL DTL,LS$ TT4,L$S MTEM.LSS 3½,469 3 ,969 20.00O 4.719 -88,500 0.757 419,000 268'500 · 1 462 750 4821 402 7855 000 70 5 8020 000 IDPH.DTE ILD.OTE IDOF,DTE RM,DTE IIGR,DTE HTEN,DTE PEF*LDT LO LDT $$2 LDT LSRHLDT TENS LDT NPHI CNL NPOR NL CFTC MRE$ CNL DTb LSS TT4L$$ MTEM.L$S 21 22 20 7 ~71 0 0 285 216 2 454 449' 7960 76 i034 7925 313 500 000 0 25O 000 O0 000 IDPH:DTE ILD~DTE IDOF, DTE IIRM DTE GR DTE HTEN DTE PEF LDT LU LDT SS2 ~DT L~RH.,LDT TENS*LDT NPHI,CNL NPOR,CNL CFTC,CNL MRES.CNL DTL,LS$ TT4,LSS MTEM,LSS PAGE: 524.500 LL.LDT 408.000 bSHV.LDT 2 035 LURH.LDT 9440 000 MTEM.LDT 157 RCNT~ NL 913 345 ~R.CNL 0 833 MTEM,CNL 77 750 TT1.LSS 921 000 SP,LS$ 31 ~50 CIMP DTE 26 0 32 48 -123 4 397 346 2 7855.000 1~'023 ;740 364~,7.28 .819 7~'625 '500 173,125 328 CIb~ 000 IMQF 656 IIXM 656 TENS 875 DPHI 723 QLS 750 Lb 250 bSHV 193 bURH MTE~ RTNR RCNT GR MTEM TTI. SP MRE$ DTE DTE DTE DTE EDT LOT ~LDT ,LDT ,LDT ,LDT .CNL ,CNL .CNL .tNb .bS$ .LS$ 8~ 8 0 97 285 7960 18 2O 2305 0 74 897 t73 234 CXMP.DTE 156 ClLM,DTE 000 IMQF,DTE :188 IIX~,DTE i8~ TEN$.DTE '96 D'PHI.LDT .512 .000 QLS,LDT LL,LDT :500 LSHV,LDT 0 ~TEM,LDT 41 RTNR'CN~ 44 RCNT,CNL 690 GR~CNL 821 ~TE~.CN~ 875 TTI,LSS 000 SP.LSS 125 ~RES.LSS 286 250 1619 000 2 033 174 125 288~:958645 127 750 174 !25 929 000 -3 291 0 875 29 891 34 344 0 000 2488 16 000 .188 174 532 0~. 7 0 ,55: 824 00~ ~3,470 ,i0,0,20 149;000 1622,,000 2,4~2 174;000 2,068 4753*697 58,969 I74,000 894*000 -3~232 0,859 Tape Verification Listing chlumberger AlasKa Computing Center DEPT. IPPH.DTE IL~.DTE IIRD.OTE SFnU.DTE MTE~.DTE RHOB.LDT OSS.LDT LITH LDT SSHV:LDT CALI.LDT MRES,LDT TNPM,CNL RCFT.CNL CALI.CNL HTEN.CNL TT2,LSS GR,LSS HTEN,LSS 11500.000 36.250 34,406 31.266 47.313 174.763 2,534 0,018 70,750 1667,000 8 797 0 825 9 758 4566 806 8 797 498 000 652,000 49.188 1091,000 CIDP.DTE CILD.DTE IFRE,DTE IIXD.DTE SP.DTE MRES.DTE DRHO.LDT nS.LOT SS1,LOT SIR~:LDT G bDT HTEiiLDT TNR CN5 CNT CN5 TEN CNn DT"bSS TT3.LSS TENS,LSS DEPT. I~P~ DTE IL~'DTE IIRD DTE SFLU DTE MTE~ DTE RHOB LDT OSS LDT LITH,LDT SSHV bDT CA RCFT CALl HTEN TT2 HTEN bDT bDT CNn LSS LSS 11400,000 36,219 ,000 0 0 030 77 063 1666000 9 266 0 8!8 172~6 2128 562 9 266 432500 674.000 46.719 !129'000 CIDP,DTE CILD.DTE IFRE,DTE IIXD,DTE SP,DTE MRES;DTE DRHO,LDT nS'LDT 881LDT S1RH LDT GR LDT HTEN bDT TNRA CNn CNTC CNn TENS CNn DT L$$ TT3 LSS TENS bSS DEPT INPH DTE Ib~ DTE IIRD DTE SFSU DTE MTE~ DTE RMOB bDT OSS bDT LIT~ LDT SSHV LDT CALI bDT MRES bDT TNP~ CNn RCFT CNn CAb! CNL 11300 42 50 173 2 76 I666 8 0 11 3691 000 CI~P,DTE 281 CI[D'DTE 750 IFRE,DTE 734 IIXD,DTE 938 SP.DTE 413 MRES,DTE 503 DRHO,LDT 005 LS~bDT 313 SSl,LDT 000 SiRH,LDT 555 GR.LDT 836 HTEN.LDT 873 TNRA.CNL 175 C~TC.CNb 555 Tg~$.C~ 23-APR-1991 2!:56 31 563 34 125 -5~ 406 0 754 O 011 ooo 2o4~0 49.156 498.000 1,354 59~9.705 80 0.000 64 875 80 000 IDPH.DTE ILD,DTE IDGF.DTE IIRM.OTE GR.DTE HTEN,DTE PEF.LDT LUeLDT SS2.LDT LSRH.LDT TENS bDT NPH! CNL CFtC CNn MRE$ CNn D~L,GS$ TT4,L$S ~TEN,L$S 36.688 ~9'406 20.00O 2,867 -40.281 0,755 0~103 265.50o 241,125 2,2~6 54,0 4 432'500 ~8~3.059 7925'000 68,000 952,000 8140~000 IDPH,DTE ,DTE IIRM,DTE GR,DTE HTEN'DTE PEF'bDT LSRH.bDT TENS,bDT NP.HI,CNL NPOR,CNb CFTC'CNn ~RBS'CNb D:TL,LSS TT4,LSS MTEM,:LSS 000 379 0 -0 00! 247 125 204 875 5.38 4J1.000 1.505 5353~869 7875,000 IDPH DTE ILD DTE IDQF DTE IIRM DTE GR DTE HTEN DTE PEF bDT ~DT bDT LSRH .bDT TENS h T NPHI C~L NPOR CNn CFTC CNh ~MRES,CNL 31.656 CI~P.DTE 29.281 CILM'DTE 0.000 IPOF.DTE 27.64! IIXN.DTE 49 563 TEN$.DTE DPHI.~DT QLS.LDT -105 2 230 271 2 8070 8 9 4439 0 64 790 172 313 324 125 Lb bDT 000 LSHV bDT 523 LURH bDT 000 MTE~ bDT 856 RTNR CNn 406 RCNT CNn 043 GR CNn 825 MTEN.CNb 750 TTI.LSS 000 SP,LSS 375 ~RES,bSS 27 234 CIHP DTE 25 0 30 50 -73 2 254 305 2 204~ 8!4 !72 DTE DTE DTE DTE bDT. bDT 5DT bDT bDT 359 CILN 000 INQF 531 IIXM 813 TENS !88 DPHI 818 QLS ~250 Lb :500 LS~V 457 bURH 000 ~TEM DT 8 RTNR RCNT.CN~ 84 GR.CNb 18 STEM,CNn ~50 TT1,LSS 500 SP,LS8 000 MRE$,LSS 39 563 ClMP DTE 33 781 ClbH DTE 0 24 45 -36 2 239 273 2 7875 11 3637 0 000 IMOF 547 IIXN 594 TENS 03t DPMI 541 ~LS 000 :250 LS~ 504 bURH DTE DTE DTE bDT bDT bDT bDT bDT 000 STEM LOT 410 RTNR CNn 598 RCNT CNn 077 GR CNL 836 MTEN.CNL PAGE: 10 27 563 29 047 0 000 -0 066 8220 000 7 007 -0 005 123 938 1623 000 2 523 173 SO0 4 9 I 6~i4 6640 49 156 173 O0 785 ~00 -3 156 0 863 27 578 32 094 0 000 -2 854 8125 000 01~ 13 250 162~ 000 171 ~0 44~4 0 8 8~2,000 2,494 0'860 0 000 '1 593 8210 000 8 905 -0'0 8 1.27,~5 16 ,ooo 54' ~ 172,375 Tape Verification Listino chlumberger Alaska Computin~ Center HTEN.CNL 411 O00 bT.bBS TT2.b$S 688~000 TT3.[J$S GR.LSS 50.875 TENS.LBS HTEN,LS$ 1153.000 DEPT. IMpH DTE [IRD DTE SFLUiDTE MTE~ DTE RHOB LDT OSS LDT LITH LDT $SHV bDT CALI LDT MRE$ LDT TNpH CNL RCFT,CNL CALI.CNL HTEN.CNL TT2,LSS GR,LSS HTEN.LSS 11200 00o 6O 844 59 438 17 391 66 688 171:'5!3417 '0.006 98,438 1666 000 8 398 0 847 17 252 2686 372 8398 446250 .700 500 46 063 1239 000 CIDP.DTE CILD.DTE IFRE.DTE IIXD.DTE SP.DTE MRES.DTE DRHO.LDT LS.LDT SS1.LDT S1RH bDT GR bDT HTEN bDT TNRA CNL CNTC CN5 TENS CNL DT LBS TT3 LSS TENS LSS DEPT I~PHiDTE ILM.DTE IIRD.DT~ SFLU,DTE MTE~DTE RHOB,LDT OSS.LDT LXTH bDT SSHV LDT CALI bDT MRES LDT TNPM CNL C~Li CNb HTEN CNL TT~ LBS GR,bSS HTEN,LSS 1110 000 I~ 523 12 148 76 875 18 516 171 275 2 116 -0 009 195 125 1666000 16438 0 853 23 465 1290 799 16 438 495 000 77! 000 88 t25 1139 000 CIDP DTE CIbD.DTE IFRE DTE IIXDDTE SPDTE MRE$ DTE DRHO bDT ~S.LDT SSi bDT $1~HLDT OR bDT MTEN,LDT TNRA,CNL CNTC.CNL TEN$,CNL DT.5SS' TT3,LSS TEN$,L$S DEPT. IMPH DTE IL~ DTE IXRD DTE SFLU DTE ~TE~ DTE RHOB LDT OS$ bDT LITH LDT SSMV LDT 11000 000 28 625 24 109 59 281 74 563 170 375 2 394 0,019 100,250 1666,000 CIDP.DTE CILD DTE IFRE DTE IIXD DTE SP DTE MRES.DTE DRHO.LDT LS.LDT SSI.bDT SI~H,LDT 23-APR-1991 21:56 66 875 DTL.LSS 952i000 TT4,bSS 7960000 ~TEM.LSS 15 68O 18i 6 3639 -103313 0 .o 285 500 2O8 5 446 i50 ! 64 4895 62 7820 ~00 5O 70 ~0 966 0 8325 000 IDPH,DTE IbD.DTE IDQF.OTE IIR~,DTE GR;DTE HTEN,DTE PEF,LDT LU.LDT SS2,bDT bSRH,bDT TENS.bDT NPHI,CN5 NPOR,CNb CFTC CNb MRE$ CNb DTL TT4 5SS MTEM LBS 8O 85 20 6 0 -0 483 !0 321! 7730 7810 750 750 000 516 343 792 012 75O 25O 000 5O0 000 000 IDPH,DTE IbD,DTE IDOF'DTE RM,OTE IX~R,DT~ HTEN,DTE PEF,bDT LU,BDT SS2,LDT LSRH,hDT TENS,bDT NPHI'CNL NPOR~CNL CFTC~CNL MRES,CNL DTL,5$$ TT4.*~SS MTEM,5SS 59,938 63,~56 20' O0 8 883 -18~969 0, 9 218, 5 2,346 IDPH'.DTE ILD.DTE IDOF'DTE IiRM,DTE GR,DTE HTEN,DTE PEF,LDT $$2,LDT LSRH'BDT 70.625 TT1.LSS 821,000 SP,LSS 171,125 63 0 0 000 16,016 47,625 -56. 4 271,500 283.250 2 420 7820~000 16 16 2659 0 72 822 170 ClMP.DTE CILM.DTE IMOF.DTE IIXM.DTE TENS,DTE DPHI.bDT ObS,LDT Lb bDT LSHV bDT 5URH LDT ~TEM LDT 994 RTNR CNL i~.!9 RCNT CNL 92 GR CNL 847 MTE~ CNL '750 TT1.LSS 000 SP,LSS 375 ~RES.LSS 12 1! 0 78 94 -138 2 446 319 2 7730 125 0 375 CI~P DTE 648 ClS~iDTE 000 813 TENS'DTE 000 DPHI.LDT 486 OLS~LDT LL.LDT ~50 250 127 ~ bDT URH-~DT 000 MTEM bDT 221 RTNR CNL 808 RCNT CNL 29 GR CNL i~53 MTE~ CN5 375 TT~ 500 875 ~RES,LS$ 16 672 CI~P.DTE 15 .828 CI5~,DTE 000 IMOF.DTE 06 IIXg.DTE 50 TENSoDTE 844 DPHI,LDT 752 OL$,LDT 50 Lb.*bDT ~50 LSHV.LDT 383 LURH,LDT 0 39 52 ..60 2 284 289 2 PAGEI 11 818,500 -3,135 0,873 16 422 16 813 0 000 -7 086 8015 000 14 lO0 -0 012 149 625 1622 000 46.844 171,,875 8~2,500 79 2S0 8§ 000 660 -008 260 510 1620 000 170 2 I04 i70 ~$0 940 000 0 896 34 906 4~ 00 0 ~03 7725 000 t5 544 0 002 oo§ °° 2 387 IS Ta~e Verification Llstinq chlumberger Alaska Computimq Center CALI.LDT 9.523 GR.LDT MRE$.LDT 0.854 HTEN,LDT TNPH.CNL i7'087 TNRA,CNL RCFT.CNL 2573.480 CNTC.CNL CALI.CNL 9.523 TENS.C~L MTEN.CNL 431,750 DT.L$S TT?.L$S 655.000 TT3.LS$ G~,LSS 44.375 TENS.LSS HTEN.LSS 1132.000 DEPT I~PHiDTE Ib~ DTE IIRD,DTE SFbU,DTE ~TE~,DTE RHOB.LDT OSS.LDT LITH,bDT SSHV.LDT CALI bDT MRES LDT TNPH CNb RCFT CNL CAb! CNL HTEN CNL TT~:bSS GR,LSS HTEN,L$S EPT MPM DTE IbM DTE IXRD DTE SFLU DTE MTE~ DTE RMO~ bDT OSS LDT kITH bDT SSHV bDT CALl,bDT TNPM.CNb RCFT,CNb CAbI,CNb HTEN,CNb TT~,bSS GR,LSS HTEN,LSS 10900,000 -999,250 '999,250 -999.250 -999 250 -999 250 1 674 '0 166 19 078 1669 000 8 664 0 86O 43 724 41.8 340 8,664 423,750 608,000 25'203 1135,000 I~837,500 999,250 '999 250 '999 250 '999 250 '999 250 '999 250 -999 250 '999 250 '999 250 '999 250 '999 250 .-999250 -999 250 -999 250 -999 250 280 000 28328 1143 000 CIDP.DTE CILD.DTE IFRE,DTE IIXD,DT£ SP, DTE ~RE$~DTE DRHO, LDT LS.LDT SSI,bDT SlRH.bDT GR.LDT HTEN:LDT TNRA~CNL CNTCCNL TENS CNL DT.L$S TT3,LSS TEN$,LSS CIDP'DTE CILD,DTE IFRE,DTE IIXD'DTE SP,DTE MRE$.DTE DRHO bDT bM bDT SSi DDT SIRH bDT GR bDT HTEN bDT TNRA.CNL CNTC'CNL TEN$'CNL DT.LSS TT3,LSS TE~S,LS$ ** END OF DATA ** 23-APR-lg91 21:56 49 719 TENS.bDT 431~750 NPMI,CNL 1 755 NPOR,CNL 49ili274 CFTC.CNL 7520 000 MR~S,CNb 55_875 D~ b,LSS 978,000 T~4,LSS 7785,000 ~TEM,L$$ -999.250 -999 250 99 250 -999 ~50 -999 50 ~1 053 344 4 910 22 1 3 8 1475 ~7 7430 000 -5~ 63 83 ~00 7705 000 -99.9 50 -999.~50 -999 50 -999 i50 -999. ~0 -999 0 -999 ~50 -999 50 -999 50 :999 250 999.250 -999;250 -999;250 -999,250 -999i2~0 14,5N4 310,750 7695,000 I~D.DTE IDOF,DTE IIRM.OTE OR,DTE HT~N,DTE P~F*bDT ~U,bDT $~2,LDT LSSH,LDT TENS,bDT NPHI,CNb NPOR,CNb CFTC.CNL T~4.'LSS MT~M,LSS D ~ H. DTE I D DT~ IDF DTE IIRM DTE PEF LDT S~ibDT LOT LSRH~hDT TENS ~ bDT NP{~!, CNL NP )R, CNL CF ~C, CNb ' s s 7520.000 ~TEM.LDT 13.972 RTNR CNL 17.433 RCNT CNb 2619.001 GR CNL 0 854 STEM CML 53!625 TT1 bS$ 822 000 SP,LS$ 168.375 MRES.LSS -999 250 CIMP,DTE .DTE ,DTE 250 IIXM.DTE .DTE .bDT -999 ,999 -999 -999 -999 31 164 83 2 7430 44 41 413 0 166 .250 CILM 250 IMOF 250 TENS 250 DPHI 703 OhS.bDT 625 LL'LDT 125 LSHV,LDT 727 LURH,LDT 000 STEM,bDT 016 RTNR.CNb 495 RCNT,CNL 574 GR,CNL 860 ~TEM,CNb 250 TTI.LS$ 50 SP.bSS 75 MRE$.LSS '99 -99~ -999 -999 -999 -999 -99~, -999 -999 -999 -999 -999 -999 -999 18 295 166 250 CIMP..DTE 250 CILM:DTE I~OF DTE 50 DPHI LDT 50 OL$ LDT 250 LL bDT ~250 LSHV bDT 50 LURH bDT 50 MTE~,LDT 250 RTNR,CNb ~250 RCNT,CNb 250 GR.CNL 0 MTEM,CNL 0 SP,LS$ 875 MRES.LSS PAGE: 12 170.000 9 2 I. 6~0 5349 49 719 170 000 814 500 -3 057 0 899 -999 250 -999 250 -999 250 -999 250 -999 250 59 154 O4 1622 000 2 768 1704.457 22 717 500 ~2 922 0 903 -999,250 -999,250 -999,250 2999,250 =999;250 .999,250 999~250 -999~250 -999~50 '999, 50 '999'250 -999;250 -999. -999~250 272i:!00 O, IS Tape ueriflcation Listing cblumberger AlasKa Com~uttnq Center 23-APR-1991 21:56 PAGES 13 **** FILK TRAILER FILE NAME : EDIT .00! SERVICE : FLIC VERSION : 001~06 DATE : 91/04/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 91/04123 ORIGIN : FLIC TAPE NAME : 74505 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT ~ PARATHON OIL CO~PANY,MCARTHUR RIYER,D-47,50.733-20195-02 **** REEL TRAILER **** SERVICE NAME ~ EDIT DATE ~ 91/04/23 ORIGIN ~ FbIC REEL NAME : 74505 CONTINUATION # PRE~IOUS REEL COMMENT : MARATMON OIL COMPANY,MCARTMUR RIVER,D-47,50-733-20195-02
