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Home My WebLink About189-0611. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12,493 N/A Casing Collapse Structural Conductor 520psi Surface 1,540psi Intermediate 3,810psi Production 7,020psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: CTCO, N2 CO 228A 10/22/2025 3-1/2" See schematic See schematic 12,490' Perforation Depth MD (ft): 10,933' 11,104 - 11,291 12,490' 8,937 - 9,090 10,039'7" 20" 13-3/8" 803' 9-5/8"10,933' 2,999' MD 6,330psi 2,110psi 3,090psi 803' 2,745' 8,797' 803' 2,999' Length Size Proposed Pools: L-80 TVD Burst 11,046 8,160psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018729 189-061 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20165-01-00 Hilcorp Alaska, LLC Trading Bay Unit D-46 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY McArthur River Hemlock Oil, Middle Kenai G Oil Same 10,042 11,329 9,121 1,975psi 11,329; 11,544 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:33 am, Oct 09, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.10.09 06:53:52 - 08'00' Dan Marlowe (1267) 325-616 DSR-10/10/25MGR22OCT25A.Dewhurst 10OCT25 10-404 * BOPE test to 2500 psi. 48 hour notice to AOGCC. JLC 10/23/2025 10/23/25 CT FCO and Re-perf Well: Dolly Varden D-46 Well Name:D-46 API Number:50-733-20165-01-00 Current Status:Gas Lift Oil Producer Permit to Drill Number:189-061 First Call Engineer:Casey Morse (603) 205-3780 (c)Leg A-2 (NW corner) Second Call Engineer:Eric Dickerman (307) 250-4013 (c) Current BHP: Maximum Expected BHP:2900 psi @ 9,250 TVD Max offset shut-in pressures July 2024 Max. Potential Surface Pressure: 1975 psi Using 0.1 psi/ft Brief Well Summary Dolly Varden D-46 is a Middle Kenai G oil producer. It was drilled from the D-19 well slot in 1989 and originally completed in the Hemlock only. In 2000, the Hemlock was isolated and G zone perfs were added. This well was originally completed as a gas lift producer and has remained that way. Recent tags show fill covering most of the G zone perfs. Production has declined substantially over the past few years. The goal of this project is to clean out to TD and re-perf the G zone to restore production. Pertinent wellbore information: - Sail angle 40 degrees / max inclination of 53 degrees from ~2000 MD to TD - SSSV: WR-SSSV, 2.813 profile at 325. - Sep-2025 o Tag fill @ 11,120 o Gas lift survey shows gas lift from orifice - Sept-2015 o Tag fill @ 11,232 - Jan-2000 o BP set at 11,525 and dump bail 10 of cement on top to abandon Hemlock o Perf G zone o In May 2000, identify leaking BP with flow from Hemlock below. Set Posiset plug @ 11,403 and dump cement on top. Tag cement @ 11,334. Coiled Tubing Procedure 1. MIRU Fox Energy offshore Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high. 3. MU FCO BHA 4. RIH and cleanout to below perfs (~11,300) or as deep as practical a. Working fluid will be water (8.33ppg or greater) b. Take returns to surface up the CT x tubing annulus c. Add foam and nitrogen as necessary to carry solids to surface d. Can use GL to assist with hole cleaning CT FCO and Re-perf Well: Dolly Varden D-46 5. RDMO CT Eline Procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 1500psi high 3. RIH and re-perforate Middle Kenai G Oil Pool from ±11,104 ±11,291 MD (±8,937 ±9,090TVD) per Engineers perf table a. All proposed perfs within Middle Kenai G Oil Pool 4. RDMO EL NOTE: WL-SSSV will need to be pulled and reinstalled. It must be tested within 14 days of the wells return to production Attachments 1. Current Wellbore Schematic (no change) 2. CT BOP Drawing (Fox energy) 3. Nitrogen procedure _____________________________________________________________________________________ Updated By: JLL 10/08/25 SCHEMATIC Dolly Varden Platform Well: D-46 Last Completed: 02/18/2000 PTD: 189-061 API: 50-733-20165-01-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 20 94 J-55 19.124 Surface 803 13-3/8 61 K-55 BTC 12.51 Surface 2,999 9-5/8 43.5 N-80 BTC 8.755 Surface 752 47 N-80 BTC 8.681 752 6,068 53.5 S-95 BTC 8.535 6,068 10,933 729 N-80 BTC 6.184 Surface 11,756 29 P-110 BTC 6.184 11,756 12,490 TUBING DETAIL 3-1/2 9.2 L-80 BTC SC Surface 11,046 RKB = 39.38 TD = 12,493 PBTD = 11,329 2 1 3 7 I II 5 6 C 4 D E B A F G G-2 Max Angle=53° @ 3,550 X Casing Patch @ 5,290 G-3 G-4 H-1 PosiSet Plug at 11,405 DIL TOC @ 11,329 DIL 6/7/00 X H-2 H-3 H-4 H-5 Fish = CIBP, Set Tool, GR/CCL Isolation Plug at 11,544 leaking 09/2025 tagged at 11120 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 38.80 38.80 - CIW, 11 x 4, 5M, DCB Single Tubing Hanger 4- 1/2 EUE Lift x 4-1/2 Butt Suspension 2 40 40 2.992 Crossover, 4-1/2 Buttress x 3-1/2 Buttress 3 325 325 2.813 SSSV Landing Nipple, Howco, XXO (2.813) 4 10,961 8,820 2.992 Locator Seal Assy. Baker 80-40, (14.5 Long) 5 10,977 8,833 2.992 Crossover, Baker 4 Acme x 3-1/2 Buttress Pin 6 11,012 8,861 2.813 BX Nipple, Baker, w/ 2.813 Otis X Profile 7 11,045 8,888 3.000 Wireline Entry Guide, Mule Shoed The following set on Drill Pipe I 10,964 8,822 4.000 Packer, Mod. F-1, Permanent, 7 26-32#, 85-40 II 10,967 8,825 4.000 Seal Bore Extension (15 Long) GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,414 2,307' 2.867 McMurry Macco, 3-1/2 SMO-1, R-1, BK-2 12 Dome 1210 2/7/2000 2 4,143 3,495' 2.867 McMurry Macco, 3-1/2 SMO-1, R-1, BK-2 12 Dome 1196 2/7/2000 3 5,399 4,461' 2.867 McMurry Macco, 3-1/2 SMO-1, R-1, BK-2 12 Dome 1186 2/7/2000 4 6,432 5,307' 2.867 McMurry Macco, 3-1/2 SMO-1, R-1, BK-2 16 Dome 1171 2/7/2000 5 7,375 6,054' 2.867 McMurry Macco, 3-1/2 SMO-1, R-1, BK-2 16 Dome 1161 2/7/2000 6 8,094 6,597' 2.867 McMurry Macco, 3-1/2 SMO-1, R-1, BK-2 20 Dome 1149 2/7/2000 7 8,747 7,103' 2.867 McMurry Macco, 3-1/2 SMO-1, R-1, BK-2 20 Dome 1137 2/7/2000 8 9,364 7,568' 2.867 McMurry Macco, 3-1/2 SMO-1, R-1, BK-2 20 Dome 1125 2/7/2000 9 9,889 7,963' 2.867 McMurry Macco, 3-1/2 SMO-1, R-1, BK-2 20 Dome 1114 2/7/2000 10 10,384 8,353' 2.867 McMurry Macco, 3-1/2 SMO-1, R-1, BK-2 20 Dome 1101 2/7/2000 11 10,880 8,755' 2.867 McMurry Macco, 3-1/2 SMO-1, R-1, BK-2 24 Orifice 2/7/2000 PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD Amt SPF Date Present Condition G-2 11,104' 11,140' 8,937 8,966 36' 18' 6/7/2000 Open G-3 11,202' 11,228' 9,017 9,039 26' 18' 6/7/2000 Open G-4 11,272' 11,291' 9,075 9,090 19' 12' 3/6/2000 Open ISOLATED DETAILS ON PAGE 2 NOTE: Stress Frac w/ 2 guns done 12/3 & 12/4/00. G2 from 11,104- 11,140 . G3 from 11,202-11,227. Pressures ranged from 5500 psi to 9800 psi. See Well History for more info. Updated By: JLL 10/08/25 SCHEMATIC Dolly Varden Platform Well: D-46 Last Completed: 02/18/2000 PTD: 189-061 API: 50-733-20165-01-00 ISOLATED - PERFORATION DETAIL Zone Top Btm Amt SPF Date Present Condition H-1 11678' 11679' 19' 8' 1/3/1991 Isolated H-2 11714' 11744' 30' 8' 11/23/1991 Isolated 11765' 11795' 30' 3' 5/2/1991 Isolated H-3 11896' 11927' 31' 4 1/3/1991 Isolated 11926' 11960' 34' 4 1/3/1991 Isolated H-4 11765' 11795' 30' 4 5/2/1991 Isolated H-4 12031' 12072' 41' 4 8/25/1990 Cement Plugged H-5 12147' 12181' 34' 4 6/26/1990 Cement Plugged ISOLATED - JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item A 11,482 9,245 4.000 PBR, Baker, 80-40 (18.43) B 11,500 9,260 3.250 Anchor, CH, Brown (150K straight pull or 15 right turns) C 11,501 9,260 3.500 Packer, Brown, 7, 3H Perm. D 11,505 9,263 3.937 Millout Extension, Baker (5.52 Long) E 11,527 9,281 2.813 Otis, X Nipple 2.813 F 11,544 9,295 - Bridge Plug, Baker Mod. N w/10 of cement G 11,559 9,306 3.000 Wireline Entry Guide STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project, They are available in the original file and viewable by direct inspection. / ~'~-(~'~// File Number of Well History File PAGES TO DELETE RESCAN ~~C~lor items- Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Beverly Bre~Nathan Lowell TO RE-SCAN Notes: Re-Scanned by.ran Vincent Nathan Lowell NOTScenned.wpa ,:1 , Unocal Alaska 909 W. 9th Avenue Anchorage. AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com r~\ \ Cbct(Ð't) UNOCALe Debra Oudean G & G Technician Date: June 22, 2005 To: AOGCC Helen Warman 333 W. ¡th Ave. Ste#100 Anchorage, AK 99501 .... VENDOR: PERMIT # API NUMBER :. LOG TYPE . SCALE . LOG..· INTERVAL RUN B- FILM CD NOTES· LAS,: j nn uvn n nunn.. .... .nnnnun'_n~~~nn 'nnu.~~~~~.um...~ lIN~~_~~,~_I~nuunn PERFORATION RECORD 2.5 HSD 5 INCH 3/11/2005 10800-11268 1 1 1 1 pds I POWERJET GUNS 6 SPF 60 DEG ! PHASING . J L~L~ ¡D-46RD i ! ...._mnmuu._n vc"vv, .........m.......VnoW on ·.·..v '_mmm·v.......v··..v· Schlumberger 189-0610 507332016501 ) ) ~ Cl q . .-. .. /,-".. ", --' .~- Ii) rc) ? ('j n r W,;¡~~~~tJ.) ~t..~) \üD ..- U~ Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received By: /'1 / (tJ/1 I. Áf{-r,v-rv¡:X L)¡ÞI/r. D"te~ 0, I i ;;It,, J~ / ' û cJ!¡Ø I g (I - 0 ~ ( ...... '{ /- ( ..( RE: SCSSSV removal ) ~'~~j~~t:.~:~FSS~YT~moy~l...... . ... ,.. .,.. F~~~:,.."~~e,.J ?~...R" ..<;l~ej(®µn??~l.coI11~. D~~~:. MO:twJIJt11·.200Þ12:50:27..~08()O· ) Lkb' c~. ~. ..Ù" \ ~ \v The valve was set and tested June 27 th 2005 at 13:30 -----Original Message----- From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Monday, July 11, 2005 9:56 AM To: Bartolowits, Paul D Cc: Fahnholz, Norman E; Lee, John R Subject: Re: SCSSSV removal When was the SCSSV reinstalled in D-46? Jim Regg Inspection Supervisor AOGCC SCANNED JUL 2 ~¿ 2005 Bartolowits, Paul D wrote: Mr. Regg, This is to notify you that the SCSSSV has been removed from D-46, PTD-1890610. The valve was removed on June 13th, 2005 for slickline work and the valve needed latch spring repairs in town. The valve is scheduled for installation on Monday, June 27th, 2005. The SSV is functional. Notification will be made to you when the valve is reinstalled and tested. Paul Paul D. Bartolowits Production Foreman Dolly Varden Platform / Steelhead Platform Unocal, Alaska Dolly Varden (907)776-6846/ Steel head (907)776-6836 Cell: (907)398-9972 Home: (907)262-4945 1 of 1 7/11/20052:33 PM '. STATE OF ALASKA - ALA, Å OIL AND GAS CONSERVATION COM!\., 110N REPORT OF SUNDRY WELL OPERATIONS RECEIVED APR .., 8 Z005 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations U Perforate New Pool D Perforate Q 4. Current Well Class: Development Q Stratigraphic D Alaska Oil & Gas Cons. Commissj( Stimulate U Other U Anchorag6 Waiver D Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory D 1890610 ServiceD 6. API Number: 50-733-20165-01-00 9. Well Name and Number: 0-46 10. Field/Pool(s): MCARTHUR RIVER, HEMLOCK 7. KB Elevation (ft): 39' RKB 8. Property Designation: Dolly Varden Platform 11. Present Well Condition Summary: , Total Depth measured 12,493' true vertical 10,041 feet feet Plugs (measured) 11,347' Junk (measured) 11,501' CIPB, Set Tool, GR/CCL Effective Depth measured 11,347' true vertical 9,136' feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size 803 20 2998 13-3/8" 10,993 9-5/8" 12,491 7" MD TVD Burst Collapse 802 2,744' 3090 psi 1,540 psi 8,845' 6,330 psi 3,810 psi 10,040' 8,160 psi 7,020 psi 803 2998 10,993 12,491 Perforation depth: Measured depth: 10,795 to 12,181 (';;;::l""{~Í'\H\iE'ri) f~pn .~ lJ 2.005 \,__] ¡.'~ ~~"~~ <--n' ¿,..t h~ ..,'" + '" True Vertical depth: 8,687 to 9,813' Tubing: (size, grade, and measured depth) 3-1/2", 9.2#, L-80 @ 11,046' Packers and SSSV (type and measured depth) Baker F-1 Permanent Packer, @ 10,964', SSV Howco XXO @ 325' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 76 33 600 92 149 600 15. Well Class after proposed work: Exploratory 0 Development Q 16. Well Status after proposed work: OilQ Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Tubing Pressure 120 120 Prior to well operation: 123 Subsequent to operation: 144 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service 0 x GINJ D WINJ 0 WDSPL D sundry Number or N/A if C.O. Exempt: n/a Contact Steve Tyler 263-7649 Printed Name :~m~thY C. Brand:,nbA :2 Signature~C/ )? Title Drilling Manager Phone 907-276-7600 Date ORIGlr\IAL RBDMS 8Ft APR ] 1. 2005 Form 10-404 Revised 04/2004 Submit Original Only ... ." 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'.. .. .:' ~ ~ :-: : ~..: :.:-' . :.~ : ~ : : : : ~ . .:: ~.'. : : . ... ,"::. . :::..~::.. .....:::.. ....:.. ........... ...... ...~: : "." .....:... .... ::...... :. ......:. :--:... ... : . .... .... ... ¡¡¡¡ ¡¡¡¡¡ Primary Job Type Primary Well bore Affected ¡¡¡¡l Mise Main Hole ¡¡¡¡ ftKB (MD) 39 41 43 325 753 ~;~ ~::·::::::::::::::::::::::::::::::::::::::a 4,151 - -' - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - -. - - - - - -. - -. 5,400 - - - - - -- - - -.. - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - -- 6,068 - - -- - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - -- -. - - - - - -- - -- 6,440 - -. -. -- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - -- 7,382 ::::: ::::::: :::::::::::::::::::::::::::::::: :::::::::::::::1 8,101 - - -- -. - - - -.. - - -. - - - - - - -. - - - - - -- - - - - - -. - - - - - - - - - - - - - - - - -- 8,754 - - -- - - - - - - -- - - -- - . -- - - - . -- . -- -- - . -- -- . - - - -- - -- -- - - - -- -- - 9,371 - - -- - --... - - - - - - - - -. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -. 9,896 - - -- - - - -. -- --. - -- -- -- -- -- - - - - - - -- - - - --. -" -- --" -- -- -- - -- 10,391 10,800 10,888 10,933 10,963 10,967 10,978 11,012 11,014 11,046 11,1 05 11,140 11 ,227 11,272 11,289 - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - -- 11 ,329 11,410 w j~:f~ ~H2" ~w~J~ 0011&# ) t (uuuuuuuuuuuuuuuuuuuuouuuuuuuuuuuuuuu_ 11,559 11,697 11,744 11,765 11 ,878 _ _ _. _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ __ _ _ _ _ _ _ _ _. _ 11 ,906 - - - - - - -- -- -- -- . . -- - - -- -- - -- -- . -- - . . - - -- - - - - - - -- - -- - . . - - -- - - . 11,960 ::::::::::::::~~ß~~~:1ß~:!~~:::::::::::::::::::::::::: 12,031 ::::::::::::::1 ~:,~~:1:1:~~Q:~~:::::::::::::::::::: :::::: 12,112 =:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 12,127 1 2,143 :: I ûiliJTI~l§i~~iJiLil~222J=lLJ : : ~ : . .. . . . ... . . ....... ...... . .................................. ... ....................................... ............ ...... .................... ............ . .............. ....... -... ............ ....... .... .... ... ........ _.....-..............................-..................... - - ~ ~. - -.. - - - - -. - - - - - -......... - - -.......... - -..... -.... -................-...........................--.......... -....................................................................................... -.........................------.--....--...--......--.............--.......-.. -.................................................................................. -....................................................................................... -...................................-............-................................... -.......................................-.......................................... -................................................................................. -......-.................................................................................-. -............................................................................................. - -.- - - - - - - -1 0;795"10;800-ftKS- - -. - - - - - - - - - - - - -. - - -" :::::::: ::2.:il:i':p-öwërjët:~oliõitj::::::::::::::::::::::: :::: :ç~m~r;:1~:,:1~:1:1:~1 ~9:m~~::::::::::::::::::::::' -' -2~·PewerJet-AoIløw-earíier-,·· - - -. - - - -... - - - - - - - -- ::::: ::::: ::::11~1a4;tU!;{O:ft}œ:: ::::: :::::: ::: ::::: :~\ - -.... -2--1/2l'-PowerJet-hollow-' - - - - - - - - - - - - - - -' - -. --. -.. :::: :6àfr¡ër;:i ~:,:iö4~n~14Õ:ftKS:::::::::::::::::: ::::::::: ::::: ~W~~~fn:!ç;:1 t:1:9:4:1:1:~1 ~Q:::::::::::::::::::::::::: ==: s{t.éè~Ëi~¢~:1:1:~ö2~1:1;~::::::::::::::::::::::::::~ - - - - - - - - - . - - - - - - - - - - - - - - - - - - -ftKB- - - - - - - - - - - - - -. - - -. - - - - - - -. :::::::: ::2-:il2~'j~õiÑërjët:boliõiÑ:::::::::::::::::::::::::: - ·carrier. -11" 202.:11 :228-ftKB- - - - - -. - - - - - - - - - -- - - - - - - -- :::: ::::::2~1:¡i":P-0wërJet:~oli0w::: ::::: :::::::::::::::::: -- :::: :¢~r:rjej";:1 I,202:1:1:Z2S:ftKa:::::::::::::::::::::::::: - - Z"PowerJet'hollow-earrier-,- - - - -. - - - - - - - - - - - - - - - - -. - - \ :: :: ::::: :::::::: :1j:,2ù2;1:1~28:ftKB:::::::: ::::: :::: :::: :::::: ;; W"":·:':':':':':···i ...... ::....,.. ... ".... '¡:::::ø :W)ti -.........................----.-.-......-..-..........--..............-............-...... -- -......................................................................................................... -.................................................................... .... .:.: ... . . ..... ........ ............... .. ....... ..... .... ..... .................. .. ...... .. . .. .... .................................. ... ... .. .. .. .. ...... .... ......... ............. .. ..... ....... ............. .................. .. .... ...................................... ........ .... ...... ... .... ......... ....... . . ...... ........ .... ..... .. ......... . ..... . , ' ":::::;:;:;:;::::;::" .. .":"',, . DOLLY Well: D-46. I ..,' . 'I . UNOCAL::¡¡¡¡~t¡f API: 507332016501 Latest Completion: 2/18/2000 Original Completion: 6/27/1990 )eñorations Shot Dens Phasing Date Zone Top (ftKB) Btm (ftKB) (shots... CO) Carrier Desc Current Status Cur Stat Date Comment /9/1990 10,795.0 10,800.0 Squeezed 3/9/1990 3/9/90, SOZ'D ; hide 11 0/2000 G2, 11,,104.0 11,140.0 12.0 60 2" Power Jet hollow ,A,FE: 135974; Unocal Supervisor: Scales, Nienhaus; ,Main carrier Zone: G2;; hide 'Hole /8/2000 G2, 11,104.0 11,140.0 6.0 60 2-1/2" PowerJet AFE: 135974; Unocal Supervisor: Tyler; Zone: G2; Main hollow carrier Hole 2/4/2000 G2, 11,104.0 11,140.0 StressFrao AFE: 143041; Unocal Supervisor: Steve Tyler; Stress Main Frac'd G-2 & G-3 Zones Hole /12/2005 G2, 11 ,105.0 11,135.0 6.0 60 2-1/2" Power Jet AFE: 163752 Main hollow carrier Hole /12/2005 G3, 11,202.0 11,228.0 ' 6.0 60 2-1/2" Power Jet AFE: 163752 Main' hollow carrier Hole /10/2000 G3, 11,202.0 11,228.0 12.0 60 2" Power Jet hollow AFE: 135974; Unocal Supervisor: Scales, Nienhaus; Main carrier Zone: G3;; hide Hole /8/2000 G3, 11,202,0 11,228.0 : 6.0 60 2-1/2" PowerJet AFE: 135974; Unocal Supervisor: Tyler; Zone: G3;; Main hollow carrier ,Hole 2/4/2000 G3, 11,202.0 11,227.0 StressFrac AFE: 143041; Unocal Supervisor: Steve Tyler; Stress Main Frac'd G-2 & G-3 Hole /10/2000 G4, 11,272.0 11,291.0 12.0' 60,2" Power Jet hollow AFE: 135974; Unqcal Supervisor: Scales, Nienhaus; Main carrier Zone: G4;; Hole /12/2005 G4, 11,274.0 11,289.0 6.0 60 2-1/2" PowerJet AFE: 163752 Main hollow carrier Hole /3/1 991 HK1, 11,678,0 11,697.0 4.0 0 Isolated 1/3/1991 HB-1, 4HPF, 19',0 PHAsE; ; isolated Main Hole: 1/23/1991 HK2, 11,714.0 11,744.0 4.0 0 Isolated 11/23/1991 HB-2, 4HPF, 30', 0 PHASE; ; isolated Main Hole /2/1991 HK2,' 11,765.0 11,795.0 4,0 H-4; isolated; Main Hole /3/1991 HK3, 11,896.0 11,960.0 6.0 60 Isolated 1/3/1991 HB-3, 6HPF, 64', 60 PHASE; ; isolated Main Hole /3/1991 HK3, 11,926.0 11,960.0 Isolated 1/3/1991 ; ; isolated Main Hole /25/1990 HK4, 12,031.0 12,072.0 Squeezed 8/25/1990 HB-4, SOZ'D; Main Hole /26/1990 HK5, 12,147.0 12,181.0 Squeezed 6/26/1990 HB-6, SOZ'D; Main Hole 3/11/05 ) ) PJSM, RU Schlumberger wireline, lubricator, change wellhead flange, pressure test to 2500 psi., arm guns and shut well in. RIH with 2.5" HC, 6 spf, 60 deg. phase, 15' perf gun. TP - 175 psi. Tied in with Schlum Perf Log dated 6-7-2000. Tools set down at 11,289'. Tools had 300 Ib drag when logging up. Spotted perf gun from 11,272' to 11,287'. Checked TP and it was 200 psi shut in. Fired perf gun, TP stayed the same. POOH. All shots fired. Well was sticky from 11,289' to 11,100'. Wt went from 300 Ibs over, to string wt (1750 Ibs) with in that interval. RIH with 2.5" HC, 6 spf, 60 deg phase, 20' perf gun. TP was 300 psi. Tied into Schlum perf log, 6-7- 2000. Spotted perf gun from 11,206' to 11,226' and fired gun. POOH. All shots fired. TP= 350 psi. RIH with 2.5" HC, 6 spf, 60 deg phase, 6' perf gun. TP was 300 psi. Tied into Schlum perf log, 6-7-2000. Spotted perf gun from 11,200' to 11,206' and fired gun. POOH. All shots fired. TP= 400 psi 3/12/05 RIH with 2.5" HC, 6 spf, 60 deg phase, 20' perf gun. Tie into Schlum perf log, 6-7-00. Spot perf gun from 11,113' to 11,133'. TP = 450 psi. Fire gun. POOH, all shots fired.. RIH with 2.5" HC, 6 spf, 60 deg phase, 10' perf gun. Tie into Schlum perf log, 6-7-00. Spot perf gun from 11,103' to 11,113'. TP = 500 psi. Fire gun. POOH, all shots fired. Rig down Schlumberger and turn well over to production. 0-46 (AFE 163752) morning report summary, CONFIDENTIAL: last revised 4/7/2005, Page 1. Unocal Coqx~ration P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager 12/20/00 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Trading Bay Unit Well D-46 APl No. 50-733-20165-01 10-404 StressFrac G2 & G3 Zones Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the StressFrac stimulation of the G2 and G3 benches in well D-46. The following intervals were stimulated on 12/4/00: Bench Top Boffom Feet Max. PSI G2 11,104 11,140 12 5500 G2 11,116 11,128 12 9800 G2 11,128 11,140 12 7200 G3 11,202 11,214 12 7800 G3 11,215 11,227 12 6300 Total: 60 If you have any questions, please contact Ralph Holman at 263-7838. Sincerely, Dan Williamson Drilling Manager ALASKA O ND GAS CONSERVATION MISSION REPORT OF S,UNDRY WELL OPERATIONS 1/(~perations performed: Operation shutdown: Stimulate: Plugging: Perforate: X "' Pull tubing: Alter casing: Repa!r well: Other: 2. Hame of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 106' RKB feet :~i Address Exploratory: ~. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: , ,, ,, , 4. Location of well at surface 8. Well number 752' FSL, 1138' FWL, Sec. 6, T8N, R13W, sM D-46 At top of productive interval 9~ Permit numbei/approval number 2001' FNL, 667' FWL, Sec. 8, T8N, R13W, SM 300-143 ,',/ At effective depth 10. APl number 50.733-2016§-01 At total depth ~ 1. Field/Pool " ' 2245' FNL, 1989' FWL, Sec. 8, T8N, R13W, SM McArthur River/G-Zone 12. Present well condition summary Total depth: measured 12493 feet Plugs (measured) Bridge plug @ 11544' with 10' of cement true vertical 10034 feet PosiSet plug O 1140,5' (DIL), TOC O 11329' (DIL) Effective depth: measured 11534 feet Junk (measured) E-line toolstdng at 11502' ELM true vertical 9286 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 803' 20" 1400 sx 803' 803' Surface 4944' 13-3/8" 1454 sx 4944' 3738' Intermediate 10933' 9-5/8" 1227 sx 10933' 8797' Production 12490, 7" 885 sx 12490' 10040' Liner Perforation depth: measured 11104-11140, 11202-11228, 11272-11291 RECEIVED true vertical'8931-8961, 9013-9034, 9070-9086 JAN 2 2 ?.001 Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 @ 11045' Alaska 011 & Gas Cons. Commission .... ,Anchorage Packers and SSSV (type and measured depth) Brown "3H' Perm. Pkr. @ 11501', Baker 'F-1' Perm. @ ~ut~5~., SSSVLN: Howco 'XXO' @ 325' · , '"~'3. Stimulation or cement squeeze summary Stimulated G2 & G3 zones with StmssFrac 11215'-11227' max. press. 6300 psi Intervals treated (measured) G2:11104'-11140', 11202'-11214' max. press. 7800 psi G3:11202'-11227' 11128'-11140' max. press. 7200 psi Treatment description including volumes used and final pressure 11116'-11128' max. press. 9800 psi 11104'-11116' max. press. 5500 psi 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 273 39 73 899 120 ..... Subsequent to operation 204 19 102 779 160 15. Attachments: 16. Status of well classification as: CopieS of Logs and Surveys run: .Daily Report of Well Operations: Oil: X Gas: Suspe,nded:., . , ,Service: ":~ 7. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~~./~_~(~~.. Title: /~{,/~/~ ~,.~. Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRu· Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor FROM' John Crisp? ~ ~. SUBJECT: Petroleum In~izlector DATE: June 22, 2000 Safety Valve Tes~ 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; :~N AL 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/Pad: MeArthur Rv. / Dolly Var& Separator psi: LPS 110 HPS 6/22/00 Well Permit Separ Set' L/P Test Test Test oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GASor CYCLE i I 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-17P~ 1810230i 110 80 80 P P 43 OIL D-18 1690040 800 700 700 p p P GAS D-20 1690950 110 80 90 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 1'820830 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 ~ 1890610_ 110 80 60 p p P 0IL D-47 1910110 ll0 80 70 P P 9 OIL D-48 1921540 ll0 80 80 p P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% ["'190 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. 6-22-00jcl THE MATERIAI~ UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000 E E Pl~ E W M A T ER IA L U N D ER TH IS M A.R K ER ,.STATE OF ALASKA ALASKA O" AND GAS CONSERVATioN ' -'"MMISSION REPOR -OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdOWn: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: Isolate 2. Name of Operator 5. TyPe of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 106' RKB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: Trading Bay Unit 4. Location of well at surface 8. Well number RECEIVED At top of productive interval 9. Permit number/approval number 2,001'FNL, 667'FWL, Sec. 8-8N-13W-SM "??:;";,1~1~ , .~00'1~. At effective depth JUL 0 7 2000 10. APl number 50- 733-20165-01 At total depth Alaska 0i- & Gas Cons, Commission 11. Field/Pool 2,245' FNL, 1,989' FWL Sec. 8-8N-13W-SM An~nr,'~ Tyonek (3-Zone 12. Present well condition summary ......... Total depth: measured 12,493' feet Plugs (measured) Bridge Plug ~ 11,544' w/10' of cement true vertical 10,034' feet Posiset Plug {~ 11,405' (DIL) TOC ~ 11,329' (DIL) Effective depth: measured 11,534' feet Junk (measured) E-Line toolstring at 11,502' ELM true vertical 9,286' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 803' 20" 1,400 sx 803' 803' Surface 4,944' 13-3/8" 1,454 sx 4,944' 3,738' Intermediate 10,933' 9-5/8" 1,227 sx 10,933' 8,797' Production 12,490' 7" 885 sx 12,490' 10,040' Liner Scab Liner Perforation depth: measured true vertical See Attached Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80, Buttress @ 11,045' Packers and SSSV (type and measured depth) Brown '3H' Perm @ 11,501'; Baker 'F-I' Perm @ 10,964'; SSSVLN, Howco 'XXO' @ 325' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5/8/00 68 281 1,988 1,298 120 Subsequent to operation 6/14/00 99 188 92 754 130 15. Affachments: t6. 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: ,~ ;igned:~ ~~~ Williamson Title: Drilling Manager Date: 7~'"'~'~'~ Form 10-404 Rev 06/15/68 SUBMIT IN DUPLICATE Dolly Varden D-46 Actual Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt SPF Comments G-2 11,104, 11,140' 8,936' 8,965' 36' 18 :2.5 ", HC, 6 SPF 60 Deg G-3 11,202' 11,228' 9,016' 9,038' 26' 18 2.5 ", HC, 6 SPF 60 Deg , G-4 11,272' 11,291' 9,065' 9,090' 19' 12 2 ", Power Jet, 6 SPF 60 Deg 81' Isolated Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt SPF Comments HB-1 11,678' 11,697' 9,392' 9,414' 19' Isolated HB-2 11,714' 11,744' 9,428' 9,453' 30' Isolated HB-2 11,765' 11,795' 9,471' 9,496' 30' Isolated HB-3 11,896' 11,960' 9,583' 9,637' 64' Isolated , HB-4 12,031' 12,072' 9;696' 9,720' 41' Plugged HB-5 12,147' 12,181' 9,786' 9,8i3' 34' Plugged 218' RECEIVED JUL 0 7 2000 Alaska 0il & Gas Cons~ Commission Anchorage Work Summary Dolly Varden, Well No. D-46 5-14-00 to 6-8-00 DAY 1 (5114100) RU SCHLUMBERGER E-LINE UNIT. PRESSURE TEST LUBRICATOR 2,500 PSI. OK. RIH WITH PRODUCTION SURVEY TOOL. SURVEY INDICATES THAT ISOLATION ASSEMBLY AT 11,544' IS LEAKING. RD SCHLUMBERGER. DAY 2 (5116/00) RU SCHLUMBERGER E-LINE. PRESSURE TEST LUBRICATOR TO 2,500 PSI. RIH WITH WEATHERFORD BRIDGE PLUG FOR 3-1/2", 9.2# TUBING. ATTEMPT TO SET ABOVE NO. 1 PLUG AT 11,502' DIL. PLUG NOT SET. POOH. UNABLE TO PULL TOOL STRING INTO TUBING TAIL. PULL OFF OF WEAK POINT. PREP TO POOH. WIRE BROKE AT KINK AT SURFACE LEAVING 10,800' OF .23 E-LINE IN HOLE. DAY 3 (5117/00) RU BRAIDEDLINE UNIT. FISH .23 E-LINE. RECOVERED 20'. DAY 4 (5118/00) CONT. FISHING E-LINE. RECOVERED 108' DAY 5 (5119100) CONT. FISHING E-LINE. RECOVERED 167' DAY 6 (5/20/00) RECOVERED REMAINDER OF CABLE FROM WELL. TOOL STRING LEFT IN HOLE. RD BRAIDEDLINE. DAY 7 (5124/00) RU SLICKLINE. RIH W/2.5" BLIND BOX. TAG TOP OF FISH AT 11,439'. POOH. DAY 8 (5125100) RD SLICKLINE. RU E-LINE. TEST LUBRICATOR TO 2,500 PSI. RIH AND SET POSISET THRUGH TUBING BRIDGE PLUG FOR 7" 29# CASING AT 11,405' DIL. POOH. MU 2-1/8" BAILER. RUN NO. 1 - RIH AND DUMP BAIL CEMENT ON PLUG. RECEIVED JUL 0 7 2000 Alaska 0~', & Gas Cons. Commission ~chorage DAY 9 (5126100) CONT DUMP BAIL RUN NO. 3-10. DAY 10 (5127100) CONT. DUMP BAIL CEMENT. RUNS NO. 11-13. ESTIMATED TOC = 11,337'. RD E-LINE. ALLOW PLUG TO CURE. DAY 11 (5130100) RU SLICKLINE. RIH W/DRIVE DOWN BAILER. TAG TOC AT 11,355' SLM. RD SLICKLINE. PUT WELL ON GAS LIFT. WATER SUCCESSFULLY SHUT OFF FROM HEMLOCK. DAY 12 (6/6100) RU E-LINE UNIT. DAY 13 (6~7~00) MU LUBRICATOR. PRESSURE TEST TO 2,500 PS1. MU GUN NO. I 2-1/2", 6SPF HC GUN. PERFORATE G-3 FROM 11,202'-11,228' DIL. MU GUN NO. 2. RIH AND PERFORATE G-2 FROM 11,124'-11,140' D~L. DAY 14 (618100) RIH GUN NO. 3. PERFORATE G-2 FROM 11,104'-11,124' RECEIVED JUL 0 7 2000 Alaska 0i.~ & Gas Cons. Commission Anchorage RKB - 39.38' Varden Well No. 46 Actual 6/8/00 CASING AND TUBING DETAIL SIZE WT GRADE CONN 1D TOP BTM. 20" 94 1~55 t9./24 Surface 803' 13-3/8' 61 K-55 BTC 12.5t Surlhcc 2.°00' 9-5/8" 43.5 N-8( BTC 8.755 Surface 752' a? N-80 BTC 8,681 752' c )08' 535 S-95 BT( 8.535 168' 1£ 933' 5 I II PosiSet Plug at 11,405' DIL TOC ® 11,329' DIL 6/7/00 Isolation Plug at 11,544~ leaking 8 A B C D G-2 G-3 G-4 -- Fish = ] Set Tool, -- H-3 __ H-4 H-5 PBTD 11,544' TD= 12,493' MAX HOLE ANGLE = 53° ~ 3,550' D~46 Draw 6-8-00 Tubing 3-1/2" 92 L-80 gTC SC Sur~b. cc lI. ~6' JEWELRY DETAfL NO-- Depth OD ID ltenl I 3880' CIW, I 1" x 4', 5M DCB Single Tubing lianger 44/2" EUE kill x 4-1/2" Butt Suspension 2 40' 4.50 2.992 Crossover, 4-1/2" Bugl'ess x 3~1/2" Buttress 3 325' 4.250 2.813 SSSV Landing Nipple, Howco, XXO (2.813") 4 2,414' 5.3[3 2.867 GLM No.l ~ McMurl~ Macco, 3-1/2' SMO-1 R4, BK-2 5,399' 5.313 2.867 GLM No.3, McMmry Macco, 3-I/2" SMO-I R-I, BK-2 6,432' 5.313 2.867 GLM No.4, McMurry Macco, 3-1/2' SMO-I B4, BK-2 7,375' 5,313 2.867 GLM No 5, McMurry Macco, 3-1/2" SMO-1 R-l, BK-2 8,094' 5.313 2.867 GLM No.6, McMurry Macco, 34/2" SMO-I R-l, BK-2 9,889' 5.313 L867 GLM No.0, McMurry Macco, 3-I/2" SMO-I R-l, BK-2 10,384' 5.313 2.867 GLM No.10 McMun'y Macco, 3-1/2" SMO4, R-l, BK-2 10,880' 5.313 2.867 GI.M No.1 t McMun'y Macco, 3-1/2" SMO-1, R-l, BK-2 5 1t¥161 ' 4.250 2.992 kocator Seal Assy. Baker 8040, (I 4,5' Long) 6 I0,977' 4000 2.992 Crossover, Baker4 Acmex~-l/- B tressP 7 11,012' 3750 2.813 ~BX' Nipple, Baker, w/2.813" Otis 'X' Profile 8 11,045' 3865 3,000 Wlrehne Eh' ry Grade,' ' Mule Shoed The fogowing set on Drill Pipe I 10,964' 6.150 4.000 Packer, Mod. F-l, Permancnt~ 7" 26-32#, 85-40 II 10,167 5.500 4.000 S~al Bore 18xtension (15' Long) Suspended Completion A I 1,482' 5.625 4.000 PBR, Baker, 80-40 (18.43') B 11,500~ 4.250 3.250 Anchor, ~CH', Browl~ (150K su'aight pull or 15 right tums) C 11,501' 5.843 3.500 Packer, Brown, 7", '3H' Perm. D 11,505' 4.500 3.937 Millout Extension, Baker (5.52' Long) E 11,527' 4250 2.813 Otis, 'X' Nipple 2.81Y' F 11,544' Bridge Plug, Baker Mod. 'N' w/10' of cement G 11,559' 3812 3.000 Wireline Entry Guide PERFORATION HISTORY Interval (DIL) Accttm, Date i ?'.one Top Btm Amt spf Present Condition 6/7/00 i G~2 11,104' 11,14ff 36' I8' 2"Power Jet, 60 dcg 6/7/00 G~3 11,202' 11,228~ 26' t 8' - Power Jet 60 deg 3/6/00 Gm, 11,272' / 1,29l* 19' 12 2"Power Jet~ 6~ d~g 1/3/91 B-I 11,678' It,697' t9' 8 Isolated 1 t/23/91 H-2 11,714' 11,744' 30' 8 Isolated 52/91 11,765' t 1,795' 30' 1/3/91 I~L3 11,896' t t 92T 1/3/91 11,926' 5/2/91 H4 11,765' 8/25/90--~- :h~ '~' 12,03l' 6/26/90 H-5 12,147' 11,960' 1t,79Y 12,072' 3 ilsolated 31' 4 ilsolated 34' 4 ilkolated 30' 4 ilsolated 41' 4 iCementPlugged Original Drill and Complete 4/4/90 Last Workover 2/18/00 Revised 7/7/00 DRAWN BY: tcb 4 I2,18l' 34' UNOCAL Alaska Drilling Department To: Mr. Blair Wondzell ~rOITl: AOGCC Tim Brandenburg Ph. (907) 263-7657 Re: Dolly Varden D-46 Pages including cover sheet: 6 RECEIVED MAY 24 ~000 O~i & Gas Cons. Gommiask)n cl/I '4 ~VPI'II nnnz ,~z,x~m Unocal Corpm'aflon P,O, Box 196247 Anohotage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Wllllam$on DHIling Manager May24,2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Re: Commissioner Robert N. Christenson Application for Sundry Approvals (Form 10-403) Dolly Varden D-46 Commissioner Christenson: Dolly Varden D-46 was worked over in February of this year to convert to a G-Zone Oil Producer. Prior to the workover an Isolation Plug (consisting of a Baker Mod. 'N' bridge plug and 10' of cement) was placed in the tail pipe of the production packer (See attached Schematic). The intent was to utilize the Hemlock production packer as an isolation assembly. Initial rates from the G-Zone were 501 BOPD and 1,085 BWPD. While on production a dramatic change in water, cut occurred (from approx. 66% to 98%). A production profile revealed that the Isolation plug was leaking and allowing the Hemlock to drown out G-Zone production. On May 16, 2000 an attempt was made to set a second Bddge Plug In the tall pipe just above the first plug. The setting tool failed to function and the plug did not set. When pulling out of the hole the' Bridge Plug would not re-enter the tubing. The e-line was parted at the weak point leaving the bddge plug and toolstdng in the well. A subsequent LIB run indicates that the toolstdng is resting in the tail pipe of the lower Isolation Packer. This toolstring was not fished due to the dsk of sticking the partially set bridge plug in the production tubing. In order to isolate the Hemlock water and restore G-Zone production, it is proposed to set a Schlumberger 7" PosiSet Through Tubing Bridge Plug in the 7" casing above the isolation packer and to dump bail 40' of cement. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Brandenburg at 263-7657. Dan Williamson Drilling Manager 0/7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request; Abandon: Suspend: Operation shutdown: Re-enter stmpended well: Alter casing: R~r well: ~ Plugging: ..... Time ex~nsion: Stimulate: Change approved progr~: Pull tubing: V~ce: X Petered: ~et: X I~iate 2, Name of Opera~r 5. Ty~ of w~l: 6. Datum elev~ion (DF UNOCAL .......... Development; ~ ~ 0~ KB ABOVE MSL ~et 3. Address ~iom~; 7. UnE or Pr~y n~e Svafigraphic: PO BOX 1~247 An~orage, Alaska 99519 Se~l~: Tr~ing Bay UnE 4. Location of well ~ surface L~ A-2, Cond. 7, Dolly V~en PlaEo~ 8. Well number 752' FSL, ~,~38' FWL, Sec. 6-SN-13W-SM D~6 At top of produc~ve intew~ 9. Pe~lt number 2,001' FNL, 667' ~L, Sec. 8-8~3W-SM 8~1 / 91~87 At effecave dep~ t0, APl numar 50.733.20166~1 At total depth 1t. Fi~Pool 2,245' FNL. I,~F FWL Sec. 8~N-t3W-SM Tyvek G-Zone t2. Present well'~nd}fl~"~mm ary Total depth: me~umd 12,493' feet Plugs (m~aur~) Bridge Plug ~ ~ 1 ,~4' w/10' ~ ~ment true ve~i~ 10,034' feet Effective depth; measured t 1 ,~4' f~t Junk (measured) E~ne tools~ng at 11,~Z ELM true ve~c~ 9,2~' f~t Casing L~gth Sl~ Cemented Me~ur~ dep~ True ve~cN d~ Stru~raJ Conductor 803' 20" 1A00 ~ 803' 8~' S udace 4,944' 1 ~318" 1,4M ~ 4,~' Intermedia~ 10,933' 9-5/8" 1,227 ~ t0,933' 8.797' Liner Peffora~on depth; measured 0RIGINAL Tubing (size, grade, and measured depth) ~a Gl & Gas ~s. ~m~ ~/2", 9.~, L-80, BuErees ~ 11,045' Packers and SSSV (~pe and mea~red ~p~) Brown 'aH' P~m ~ t t,S0~'; B~er'Fd' P~m ~ 10,~4'; 888VLN, Howco '~O' 13. Attach~[~'~ D~Upa~ summ~ of pmpo~:""~ Data[ed op~aona p~mm; ' ' oep ~4. Estimated date for commencing operation 15. Status of well ~sificafion ~: 5/25100 t6. If proPosal well verbally ~mved: '"' ~1; X Gas: Su~nded; Name ~ approvcr Date approved Se~ic~ ..... ~7, I hereby ~i~at the foregoing is tub ~d correct ~ the best of my knowledge. .,D~Wiili~eon Tide'. DflllingMa~ Date: - FOR COMMISSION USE ONLY Co~d~ona of approval: Notify Commis~an so repmsenta~ve may ~tne~ .... -- Mechanical Integrity Test Subs~uent form r~uired 10- ~O ~ ~ 6 App.y~ by ordsr of ~e Commi~ioner 0 Taylor oeamount Form 10-403 Rev 06/15/88 Q/~ .A ~7.~1~1 SUBMIT IN TRIPLICATE IAIWOI' I I flflfl7 '~7'~PlAI Unocal Alaska Busiaess Unit Dolly Varden Platform Well No. D-46 III Isolate Hemlock I RU E-Line. 2 Mu Posiset Plug and framing tool. 3 RI_EL 4 Set Posiset Plug for 7" 29# at 11,465'. POOH. 5 6 RU 2-1/8" Dump Bailer 7 RIH. 8 Dump Cement on Posiset Plug. ~ 9 POOH. 10 Repeat as necessary to place 40' cement plug for a top of ceanent at. 11,425'. Page 1 ~VPI't nnn7 UNOCALe 39.38' $ I It, 0-2 Isolation iealdug A D E Fish = CIBP, 8et Tool, GR/CCL I'I-2 ti-4 = PBTD 11,544' TD= 12,493' MAX HOLE ANGLE -- 53° ~ 3,550' D-4~5 Draw 2Q-/~ - 7 A P~RT.' 0hi size Dolly Varden Well No. 46 Actual Completion 2/18/00 . i I iii iii . CASING AND TUBING DI[TA.IL ORA.D]/ CONN ED TOI~ BTM. 20" 13-3/8" 9-5/8" 94 61 47 29 29 Tubing 3-1/2" 9.2 J-55 19,124 Surfaoe 803' K-55 gTC 12.51 Surfge 2,999' N-80 BTC 8.755 Surface 752 N-80 BTC 8,681 752' 6,068: S-95 BTC 8.535 6,068' 10,933' N-80 ItTC 6.184 Surface 11 ?-110 BTC 6.18,1. 11;756 12,490' L-80 BTC 8C Surtlaco 11,046' JEWELRY DlgTAIL ~o. ~_. o.o m I 38.80' - - 2 40' 4,50 2.992 3 325' 4.2:50 :L813 4 2,414' 5.313 2,867 4,143' 5,313 2.867 5,399' 5.313 2.867 6,432' 5.313 2,867 7,375' 5.313 2.86.7 8,094' 5.313 2.867 8,747' 531:5 2.867 9,364' 5.313 2.867 9,889' 5.313 2.867 10,384' 5.313 2.867 10,880' 5.313 2,867 5 10,961' 4,250 2.992 6 10,977' 4.000 2.992 7 11,012' 3.750 2,813 8 11,045' 3.865 3,000 I 10,964' 6.150 ,*,000 II 10.967' 5500 .... 4,000 11,482'_ 5.625 4,000 11,500' 4.250 3.250 11,501' 5,843 3.500 11,505' 4.500 3.937 11,527' 4.250 2,813 11,544' - 11,559' 3.812 3,000 CIW, 11" x 4"~ SM, DCB S~a$1e Tubing Hanger 4-1/2 BUI5 Lii~ x ~1~' Bu~ S~nsi~ Cms~v~, 4-I~" Bu~ x 3-1/2" Bu~ess SSSV ~d~s Nipple, ~wco, ~0 (2.81Y9 OLM No, i, MoM~ Metro, 3-1~" 8MO-I~ R-I, O~ No,2, McM~ ~ 3-1/2" SMO-I, O~ No.3, MeMu~ Mac~, 3-1/2' $MO-1, R-l, BK-2 G~ No~, MoM~ Ma~, 3-1/2n SMO-I, ~-1~ BK-2 OLM No.5, McM~ M~, 3-1/2" 8MO-I ~ R-I ~ BK-2 O~ No.6~ M~u~ ~eo, 3-1/2" 8MO-1, R-I, BK-2 O~ No,7~ MoMu~ M~o~ ~-1/2" SM~I, R-l, BK-2 O~ No.8, McM~ M~o~ 3-1/2" SMO-I, R-l, BK-2 O~ No.9, McMu~ M~ 3-1/2" SMO-I~ R-I, BK-2 G~ No. 10 MaM~ Macco~ 3-1~n SMO-I, R-l, BK-2 C~ov~, B~ 4" Ao~ x 3-1/2" Bu~ese Pin 'BXJ Nipple, Bak~, w/2,813' Otis 'X' Wkelin~ ~ ~e~ Mule T~e fo~o~ng ~ on DrlB Pac~ Mod. ~-1, Psmn~ 7" 26-52~, Sn~ded Co,piton PBR, B~, 8~0 (18,43~) ~h~, '~', Bm~ (150K ~asht pull or 1 P~k~, Bro~ 7% ~3H~ Millout Extemion, Bn~ (5.52' ~) Bgd~ Pl~ g~ M~. ~' w/10' of c~,nt ' ~,z~o~oN mSTdaV " Interval (DIL) Da~ ' ~e Top B~ ~ 8p[' ~~ol -" 3/~0/~ ~2 l 1,104' 11,140' 36' 12' 2"Po~r J~, 3/6/00 ¢3 ~L202' IL2ia' 26' ~" ..... 3/~00 ~4 11~72' "" 11,291' 1~ I2 .... 1/3/91 B- i' 11,678' 11,6~ 19'" 8 ~ola~ 11/23/91 H-2 11,~14' I 1,7~' 30~ 8 ~h~ ' '5~91 11,765' ~,~5' ~o' 1/3/91 ~'-3 11,896' 11,~7 31' 4 '~ ......... 1/3/91 " I 1~926' 11,~0' 34' '"~ ~la~ 5~! H4 11;765' I 1,795' 30' 4 ~lat~ ~5~ .... H4 1~031' 12,072' '4i' 4 6/26/90 H-5 { 12,14T 12,18I' 34' ' 4 ~ ~g~' Original Drill and Complete 4/4/90 Revised 3/10/00 'A~fl.q 'lV.qt3hlflY:tdl:~vP.l' I I flflflZ UNOCAL P. KB = 39.38' 5,290' Proposed PosiSet ]Plug at ,465' w/40' Cement leal~g B C G-3 G-4 CIBP, 8et Tool, GI~dCCL H-1 H-3 H-4 I~BTI) 11,544' TD ~ 12,493' lVLAX HOLE ANGLE = 53° ~ 3,550' D'46Pr°P ICl/el 'ct Dolly Varden Well No. 46 Proposed CASING AND TUBING DETAIL SV_,F, wx oR~uz ,,, CO.S m rot 20" 94 1-55 19.124 Surface 803' t3-3/8" 61 K-55 BTC i2,51 Surfac~ 2,999' 9-5/8' 43.5 N-80 BTC 8.755 $~ce 752' 47 N-80 BTC g.681 752' 6,068' 53.5 S-95 ~TC g.53~ 6,068' 10,933' 7" 29 ~-80 B~C 6.18a 8~aee i 1,756 29 P-Il0 BTC 6.184 11fl56 12,490' Tublug 3-1/2" 9.2 I.,-80 BTC SC Surface 11,046' JEWELRY DETAIL NO, Depth OD 1D lttm 1 38.80' - CIW, 11" x 4', 51vI, DCB 5~gl& Tubtns Ha,uSer 4-1/2' ~ Li~ x n-l~2" BuU Su~oa 2 40' 4.50 2.992 Oossov~, {-1/2" Bu~ems x 3-1~" 3 325' 4.250 2.813 SSSV ~di~ Nipple, How~, ~O (2.813") ~ 2,414' $.3 i 3 2.867 O~ NO. l, Mc~ Mae~o, 3-i/2° ~O-1 ~ R-I ~ BK-2 · ,la3' 5.313 2,867 O~ No,2, M~ Ma~0, 3-1/2" SMO-I, R-I, BK-2 ,, 5,399' 5.313 2.867 O~ No,3, McMu~ M~co, 3-I/2 $MO.I, R-l, BK-2 6,432' 5.313 2.867 OLM No.4, McM~ M~o, ~-1~" SMO-I, K-l, BK-2 7,375' 5,313 2,867 GLM ~o.5, McMu~ M~, 3-1~" SMO-I, K-l, BK-2 8,094' 5.313 2.867 O~ No.6, McMu~ M~, 3-1~" SMO-I, R-l, BE-2 8,7a7' 5.313 2.867 O~ No,7, McM~ M~co, ~-i/2" SMO-I, R-l, BK-2 9,364' 5.313 2,867 O~ ~o,8, McMu~ M~co, ~-I/2" 9,889' 5.313 2.867 O~ No.9, Mc~ Ma~, 3-1/2" SMO-I, R-l, BK-2 10,384' 5.313 2-~67 OLM No.10 McM~ M~, 3-1/2" SMO-1, ~1, BK-2 10,880' 5.3 i3 2,867 O~ No, I 1 McMu~ ~, ~-1/2" $MO-I, R-I, 5 10,961' 42150 2.~2 L~ S~ Any. B~m 80-~, (lA.5' 6 I0,977' 4.000 2.992 Oo~ver, ~ker 4" Ac~ x 3-112" Bumess 7 11,012' 3.750 2.8~3 'BX' N}pp]e, Bak~, w/2.813" O~ 'X' P~flle 8 11,045' 3.865 3.000 W~l~e ~ ~Me, M~e Shoed ~e f~ilo~u{ ~ on Drffi 1 10,964' 6,150 4,000 Pack~, Mod, N-l, P~t, 7" 26-~2~, 8~0 lI 10,967' 5,500 4,000 Se~ Bom ~mi~ (15' A 11,482' 5.625 4.~ PBR, Bak~, 80~0 (18.43') B 11,500' 4.250 ~.~0 ~c~r, 'CH', Bro~ (150K ~t pull C 11,501' 5.84~ 3.500 P~ker, ~o~, 7", '3H' P~. D 11,505' 4,500 3,937 M~lout ~{~i~, B~ (5.52' E 11,527' 4.250 2.813 0~{, 'X' Nippl~ 2.~3' F 11,~a' B~dge Plug; Baker Mod, 'N' w/t0' ofcemeat O I 1,559' 3.812 3.~ Wireline ~ Ouide ........ ~E~O~TION ~O~Y ........ , ~ ~ne Top { B~ ~ ~f ~e~t 3/10/00 ~2 11,I04' 11,140' ~ 12 27~ 3/~00 ~3 11,202' ! 1,~' 26' 12 2"Power J~ 60 deg - 3/6/00 04 11~72' ' 1¥~91"' ' 1~ 1Z 2"Po~ J~ 60d-eg ~' 1/3/91 B-1 11,678' 11,697' 19' 8 ~1~ I I~3/91 H-2 11,71# 11,744' 30' 8 ~1~ 52/9I I1,765' I 1,795' ~ 30' 3 ~1~ ,,~.. , .... 1/3~1 H-3 I 1,896' 11,927' 31' 4 .......... 1/3/91 11,926' 11,960' 34' 4 ~ola~ ~ 5/~91 H~ 11,765' 11,795' 3ff 4 ~ola~ 8~5/90 H~ 12,031' 12,~2' ~'fc 4 ~ ~ugg~ ' 6~6/90 H-5 [~1~7' 12,181' 34' 4 ~ Phgg~ Original Drill aad Complete 4/4/90 Revised 3/10/00 O~A STATE OF ALASKA C~O ALASKA ND GAS CONSERVATION MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Union Oil Company of California (Unocal) 89-61 / 91-387 3. Address 8. APl Number P.O. Box 196247 Anchorage, Alaska, 99519-6247 50- 733-20165-01 4. Location of well at surface Leg A-2, Cond. 7, Dolly Vard~ ~, ~ 9. Unit or Lease Name 752' FSL, 1,138' FWL, Sec. 6-8N-13W-SM[~~~ Tradinc~ Bay Unit AtTop Producing Interval~ [ .,,~.;~: ! .,m=a~,": 10. Well Number 1,623'FNL 1,485'FWL, Sec. 8-8N-13W-SM~! '~..~1~~ l ~:~EO'~- i-~-~1~~ D-46 At Total Depth 11. Field and Pool 2,245' FNL, 1,989' FWL Sec. 8-8N-13W-SM McArthur RIver Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kenai G Zone 106' KB ABOVE MSLI ADL 18729 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions N/A N/AI 3/1/00 112 feet MSL 1 12,493'MD / IO,041'TVD 11,541'MD /9,292'TVD Yes: No: X 332' feet MD N/A 22. Type Electric or Other Logs Run None 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94 J-55 Surface 803' 1,400 sx N/A 13-3/8" 61 K-55 Surface 2,999' 17-1/2" 1,454 sx N/A 9-5/8" 43.5/47/53.5 S-95/N-80 Surface 10,933' 12-1/4" 1,227 sx N/A ,, 7" 29 N-80/P- 110 Surface 12,490' 8-1/2" 885 sx N/A 241 Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET IMD) 3-1/2", 9.2#, L-80 11,04,6' 10,964' DPM See Attached Sheet N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL IMDt AMOUNT & KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST .... ,, Date First Production I Method of Operation (Flowing, gas lift, etc.) 3/2/00I Gas Lift ~ate of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 3/15/00 24 TEST PERIOD => 501 25 1,085 N/AI 50 'Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 160 1,291 24-HOUR RATE => 501 25 1,085 33 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ORIGINAL 000 Na~ka Oil & Gas Cats. (Xa~i~ea Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ~-~ J ~' 30. ' ~' '~' GEOLOGIC MARKERS FORMATION TESTS NAM E Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and lime of each phase. RECEIVED · t AR Z7 000 31. LIST OF ATTACHMENTS Perforalion Data Sheet, Activity Summary, Welbore Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~~ ,,- ,. Title ~//~~, Date L'~ '"'~) '-~) 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 space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other eleva§on (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Dolly Varden D-46 Actual Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt SPF Comments G-2 11,104' 11,140' 8,936' 8,965' 36' 12 2 ", Power Jet, 6 SPF 60 De~ G-3 11,202' 11,228' 9,016' 9,038' 26' 12 2 ", Power Jet, 6 SPF 60 Deg G-4 11,272' 11,291' 9,065' 9,090' 19' 12 2 ", Power Jet, 6 SPF 60 De~l 81' Isolated Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt SPF Comments HB-1 11,678' 11,697' 9,392' 9,414' 19' Isolated HB-2 11,71 4' 11,744' 9,428' 9,453' 30' Isolated HB-2 11,765' 11,795' 9,471' 9,496' 30' Isolated HB-3 11,896' 11,960' 9,583' 9,637' 64' Isolated HB-4 12,031' 12,072' 9,696' 9,720' 41' Plu!~ed HB-5 12,147' 12,181' 9,786' 9,813' 34' Plu~led 218' RECEIVED · MAR 27 2000 AJaska Oil & Gas Cons. Commission © © Workover Summary Dolly Varden, Well No. D-46 1-26-00 to 3-10-00 DAY 1 (1126/00) RU SCHLUMBERGER E-LINE UNIT. PRESSURE TEST LUBRICATOR 2,500 PSI. OK. RIH WITH BOT MOD. N BRIDGE PLUG. DAY 2 (1/27/00) SET PLUG IN TAIL PIPE AT 11,525' ELM. POOH. MU 2-1/8" BAILER. FILL WITH CEMENT. RIH. DUMP BAILER ON PLUG AT 11,525' ELM. POOH. FILL BAILER. RIH, DUMP BAILER ON PLUG FOR 10' TOTAL ON BRIDGE PLUG. POOH. RD E-LINE. BLEED GAS LIFT GAS OFF ANNULUS. DAY 3 (1/28/00) FILL ANNULUS WITH FILTERED INLET WATER (FIW). PRESSURE TUBING TO TEST PLUG. PRESSURE TO 1,600PSI. ANNULUS TRACKING WITH TUBING INDICATING GASLIFT MANDREL CHECK VALVE LEAK. HOLD PRESSURE FOR 30 MIN. CHART RECORDER INDICATING BLEED OFF OF 100 PSI IN 30 MIN. NEW TUBING AND ANNULUS GAUGES INDICATING NO BLEED OFF IN 30. MIN. BLEED TUBING AND ANNULUS TO ZERO. DAY 4 (1/29/00) RU APRS E-LINE. PRESSURE TEST LUBRICATOR TO 1,000 PSI. REPAIR LEAK RETEST TO 1,000 PSI. TEST O.K. MU 2.625" CHEMICAL CUTTER FOR 3-1/2" TUBING. RIH. SET DOWN AT 3,240'. PULL 500 LBS OVER TO PULL FREE. RIH SLOW, SET DOWN AT 3,276' ATTEMPT PU. NO GO. TOOLS STUCK AT 3,276'. WORK UP TO 1,500LBS - NO MOVEMENT. PUMP DOWN TUBING RETURNS FROM ANNULUS. WORK WIRE TO 3,000 LBS. PULL TO 3,800 LBS, PULL OUT OF ROPE SOCKET. LEAVE 25' CHEMICAL CUTTER FISHIN IN TUBING. DAY 5 (1/30/00) RU SLICKLINE. RIH WITH 2.25 OVERSHOT. RIH. PU WT AT 2,900' = 225 LBS. LATCH FISH AND SHEAR OFF LEAVING FISH BAITED. POOH. RIH W 2-1/2" JDC. LATCH FISH. PULL TO 1,500LBS. JARS NOT WORKING. SHEAR OFF POOH. CHANGE JARS. RIH. LATCH FISH. JAR AT 1,500 LBS. 10 TIMES WHEN SLICKLINE PARTED BELOW STUFFING BOX. SPLICE WIRE. SHEAR OFF FISH. POOH. RIG DOWN SLICKLINE. DAY 6 (1/31/00) RIG UP 3/16" BRAIDED LINE. TEST LUBRICATOR TO 2,500 PSI. RIH ENGAGE FISH AT 3,244' BLM. JAR AT 2,20-2,500 LBS TWO TIMES. FISH FREE. POOH 100% RECOVERY. MU 2.80 GAUGE RING RIH. RECEIVED MAR 2.? 2000 Alaska Oil & Gas Cons. Commission Anchor e © DAY 7 (2/1/00) CONT. RIH WITH 2.80" GR TO 11,500' W/NO PROBLEMS. POOH. RD WIRELINE. RU ALASKA PIPE RERCOVERY SPECIALIST (APRS) E-LINE. MU AND ARM 2.625" CHEMICAL CUTTER. RIH TO 11,448' ELM. SEVERE TUBING. (11,459' TUBING TALLY MEASUREMENT). POOH. TIGHT IN NO. 14 GLM. WORKED FOUR TIMES AND PULLED THROUGH. DAY 8 (2/12/00) REC, EIVEr TEST BOPE 250/3,000 PSI GOOD TEST. WHITNESSED BY AOGCC INSPECTOR. ~ ~.? ~.000 DAY 9 (2/13/00) Alaska 0il & Gas Cons. Commiss~on BREAK CIRC. DOWN TUBING AT 2 BBL/MIN. RETURNS CLEAN. PULL HANGER FREE W/ 100K. PULL TO 165K ON TUBING. WORK FOR 1 HOUR WITH NO MOVEMENT. RU APRS E- LINE. ARM 2.625" CHEMICAL CUTTER. RIH TO 11,450' W/NO PROBLEMS. PULL 20K OVER AND FIRE CUTTER AT 11,448' ELM. LOST 20K ON WEIGHT INDICATOR. POOH WITH CUTTER. TIGHT IN NO. 14 GLM. WORK PAST. TOOLS STUCK AT 9,749'. WORK TUBING - TOOLS FREE. POOH. RD APRS. PULL TUBING. PULLING TIGHT. WORK STRING FROM 70K TO 175K. WORK AND RECIPROCATE. TUBING FREE UP WEIGHT 140K. PULL HANGER TO FLOOR. CLOSE ANNULAR AND CIRCULATE 390 BBLS. FLOW CHECK. POOH WITH COMPLETION. CONDUCT H2S DRILL. SECURE WELL AND MASK-UP. CONT. POOH WITH COMPLETION. DAY 10 (2/14/00) CONT. POOH LAYING DOWN COMPLETION. ESTIMATED TOP OF TUBING STUB 11,462'. SET WEAR BUSHING. PICK UP FISHING/SCRAPING ASSY. UP. RIH PU 3-1/2" DRILL PIPE. DAY 11 (2/15/00) CONT. RIH WITH FISHING ASSY. WASH FROM 11,345' TO 11,462 (TOF). CIRCULATE 1.5 TIMES BOTTOMS UP. SLACK OFF AND ENGAGE FISH. PULL TO 300K AND PULL SEALS FREE. DISPLACE WELL TO FIW W/3% KCL. POOH. LAY DOWN BHA/FISH. DAY 12 (2/16/00) CONT. LD FISH. MU BAKER MOD. F-1 PACKER. RIH ON DRILL PIPE TO 10,964' DRILL PIPE MEASUREMENT. DROP BALL. PRESSURE UP TO 2,000 PSI TO INITIATE SETTING SEQUENCE. PULL 15K OVER AND SET DOWN 25K. PRESSURE TEST ANNULUS TO 1,500 PSI. NOT GETTING RETURNS UP DRILL PIPE. PULL 150K AND SLACK OFF 40K TWICE TO ENSURE GOOD SET. RE ATTEMPT PRESSURE TEST. SAME RESULTS. ATTEMPT TO SHEAR SETTING BALL IN B-2 SETTING TOOL. PRESSURE BLEEDING OFF INDICATING BALL NOT ON GOOD SEAT. RELEASE SETTING TOOL FROM PACKER WITH 15 RIGHT HAND ROTATIONS. PU 10' FROM PACKER. ATTEMPT TO SHEAR BALL SEAT. SAME RESULTS. POOH. FOUND RUNNING TOOL SEAL MISSING AND BALL NOT ON SEAT DUE TO SCALE. DAY 13 (2/17/00) PU 3-1/2" GAS LIFT COMPLETION. RIH. STAB SEALS INTO PACKER AND PRESSURE TEST TO 1,500 PSI. FOR 30 MIN WITH NO BLEED OFF. PULL OUT OF PACKER. PU SSSV LANDING NIPPLE RIH. SPACE OUT. CIRCULATE 20 BBLS CORROSION INHIBITOR FLUID SPOTTING AROUND TUBING TAIL. LAND COMPLETION. TEST SEALS TO 1,000 PSI FOR 15 MIN. NO LEAK OFF. TEST HANGER TO 5,000. PSI. NIPPLE DOWN BOPE. INSTALL TREE, TEST TO 5,000PSI. RELEASE RIG. DAY 14 (3/1/00) GAS'LIFT WELL. FLUID LEVEL AT 4,753'. 300 PSI ON TUBING. RU SLICKLINE. PRESSURE TEST LUIBRICATOR TO 3000 PSI OK. RIH AND RECOVER SSSV BLANKING SLEEVE AT 323'. POOH. RIH W/2-1/8" DUMMY GUN AND 2.80" GR. UNABLE TO PASS SSSV LANDING NIPPLE. POOH. DAY 15 (312/00) RIH W/2-1/8" DUMMY GUN TO 11,482' SLM. POOH. RIH W/2.80" GR. TO 11,482' SLM. POOH. RD SLICKLINE. RU E-LINE. PRESSURE TEST LUBRICATOR TO 2,M500 PSI. OK. RIH. PERFORATE G-3 11,202'-11,228' (DIL) W/2" POWER JET, 6SPF, 60 DEG PHASING. POOH. 320 PSI ON TUBING. RD E-LINE. RU SLICKLINE. DAY 16 (3/3/00) RIH. RECORD PRESSURE INFO AT 11,215' SLM . POOH. RD SLICKLINE. RELEASE WELL TO PRODUCTION. PRESSURE APPROX. 2750 PSI. DAY 17 (3/6/00) SI WELL. 625 SITP. RU E-LINE. PRESSURE TEST LUBRICATOR TO 2,500 PSI. OK. RIH. FLUID LEVEL AT 2,500'. PERFORATE G-3 11,202'-11,228' (DIL) W/2" POWER JET, 6SPF, 60 DEG PHASING. POOH. RIH PERFORATE G-4 11,272'-11,291' (DIL) W/2" POWER JET, 6SPF, 60 DEG PHASING. POOH. RIH PERFORATE G-4 11,272'-11,291' (DIL) W/2" POWER JET, 6SPF, 60 DEG PHASING. POOH. RD E-LINE. RETURN WELL TO PRODUCTION. DAY 18 (3/9/00) SI WELL. 600 SITP. RU E-LINE. PRESSURE TEST LUBRICATOR TO 2,500 PSI. OK. RIH. FLUID LEVEL AT 6,780'. PERFORATE G-2 11,104'-11,140' (DIL) W/2" POWER JET, 6SPF, 60 DEG PHASING. DAY 19 (3/10/00) POOH. RIH. PERFORATE G-2 11,104'-11,140' (DIL) W/2" POWER JET, 6SPF, 60 DEG PHASING. POOH. RD E-LINE. RELEASE WELLTO PRODUCTION. RECEIVED MAR 22 2000 cons. Comm o L OC L! RKB = 39.38' 5 l i1 8 G-3 G-4 A B C D E H-I H-2 H-3 __ tt-4 PBTD 11,544~ TD: 12,493' MAX HOLE ANGLE = 5Y' @ 3,550' D46ActualSchem0200,doc SIZE Varden No. 46 Actual Completion 2/18/011 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 20" 94 13 3/8" 61 9-5/8' 43.5 47 53.5 T' 29 29 Tubing 3-1/2" 9.2 J-55 19.124 Surface K-55 BTC 12.51 Sur~hce N-80 BTC 8.755 Sur~hce N-80 BTC 8.681 75T S-95 BTC 8.535 6.{)68' N-80 BTC 6.184 Surface P Il0 BTC 6.184 11.756 I, 80 BTC SC Surface 8{)3' 2.999' 752' 6.068' 10.93Y 11,756 12.490' NO. _De~ O~D JE ELR~ DETAIL ED Item 38.80' 2 40' 3 325' 4 Z414' 4.143' 5,399' 6.432' 7.375' 8.094' 8.747' 9.364' 9,889' 5 10.961' 0.964' C[W. I 1" x 4". 5M. DCB Single Tubing Hanger 4 I/2" EUE 15ft x 4-1/2' Butt Suspension 4.50 2.992 Crossover, 4 I/2- Bum'ess x 3 I/2' Bum-ess 4.250 2.813 SSSV Landing Nipple. ltowco. XXO (2.8IY') '7.313 2.867 GLM No 1. McMun'y Macco, 3 t/2" SMO-t, R-I~ BK-2 5.313 2.867 GLM No.2. McMurry Macco, 3d/2" SMOd, R-I, BK-2 5,313 2.867 GLM No3 McMurry Macco. 3-1/2" SMO-I, R-I, BK 2 5.313 2.867 GLM No.4. McMurry Macco. 3-1/2' SMO-I, R I. BK-2 5.313 2.867 GLM No.5. McMun'y Macco, 3-1/2" SMO 1, R-I. BK-2 5313 2.867 GI,M No.6. McMun'y Macco, 3 I/2" SMO- t. R-1, BK-2 5.313 2.867 GLM No.7, McMun'y Macco. 3 I/2" SMO-I, R-I. BK-2 5.313 2.867 GLM No.8, McMmTy Macco. 3-1/2' SMO-I. R I. BK-2 5.313 2.867 GLM No.9. McMun'y Macco. 3 I/2" SMO 1. R-l. BK-2 5.313 2.867 GLM No. I0 McMurry Macco. 3 I/2" SMO-1, R-t. BK2 5.313 2.867 GLM No.t I McMurry Macco. 3-1/2" SMO-I, R-1, BK 2 4.250 2.992 Locator Seal Assy Baker 80-40, (t4.5' Longj 4.000 2.992 Crossover. Baker 4" Acme x 3 I/2" Butlress Pin 3750 2,813 'BX' Nipple, Baker, v,/2.8t3" Otis 'X' Profile 3865 3000 Wi~eline Enn'y Guide, Mule Shoed The following set on Drill Pipe 6. t50 4.000 Packer~ Mod. FI. Permanent. 7" 26 32#. 85 4fi 5.500 4.000 Seal Bore Extension (15' Long} Suspended Completion 1,482' 4000 3.000 PBR. Baker. 80 40 (18.4Y) 1.500' 4.250 3.25fi Anchor, 'CH', Brown ( 150K slraight pull or 15 dght tumsi 1.501' 5843 3.500 Packer. Brown. 7", '3H' Perm 1,505' 4.500 3.937 Millom Extension, Baker (5.52' lxmg) 11.52T 425(/ 2.8t3 Otis, 'X' Nipple 2.8t Y' 1.544' Bridge Plug. Baker Mod 'N' w/[(P of' cemeltt 1.559' 3.812 3.000 Wire fine Entry Guide PERFORATION HISTORY h~terval (DIL) Accurm Date Zone Top Btm Amt spl' Present Condition 3/10/fK) (3-2 11,10~' 11,140' 3/2/00 G-3 I 1,202' l t ,228' 3/6/00 G-4 11,272' 11.291' I/3/91 B-I I 1,678' ll,697' 36' 26' t9~ 19' 12 [?Power Jet, 60 deg 12 2"Power Jet, 60 deg 12 2"Power Jet, 60 deg 8 Isolated 30' 8 [Isolated 52/9 I l/3/91 H-3 I/3/9 I 5/2/91 H-4 8/25/90 t-t-4 6/26/90 H-5 11,765' 11,896' 11,926' 11,765' 12,031' 12,147' 11,795' 11,927' ll,9f~)' 1t,795' 12,072' 12, t81' 30' 3 ilsotated 3F 4 ilsolated 34' 4 ilsolated 30' 4 [Isolated 4t' . 4 iCemem Plugged 34' Original Drill and Complete 4/4/90 Revised 3/10/00 DRAWN BY: Unocal Corporation P.O. Box 196247 Anchomge, AK 99519 (907)276-7600 UNOr L Wednesday, December 22, 1999 AOGCC Attn: Mr. Jack Hartz 3001 Porcupine Drive Anchorage, AK 99501 Application for Sundry Approvals (10-403) Dear Mr. Hartz: Please find enclosed three Application For Sundry Approvals (Form 10-403) for the Dolly Varden Platform No. 46. The scope of the well work is to include the isolation of the hemlock via a wireline bridge plug, removal of the current completion, and installation of a new completion that will allow for the addition of Tyonek G Zone intervals. Additionally a variance is requested for the following: Employ the use of secured 7,500 psi flexible lines fitted with WECO 1502 unio for service as a downstream choke line. _ This is consider adequate since D-46 as the Hemlock will be isolated via the bridge plug and the Tyonek interval will not yet be perforated. This system was employed for the previous Dolly Varden workover (D-12rd) in September of this year. If you should have any questions regarding this request, please feel free to contact me at 263-7677. ORIGINAL Dan Williamson Drilling Manager RECEIVED DEC l i) O ?A STATE OF ALASKAM ALASKA ND GAS CONSERVATION MISSION 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: X Perforate: X Other: '~'-Isolate , 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: X 108' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: PO BOX 190247 Anchorage, Alaska 99519 Service: Trading Bay Unit 4. Location of well at surface Leg A-2, Cond. 7, Dolly Varden Platform 8. Well number 752' FSL, 1,138' FWL, Sec. 6-8N-13W-SM D-46 At top of productive interval 9. Permit number 2,001' FNL, 667' FWL, Sec. 8-8N-13W-SM 89-61 191-387 At effective depth 10. APl number 50-733-20165-01 At total depth 11. Field/Pool 2,245' FNL, 1,989' FWL Sec. 8-8N-13W-SM Hemlock 12. Present well condition summary Total depth: measured 12,493' feet Plugs (measured) Cement Plug @ 11,966' true vertical 10,034' feet Effective depth: measured 12,355' feet Junk (measured) None true vertical 9,942' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 803' 20" 1,400 sx 803' 803' Surface 4,944' 13-3/8" 1,454 sx 4,944' 3,738' Intermediate 10,933' 9-5/8" 1,227 sx 10,933' 8,797' LinerPr°ducti°n 12,490' 7" 885sx 12,490' REEEII~4~D" Perforation depth: measured truevertica, See Attached ORIGINAL .,c Tubing (size, grade, and measured depth) 3-1/2" N-80 @ 11,559' ~~.~ ~ll~l~ Packers and SSSV (type and measured depth) Brown 3H Perm Packer @ 11,501', Otis TRSV, flapper type FMX @~2~1.1~ 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 2/1/00 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby,~,~rtify that the,,fore.,goir~g is true and correct to the best of my knowledge. Signed~~/~j~j~~(,~)'anWilliamson Title: Drilling Manager Date:/~--2~¢ ' ~ - FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApprovaLNo. Plug integrity.~ BOP Test ~¢~ Location clearanceI Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNED-BY Robert N. Christenson / Approved by order of the Commissioner Commissioner Date / Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Alaska Business Unit Dolly Varden Platform Well No. D-46 UNOCAL ) 1 RU E-Line. 2 RIH. 3 Set 3~$' 9:2#:Bfidgeptug intailP~pe~+/-l'l~535' 4 POOH. 5 Pressure test to 1,500 psi. Sever Tubing/Circulate Well Clean 6 RIH. 7 Chemical Cut tubing at +/-11,475' 8 POOH. 9 Rig Down E-line. 10 Circulate well clean with Filtered Inlet Water. Pull 11 12 13 14 15 16 17 18 19 Completion Install BPV. ND Tree. NU Riser, DBL Gate, Hydril and valves. Install Two Way Check, Test Joint. Test BOPE to 3,000 psi. Pull Test Joint, Two Way Check. RU to Pull Completion. MU LD Joint., Back Out Lock Down Screws. POOH standing back 3-1/2" Tubing . Scraper Run 20 MU Mill and Scaper BHA. 21 RIH to 11,470'. 22 Circulate well to 3% KC1 Completion Fluid. 23 POOI-I/LD 3-1/2" Tubing. Set Production Packer 24 RU E-Line. 25 RII-I and Set Permanent Packer at 11,050'. 26 POOH with E-Line 27 RD E-Line. Page 1 RECEIVED DEC P...B Unocal Alaska Business Unit Dolly Varden Platform Well No. D-46 UNOCAL ) Run Completion 28 PU Packer/Completion. 29 RIH with 3-1/2" Completion to 11,050'. 30 MU SSSV/Control Line. 31 RIH banding control line. 32 Space Out. 33 MU Tubing Hanger - Land. 34 Pressure test annulus. 35 LD Landing Joint, Set BPV. 36 Nipple down BOPE. Perforate Pe~f0rate G~Zone~Bcnches 2, 3, 4. RECEIVED Page 2 Subject: Dolly Varden 46 Date: Thu, 30 Dec 1999 10:36:25 -0800 From: "Brandenburg, 'lqm C-Contract" <brandenburgt@unocal.com> To: "'tom_maunder@admin.state.ak. us"' <tom_maunder@admin.state.ak. us> CC: "Williamson, Dan R" <williamsond@Orion. Unocal.com>, "Martin, J. Hal" <martinh@Orion. Unocal.com>, "Cole, David A" <dcole@Orion. Unocal.com> Mr. Maunder, As a follow up to our telephone conversation yesterday, Unocal intends to isolate the Hemlock in Dolly Varden Well 46 in order to preserve future Hemlock utility of the lower wellbore. The proposed completion will permit future reworking of the well to allow for access to the Hemlock. If you have further questions, please do not hesitate to call me at 263-7657. Tim ; I of I 12/30/99 9:57 AM RKB = 38.80' 6 7 8 9 10 11 12 B C D-46 Sclnn 4-04-90 doc.doc ~ B-1 ~ B-2 B-3 B-4 SIZE WT Actual Completion 4/4/90 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM, 9-5/8" 43.5 47 53.5 7" 29 29 J-55 19.124 Surface 803' K-55 BTC 12.5l Surface 2,999' N-80 BTC 8.755 Surface 752' N-80 BTC 8.681 752' 6.068' S-95 BTC 8~535 6,068' 10,933' N-80 BTC 6.184 Surface 11,756 P-110 BTC 6.184 1L756 12,490' Tubing 3~1/2' 9.2 N~80 BTC 11,482' JEWELRY DETAIL NO_. Depth OD ID Item I 38.80' CIW, 11" x 4", 5M, DCB Single Tubing Hanger 1/2" EUE Lift x 4-1/2" Butt Suspension 2 46' Crossover, 4q/2" Buttress x 3-1/2" Buttress 3 292' 5.620 2.813 Otis Series t0 TRSV, 'FMX' SSSV (2.813 I.D.), Locked Open 4/94. Baker 'XV' WLR SSSV Installed (1.56" LDO 4 2,508' 5.750 2.992 Camco, 3~I/2" 'MMG' II, t-t/2" 4,486' 5.750 2.992 Camco, 3-1/2" 'MMG' I1, 1-1/2" 5,495' 5.750 2.992 Cameo, 3q/2" 'MMG' II, 1-1/2" 6,226' 5.750 2.992 Camco, 3-1/2" 'MMG' II, I-t/2" 6,867' 5.750 2.992 Camco, 3~1/2' 'MMG' II, I-1/2' 7,504' 5.750 2.992 Camco, 3-1/2" 'MMG' i1, I-1/2" 8,107' 5.750 2.992 Camco, 3-l/2" 'MMG' II, 1-1/2" 8,680' 5.750 2.992 Camco, 3-1/2" 'MMG' II. lq/2' 9,277' 5.750 2.992 Camco, 3-1/2' 'MMG' 1i, I-1/2" 9,731' 5.750 2.992 Camco, 3-i/2" 'MMG' II, 1-1/2" 10,186' 5.750 2.992 Camco, 3-1/2" 'MMG' II, 1-1/2" 10,612' 5.750 2.992 Camco, 3-l/2" 'MMG' II, 1-1/2' 11,037' 5.750 2.992 Camco, 3-1/2" 'MMG' II, I-1/2" 11,425' 5.750 2.992 Camco, 3-1/2" 'MMG' II, 1-1/2" 5 11,482' 4.000 3.000 PBR Seal Assembly, Baker~ (I 5') (Not Sheared) 6 11,48I' 5.625 4.000 PBR, Baker, 80-40 (18.43') 7 11,500' 4.250 3.250 Anchor 'CH', Brown 8 I 1,501' 5.843 3.500 Packer, Brown. 7", '3H~ Pem~. 9 11,505' 4.500 3.937 Mill Out Extension, Baker (5.52' Long) 10 11,51 I' 5.000 2.992 Crossover, 4-1/2" LTC Box x 3-1/2" Butt Pin 11 I1;527' 4.250 2.813 Ors, X N~pple, 2.813 A. Tri State Casing Patch from 5,290 -5,_92 B, 1-1/2TM Gas Lift Valve C. Plugged Back to 11,962, iwo Thru-Tubing Bridge Plugs PERFORATION HISTORY I Interval Accum. Date !- Zone Top Btm Amt spf ~Present Condition 1/3/91 i tl,926' I 11,960' 34' 4 5/2/91 B~ ll,765' 111795'_ 30' [ 4 8/25/90 B2~ 12,031' 12,072' [ 41' [ 4 CementPlugged PBTD = 11,962' TD = 12,493' MAX HOLE ANGLE = 53~ ~ 3,550' DRAWN BY: tcb 38.80' 5 6 7 8 A D-46 Schm Proposed V,doc G-2 G-3 G-4 B-1 B-2 B-3 -- B-4 SIZE WT '¥arden :No. 46 Proposed CASING AND TUBING DETAIL GRADE CONN ID TOP BTM, 20" 94 J-55 !9.124 Surthce 803t 13-3/8' 61 1(.-55 BTC 12.51 Surlhce 2,999' %5/8" 43.5 N-80 BFC 82755 Surface 752' 47 N-80 BTC 8.681 752' 6,068' 53.5 S-95 [gTC 8.535 6,068' 10,933' T' 29 N~80 BTC 6184 Smqiice 11,756 29 P-II0 BTC 6A84 I1,756 I2,490' Tubing 34/2" 9.2 L-80 BTC 11,080' JEWELRY DETAIL 1/2" EUE [.itt x 4-1/2' Butt Suspension 2 46' Crossover, 4-I/2" Buttress x 3- I/2" Buttress 3 300' SSSV GLM, 3-1/2", 1-UT'Valve £dM,3-1/2 , t-1/2 Valve G[ M, 3-1/2', I d/2" Valve 5 Locator Seal Assembly 6 11,080~ Packer, 7" Permanent 7 Seal Bore Extension 8 Otis, 'X' Nipple, 2813 9 Wireline Entry Guide Tri State Casing Patch from 5,290'-5,292' A. Tubing cut at -t/~l 1,475' B Isolation Retainer at t4- 1 t,535' PERFORATION HISTORY [ i Interval Accmn. Date Zone Top Btm ] Amt spf --'] lh-e'-'--~ent Condition G-2 11,104' 1 t340' 36' 6' Proposed G~3 11,202' I 11,228' 26* 6' Proposed (3-4 [II,272' II,291' I 19' 6' [Proposed I/3/91 ~ ~ B-1 I 1,678' 11,697' 19' 8 Proposed Isolation 11/23/91 ~ ~ I~TM 1 L714' 11,744' 30' 8 I Proposed Isolation ' 52/~5i''-' ; I 1,765' 11,795' 30' 3 ~ Proposed Isolation a~3 11,896'I 11,927' 31'i 4 Proposed Isolation 1/3/9I I~-fi~--! / [,960' 34'I 4 Proposed Isolation 5/2/91 i'~ [ 11,7 5 i * 1,795' I 30' i 4 Proposed Isolation 8/25/90 I B-4 1 --,( 31 [ -,072 41 4 [Cement Plugged 6/26/90 B-5 I-,147 [ -,I 81 34 4 Plugged PBTD Proposed 11,470 TD= 12,493' MAX HOLE ANGLE = 53° ~ 3,550' DKAWN BY: tcb Dolly Varden D-46 Actual Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments H B-1 11,678' 11,697' 9,392' 9,414' 19' HB-2 11,714' 11,744' 9,428' 9,453' 30' HB-2 11,765' 11,795' 9,471' 9,496' 30' HB-3 11,896' 11,960' 9,583' 9,637' 64' HB-4 12,031' 12,072' 9,696' 9,720' 41' Plugged HB-5 12,147' 12,181' 9,786' 9,813' 34' Plugged 218' RECEIVED DEC 28 199~ Nast~ 0111 Gas Cone. ComPri Anchorage © © Dolly Varden D-46 Proposed Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments G-2 11,104' 11,140' 8,936' 8,965' 36' Proposed G-3 11,202' 11,228' 9,016' 9,038' 26' Proposed G-4 11,272' 11,291' 9,065' 9,090' 19' Proposed HB-1 11,678' 11,697' 9,392' 9,414' 19' Proposed ,Isolated HB-2 11,714' 11,744' 9,428' 9,453' 30' Proposed Isolated HB-2 11,765' 11,795' 9,471' 9,496' 30' Proposed Isolated HB-3 11,896' 11,960' 9,583' 9,637' 64' Proposed Isolated HB-4 12,031' 12,072' 9,696' 9,720' 41' Plugged H B-5 12,147' 12,181' 9,786' 9,813' 34' Plugged 299' RECEIVED DEC '28 1,99~ Naslm Oil & Gas Coner. Cem~ Anchorage 20' 18'-7" 17'-6" RIG FLOOR BOTTOM ROTARY TABLE BTM RT BEAM 17' BOTTOM TROLLEY BEAM TO TRIP TANK //~ PITCHER NIPPLE ~ TO FLOW LINE RISER I I 13-5/8" OK r IM ANNULUR PREVENTE~ I I I , I 13-.5/8" SM DOUBLE GATE BOP 1KILL () TOP PIPE CELLAR FLOOR DRILL DECK FLOOR ["~ BLIND , 5M CROSSOVER SPOOL RECEIVED DEC P8 1990 Nalia 011 & Gas Gon& Comml,~lo. Anchorage DOLLY VARDEN PLATFORM COOK INLET, ALASKA ..... ABTC~R j GC)N rl~. dObl N~' DOLLY VARDEN PLATFORM BLOW OUT PREVENTER D-46 UNOCAL ) D-DY-015 1 OF1 To Production Header: 1502 Weco Threaded Connection x 2" 7,500 psi flexible line UNOCAL Portable 5M psi Choke Manifold To Crown Vent Line: 1502 Weco Threaded Connection x 2" 7,500 psi flexible line Choke Choke All valves are National 5M psi manual ball valves Manual Choke From BOP Choke line: 2" 7,500 psi flexible line with Baker-locked 4-1/16" 5M psi flange bolted to inlet AND GAS CONSERVATION' COMI~ION REPORT OF SUNDRY WELL OPERATIONS / 1. Operations Performed: OperatiOns Shutdown__ Stimulate__ Plugging__ Perforate Pull Tubing Alter Casing Repair Well Other 2. Name of Operator " I 5. Type of Well: 6' Datum elevation (DF or KB) UNOCAL (Marathon Oil cOmpany - Sub Operator) I De. vel.oprn, ent ~ 106° KB above MSL ...... ....... ' I ,- xp,ora[ory 3. Address I Stratigraphic "-' 7. Unit or Property name P.O. Box 196247 Anchomee, AK 99519 I Service '--' Trading Bay Unit 4. Location of well at"surface ~ "L;~ 'A-2'cond. #7;~OollY Varde'n 151atform "~ 8. Well number feet 752' FSL, 1,138' FWL, Sec. 6-8N-13W-SM At top of productive interval 2,001' FNL, 667' FWL, Sec. 8-8N-13W-SM At effective depth At total depth 2,117' FNL, Sec. 8,SN-13W-SM 12. Present well condition summary Total Depth: measured 1 2,493' true vertical 1 0,034' feet feet RECEIVED MAR - 4 1994 Oil & Gas Cons. Commission ' Anch0mge Plugs (measured) D-46 9. Permit number/approval number 89-61 / 91-387 10. APl number 50- 733-20165-01 '1"1. Field/Pool Hemlock Cmt plug {~ 11,966' 13. Effective depth: measured 1 2,355' true vertical 9,942' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length feet feet Junk (measured) None Size Cemented Measured depth 803' 20" 1,400 sx 803' 4,944' 13-3/8" 1,454 sx 4,944' 10,933' 9-518" 1,227 sx 10,933' 12,490' Tubing (size, grade, and measured depth) 3.5", 9.2#, N-80 Butt Tbg @ 11,559' Packers and SSSV (type and measured depth) 7" 885 sx 12,410' B-1 11,678' - 11,697' MD 9,400' - 9,415' TVD B-2 11,714'- 11,744' MD 9,429'- 9,454' TVD B-3 11,896' - 11,960' MD 9,584' - 9,638' TVD Brown 3H Perm Pkr w/Baker millout ext (~, 11,501'; Otis 3.5" Series 10 TRSV, flapper type FMX (~ 292' Stimulation or cement squeeze summary True vertical depth 803' 3,738' Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injecti0n..Data Oil-Bbl. Gas-Mcr Water-Bbl. Casing Pressure Tubing Pressure Prior to well operation 11/21/91 65 / 94 402 1200 Subsequent to operation 11/24/91 107 / 157 543 1180 150 130 15. Attachments 116' Status of well classification as: Copies of Log and Surveys run __ Daily Report of Well Operations X Oil X Gas 17. I hereby g,ertify that the foregoing is.true and correct to the best of my knowledge Suspended Service Form 10-404 Rev 0~/15/88 SUBMIT IN DUPLICA~, DA~LY HELL OPERATIONS D-46 11/23/91 Held safety meetincj. Pressure tested 8OPE & lub to 2800 psi° Test cjoodo Established communications blackout. RIH w/ 2-1/8" strip, 4SPF, 0° phased. Flowed well to obtain underbalance and perforated 11,714' - 11,744' DIL. RD. Return well to production. RECEIVED MAR - 4 1994 Alaska Oil & Gas Cons. Commission Anchorage H:\wp\WELLOPS\D46 S~'~O STATE OF ALASKA ~ ALA IL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS I12 Operations Performed: Operations Shutdown Stimulate Plugging Pull Tubing A~er Casing ~epair Well Name of Operator I 5. Type of W~II: I 3'. UNOCAL (Marathon Oil Company-Sub-Operator) De..v~e.l?~p.~m~e~n..t,X Address I Stratig raphic -'- P. O. Box 190247 Anchorage, AK 99519 I Service , Perforate Other 4. Location of well at surface 752' FSL, 1,138' FWL, Sec. 6-8N-13W-SM At top of productive interval 2,001' FNL, 667' FWL, Sec. 8-8N-13W-SM At effective depth At total depth 2,117' FNL, Sec, 8-8N-13W-SM 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 Leg A-2 Cond. #7, Dolly Varden Platform 12,493' 10,034' 12,355' 9,942' Length 803' 4,944' 10,933' 12,490' feet feet feet feet RECEIVED 13. Tubing (size, grade, and measured depth) 3.5", 9.2#, N-80 Butt Tbg @ 11,559' Packers and SSSV (type and measured depth) MAR - 4- 1994 0il & Gas Cons. Commission Plugs (measured) 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-46 9. Permit number/approval number 89-61 / 91-162 10. APl number 50- 733-20165-01 11. Field/Pool Hemlock Cmt plug ~ 11,966' Junk (measured) None Size Cemented Measured depth 20" 1,400 sx 803' 13-3/8" 1,454 sx 4,944' 9-5/8" 1,227 sx 10,933' 7" 885 sx 12,410' B-1 11,678' - 11,697' MD 9,400' - 9,415' TVD B-2 11,714' - 11,744' MD 9,429' - 9,454' TVD B-3 11,896' - 11,960' MD 9,584' - 9,638' TVD True vertical depth 803' 3,738' Brown 3H Perm Pkr w/Baker millout ext (~ 11,501'; Otis 3.5" Series 10 TRSV, flapper type FMX ~ 292' Stimulation or cement squeeze summary Intervals treated (measured) feet Treatment description including volumes used and final pressure 14. Representative Daily Averaae Production or Injection Data Oil-Bbl. Gas-Mcf Water-Bbl. Casing Pressure Prior to well operation 5116/91 94 / 34 319 1130 Subsequent to operation 5/28/91 195 ' 25 3001 1210 Tubing Pressure 180 170 15. Attachments J 16. Status of well classification as: I Copies of Log and Surveys run Daily Report of Well Operations X Oil X Gas 17. I hereby~fy th~.he :or~:~ true a,~o~of my knowledg.~ Signed /V~, {,~ ./,~,.a-~aw,,,,-(.,,.~,A./ Title Suspended Service , , , ~'~MIT IN DUPLICATe, Form 10-404 Rev 06/15/88 © © DAILY HELL OPERATIONS D-46 5/21/91 Held safety meeting. Pressure tested BOPE & lub to 2500 psi. Test good. Established communications blackout. RIH w/ 2-1/8" strip, 6SPF, 0° phased. Flowed well to obtain underbalance and perforated 11,714' - 11,744' DIL. RD. Return well to production. RECEIVED MAR - 4 1994 Alaska Oil & Gas Cons. Commission Anchorage H:\wp\WELLOPS\D46 ALASKA OIL AND GAS CONSERVATION COMMISSION 4/? WALTER J. HICKEL, GOVERNOFI 3001 PORCUPINE DRIVE ANCHORAGE, AI.A~KA 99501-,3192 PHONE: (907) 27~-14,33 TELECOPY: (907) 276.7542 July 14, 1993 Mr. G. Russell Schmidt Drilling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Schmidt, , · In conducting an audit of well files I have found a number of wells containing approved ~C~Ition of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. To be in compliance with AS'20 AAC 25.280(d) of the RegUlations, the Form 10-404 is required to be filed within 30 days following completion of work. In previous telephone conVersa~J~-ns concerning 'the subject, it had been._explained to me that either ARCO or Marathon had been th~operator on the majority of the work proposed; however, it iS the feeling of the Commission that if the work was completed, it is UNOCAL's responsibility to see that the appropriate paperwork be filed ina timely manner inasmuch as UIqOCAL is the operator of the field and UNOCAL personnel signed the Application' of Sundry Approval forms. Your assistance in supplying us with the apprOpriate forms and in helping resolVe t.his problem.in the future will be appreciated. We would also appreciate notification of any canceled Work so that the corresponding Application. on . : . file can-be marked accordingly., · . .. ... Sincerely, · · Statistical Technician ~) p~inled mt reGy~led p~per b y ~.~"/~. Well Permit No. No. D-4 82-41 D-5RD 80-65 D-26 74-9 D-27 75-24 D-40 82-83 D-42 83-53 D-46 89-61 Approval Date & No. 3-1-91, 91-060 5-31-91, 91-163 7-2-91, 91-188 11-22-91, 91-353 9-2-91, 91-189 9-20-91, 91-284 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 5-31-91, 91-160 7-2-91, 91-190 5-31-91, 91-162 12-11-91, 91-387 Trading Bay Unit Description Perforate 2-91 Perforate 5-91 Workove~ 4=91 Perforate 11-91 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&$4 10-3-91 Perf 5-91 Scale Cleanout 6-20-91 Perf 5-91 Reperf HB-2 11-91 10-403 Signed By G. Bush G. Bush G. Bush G. Bush G. Bush'. G. Bush G. Bush G. Bush G. Bush · G. Bush G-5 67-71 G-6 82-33 3/15-91, 91-086' 10-30-91, 91-325 4-21-92, 92-093 Short & long inj. profile (If work was completed the 10-403 required a 18-407, Completion, Recompletion. report for this · Perf. 10-19-91 Perf 4-92 . G. Bush -_ G. Bush G. Bush G-17 G-19 G-21 G-27 78-3 69-17 72-42 · 78-70 G-31 69-72 K-1 67-65 K-2RD 78-38 K-3 80-144 K-9 68-38 11-1-91, 912331 11-10-92, 92-238 · 4-21192, .92-094 '6-17-93, 93-154 · 4-21'92, 92-95 i-6-93, 92-203 · 3-21-91, 91-95 2-9-90, 90-082 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 2-9-90, 90-081 11-14-89, 9-987 Perforate G. Bush Temp. log 10-15-92 .. G. Bush Perf 4-92 Coil tubing cleanout Perforate Convert to inj. G, Bush" ' '~'!" ' RJ'Schmidt R S chmidt Production profile G. Bush Perforate 2/90 R. Roberts Perf., cement squeeze Stim, p. tubing, perf. 6-90 Perforate 6-91 R. Roberts G. Bush G. Bush Perforate 2/90 R. Roberts Repair well, p. tubing, stimulate, perforate R. Roberts ALASKA OILANDGASCONSERVATION COMMISSION e i t G I N A t APPLICATION FOR SUNDRY APPROVAL: _ 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program 2. Name of Operato. r J 5. Type of Well: UNOCAL (Marathon Oil Co - Sub Operat~3r) DevelopmentL~Exploratory / Stratigraphic __ 3. Address Service P. 0. Box 190247 Anchorage, AK 995[].9 Operation shutdown __ Re. enter suspended well __ Reperforate Plugging ~ Time extension __ Stimulate ..._ Pull tubing ~ Variance ~ Perforate ~ Other X H B- 2 6. Datum elevation (DF or KB) ~ 106' KB above MSL 4. Location of well at surface Leg A-2 Cond. #7, Dolly Varden 752' FSL, 1,138' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 2,001' FNL, 667' FWL, Sec. 8 -8N- 13W- SH At effective depth P1 at form Attot~.l,d~]~, FNL, 2,117' FWL, Sec. 8 8N- 13W- SM 12,493 ' feet Plugs (measured) 10,034' feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 12,355 ' feet Junk (measured) true vertical 9,942 ' feet casi ng Length Size Cemented Structural Conductor 803' 20" 1,400 sx Sudace 4,944' 13-3/8" 1,454 sx Intermediate 10,933' 9-5/8" 1,227 sx feet 7. Unit or Property name Trading Bay Unit 8. Well number D-46 9. Permit number ~61~ 10. APl number 5o- 733-20165-01 11. Fi. etd/P.o¢ M~Arthur River rleme - Hemlock RE6EiVED DEC - $1991 Alaska 0il & Gas Cons. Comr~i$$len Anc, lt0rage Measured depth True vertica depth 803' 803' 4,944' 3,738' 10,933' Production Liner 12,490' 7" 885 s x 12,410' Perforation depth: measured true vertical Tubing (s~ze, grade, and measured depth) 3.5", 9.2#, N-80 Butt Tbg Packers and SSSV (type and measured depth) 13. Attachments 1, & B-1 11,678' - 11,697' MD 9,400' - 9,415' TVD B-2 11,714' - 11,744' MD 9,429' - 9,454' TVD B-3 11,896' - 11,960' MD 9,584' - 9,638' TVD 11,559' Brown 3H Perm Pkr w/ Baker mi 1 lout ext Otis 3.5" Seriew 10 TRSV, flapper type ~ 11,501' FMX e 292' Detailed operations program __ BOP sketch .X.- 2, Description summary of proposal _Z.. 3 Lonnie Smith 11/22/91 Date approvedi N ale of approver 15. Status of well classification as: Gas m Suspended 14. Estimated date for commencing operation 11/22/91 16. If proposal was verbally approved Oil X Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed G c~..~.-,, ~ (~ ,-.,,..c~',._ Title . ~,.c~, ~¢.._~_.. FOR COMMIS~N USE ONLY Conditions of ~rova~otify Commission so representative may ~tness Plug integrity ~ BOP Test ~ ~ation clearance ~ M~hanical Integri~ Test ~ Subsequent form required 10- ~- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the commission Form 10-403 Rev 06/15/88 Attachment # 1 ~*-~ Dolly Varden Well D-46 Reperforate HB #2 Procedure 1) 2) 3) RU E-LINE UNIT. HOOK UP PLATFORM COMMUNICATION SYSTEM IN UNIT. PRESSURE TEST LUBRICATOR AND BOPE TO 2500 PSI. DISCONNECT SCSSV FROM MANIFOLD AND LOCK OPEN SCSSV WITH AUXILIARY PUMP ON PLATFORM. REGULATE PRESSURE BETWEEN 3700 - 4000 PSI. ENSURE CONTROL LINE PRESSURE DOES NOT BLEED OFF. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT. RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE 1000' WHEN POOH. RIH WITH 30' 2-1/2" HC GUN, 4 SPF, 180-PHASE, AND PERFORATE THE FOLLOWING INTERVAL UNDERBALANCE. RUN BENCH INTERVAL (DIL) FOOTAGE i HB-2 11,714'-11,744' 30 4) RD E-LINE UNIT. FLOW WELL TO GROUP SEPARATOR FOR 12-24 HOURS OBTAINING WC'S EVERY FOUR HOURS. MONITOR SCREEN FOR PERFORATING DEBRIS. OBTAIN A SERIES OF 24-HOUR TESTS POST CLEAN-UP. \oe60\61.doc RB(E IV£D DEC - 6 1991 Alaska Oil & Gas Cons. ~,~horage Attachment #2 MARATHDN DI~DMPANY TRADING BAY UNIT WELL D-46 Completed 8/P5/90 All meosurements ore RKB to top oF equipment. 40' C:meron DCB Tbg Hngr 4.5' 8RD RUE Top x 4,5' Butt 29P' Otis Series 10 TRSV, Flapper Type FMX, w/2.813' profile, 0.25' control line. Comoletlon Strlno: 0'-11,482' 3,5', 9,2~, N-80 ~u~ 803' ~0', 94~, J-55 Csg, Sqz PerFs 10,795'-800' 8999' 13-3/8', 62#, K-55 Csg. All gos liFt mandrels ore 3.5' Camco MMG I[ w/1.5' pockets. DeDth Valve 8508' 1 4486' 2 5495' 3 6226' 4 6867' 5 7504' G 8107' 7 8680' 8 9277' 9 9731' 10 10,186' 11 10,612' 12 11,037' 13 11,425' 14 TyDe L:tch Altech RK Altech Daniels RK Port Size 16/64 16/64 16/64 20/64 20/64 24/64 24/64 24/64 28/64 28/64 28/64 28/64 28/64 28/64 B-1 B-2 B-3 10,933' 11,482' 11,500' 11,501' 11,511' 11,527' 11,559' Zone B-1 B-4 B-5 9-5/8', 43,5, 47, & 53,5#, N-80 Csg w/9-5/8' Tristate csg patch From 5290'-5292', PBR w/Seol ossy, (15' Stroke>, Seats not sheared out oF PBR. K-Anchor Latch, Brown 3H Perm Pkr w/Baker miHout ext. X/O 4.5' LTC Box x 3,5' Butt Pin. Otis 3.5' X-Nipple (2,813' ID>, Shear-out Sub (3.00' III). PERFDRATIDN~ In~ervol F__~t SPF Phasing 11,678'-1L697' 19' 4 O' 11,714'-11,744' 30' 4 O' 11,896'-11,960' 64' 4 O' 12,031'-12,072' 41' Cmt plugged 12,147'-12,181' 34' Cmt plugged B-4 B-5 Top oF Chi e 11,966' Top o¢ Csg Plug @ 1~,11~' Top o¢ Cmt ~ 1~,1~7' ToD oF Cso PLug @ 1~14~' 12,490' 7', 29#, N-BO Csg. TD e 12,493' Revision ]:)ate, 7/31/91 Revised By: JDM/evo Previous Revislom Nero WeLL . At.tachment.,#3 - . Wireline Lubricator w/Associated BOPE - GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP · 4'~lz.l:S~.-;ooo ..~ C.ISTMAS TREE' -- POSITIVE CHOKE DEO - 6 1991 AIas~ Oil & Gas (;OHS. Gomm'~,~ 'Anchom;le ---- 2' 5000 psi _-- 2' 3000 13 3/8' CASING · ~,i-. ;~ STATE OF ALASKA '~ ALASKA OIL AND GASCONSERVATION COMMISSION APPLICATION .FOR SUNDRY APPROVALS 1. Type of Request: Change approved program __ Pull tubing Operation shutdown __ Re.enter suspended well __ Plugging __ Time extens,on __ Stimulate __ Variance __ Pedorate X. Other Abandon __ Suspend __ Alter casing __ Repair well 2. Name of Operator UNOCAL (Marathon 3. Address P. 0. Box 190247 4. Location of well at sudace 752' FSL, 1,138' At top of productive interval 2,001' FNL, 667' At effective depth · ! 5. Type of Well: 0il Co- SUb 0Peraflor) Development__X "-r Exploratory __ Anchorage, AK g95~19 StratigraphiCservice____ Leg A-2 Cond. //7, Doily Varden Platform FWL, Sec. 6- 8N- 13W- SM FWL, Sec. 8 -8N- 13W- SM At total dep_th 2,395' FNL, 2,117' FWL, Sec. 8 8N - 13W - SM 6. Datum elevation (DF or KB) 106' KB above NSL feet 7. Unit or Property name Trading Ba,y Unit 8. Well number D-4~ ..... 9. Permit number 89-61 10. ~,PI number ' 5o- 73:3-20165-01 11. Field/Pool MCAt4'r,~ur 'R'i ve'r Field - Hemlock 12. Present well condition summary Total depth: measured true vertical 12,493 ' feet ' Plugs (measured) 10,034' feet Effective depth: measured true vertical 12,355 ' feet Junk (measured) 9,942' feet Casing Length Structural Conductor 803 ' Sudace 4,944 ' Intermediate 10,933 ' Production Liner 12,490' Perforation depth: measured Size Cemented 20" 1,400 sx 13-3/8" 1,454 sx 9-5/8" 1,227 sx Measured depth True vertical depth 803' 803' 4, g44' 3,738' 10,933' 7" 885 sx 12,410' B-1 11,678' - true vertical B-2 11,714' - B-3 11,896' - Tubing (size, grade, and measured depth) 3.5", 9.2//, N-80 Butt Tbg e. 11,559' Packers and SSSV (type and measured depth) Brown 3H Perm Pkr Ot i s Sari ew 13'. Attachments Description sum'marY of proposal ~ #1, 2, and 3 11,697'MD 9,400' - 9,415' TVD 11,744'MD 9,429' - 9,454' TVD 11,960'MD 9,584' - 9,638' TVD w/ Baker mi 1lout ext e 11,501' 10 TRSV, flapper type FMX ~ 292' 85II Detailed operations pr0~ran~ m BOP sketch X 15, Status of well classification ~ Ga __ 1991 Alaska Oil & g~.~ C0.n.S' Commission anohorage Date. ~'- 13 -<=) ~ 14. Estimated date for commencing operation 5/91 16. If propo, sal was verbal!y approved Oil X Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMM,I$S1ON USE ONLY Conditions of a~l;Jroval-:"lq'otify Commission so representative maY witness Plug integrity __ BOP Test m Location clearance ~ z~,~ _z~.. Mechanical Integrity Test m Subsequent form required 10-,..'~.~M-C~NE0 Approvea Copy Returned. 'L0t, lt, ilE C. Approved by order of the Commission ~ ' ~ Commissioner F;;m'10'403 Re"v 06115/88 ' ' J APproval NO.?~ .-/~, ,,~ SUBMIT IN TRIPLICATE Attachment 'gl WELL D-46 PROCEDURE 1) OBTAIN A 24-HOUR WELL TEST WITH A MINIMUM OF FOUR WC'S. 2) SKID RIG #77 OVER D-46. 3} RU E-LINE UNIT. HOOK UP PLATFORM COMMUNICATION SYSTEM IN UNIT. PRESSURE TEST LUBRICATOR AND BOPE TO 2500 PSI. 4) DISCONNECT SCSSV FROM MANIFOLD AND LOCK OPEN SCSSV WITH AUXILIARY PUMP ON PLATFORM. REGULATE PRESSURE BETWEEN 3700 - 4000 PSI. ENSURE CONTROL LINE PRESSURE DOES NOT BLEED OFF. SI WELL TO RIH & POOH. 5} RIH WITH 30' 2-1/8" STRIP GUN, 6 SPF, O-PHASE, AND,PERFORATE THE FOLLOWING INTERVAL UNDERBALANCE. RUN BENCH INTERVAL {DIL) FOOTAGE I HB-2 11,714'-11,744' 30' 6) RD E-LINE UNIT. FLOW WELL TO GROUP SEPARATOR FOR 12-24 HOURS OBTAINING WC'S EVERY FOUR HOURS. MONITOR SCREEN FOR PERFORATING DEBRIS. OBTAIN A SERIES OF 24-HOUR TESTS POST CLEAN-UP. \docs\oe57\21. doc RECEIVEb Completed 8/25/90 MARATHON OIL CDMP~,N~.'jii:/ TRADING BAY UNI~'::~'??~ WELL D-46 Ail MeasureMen.ts ore RKB to .top oF equ)pment. 40' Cameron DCB Tb9 H.n,~:,,.?)~, 8RD EUlr Top x 4.5' Butt 898' O.tis Series 10 TRSV, ~Fio.pper Type FMX, w/8.813' profile, 0.25: con.trol line. · . Comoletign Strln~ 803' eot 94~, J-55 Csg. . Sqz PerFs 1~795'-800' 8999' Att .. .. 13-3/8; 62#, K-55 Csg. gas {;Fl mandrels are 3.5' Camco MMG II w/1.5' pockets. De_D.th Valve 2508' 1 4486' 8 5495' 3 6226' 4 6867' 5 7504' 6 8107' 7 8680' 8 9877' 9 9731' 10 10,186' 11 10,618' 12 11,037' 13 11,425' 14 ~ Loich Altech RK Abtech Daniel; I DanieLs RK por~ Size 16/64 16/64 16/64 20/64 80/64 24/64 84/64 84/64 88/64 28/64 88/64 88/64 88/64 88/64 B-I 10,933' 11,488' IL500' 1L501' IL511' 1L587' 11,559' Zone B-1 B-5 9-5/8~ 43.~ 47, & 53.5#, N-80 Cig w/9-5/8' Trlstote cs9 porch ~rom 5890'-5298'. PBR w/Sect ossy. (15' S.troke). ou~ of PBR. K-Anchor La.tch. Brown 3H Perm Pkr w/Baker m;llOU.t ext. X/O 4,5' LTC Box x 3,5' Bu.t~ Pan. Otis 3.5' X-Nipple (8.813' ID). She~r-ou.t Sub (3.00' ID). Seels not she0~rect RECEIVED MA y 0 t991 Alaska 0il & (;as Cons. Con?mission Anch°rage In.tervol Irt SPF Ph~s;ng 11,678'-1L697' 19' 4 O' 11,714'-11,744' 30' 4 O' 11,896'-11,960' 64' 4 O' 12,031'-12,072' 41' Cmt ptugged 12,147'-12,181' 34' Cml plugged Dote 7/~7 1/11/91 1/4/91 12131/90 12/31/90 B-4 B-5 T~p o¢ Cml e 12,076' T~ of' Crag PLug e l~tl~'' T~p o¢ Cml ! IE, IET' Top o¢ C$O Ptu9 e 1~,148' 1~490' 7', 29#, N-80 Ceo. TD @ 1~493' Revl;;on Date, 1t/90 Revised By, SSL/ne? Reason, New Welt Previous Revision. None 'DOLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP .i · GREASE HEAD (Hydraulically Activated) LUBRICATOR -4'~1/.-'1:6~. 5000 CHISTMAS TREE' POSITIVE CHOKE RECEIVED MA y 3 0 t99~ Alaska Oil & ~as Cons. Commission Anchorage ---- 2' 5000 ...- 2' 3000 · 13 3/8' CASING · ALA~,~OIL AND GAS CONSERVATION-~,,a'OM MISSION" ~/1'~" - "':-~ WELL COMPLETION OR RECOMPLETION REPORT ~~t~I~,~ 1. Status of Well Classification of Service Well OIl,x[] GAS [] SUSPENDED [] ABANDONED [] SERVICE 2. Name of OperatOr ' - ' " 7. Permit NUmber [C)CAI'ION~ UNOCAL (Marathon 0il Co. Sub-operator) f' VERIFIED 89-61 2. Address' " ,. ~ B. APl Number P. 0. Box 190247 Anchorage, AK 99519 B.~ q 5o- 733-20165-01 4. Locat~o, ofwe, atsurface Leg A-2, Cond. //6 Dol.ly Varden~ 9. Unit or Leese Name At Top Producing lntervai 10. Weli Number 2,001' FNL, 667' FWL, Sec. 8 8N-13W-SM .f ._d-.~.Z~I D-46 ..... 2,395' FNL, 2,117' FWL, Sec.. 8 8N-1 ~'$~ . . ...~.i ~cArthur RiYer F~eld 5. Elevation in feet {indicate KB, DF, etc.} I 6. Lease Designation and Serial No. 106' KB above ~$kI ADL 18729 Itemlock Zone 121 Date Spudded 13. Date T.D. Reached {4. Date Comp., Susie. or ~band. I 15. Water Depth, if o~fshore 1'16. No.' of'Completions , ,eet S I Z , 17. Total Depth (MD+TVD) 18. Plug Back Depth (M~D) 19. Directiona Survey J20. Depth Where SsSv set J 21. Thickness of Permafrost ~2,493' - ~0,034 ,~2,355'- 9,942' Y~S~ Moa / 292' ,eetMD J N/A ' 22. Type Electric or Other Logs Run D[L/Son~c/GR; FDC/CNL/GR; CBL 23. CASING, LINER AND c'EMENTING RECORD SETTING DEPTH MD 'CASING SIZEWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,. 20" In place from Well D-19 N/A 13-3/8" In plac~ from We'l D-19 ~ N/A 9-5/8" 47/53.5~ N-80 0' 10,933' 12'25" 1227 sx Class G 300.00~ 7". liner 0' 12,490' 8.5" 885 sx Class G 3~0,000~ 24. Perfdrations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5 ]].4R7~ 11 B'I 1'1,678' - 11,697' MD 9,400' -9,415' TV[,26. AC~D, FRAC~uR~,.cEMENTsQuEEZE, ETC. ,, B-4 12,031' -' 12,072' MD 9,696' - 9,729' TV[ DE,TH ~N~ERVA~.(Mm AMOUNTa K~NDOF.~AT~R,A~USED All Perle are 4 SPF, 0° Phasing ~' ' "' . ,,, -, 27. PRODUCTION TEST 'et,o" o, O,era',on e,c., DateofTest Hours Tested iPRODUCTION FOR OIL-BBL' GAS-MCF wATER-BBL CHOKE SIZE ~GAS-OILRATIO 9/27/90 - 6 ~ ,TES~',ER~OD ~' 14'67 6,2 277.~ rN/~~ ~9n Flow TUbing Casing Pressure CAECULATED .'~ OI[:BB'L GAS-MCF WATER~BBk OI['~R~VITY-API'~rr) "~,~- 140 150 .... ' :~4:HOUR RATE ~ "'88 ' 37 ' ~664 , '340 . 28. CORE DATA , . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SUbmit core chips. . .-. , : . . NOV 2 d 1990 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE JAllallO 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Tvonek q-7one Tot 11,016' 8,865' Hemlock B-! Too 11,664' 9,389' l~!est ~oreland Tot 12,401' 9,972' I , 31. LIST OF ATTACHMENTS Attach #1, Daily Operations Summary; Attach #2, Current l'!ellbore Diagrar Attach #3, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed__ ~----~~~~ Title ~::~/.~/~ ~ S~, Date /'//~' O/~(,2 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 Attachment ~1 ~ Daily Summary of Well Operations Dolly Varden Well D-46 12/30/89 ACCEPTED RIG from Well D-§RD. Skid well. 12/31/89 ND dry hole tree. NU riser spools and BOP's and tested same. 01/01/90 LD d.p. from derrick. Started picking up BHA. 01/02/90 RIH. Tag cmt g 2907'. Drl cmt 2907'-2993'. Test csg to 2450 psi. Drill float equip cmt and new formation to 3010'. Conduct LOT to 14.2 ppg EMW. Drill 3010'-3236'. 01/03/90 Drill 3236'-3364'. POOH. 8HA. RIH. Drill 3364'-3634'. POOH. BHA. RIH. Drill 3634'-3659'. 01/04/90 Dril] 3659'-4258' POOH. BHA. RIH. W/R 3742'-3750', 3876'-3939' 4033 -4258'. Driil 4258'-4482'. 01/05/90 Drlg and survey from 4482'-5549'. Wiper trip to shoe, no problems. Drlg and survey from 5549'-5625'. 01/06/90 Drlg and survey 5625'-5906'. 01/07/90 Dir drill 5906'-6091'. 01/08/90 Drill 6091'-6129' CBU POOH. BHA. Test BOPE. RIH. WR 5087'-5127' 5505'-5568', 5326;-5830;. 01/09/90 Reamed from 5830' to 6129'. Drld from 6129' to 6648'. Lost 600 psi pump pressure. POOH looking for washout. RECEIVED Daily Summary of ~'l~F10perati ons DVP Wel 1 D-46 Page 2 01/10/90 Fin POOR. Found center jet on bit washed out. RIH. Drld from 6648' to 6976'. 01/11/90 Drld from 6976' to 7221'. CSU. Made 25 stand ST. Drld from 7221' to 7410'. 01/12/90 Drl'd from 7410' to 7413'. Tripped for bit. Drld from 7413' to 7662'. 01/13/g0 Drld from 7662' to 7903' Made 10 stand ST. Bolts on drawworks shaft coupling sheared out. P~OH. Started testing BOP's while working on drawworks shaft coupling. 01/14/g0 Fin testing BOP's. Repaired drawworks shaft. RIH. Drld from 7903' to 8130'. 01/15/90 Drld from 8130' to 8253'. Made 10 stand ST. Drld from 8256' to 8520'. 01/16/90 Circ gas cut mud. Drlg 8520'-8600' CBU. POOH. Tight g 8399' and 7196' Change BHA. RIH. Wash and ream 50; to bottom. Drlg 8600'-8736'. ' 01/17/g0 Work tight hole g 8686'. Drill 8736'-8848'. ST 15 stds. No problems. Drill 8848'-g078'. 01/18/g0 Drill g078'-9266'. Work tight hole. Drill 9266'-9314'. CBU. POOH. Stuck pipe g 5410'. Work stuck pipe to 5400'. O1/Ig/go Attempt to jar fish down. RU freepoint. Fish free at T/O jars. Mix and Run pump Hi-vis pill. freepoint. Stuck g 3733'. Reduce MW g.g to 9.6 ppg. Pump 40 bbl H 0 followed by 40 bbl Hi-vis pill. Mix and spot DFE 1402 pipe free pill g g~6 ppg · Daily Summary of'l~F1 Operations DVP Well D-46 Page 3 01/20/90 Mix and spot 1402 pipe free pill (189 bbl). Move I bbl every 1/2 hr. Run freepoint. Stuck ~ 3360'. Backoff ~ 3360'. POOH. MU washpipe. RIH. Wash over 3354'-3537'. CBU. POOH. 01/21/90 RIH w/ screw in sub. Engage fish g 3354'. Make backoff L~ 3542' POOH. Recovered 188.29' of 5" d.p. RIH w/ washpipe. Washover 3542'-3~32'. CBU. POOH. RIH w/ screw-in assembly. Backoff g 3864' POOH. Recovered 315.66'. RIH w/ washpipe. Washover 3862'-3900'. TOF g 38~2'. 01/22/90 Washover fish 3900'-3984'. CBU. POOH. Left 8.58' piece of washpipe in hole. RIH w/ screw-in assembly. Screw-in to fish g 3862' Run freepoint. Pipe stuck g 3987'. Backoff g 3987'. POOH. Recovered 4 its d.p. (127.05'). MU overshot assembly and RIH. Attempt to engage fish g 3964'. POOH to 3964' w/ 15M drag. POOH. No recovery. LD overshot. 01/23/90 RIH w/ bit and stab to 3987'. Did not tag anything on TIH. POOH Test BOPE. PU 2 its g-5/8" washpipe and RIH. Washed along side fish [o 4064'. POOH. RIH w/ screw-in assembly. RIH. Attempt to screw into fish. WL sheave fell out of derrick. Left WL tools in hole. POOH. MU new screw-in assembly. RIH. Screwing into fish. 01/24/90 Screw into fish ~ 398g'. Back off ~ 4082'. POOH. Rec 3 its d.p. (90.66'). RIH w/ screw-in assembly. Screw into fish 4079' Run freepoint. Back off ~ 4178'. POOH. Rec 3 its d.p. (94.42'). MU 3 jt~ washpipe and RIH. Workover fish. 01/25/90 Washover fish 4172'-4264'. Circ. POOH. RIH. Screw into fish ~ 4171'. Back off ~ 4365' POOH. Recovered 6 its d.p. (188.67'). RIH w/ 6 its washpipe. AttemPt to washover TOF ~ 4360' w/o success. POOH. Recovered 6' piece of split 8,1/8" washpipe. RIH w/ 3 its washpipe. Wash along side of fish 4360'-4458' w/o bottoming out. CBU. 01/26/90 POOH. RIH. Screw into fish ~ 4360'. Unable to get past 4441' w/ string shot. Back off~ 4424' POOH. Recovered 2 its d.p. 63.52'. washpipe. Washover fis~ 4424' to 4514' CBU. POOH. RIH. Scre~i~q~, Attempt to circ. Fire string shot ~ 44~1'. Established circ, NOV 2 61990 41as~ Oil.& Gas Cons. ~chora~ Daily Summary of ~i~.,.,rl Operations DVP Wel 1 0-46 Page 4 01/27/90 RIH w/ spud jars and try to work through obstruction e 4441' w/o success. Backoff e 4424'. POOH. RIH w/ 6 its w.p. Wash over fish 4423'-4596'. POOH. RIH w/ external cutter. Cut HWDP $ 4575'. 01/28/90 POOH. Recovered Ijt d.p., 4 its HWDP, I cut jt HWDP0 (154.74'). Also recovered all wireline tools and 3' x 3" piece of w.p. RIH w/ w.p. Washover 4574'-4752'. CBU. POOH. RIH w/ O.S. Attempt BO. Grapple slipped. POOH. RIH w/ O.S. Latch fish. 01/29/90 Made backoff. POOH. Recovered 147.61' of heavy weight d.p. Washed over fish to 48gg' POOH. RIIJ. Screwed into fish and made a backoff ~ 4907'. POOH. Recovered 180.64' of heavy weight d.p. TOF 4g07' DPM. 01/30/90 RIH and washed over fish from 4g07' to 5025'. Tripped for screw-in assembly and screwed into fish. Jarred down on fish. Drlg jars hitting. Attempted backoff below jars w/o success. Backed off on top of jars. POOH. Recovered ~5 its of heavy weight d.p. TOF 5058'. RU to test BOPs. 01/31/90 Tested BOPs. PU 10-3/4" mill and washpipe and RIH. Milled on stab blade 5098' to 50gg'. POOH. 02/01/90 LD Grade "E" d.p. RIH w/ Grade "G" d.p. and screwed into fish. Jarred on fish, same came free. POOH w/ fish. Had full recovery. 02/02/90 Fin LD fish. LD fishing tools. PU BHA. RIH, picked up heavy weight d.p. and Grade "E" d.p. Reamed 3892' to 4056'. RIH to 5300'. Circ and conditioned mud. 02/03/90 Staged in hole. Had 77' of fill. Circ and cond mud. ST to csg shoe. 02/04/90 Fin ST. Cond mud, POOH. PU new bit and BHA and RIH. Directionally drld from 9314' to 9350'. Daily Summary of l~-~q Operations DVP Wel 1 0-46 Page 5 02/05/90 Drld from 9350' to 9400'. ST to shoe. Drld from 9400' to 9739', 02/06/90 Drill 9739'-9743'. CBUo POOH, Test BOPEo RIHo Drill 9743'-9761', 02/07/90 Drill g761'-9786'. POOH for washout. RIH. Drill g786'-gg20'. ST 50 stds. RIH. Drill gg20'-gg25'. 02/08/90 Drld 9925'-10186' Surveyed w~ MWD-D. ST to 7000' Washed and reamed 10073'-10186'. D~ld 10186'-10210'. Surveyed with ~WD-D. 02/09/90 Drld 10210'-10218'. CSU. POOH. Inspected BRA. Lost cone in hole, RIH w~ reversing basket and burn shoe to 10195'. Washed to 10218'. Milledover junk ~ 10218'. 02/10/90 Milled over junk ~ 10218' 10221' Circ. POOH. No recovery. RIH w/ fishing magnet to 10004'. Washed and reamed to 10221'. POOH. No recovery. RIH w/ 11.5" junk mill to 10170'. Washed and reamed to 10221'. Milled on junk ~ 10221'. 02/11/90 Milled on junk ~ 10221'.- POOH. RIH w/ reverse circ basket. Milled over fish 10221'-10223'. POOH. Recovered core of formation. RIH w/ drlg assembly. 02/12/90 Fin RIH w/ drlg assembly to 10146'. Reamed to 10223'. Drld 10223'-10395'. 02/13/90 Drld 10223'-10395'. ST 35 stds. Washed 10375'-10405'. Drld 10405'-10556'. CSU. Dropped survey. POOH. 02/14/90 Fin POOH. Tested BOP. RIH w/ new bit. Drld 10556'-10659'. Daily Summary of'l~-~+~ Operations DVP Well D-46 Page 6 02/15/90 Drld 1065g'-10728'. Pipe hung up 0 10686' Worked pipe w/o success. Drld to },07.37'. LD 2 its. Reamed 10661'-10737~. Drld 10737'-10758'. ST to 887 Drld 10758'-10887'. 02/16/90 Drld 10887'-10933'. CBU. POOH. Pipe hung up ~ 8608' Worked pipe w./o success. RU WL and ran freepoint. Attempted backoff ~ailed. POOH w/ WL. 02/17/90 POOH with wireline. Spotted 260 bbl pill. RIH with freepoint. Pipe free at 4,522' Attempted backoff at 4,522'. RIH with freepoint. Free at 3,876'. RIH wi~h stringshot. Pipe freed up. Backed off at 4,254' dp while working left hand torque. CBU. ROOH. RIH with screw in sub. Att to screw in. POOH. P/U joint drillpipe. RIH. Screw into fish. Jarred. 02/18/90 Jarred fish. RIH freepoint. Free 7,887'. Attempt backoff 7,875'. Back off 4,524'. Retorqued pipe. Attempted backoff 7,875'. Backed off 4,524 retorqued pipe. Attempt backoff 7,875'. Failed. Worked pipe. RIH freepoint. Pipe free 4,261'. Attempt backoff. Backed off 678'. Retorqued pipe. BaCked off at 4,261'. cBu. Tripped for jars and drill collars. 02/19/90 Finished RIH. Screwed into fish at 4,261'. Jarred Backed off at 4,261'. Tripped for bumper sub. Circulated. Screwed into ~ish at 4,261' jarred on fish RIH with freepoint. Could not get b. elow 4,150' POOH with w. ire line RIH ~ith string shot. Backed of at 4 261' , POOH. PiJked up washp~pe. RIHi 02/20/90 Finished RIH with washpipe. Washed over from 4261' to 4468'. CBU. POOH. RIH. Screwed into fish at 4,261. RIH with stringshot. Made backoff at 4,554. POOH. Full recovery of fishing assembly and 1 jt of dp. RIH with screwin assembly. Screwed into fish at 4,554. Jarred on fish. RIH freepoint stringshot tool Attempted backoff at 4,746 wlm failed. Jarred on fish. RIH w/ stringsh~t. Pipe backed off. Gained 1OK p/u wt. POOH w/ w/1. 02/21/90 POOH, recovered 6 jts. of drillpipe. TOF 4742' DPM. RIH with screwin assembly. Hit obstruction at 3692' POOH. R~H. with junk mill.to 3690'. Mill on junk fr. om 3690' 3795', to 4740. Ctrc and conditioned mud, POOH. RIH with screw in assembly. Daily Summary of 'l~J~q Operations DVP Wel 1 D-46 Page 7 02/22/90 Jarred on fish. RIH with freepoint/backoff tool and attempted backoff at 5,475'. Gained 75K stringweight. CBU POOH. Recovered 3,130' (100 its) of DP. Made conditioning trip with bit a~d stabs. RIH with screw in assembly and screwed into fish at 7,872' dpm. Jarred on fish. 02/23/90 Jarred on fish. RIH with Spud jars to 8120' wlm. RIH with freepoint. RIX with stringshot and made backoff at 7965' wlm. POOH. Recovered Ijt dp and 2 jts jwt. RIH with washpipe to tof at 7964' dpm and attempt to wash over fish without success. POOH. 02/24/90 Ran in hole w/ crippled mule shoe and 8 its of washpipe, unable to work over the top of fish. POOH. LD 3 its of washpipe and ran in hole. Attempted to work over top of fish ~ 7964' w/o success. POOH. PU screw-in assembly and started running in hole. 02/25/90 Fin RIH. Attempted to screw into fish. POOH. RIH w/ one jt of washpipe and one bent jt of d.p. Washed over fish from 7964' to 7997'. POOH. RIH w/ external cutter and cut heavy wt. Start POOH. 02/26/90 POOH w/ external cutter. No recovery. Washed over fish and reamed to 8003'. Tripped for mill. Reamed 8003' to 8054'. POOH. MU external cutter and started in hole. 02/27/90 RIH w/ external cutter. Unable to get deeper than 8003'. Attempted external cut ~ 7982'. POOH. No recovery. RIH w/ wash pipe and washed over fish 7964' to 8051'. CBU. POOH. Tested BOPs. 02/28/90 RIH and washed over fish 7964' to 8051'. CBU. POOH. RIH w/ Ijt washpipe with metal muncher mill on drive bushing. Milled two feet on fish. POOH. RIH w/ overshot to shoe. Slip and cut drill line. 03/01/90 Fin RIH and attempted to latch fish w/ overshot. POOH. RIH w/ washpipe and metal muncher mill and mill top of fish. POOH. RIH w/ external cutter and washover fish. Daily Summary of/~ Operations DVP Well 0-46 Page 8 03/02/90 Made external cut. POOH. Recovered 33.80' of heavy wate d.p. TOF 8006'. RIH w/ washpipe and washed from 8006' to 8100'. CBU. POOH. RIH w/ overshot and latched fish. Made spud jar run to 8051' WL. 03/03/90 RIH ,w.,/y stringshot and made backoff. POOH Recovered 55.72'. TOF 8062'. RIH.y washpipe and washed over fish 8062; to 8185'. CBU. POOH. RIH and screwed into fish. Jarred fish free. Start POOH. 03/04/90 Fin POOH w/ fish. Had full recovery. RIH to 8000'. CBU. RIH to 8350'. Reamed 8350' to 8660'. RIH to 9038'. CBU. RIH to 10,067'. CBU. RIH to 10,619' hit bridge. Start reaming. 03/05/90 Fin reaming fill to 10og33'. Circ and cond mud. ST to csg shoe. Circ and cond mud. Started POOH. 03/06/90 Fin POOH. RU and ran 136 jts 9-5/8" csg (5641'). Csg parted. RIH w/ spear and jars. Tagged fish ~ 5285'. Speared fish. Jarred on fish. 03/07/90 Jarred on fish. POOH w/ spear. RIH w/ dressing mill. Dressed off top of g-5/8" csg. Circ. POOH. RU to run csg. 03/08/90 Fin RU to run csg. PU csg patch. RIH w/ 9-5/8" csg. Worked csg patch over stub ~ 5295'. Made several attempts to engage csg patch. Latched csg patch. Overpulled 20OK. Tested csg and patch to 2500 psi leaked to 1500 psi. ND BOP. Set slips. NU BOP. Tested BOP. RIH w/ 8-1/2" bit. Daily Summary of~ Operations DVP Well D-46 Page g g-5/8" Casing Detail KB to top of casing head Cameron 13-5/8" 3M x 13-5/8" 3M csg head I cutoff jt 9-5/8", 43.5#, BTC, N-80 17 its g-5/8", 43.5#, BTC, N-80 107 its g-5/8", 47#, BTC, N-80 Tri State leaded casing patch 20 Jts 9-5/8", 47#, BTC, N-80 116 Jts g-5/8", 53.5#, BTC, s-g5 Float collar 2 Jts g-5/8", 53.5#, BTC, s-g5 Float shoe FROM TO 0.00' 40.95' 40.95' 42.32' 42.32' 63.38' 63.38' 752.81' 752.81' 5289.50' 5289.50' 5292.00' 5292.00' 6068.17' 6068.17' 10,847.73' 10,847.73' 10,849.38' 10,849.38' 10,931.25' 10,931.25' 10,933.00' 03/09/90 Fin RIH w/ 8-1/2" bit. Circ. POOH. RIH w/ retrievable pkr to 10,752'. RIH w/ perf gun. Set pkr. Perf csg to 10,795'-10,800' DPM. Circ g-5/8" annulus. POOH w/ retrievable pkr. 03/10/90 RI[( w/ retainer. Set g 10749'. Circ. Circ 389 sx cmt. POOH 10 stands. CBU. POOH. RIH w/ retrievable pkr to 5320'. Tested csg below pkr to 2500 psi. POOH. Set pkr g 4982' w/ stinger ~ 5080'. Circ. Circ 838 sx cmt. Waited on cmt. 03/11/90 Waited on cmt. POOH w/ pkr. ND BOP. Reset slips on g-5/8" w/ 30OK. NU 13-5/8" casinghead. Tested wellhead. NU BOP. 03/12/90 NU riser and BOPs. Test BOPs. RIH, tag rim cmt ~ 5147'. Test csg to 2500 psig. Drill out upper squeeze to 5365'. Test csg patch and squeeze to 2500 psig. RIH, tag firm cmt g 10743' (6' above retainer). Drill cmt and retainer. 03/13/90 Drill up retainer g 10,749' and cmt to 10,848'. Attempt to test squeeze perfs (10,786'-10,791') to 2150 psi w/o success. Drill out float collar. POOH. RT bit and scrapers to PBTD. PU cmt retainer and RIH to squeeze shoe and existing perfs {10,786'-10,791'). 03/14/90 RIH w/ retainer. Reverse debris out of drill string (plastic coating and cmt). Break circ. Set retainer. Attempt to e~tabliSh (nje~tion ratew/o success (held 3500 psig). POOH. RIH w/ bit and drill out retainer. Circ Daily Summary of"l~--F1 Operations DVP Wel 1 D-46 Page 10 and clean hole. Test csg to 2150 psig0 ok. POOH. RIH w/ retrievable cementer. 03/15/90 RIH ~ pkr and set ~ 10,486' Test shoe and perfs to 3000 psi, ok. POOH. RIH,~ bit. Drill out shoe ~nd 10' formation. Test shoe to 14.0 ppg. Change out drill line, circ and cond mud. 03/16/90 Change out drill line, circ and cond mud. POOH. PU drlg assembly. RIH. String plugged off ~ 7000'. POOH w/ wet string. Cmt bridges found in string. RIH rabbiting and rattling pipe. String plugged off at 5000'. POOH w/ wet string. 03/17/g0 POOH. Stand back drlg assembly. RIH w/ d.p. and ball shear out sub. Rabbit and rattle each std. Break circ. Drop ball and pressure up to 2000 psi 6 times. Blow ball and circ nut plug pill. POOH. RIH w/ drlg assembly. 03/18/90 RIH w/ drlg survey. Drill from 10,944'-11,097'. 03/19/90 Drill 11,097'-11,310'. CBU. Drop survey. POOH. Test BOPs. 03/20/90 Fin testing BOPs. RIH. Drld from 11,310' to 11,485'. 03/21/90 Drld from 11,485' to 11,710'. 03/22/90 Drill 11,710'-110721' CBU. POOH. MU bit #20. RIH. Drill 11,721'-11,794'. Too~ 60 bbl saltwater kick. SI well. SIDPP = 200 psi. SICP = 240 psi. SI injection wells in vicinity of D-46. Wt up to 10.3 ppg. Circ on choke. Note: Took kick in top of Hemlock Bench #2. 03/23/90 Circ 10.3 ppg mud on choke. Checked for flow, well flowed. Circ 10.5 ppg mud around on choke, no flow. Circ and raise mud wt to 10.7 ppg. Pulled into csg and conditioned mud. RIH. CBU. Drld from 11,794' to 11,894'. Daily Summary of Operations DVP Well 0-46 Page 11 03/24/90 Drld from 11,894' to 12,063'. CBU. Made 12 std ST. Drld from 12,063' to 12,186'. 03/25/90 CBU. Dropped survey. Tripped for bit. Drld from 12,186' to 12,365'. 03/26/90 Drld from 12,365' to 12,493'. ST to csg shoe. Circ and cond mud. POOH SLM. 03/27/90 Fin POOH. RIH w/ DIL/Sonic/GR and logged 12,479' to 10,933'. RIH w/ FDC/CNL/GR and logged 12,436' to 10,933'. RIH. CBU. ST to csg shoe. Circ and cond mud. o3/ 8/go Spotted pill in open hole. POOH. LD BHA. Change rams to 7". RU and run 7" prod csg. 03/29/90 Fin running 7" prod csg to 12,490 and cemented same w/ 885 sx cmt. Waited on cmt. Set slips w/ 350,000~. Made rough cut. 7" Casing Detail RKB to casing spool 31Jts 7", 29#, TKC, N-80 254 Jts 7'', 29#, Butt, N-80 16 Jts 7",. 29#, Butt, P-110 Float collar 2 Jts 7', 29#, Butt, P-110 Float shoe 03/30/90 TO FROM 0.00' 40.95' 40.95' 1326.67' 1326.67' 11,756.55' 11,756.55' 12,405.67' 12,405.67' 12,407.38' 12,407.38' 12,491.21' 12,491.21' 12,490.00' Made final cut on 7" prod csg. NU tbg spool and tested same to 3000 psi. NU and tested BOPs. LD 5" d.p. from derrick. 03/31/90 Fin LD 5" d from derrick. Ran in hole w/ 6" bit PU 3-1/2" d.p. Tagged up ~ 12,355;~'CBU. Tested csg to 1000 psi for 30 ~in. Started POOH w/ d.p. 04/01/90 Fin POOH w! d.p. RU and ran cmt bond log. Daily Summary of 1 Operations DVP Wel 1 D-46 Page 12 ~ 04/02/90 Fin running gamma ray log back to surface. Ran rate gyro from 12,345' to surface on 50' stations. RIH w/ bit and tandem scrapers. Started displacing mud w/ filtered inlet water and cleaning pits. 04/03/90 Fin displacing mud w/ FIW. Circ FIW while cleaning pits. Tripped scrapers to surface and back to 12,355'. Circ FIW. Mixed and pumped filtered 3~ KCl brine. POOH. 04/04/90 Fin POOH w/ d.p RIH :~ tailp!pe, prod pkr and 3-1/2" tbg. External.testing to 5000 psi. Fin RIH 3-1/2 tbg. Installed hgr. Started displacing hole w/ inhibited fluid. 04/05/90 Fin displacing hole w/ inhibited fluid.. Landed hgr. Set prod pkr. Tested pkr to 2500 psi. Ran 2.7" gauge ring in tbg. Closed SCSSV. Set BPV. ND BOP. NU tree. Tested void to 5000 psi. Tested tree to 3500 psi. Prepared rig for skid. RELEASED RIG g 24:00 hrs. on 04/04/g0. 06/27/90 RU on D-46. PT lubricator. Perf Hemlock Bench 5 12,181' to 12,147.5' w/ 4 'SPF. Flow well. RIH w/ run #2. Operator closed swab valve cutting E-line. Left perf gun and 11,500' of line in hole. WO braided line to fish E-line. 06/28/90 Drop from report until braided line is available. 06/30/90 RU .250 braided WL unit. SITP - 600 psi, CP - 60 psi. Held safety meeting. Pressure test lubricator to 2500 psi. RIH w/ wirefinder tag fish g g84', work to gg4'. POH. RIH two prong wiregrab, grab fish g gg4'. POH. PU · weight of line g 640' Pull into lubricator. SITP - 850 psi. Cut wire, strip over w/ grease injector. RD WL. RU E-line. Pull 5' of WL. Unable to pull through grease injector. Close WL BOP's. Unable to obtain complete pressure seal. SITP - g40 psi. Flow well to test separator. FTP 180#. WL BOP's holding pressure. Daily Summary of~"k~l~ Operations DVP Wel 1 D-46 Page 13 07/01/90 Cont to flow well to test. FTP - 180 psi. WL BOP's holding. PU grease injector. Repair WL damage, install grease injector. Spool 400' of WL on drum. Cut line, install lubricator, WL BOP's and tie back to WL drum. POH w/ WL and perf gun, disarm gun. Recovered entire fish, no damage to perf gun. RD E-line. Open well to test, on 2 hour test well flowing ~ 324 BFPD, 96% WC, 13 80PD. 07/02/90 Cont to flow well to test. 07/03/90 Results of 24 hr. test are: 1456 BFPD at 95.6% WC (64 BOPD, 1392 BWPD) producing by gas lift with 1400 MCFPD lift gas, 210 psi FTP and 1150 psi CP. 07/04/90 No test data available. 07/05/90 Results of 24 hr. test are: 1867 BFPD at 96.8~ WC (60 BOPD, 1807 BWPD) producing by gas lift with 2154 MCFPD lift gas, 120 psi FTP and 1160 psi CP. 07/06/90 Results of 24 hr. test are: 1869 BFPD at 97% WC (56 BOPD, 1813 BWPD) producing by gas lift with 2154 MCFPD lift gas, 150 psi FTP and 1160 psi CP. 07/07/90 - No test data. 07/09/90 07/10/90 Dropped from report until procedure to plug back Hemlock Bench 5 is developed. mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmNNNNmmm! 07/20/90 RU WL to run water flow logging tool (detect channeling above and below Hemlock Bench 5). Tool failed. Laid down tool. 07/21/90 Repaired tool. Pressure test lubricator to 2500 psi. RIH w/ water flow logging tool w/ well shut in. Opened well and Stablized flow. Correlated to Daily Summary of~ Operations DVP Wel 1 0-46 Page 14 E-log depth. Hade stop checking for downflow. No flow indicated. POOH w/ well shut in. RU for upflow logging run. RIH w/ logging tool. 07/22/90 Ran water flow log, checking for upflow. No upflow indicated. POH w/ logging tools. RIH w/ NPBT thru-tubing bridge plug, set plug at 12,142' to isolate Bench 5 perfs. Naintaining 520 psi S~TP during operations. RIH w/ 40' cmt bailer. 07/23/90 Nade a total of 6 cmt bailer runs w/ 2-1/8" bailer (2 runs cat did not release from bailer), Established new PBTD of 12,132'. RD WL. WOC. 07/24/90 WOC until Wednesday morning, then will pressure test through tubing bridge plug. 07/25/90 WOC. Perform pressure build-up test on tubing. 07/26/90 Bled TP 420 psi to 20 psi. TP increased to 120 psi in 1-1/2 hrs. RU WL, Pressure test lubricator to 2500 psi. RIH w/ sinker bars. CCL. Tag new PBTD 12,127', POH. Unloading well prior to perforating Hemlock Bench 1. 07/27/90 Unloaded 20 bbls of fluid from tbg. RIH w/ 2-1/8" strip gun. Perf Hemlock Bench I 11,678'-11,697'. POH. RD WL. Flowing well to group separator to clean up after perforating . 07/28/g0 Flowed well to group separator. WC 95.8%. 07/29/90 On 20 hr test well produced at a rate of 1292 BFPD, 94,0~ WC, 72 BOPD, 1220 BWPD. 07/30/90 RU WL, Pressure test lubricator to 2500 psi. RIH w/ production logging string consisting of GR, CCL, fullbore spinner, pedal basket, temp and pressure. Made flowing passes, Thru tbg bridge PlUg leaking from Hemlock B-5. Currently checking for cross flow to Heml6ck B-l~w/ well shut-in. Daily Summary of Operations DVP Well 0-46 Page 15 07/31/90 Well SIo waiting on static bottom hole pressure to stabilize. Ran pressure survey above and below Bench 1. Pressure gradient indicated no cross flow. POH. RIH w! GR/CCL and tagged TOC ~ 12,120' DIL. POH and RD. 08/01/90 Well SI, waiting on dump bailer equipment. 08/02/90 RU cementers. Pressure test lubricator to 2600 psi. SITP = 700 psi° RIH w/ thru tbg bridge plug and set ~ 12,111' DILo POOH. RIH w! 28' dump bailer. Dump cmt on plug. POOH. Maintained 700 psi on tbg. Three more bailer runs required. 08/03/90 Made a total of 6 bailer runs. Two runs partially dumped at surface. Estimated 10' of cmt on plug. RD WLo WOCo 08/04 - 08/5/90 WOC. 08/06/90 WOC. Will bring on production 08/06/90. 08/07/90 Producing well, 1100 8FPD, 95% WC~ o8/o8/9o RIH w/ production logs. Made stationary stops. No crossflow. Opened well. Flow detected through log when FBHP = 4175 psi at approximate rate of 1000 BFPD. 08/09/90 RIH w/ GR and CCL. Tag fill ~ 120092' DIL. POOH. RIH w/ cmt in 28' 2-1/8" O.D. bailers. Dump bailed two successful runs (4.8'). RIH w/ third bailer run. Total of four bailer runs to be dumped on leaking plug. 08/10/90 Dumped bailed third and fourth bailer runs. Tagged 10' higher than expected. Pressure tbg up to 800 psi from 650 psi and will maintain positive pressure while WOC. Daily Summary of~.~¥1 Operations DVP Well 0-46 Page 16 08/11- 08/9/90 WOC. 08/13/90 Put well on gas lift. Producing 870 8FPD, 984 WC. Well heading. 08/14/90 Results of 24 hr test: 1022 BFPD, 97.84 WC and 22 BOPD. Cont testing well. 08/15/90 Results of 12 hr test: 1144 BFPD, 964 WC and 46 BOPD. Cont testing well. 08/16/90 No test. Flowing well to group separator. 08/17/90 No test. Flowing well to group separator. Dropping from report. 8/25/90 Perforated Hemlock Bench 4 12,031' DIL to 12,072' DIL with enerjet III strip guns, 4 shots per foot. Well flowing to group separator for cleanup prior to test. docs\dvp\d46.doc AttaChment #2 MARATHDN DIL CDMPANY TRADING })AY UNIT WELL D-46 Completed 8/25/90 AIL measurements are RKB to top aP equipment, 40' Cameron DCB Tbg Hngr 4,5' 8RD EU£ Top x 4,5' Butt 292' Otls Series 10 TRS¥, Flopper Type FMX, w/2.813' prof':le, 0.25~ control Imne. Completion String. 0'-11,488' 3.5~ 9,8~, N-80 Bu~ ~bQ. 803' 80', 94~, J-55 CsQ. Sqz Per,es 10,795'-800' 8999' 13-3/81 68~, K-55 Csg. Alt gas I;Pt mandrels are 3.5' Camco MMG II w/1.5' pockets. Depth Valve 2508' 1 4486' 8 5495' 3 6886' 4 6867' 5 7504' 6 8107' 7 8680' 8 9277' 9 9731' 10 10,186' 11 10,612' 12 11,037' 13 1L4P5' 14 Type Latch Altech RK Altech R-BO RK port S;Ze 16/64 ]6/64 ]6/64 20/64 20/64 24/64 24/64 ~4/64 28/64 28/64 28/64 88/64 28/64 28/64 B-1 10,933' lt482' 1L500' 11,501' 1L511' 11,527' 11,559' 9-518', 43.5, 47~ & 53.5,, N-80 Csg w/9-5/8' Tristate csg patch From 5290'-5292'. PBR w/Seal assy. (15' Stroke). Seats not she~red out oF PBR. K-Anchor Latch. Brown 3H Perm Pkr w/Baker mlUou~ ext, X/O 4,5' LTC Box x 3,5' Bu%t Otis 3.5' X-Nipple (2.813' ID), Shear-out Sub (3.00' ID). Zone B-1 B-4 B-5 PERFDRATIONS Interval Ft S ,PF, i Phasing Dote 11,678'-11,697' 19' 4 O' 7/27 12,031'-12,078' 41' 4 O' 8/85 12,147'-12,181' 34' Cm't ptugged 7/83 B-4 B-5 Top oF C~t 8 18,076' Top o~' Csg Plug 8 Top oF C~t e Top o~' Csg Plug e 18,i42' 12,490' 7% 29#, N-80 Csg. TD 8 1~493' Rev;slon Date. 11/90 Revised By, ~gL/neP Re~son, New Well Previous Revision, None · 2r. SURVEY REPORT MARATHON OIL COMPANY TRADING BAY UNIT, WELL NO. D-46 MCARTHUR RIVER FIELD, KENAI BOROUGH, ALASKA APRIL 9, 1990 RECEIVED MAY - 2 1990 Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77224 713461-3146 Fax: 713/461-0920 April 9, 1990 Mr. Guy Whitlock Marathon Oil Company 3201 C Street # 800 Anchorage, Alaska, 99503 Re: Trading Bay Unit, Well Number D-46 McArthur River Field, Kenai Borough, Alaska Dear Mr. Whitlock: Enclosed please find one (1) original and six (6) copies of the completed survey of Well No. D-46. We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely, Vice President, Technical Services GU/cv EnclOsures Gyrodata Services, Inc. Houston, TX / Lafayette. LA / New Orleans. LA/Ventura, CA / Aberdeen, U.K. / ~algary, Alberta Anchorage, AK / Kuantan, MalaYsia / Buenos Aires, Argentina / Bergen, Norway A Gyrodata Dire{ct ional Survey for MARATHON OIL COMPANY TRADING BAY UNIT WELL NUMBER D-46 McARTHUR RIVER FIELD,KENAI BOROUGH ALASKA Date Run: 01-APR-90 14:35:16 Job Number: AK0390G221 Surveyor: WELDON Calculation Method: RADIUS OF CURVATURE Survey Latitude: 60de§ 48min 45sec N Bearings are Relative to TRUE NORTH Proposed Well Direction: S 66deg 32min 24sec E Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A ' Gyrodat a ARATHON OIL COMPANY RADING BAY UNIT WELL NUMBER D-46 :ARTHUR RIVER FIELD,KENAI BOROUGH ALASKA ~b Number: AKO390G221 Directional Survey MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft de§ min deg min deg/100' VERT DEPTH ft CLOSURE DISTANCE BEARING ft deg min 50.O 0 7 100.O 0 6 150 .O 0 2 200 .O 0 9 250.0 0 7 300.0 0 2 350.O 0 9 400.0 0 6 450.0 0 10 500.0 0 2 550.0 0 12 600.0 0 12 650.0 0 5 700.0 O' 5 750.0 0 .4 800.0 0 9 850.0 1 3 900.0 1 37 950.0 2 23 1000.O 3 17 1050.0 4 7 llO0.O 4 49 1150.O 5 41 1200.O 6 43 N 0 0 E .00 .0 .0 N 0 0 E MEASURED DEPTHS REFERENCED TO DOLLY VARDEN RKB ELEVATION 0 - 12345 FT. GYRODATA MULTISHOT SURVEY RUN IN 7 5/8 CASING N 17 37 W .22 50,0 .0 N 17 37 W N 46 23 W .11 100.0 .1 N 27 2 W N 78 449 E .24 150.0 .2 N 16 49 W N 18 W .31 200.0 ,2 N 4 11 W S 89 3 W .32 250,0 .3 N 19 56 W N 50 27 E .30 300.0 .4 N 19 59 W N 68 37 W .34 350.0 .4 N 18 16 W S 16 23 W .38 400.0 .4 N 31 30 W N 75 44 W .38 450.0 .4 N 45 15 W S 15 45 E .35 S 65 15 W .39 N 53 2 W .41 N 87 47 W .28 $ 68 12 W .07 N 41 42 W .18 S 12 52 W .38 S 27 27 E 1.89 S 46 16 E 1.42 S 50 54 E 1.56 $ 55 36 E 1.86 S 59 26 E 1.75 S 64 44 E 1.62 S 65 55 E 1.75 S 65 25 E 2.07 500.0 .4 N 53 57 W 550.0 .4 N 65 29 W 600.0 .6 N 70 31 W 650.0 .7 N 70 30 W 700.0 .8 N 73 11 W : 750.0 .9 N 73 26 W 800.0 .9 N 75 49 W 850.0 .9 S 71 6 W 900.0 1.2 S 6 10 W 950.0 2.6 S 26 27 E 999.9 1049.8 1099.6 1149.4 1199.1 5.0 S 39 23 E 8.1 S 46 30 E 11.9 S 51 33 E 16.4 S 55 22 E 21.7 S 57 55 E Page HORIZONTAL COORDINATES feet .00 N .05 N .13 N .17 N .23 N .29 N .34 N .41 N .36 N ,31 N .26 N .18 N .20 N .24 N .23 N .24 N .23 N .28 S 1.21 S 2.37 S 3.84 S 5.57 S 7.40 S 9,31 S 11.53 S .00 E .01 W .06 W .05 W .02 W .11 W .12 W .13 W .22 W .32 W .36 W .40 W .57 W .69 W .76 W .82 w .89 W .83 W .13 W 1.18 E 3.15 E 5.87 E 9.31 E 13.47 E 18.39 E ,. ,. t~THON OIL OOMPAN¥ ~DING BAY UNIT WELL NUMBER' D-46 ;ARTHUR RIVER FIELD,KENAI BOROUGH ALASKA )b Number: A~O390G221 Gyroda~a Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min dee min deE/100' 1250.O 7 33 S 65 47 E 1300.O 8 19 S 68 29 E 1350.O 9 26 S 72 32 E 1400.O 10 23 S 72 21 E 1450.O 11 47 S 72 52 E 1500.0 1550.0 1600.0 1650.0 1700.0 1750.O 1800.O 1850.O 1900.O 1950.O 2000.0 2050.O 2100,O 2150.O 2200.0 2250.0 2300.0 2350.0 24O0.0 2450.0 13 6 S 71 4'8 E 14 29 S 71 11 E. 15 54 S 70 57 E 17 18 S 70 37 E 18 27 S 70 56 E 19 24 S 71 45 E 20 32 S 73 44 E 21 41 $ 75 38 E 22 53 S 76 43 E 24 28 S 77 5 E 26 26 S 77 16 E 28 18 S 76 51E 30 14 S 76 39 E 32 8 S 76 36 E 33 54 S 76 18 E 35 52 S 76 26 E 37 44 S 75 53 E 39 27 S 75 39 E 41 22 S 75 35 E 41 57 S 75 20 E 1.66 1.71 2.55 1.90 2.83 2.66 2.79 2.81 2.82 2.29 1.98 2.63 2.70 2.52 3.18 3.95 3.76 3.86 3.80 3.56 3.92 3.79 3.45 3.81 1.22 VERT DEPTH ft 1248.7 1298.3 1347.7 1396.9 1446.0 1494.8 1543.4 1591.6 1639.5 1687.1 1734.4 1781.4 1828.1 1874.3 1920.1 1965.3 2009.7 2053.3 2096.1 2138.0 2179.0 2219.0 2258.1 2296.2 2333.5 CLOSURE DISTANCE BEARING ft dee min 27.9 S 59 37 E 34.7 S 61 7 E 42.3 S 62 49 E 50.8 S 64 26 E 60.4 $ 65 44 E 71.1 S 66 44 E 83.0 S 67 25 E 96.1 S 67 55 E 110.3 S 68 17 E 125.6 S 68 35 E 141.8 S 68 54 E 158.9 S 69 19 E 176.8 S 69 52 E 195.7 S 70 28 E 215.6 S 71 4 E 237.0 S 71 37 E 259.9 S 72 6 E 284.3 S 72 30 E '" 310.1 S 72 51E 337.3 S 73 8 E · 365.8 S 73 23 g 395.7 S 73 36 E 426.9 $ 73 45 E 459.3 S 73 53 E 492.5 $ 74 0 E HORIZONTAL COORDINATES feet 14.09 S 24.04 E 16.77 S 30.40 E 19.35 S 37.67 E 21.94 S 45.87 E 24.81 S 55.04 E 28.08 S 65.30 E 31.87 S 76.61 E 36.12 S 89.00 E 40.82 S 102.49 E 45.87 S 116.97 E 51.06 S 132.33 E 56.12 S 148.63 E 60.88 S 165.99 E 65.41 S 184.40 E 69.96 $ 203.95E 74.73 S 224.90 79.88 S 247.30 85.48 S 271.10 91.47 S 296.28 97.85 S 322.77 104.60 S 350.55 E 111.76 S 379.63 E 119.43 S 409.86 E 127.48 S 441.26 E 135.82 S 473.42 E tRATHON OIL COMPANY .~ ~ADING BAY UNIT WELL NUMBER' D-46 :ARTHUR RIVER FI£LD,KENAI BOROUGH ALASKA )b Number: AKO390G221 Gyrodata Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/100' 2500.0 42 7 $ 75 13 E 2550.0 41 59 S 75 12 E 2600.0 41 50 S 75 21 E 2650.0 41 46 S 75 0 E 2700.0 41 31 S 75 27 E 2750.0 41 20 S 75 lB E 2800.0 41 7 S 74 55 E 2850.0 ° 40 47 S 74 51 E 2900.0 40 46 S 75 27 E 2950.0 41 1 S 75 41 E 3000.0 41 51 S 75 9 E 3050.0 43 32 S 75 58 E 3100.O 44 40 S 75 48 E 3150.O 46 38 S 75 14 E 3200.0 48 17 S 75 2 E 3250.0 49 52 $ 74 41 E 3300.0 51 20 $ 74 38 E 3350.0 52 38 S 74 50 E 3400.0 52 39 S 74 38 E 3450.0 52 36 S 74 37 E 3500.0 52 53 $ 74 38 E ~'3550.0 52 59 $ 73 56 E 3600.0 52 45 S 73 54 E 3650.0 51 14 S 74 0 E 3700.0 51 14 S 74 4 E .39 .28 .36 .49 .78 .54 .55 .65 .77 .61 1.81 3.54 2.26 4.04 3.30 3.22 2.92 2.62 .33 .08 .56 1.12 .46 3.03 -.12 I VERT DEPTH ft 2370.7 2407.8 2445.0 2482.3 2519.6 2557.1 2594.7 2632.5 2670.4 2708.2 2745.6 2782.4 2818.3 2853.3 2887.1 2919.8 2951.5 2982.3 3012.7 3043.0 3073.3 3103.4 3133.6 3164.4 3195.7 C L O S U R E DISTANCE BEARING ft. deg min 526.0 S 74 4 E 559.5 S 74 8 E 592.9 S 74 12 E 626.2 S 74 15 E 659.4 S 74 18 E 692.5 S 74 21 E 725.4 S 74 23 E 758.2 S 74 24 E 790.9 S 74 26 E 823.6 S 74 29 E 856.7 S 74 31E 890.6 S 74 34 E 925.4 S 74 37 E 961.1 S 74 39 E 997.9 S 74 40 E 1035.7 S 74 40 E 1074.4 s 74 40 E 1113.7 s 74 40 E 1153.5 S 74 40 E 1193.2 S 74 40 E 1233.0 S 74 40 E 1272.9 S 74 39 E 1312.8 S 74 38 E 1352.2 S 74 37 g 1391.1 S 74 36 E HORIZONTAL COORDINATES feet 144.33 S .505.80 E 152.89 S 538.18 E 161.37 S 570.48 E 169.90 S 602.71 E 178.37 S 634.83 E 186.76 S 666.83 E 195.26 S 698.67 E 203.80 S 730.30 E 212.17 S 761.87 E 220.33 S 793.57 E 228.66 S 825.59 E 237.11 S 858.43 E 245.60 S 892.17 E 254.54 S 926.79 E 264.00 S 962.39 E 273.86 S 998.86 284.09 S 1036.12 294.46 S 1074.11 304.92 S 1112.45 315.46 S 1150.76 326.01 S 1189.14 E 336.81 S 1227.54 E 347.85 S 1265.84 E 358.75 S 1303.71 E 369.47 S 1341.19 E ,, ,. ~P, ATHON OIL COMPANY RADING BAY UNIT WELL NUMBER D-46 .~ARTfiUR RIVER FIELD,KENAI BOROUGH ALASKA Number: AK0390G221 Gyrodata MEAS INCL DEPTH ft deg min 3750.0 51 23 3800.0 48 39 3850.0 48 7 3900.0 47 18 3950.0 47 7 4000.0 46 15 4050.O 45 3O 4100.O 44 42 4150.O 42 55 4200.0 42 0 4250.0 42 1 4300.0 41 57 4350.0 41 28 4400.0 41 8 4450.0 41 9 4500.O 4O 55 4550.0 40 38 4600.0 40 .5 4650.0 40 12 4700.0 40 9 4750.0 39 32 ~'4800.0. 39 54 4850.0 39 39 4900.0 39 14 4950.0 38 37 BORE HOLE BEARING deg min 74 lie S 73 OE 73 53 73 59 7448E 743'3 7357E 7437E 75 32 76 53 S 77 1E S77 5E 76 58 7637E 76 46 76 45 77 IOE 77 12E 77 22 S77 4E S77 2E 77 33 77 27 S 77 5E 7657E DOG-LEG SEVERITY deE/100' .36 5.77 1.70 1.63 1.26 1.77 1.72 1.87 3.79 2.59 .17 .16 .96 .80 '.19 .48 .80 1 .O7 .30 .39 1.25 .99 .52 .94 1.25 Directional VERT DEPTH ft 3227.0 3259.1 3292.3 3326.0 3359.9 3394.2 3429.0 3464.3 3500.4 3537.3 3574.4 3611.6 3648.9 3686.5 3724.2 3761.9 3799.7 3837.8 3876.1 3914.3 3952.6 3991.1 4029.5 4068.2 4107.1 Survey .CLOSURE DISTANCE BEARING ft dee min 1430.2 S 74 35 E 1468.5 S 74 34 E 1505.8 S 74 32 E 1542.8 S 74 31 E 1579.5 S 74 31 E 1615.9 S 74 31E 1651.815 74 31 E 1687.2 S 74 30 E 1721.8 S 74 31 E 1755.5 S 74 33 E 1789.0 S 74 36 E 1822.4 S 74 39 E 1855.6 S 74 41 E 1888.6 S 74 43 E 1921.5 S 74 45 E 1954.3 S 74 47 E 1986.9 S 74 49 E 2019.3 S 74 52 E 2051.5 S 74 54 E 2083.7 S 74 56 E 2115.7 S 74 58 E 2147.7 S 75 0 E 2179.6 $ 75 .2 E 2211.4 S 75 4 E 2242.7 S 75 6 g Page HORIZONTAL COORDINATES feet 380.14 5 1378.72 E .390.96 S 1415.47 E 401.61 S 1451.30 E 411.85 S 1486.84 E 421.72 S 1522.18 E 431.33 S 1557.27 E 441.07 $ 1591.81 E 450.66 S 1625.91 E 459.57 S 1659.35 E 467.62 S 1692.13 E 475.17 S 1724.72 E 482.66 S 1757.31 E 490.14 S 1789.73 E 497.68 S 1821.86 E 505.25 S 1853.88 E 512.76 $ 1885.84 E 520.13 S 1917.65 E .,~i~ 527.31S 1949.22 E 534.41S 1980.67 E ~ 541.55 S 2012.12 E 548.73 S 2043.34 E 555.76 S 2074.51 E 562.68 S 2105.73 E 569.68 S 2136.71 E 576.74 S 2167.32 E ,. ~RATHON OIL COMPANY .~ADING BAY UNIT WELL NUMBER D-46 :ARTHUR RIVER FIELD,KENAI BOROUGH ALASKA ~b Number: AKO3906221 MEAS INCL DEPTH ft deg min BORE HOLE BEARING deg min 5000.0 38 26 S 76 55 E 5050.0 38 41 S 76 56 E 5100.O 38 56 S 76 48 E 5150.O 37 34 S 76 40 E 5200.0 37 46 S 76 20 E 5250.0 37 55 S 76 42 E 5300.0 37 8 $ 76 7 E 5350.0 37 23 S 76 17 E 5400.0 37 11 S 76 21 E 5450.0 37 1 S 75 59 E 5500.0 36 53 S 76 2 E 5550.0 36 54 S 76 18 E 5600.0 37 2 S 76 33 E 5650.0 36 28 $ 77 17 E 5700.0 35 48 S 77 39 E 5750.0 35 8 S 78 33 E 5800.0 35 5 $ 78 53 g 5850.0 34 29 S 77 29 E 5900.0 34 8 S 74 41 E 5950.0 34 16 · S 73 15 E 6000.0 33 58 $ 72 21E -6050.0 33 25 S 70 36 E 6100.O 32 48 $ 69 42 E 6150.O 33 0 S 68 55 E 6200.0 33 37 S 68 34 E ~yrodata DOG-LEG SEVERITY deg/100' .36 .52 .50 2.72 .56 .53 1.71 .55 .43 .53 .29 .33 .38 1.44 1.39 1.71 .40 2.01 3.23 1.64 1.17 2.22 1.58 .94 1.28 Directional Survey VERT DEPTH ft 4146.2 4185.3 4224.2 4263.5 4303.1 4342.6 4382.2 4422.0 4461.8 4501.7 4541.6 . 4581.6 4621.6 4661.6 4702.0 4742.7 4783.6 4824.7 4866.0 4907.4 4948.8 4990.4 5032.2 5074.2 5116.O ,CLOSURE DISTANCE BEARING ft deg min 2273.9 S 75 7 E 2305.0 S 75 9 E 2336.3 S 75 10 E 2367.3 S 75 11 E 2397.8 S 75 12 E 2428.5 S 75 13 E 2459.0 S 75 14 E 2489.2 S 75 15 E 2519.5 S 75 16 E 2549.7 $ 75 16 E 2579.7 S 75 17 E 2609.7 S 75 18 E 2639.8 S 75 18 E 2669.7 S 75 19 E 2699.2 S 75 21 E 2728.1 $ 75 23 E 2756.8 S 75 25 E 2785.3 $ 75 26 E 2813.5 S 75 27 E 2841.6 S .75 26 E 2869.6 S 75 24 E 2897.3 S 75 22 E 2924.5 $ 75 19 E 2951.5 S 75 16 E 2978.8 $ 75 12 E Page HORIZONTAL COORDINATES feet 583.78 S 2197.65 E 590.83 S 2228.01 E 597.95 $ 2258.53 E 605.05 $ 2288.66 E 612.19 S 2318.37 E 619.34 $ 2348.20 E 626.50 S 2377.80 E 633.72 S 2407.20 E 640.89 $ 2436.63 E 668.10 S 2465.92 E 655.36 S 2495.09 E '662.54 S 2524.23 E 669.60 S 2553.46 E 676.37 S 2582.59 E 682.76 S 2611.37 E 688.75 S 2639.76 694.37 S 2667.95 700.21 S 2695.87 706.98 S 2723.22 714.75 S 2750.23 723.04 S 2777.02 E 731.85 S 2803.31 E 741.12 S 2829.00 E 750.72 S 2854.41 E 760.67 S 2880.00 E A ~yrodata ,RATHON OIL COMPANY ~DING BAY UNIT WELL NUMBER D-46 ~ARTHUR RIVER FIELD,KENAI BOROUGH ALASKA ,b Number: AKO390G221 MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft dee min dee min deE/100' 6250.0 33 56 S 68 23 E 6300.0 34 19 S 67 59 E 6350.0 34 38 S 67 31 E 6400.0 35 24 S 67 19 E .6450.0 35 48 S 67 28 E 6500.0 36 26 S 66 58 E 6550.0 36 21 S 66 19 E 6600.0 35 51 S 66 8 E 665,0.0 36 10 S 65 55 E 6700.0 36 21 S 65 46 E 6750.0 36 34 S 65 36 E 6800.0 37 6 S 65 17 E 6850.0 37 8 S 64 45 E 6900.0 37 8 S 64 16 E 6950.0 37 56 S 64 18 E 7000.0 38 29 S 63 53 E 7050.O 38 26 $ 63 17 E 7100.O 38 22 S 63 16 E 7150.0 38 38 S 62 51 E 7200.0 39 26 S 62 27 E 7250.0 39 36 S 62 23 E ~.7300.O 39 16 S 62 1E 7350.0 38 48 S 61 25 E 7400.0 39 52 S 61 23 E 7450.0 40 29 S 60 39 E .67 .90 .80 1.58 .81 1.38 .78 1.03 .69 .42 .46 1.15 .64 .57 1.60 1.23 .75 .13 .74 1.70 .33 .81 1.21 2.15 ' 1.56 Directional VERT DEPTH ft 5157.6 5199.0 5240.2 5281.1 5321.8 5362.2 5402.4 5442.8 5483 5563.8 5603.8 5643.7 5683.6 5723.2 5762.5 5801.6 5840.8 5880.0 5918.8 5957.4 5996.0 6034.8 6073.5 6111.7 Survey ,CLOSURE DISTANCE BEARING ft dee min 3006.4 S 75 9 E 3034.2 S 75 5 E 3062.3 S 75 1 E 3090.7 S 74 56 E 3119.6 S 74 52 E 3148.8 S 74 48 E 3178.2 S 74 43 E 3207.3 $ 74 39 E 3236.4 S 74 34 E 3265.6 S 74 29 E 3295.0 $ 74 25 E 3324.6 S 74 20 E 3354.4 $ 74 15 E 3384.1 S 74 10 E 3414.1 S 74 4 E 3444.6 S 73 59 E 3475.2 S 73 53 E 3505.7 $ 73 48 E 3536.3 $ 73 42 E 3567.2 S 73 36 E 3598.4 S 73 30 g 3629.6 S 73 25 E 3660.4 S 73 19 g 3691.4 S 73 12 E 3722.9 S 73 6 E Page HORIZONTAL COORDINATES feet 770.87 S 2905.85 E 781.30 S 2931.89 E 792.02 S 2958.09 E 803.03 S 2984.58 E 814.23 S 3011.45 E 825.64 S 3038.62 E 837.40 S 3065.85 E 849.28 S 3092.8I E 861.22 S 3119.67 E 873.33 S 3146.66 E 885.56 S 3173.73 E 898.03 S 3201.00 E 910.77 S 3228.34 E 923.76 S 3255.59 E 936.98 S 3283.03 E 950.49 S 3310.85 964.33 S 3338.70 978.29 S 3366.44 992.39 S 3394.19 1006.86 S 3422.15 1021.59 S 3450.35 E 1036.40 S 3478.45 E 1051.32 S 3506.17 E 1066.49 $ 3534.00 E 1082.12 S 3562.21 E A 'Gyrodata ~RATHON OIL COMPANY RADING BAY U~IT WELL NUMBER D-46 :ARTHUR RIVER FIELD,KENAI BOROUGH ALAS'gA ~b Number: AHiO390G221 Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH, BEARING SEVERITY ft deg min deg min deg/100' 7500.0 40 21 S 60 54 E 7550.0 40 26 S 59 58 E 7600.0 40 10 S 59 46 E 7650.0 41 2 S 59 35 E 7700.0 41 40 S 59 35 E 7750.0 41 37 S 59 6 E 7800.0 41 36 S 58 28 E 7850.0 41 48 S 57 50 E 7900.0 41 48 S 57 55 E 7950.0 41 54 S 57 42 E 8000.0 41 11 S 57 33 E 8050.0 40 44 S 57 18 E 8.100.O 40 33 ~ S 57 42 E 8150.O 40 2 S 57 20 E 8200.0 39 52 S 57 16 E 8250.0 39 36 S 56 46 E 8300.0 39 58 S 56 13 E 8350.0 39 30 S 55 53 E 8600.0 38 37 S 54 30 E 8450.0 39 14 S 55 12 E 8500.0 38 24 S 54 55 E 8550.0 38 16 S 54 58 E 8600.0 38 19 S 54 53 E 8650.0 38 23 S 54 28 E 8700.0 39 7 S 54 30 E .41 · 1.20 .59 1.73 1.27 .65 .83 .94 .10 .35 1.46 .96 .63 1.15 .34 .83 1.01 1.00 2.49 1.50 1.69 .27 .13 .54 1.47 VERT DEPTH ft 6149.8 6187.9 6226.0 6264.0 6301.5 6338.9 6376.2 6413.6 6450.9 6488.1 6525.5 6563.3 6601=.2 6639.4 6677.7 6716.1 6754.6 6793.0 6831.8 6870.7 6909.7 6948.9 6988.2 7027.4 7066.4 CLOSURE DISTANCE BEARING ft deg min 3754.6 S 73 0 E 3786.3 S 72 53 E 3817.8 S 72 47 E 3849.5 S 72 40 E 3881.6 S 72 34 Ei 3914.0 S 72 27 E 3946.3 S 72 20 E 3978.5 S 72 13 E 4010.8 S 72 6 E 4043.2 S 71 59 E 4075.3 S 71 52 E -4107.0 S 71 45 E 4138.6 S 71 39 E 4170.0 S 71 32 E 4201.1 S 71 26 E 4232.1 S'71 19 E 4263.0 S 71 13 E 4293.9 S 71 6 E 4324.2 S 70 59 E 4354.3 S 70 52 E 4384.5 S 7O 45 E 4414.4 S 70 39 E 4444.2 $ 70 32 E 4474.0 S 70 26 E 4504.1 S 70 19 E HORIZONTAL COORDINATES feet 1097.95 S 3590.51 E 1113.93 S 3618.69 E 1130.17 S 3646.66 E 1146.60 S 3674.74 E 1163.32 S 3703.23 E 1180.26 S 3731.80 E 1197.47 S 3760.19 E 1215.02 S 3788.45 E 1232.74 S 3816.67 E 1250.51 S 3844.91 E 1268.26 S 3872.91 E 1285.91 S 3900.53 E 1303.40 S 3928.00 E 1320.77 S 3955.28 E 1338.11 S 3982.29 E 1355.51 S 4009.10 1373.17 S 4035.78 1391.O2 S 4062.29 1409.00 S 4088.16 1427.09 S 4113.85 1445.04 S 4139.54 E 1462.86 S 4164.93 E 1480.66 S 4190.28 E 1498.60 S 4215.59 E 1516.78 S 4241.O6 E ,. ARATHON OIL COMPANY RADING BAY UNIT WELL NUMBER D-46 cARTHUR RIVER FIELD,KENAI BOROUGH ALASKA ob Number: AK0390G221 Gyrodata Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH. BEARING SEVERITY ft deg min deg min deg/100' 8750.0 39 35 S 53 35 E 8800.0 39 48 S 53 39 E 8850.0 39 48 S 53 31 E 8900.0 39 56 S 53 13 E 8950.0 40 20 S 52 24 E 9000.0 40 52 S 52 49 E 9050.0 41 35 S 52 17 E 9100.O 41 35 ' S 52 7 E 9150.O 41 52 S 51 36 E 9200.0 42 39 S 51 29 E 9250.0 42 9 S 51 2 E 9300.0 41 39 S 51 4 E 9350.0 41 3 ~ S 50 55 E 9400.0 40 59 S 50 47 E 9450.0 41 11 S 50 32 E 9500.0 41 Il S 50 40 E 9550.0 41 39 S 50 7 E 9600.0 41 47 S 50 22 E 9650.0 41 55 S 50 14 E 9700.0 41 54 S 50 24 E 9750.0 41 37 S 50 20 E 9800.0 40 56 S 49 56 E 9850.0 40 17 S 49 59 E 9900.0 39 45 S 49 57 E 9950.0 39 22 S 50 3 E 1.51 .44 .17 .46 1.35 1.20 1.59 .22 .88 1.60 1.18 1.01 1.22 .21 .52 .19 1.19 .43 .33 .23 .59 1.45 1.30 1.05 .78 VERT DEPTH ft 7105.0 7143.5 7181.9 7220.3 7258.5 7334.1 7371.5 7408.8 7445.8 7482.7 7520.0 7557.5 7595.2 7632.9 7670.5 7708.0 7745.4 7782.6 7819.8 7857.1 7894.7 7932.7 7970.9 8009.5 CLOSURE DISTANCE BEARING ft deg min 4534.6 S 70 13 E 4565.2 S 70 6 E 4595.9 S 69 59 E 4626.6 S 69 52 E 4657.4 S 69 45 E~ 4688.5 $ 69 38 E 4720.0 S 69 31E 4751.7 S 69 24 E 4783.5 S 69 17 E 4815.5 S 69 9 E 4847.6 S 69 2 E 4879.4 S 68 55 E 4910.8 S 68 48 E 4942.0 S 68 41 E 4973.3 S 68 34 E 5004.6 S 68 27 E 5036.1 S 68 20 E 5067.7 S 68 13 E 5099.5 S 68 6 E 5131.3 S 67 59 E 5163.0 $ 67 52 E 5'194.4 S 67 45 E 5225.4 $ 67 39 g 5256.1 S 67 33 E 5286.5 S 67 26 E HORIZONTAL COORDINATES feet 1535.39 S 4266..71 E 1554.33 S 4292.42 E 1573.33 S 4318.17 E 1592.45 S 4343.89 E 1611.93 S 4369.56 E 1631.70 S 4395.42 E 1651.74 S 4421.58 E 1672.08 S 4447.80. E 1692.63 S 4473.97 E 1713.55 S 4500.30 E 1734.65 S 4526.60 E 1755.64 S 4552.57 E 1776.42 S 4578.23 E 1797.14 S 4603.68 E 1817.97 S 4629.10 E i838.86 S 1859.95 S 1881.22 S 1902.53 S 1923.86 S 4654.54 4680.02 4705.60 4731.27 4756.97 1945.10 1966.25 1987.18 200 7.86 2028.34 4782.61E 4807.92 E 4832.83 E 4857.45 E 4881.85 E ,. ARATHON OIL COMPANY [lADING BAY UNIT WELL NUMBER D-46 cARTHUR RIVER FIELDsKENAI BOROUGH ALASKA ob Number: AK0390G2.1 ~yrodata Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH. BEARING SEVERITY ft deg min deg min deg/100' 10000.O 39 11 S 49 59 E 10050.0 38 57 S 49 29 E 10100.O 38 51 S 49 50 E 10150.0 38 3 S 50 21 E 10200.0 37 0 S 49 32 E 10250.0 36 53 S 49 8 E 10300.0 36 15 S 48 40 E 10350.0 35 39 S 48 26 E 10400.0 35 4 S 47 51 E 10450.0 35 27 S 47 51 E 10500.0 35 11 10550.0 34 45 ]0600.0 35 6 10650.0 35 39 10700.0 35 58 S47 25 E S 4656E S 4637 E S46 4E S 45 44 E 10750.0 36 48. S 45 21 E 10800.0 36 58 S 44 54 E 10850.0 37 46 S 44 36 E 10900.0 36 41 S 43 1 E 10950.0 36 7 S 43 48 E 11000.0 35 33 S 43 24 E 11050.0 35 23 S 44 8 E 11100.0 34 53 S 43 54 E ' 11150.O 34 42 S 43 54 E 11200.0 34 28 S 44 14 E .39 .78 .50 1.70 2.34 .52 1.40 1.24 1.34 .77 .73 1.04 .80 1.25 .77 1.71 .65 1.64 2.90 1.47 1.21 .92 1.03 .36 .60 VERT DEPTH ft 8048.2 8087.0 8125.9 8165.1 8204.7 8'244.7 8284.9 8325.3 8366.1 8406.9 8447.7 8488.7 8529.7 8570.5 8611.0 8651.3 8691.3 8731.0 8770.8 8811.1 8851.6 8892.3 8933.2 8974.3 9015.4 C L O S U R E DISTANCE BEARING ft deg min 5316.7 S 67 20 E 5346.7 S 67 14 E 5376.6 S 67 8 E 5406.4 S 67 2 E 5435.5 S 66 56 E 5464.1 S 66 51 E 5492.5 S 66 45 E 5520.4 S 66 39 E 5547.8 S 66 34 E 5575.2 S 66 28 E 5602.5 S 66 22 E 5629.6 S 66 16 E 5656.6 S 66 11 E 5683.8 S 66 5 E 5711.3 S 65 59 E 5739.1 S 65 52 E 5767.2 S 65 46 E 5795.5 S 65 40 E 5823.6 S 65 33 E 5851.1 S 65 26 E 5878.3 S 65 20 E 5905.3 S 65 14 E 5932.1 S 65 8 E 5958.7 S 65 2 E 5985.2 S 64 56 E HORIZONTAL COORDINATES feet 2048.68 S 4906.10 E ,2069.05 S 4930.14 E 2089.37 S 4954.07 E 2109.32 S 4977.91 E 2128.92 S 5001.22 E 2148.51 S 5024.01 E 2168.09 S 5046.46 E 2187.52 S 5068.46 E 2206.82 S 5090.01 E 2226.19 S 5111.41 E 2245.67 S 5132.77 E 2265.15 S 5153.79 E 2284.76 S 5174.65 E 2304.74 S 5195.59 E 2325.10 S 5216.60 E 2345.87 S 2367.05 S 2388.60 S 2410.43 S 2431.98 S 2453.18 S 2474.13 S 2494.83 S 2515.39 S 2535.78 S 5237.77 E 5259.03 E 5280.40 E 5301.34 E ~ 5321.72 E 5341.91E 5361.98 E 5381.97 E 5401.75 E 5421.49 E ~' ~' A ~G¥'r o d a t a ~RATHON OIL COMPANY ~ADING BAY UNIT WELL NUMBER D-46 :ARTHUR RIVE,R, FIELD,KENAI BOROUGH ALASKA ,b Number: AKO390G221 Directional Survey Page MEAS INCL BORE HOLE DOG-LEG VERT DEPTH ~ BEARING SEVERITY DEPTH ft deg min deg min deg/100' ft 11250.O 34 39 11300.O 34 59 11400.O 35 50 11450.0 36 38 11500.0 37 15 S 44 28 E .45 9056.6 S 44 4 E .80 9097.7 S 43 49 E .86 9179.2 S 43 17 E 1.72 9219.5 S 42 30 E 1.58 9259.5 S 41 30 E 1.20 9299.3 S 41 15 E 1.36 9338.9 S 40 44 E 1.08 9378.2 S 39 42 E 2.18 9417.6 S 40 29 E 12.57 9458.9 $ 41 5 E 1.68 9501.8 S 41 2 E 1.32 9544.8 ~ S 40 35 E 2.16 9587.4 S 40 23 E 2.43 9629.4 S 40 7 E 3.44 9670.8 11550.0 37 16 11600.0 37 56 11650.0 38 22 11700.0 37 29 11750.0 31 13 11800.0 30 26 I1850.O 31 5 11900.0 32 9 11950.O 33 21 12000.0 35 4 12050.0 36 53 12100.O 38 23 12150.0 39 44 12200.0 4O 41 12250.0 42 10 S 39 33 E 3.69 9711.2 S 39 30 E 3.00 9750.8 S 38 45 E 2.84 9789.7 S 38 24 E ' 1.97 9827.8 S 37 57 E 3.01 9865.3 12300.O 43 13 ~12345.O 43 38 S 37 5 E 2.40 9902.1 S 35 46 E 2.23 9934.8 Final Station Closure: 6610.5 feet South 62 deg 31 min 41 sec East CLOSURE DISTANCE BEARING ft deg min 6011.8 S 64 50 E 6038.5 S 64 45 E 6092.7 S 64 33 E 6120.3 S 64 27 E. 6148.2 S 64 21 E~ 6176.2 S 64 14'E 6204.4 S 64 8 E 6232.8 S 64 1E 6260.9 S 63 54 E 6286.7 S 63 48 E 6310.3 S 63 43 E 6333.9 S 63 37.E 6358.1 S 63 32 E 6383.0 S 63 26 E 6408.8 S 63 20 E 6435.8 S 63 14 E 6463.7 S 63 7 E 6492.5 S 63 1E 6521.9 S 62 54 E 6552.0 S 62 46 E 6582.7 S 62 39 E 6610.5 S 62 32 E HORIZONTAL COORDINATES feet 2556.06 S 5441.31 E 2576.51 S 5461.24 E 2618.22 S 5501.43 E 2639.63 S 5521.79 E 2661.65 S 5542.24 E 2684.15 S 5562.50 E 2707.04 S 5582.66 E 2730.35 S 5602.92 E 2753.82 S 5622.76 E 2775.39 S 5640.92 E 2794.79 S 5657.66 E 2814.07 S 5674.46 E 2833.91 S 5691.59 E 2854.48 S 5709.15 E 2875.94 S 5727.31 E 2898.49 S 2922.04 S 2946.49 S 2971.72 S 2997.73 S 5746.13 5765.56 5785.44 5805.57 5826.02 3024.61 S 3049.50 S 5846.66 E 5865.03 E CHART NO. 1101StS-I,. © © ..- COUPLETION DATE, ¢~' i "~ ? 1 ~e co. CONTACT,,,. ............... AOGCC GEoLoGICAL'blA,~~S INVENTORY UST .... [, check off or list data as it is recei,ved J,,, ' '4~i7 i' /~/-~//~o,," dril,lin[j hiatUS/~"', s, urveY I ~*r we!! tests, ?~1 ,core des, ription ,cored,,intcrwls , core an,a,! ,~is ~' dr~ d!t,Ch,inte~als ....... digital data ................ f,'yW , i i J i i i i i i i i i i i ii iiiii Il I I I I lillllllllll Il I I I I I I I ~'OG TYPE " ' RUN INTEFIV/ILS ......... ' SCALE NO. i ii il i i i ,., ,,,, ~ , ~ , ~ , ?! ', , , $1 ...... _ , ..... ,,, , ~:'! ........ ,. , , , .., , i31 ,, , ,,, ~ ~ ~ , ,~ , , J ,, , , , ,, , ,, , ,, , ,, ,,, .............. , ....... ~ ~ I I Memorandum UNOCAL ) DOCUMENT TRANSMITTAL May 2, 1990 HAND DELIVERED TO: John Boyle FROM: R.C. Warthen K. D. Kiloh LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Trading Bay Unit ~ McArthur RiVer~ Field'- 1 sepia and 1 blueline as follows: Segmented AcousticCement Bend Log/VDL/Gamma Ray Gamma Ray Log Compensated Densilog/Compensated Neutron/Gamma Ray BHC Acoustilog/Gamma Ray Dual Induction Focused Log/Gamma Ray i directional survey I magnetic tape w/listing ~GZ~/ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: ~ DATED: Rii II. IV.'IID MAY 1990 FORM 1-0C03 (REV. 8-$5) PRINTED IN U.S.A. · i . M~R 1~ ' ?0 1~ :~ MOC-~Y YARDOMSE P.1/2 ,_ . ......... _ --., ~ool~tOn (generel)~ell stgn_ , A~U~TOR, i 'lezerv. pq~ ~ . Pre.. ~f~r,.,..olo~ur~ ~,, _~ /~_ _.~,, . __ _ p~tg ' 'Pu~' tn~ olos ~t.~ JO0 pitf ~4n_~ : ~ ~,i d.te.toru , '~/~ _::t .... :_~~ _ KELkY AND ~hO0R .SAF~Y ,VAlet ,. '.'~..:.-. ' ~,~.,~ b~ v.., p,-.,,. ~'__ . ~, ~_..:..:,.. ,,,,, ,,m, . __,_ ~ _ '~ ' --- ~"' """~'"'"~ >" '"'"""~' ~o~. ~,. -~-, ~-. ~. ' _ ,.=., .,v.. /~__ .. . f .- .. . L .. .- --: -;:- '" ...... . ~/ ' t ' - , . , . · .:, .: / ~ - .,.., . ' ~t ':" Rep~t~ or r.pli.~in~ ,f filled equt~en~ ~ bo nado ~t~htn _ dayt i ' '.'.' ~ I · "' .. .. , ~ , ,,. ~,., ~ .~. . .. .i."..~' . · . ~ I _~'::- ~ .... : · ~' - ., · ' · " I , . · _ ,. I I I I I I IIII I J I I _J I_. : ..... .. . ,il: J~. . · . · .. · ' . " · (rev 03/I7/8J) lfllpea~ort °. .* . ':j TEST PRESSURES Itllll I . I ' PI ~T11q~ Choke Val yes % ~. o ' 2'/'~ ~. . · , · ~ ..... ., 11 L; Kill Val ~e _.~ ~-'~ .._ ~ /-~ ~ .Choke Hanifold _ kt~ ?.__~_~P ~ Upper Kellg Cock ~'. ~_. .. Lower ' Kel l g Cock . . Hydraul. i o Leaks ._ ,'L/'"O .,,v~. _.. ' ~ake and/Type Remote-Operated Choke Size of Adjustable Choke. ' '.' . Size of Po$i tJ ve Choke .. RZG J~o, · . . cosruo'x, ..,"'.' . " "..' , . , , _ .. -- _ · , , O~ntn~ m~ f "~ ~"' " ;~ . p..,*'. ., ... , ~ '* . ; . .. . ., . . .'.'- ~ · . , . . . .., . . . Cl°atn~ Pre~sure /J--P O' .... ~:- ' . Closing Time , ' J'~ ~. ..... --- , .. · r .... ~ _ I I II II Annular Bag t · Blind Rams Opening Pressure ope-/..g Time · Condition of:. · Pi t Level Recorder s Pressure oa. uges .'. aLg' Pusher .. " "';' Foreman June 30, 1989 Telecopy: (907)276-7542 Union Oil ~' 'y o£ ~li£o~ia a~horage, Alaska 99502 Dear Enclosed is ~ approved appl£ea~ion for per~t~ ~o drill ~he above re£eren~e-d ~I.1. ~e permit co drill does nsc exempt you from obCaintns additional ~ermi~s required by la~ fron o~r $ove~n~tl lSen~ies, and aoes no~ au~rtze c~c~in~ dritlt~ operations ~ttl all o~her required ~~c~in~ de~e~~i~8 are ~. To aid us tn sehe~lin~ field ~rk, please no=i-[y =hie office 24 hours prior ~o c~ne~ng ins~alla~n of ~ bl~u~ pr~en~ton equi~~ 8o t~ a representative of ~he Co~.ol~ ~y be presen~ co ~nes8 ~ee~ln~ o~ ~he equi~~ before ~he surface casing shoe is ~illed. ~re a ~rcer 8yo~ is required, please als? nOC~Y~-C~:8 off~e'e 2~'~"~ur~ pri~'~'"'~O c°~nein~ eq-~~n~ Ins~atla~ion ~ ~c ~he *C~so~-~y .w~c.~a8 tesci~ before ~illlq below Che 8~ o~ c~ eonduecor pipe. Chai~ of Alaska Oil sad ~s C~nserVation Con~nisslon B¥ OE)~ OF T~i Depart'men~ o£ Fish & ~me, Habitat Section w/o encl. ~par. ~men~ of ~v~ro~n~al ~nse~ac~on w/o anti. Bill a. ~re~ _ Unocal'Oil & Gas DIvis~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Robert T. Anderson District Land Manager Alaska District IJNOCAL ) ,"~ ~.~ El ;(3 SR ,r..'N'G 8R ENG ,'.-::: ? OL I' ii Alaska 0]! & ~as Conse~vat~on~~ Com,dss~on 3001 Porcupine Drive Anchorage~ AK 99504 Gentlemen: TRADING BAY UNIT State of Alaska HcArthur River Field ' Application to Drill and Complete TBUS WEll D-46, Lease Number ADL-18729 Union 0il Company of California, as operator of the Trading Bay Unit, hereby requests approval to drill, complete and produce Trading Bay Unit State well D-46 in the HcArthur R/vet Field "Hemlock Zone" pursuant to Rule 5, Conservation Order No. 80. The proposed completion of th~s well w~ll result in additional recovery of Hemlock Production. · Your approval of this request will be appreciated. KAT: rms ' V~(y truly yours, ' .. -,Kevi~ Land~anA. Table. r cc: E. O'Donnell R. Warthen RECEIVED JUN 2 91989 Alaska 011 & Gas Cons. Commission Anchorage ©© Alaska Domestic Production Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 June ]5, ]989 Mr. Mike Minder Alaska 0il & Gas Conservation Commission 300] Porcupine Drive Anchorage, AK 9950] Dear Mi ke: The following is to clarify the questions which arose during the Commission's initial review of the Dolly Varden's Well D-46 Permit to Drill: 1. Well D-46 will approach two injection wells within a distance of 10 feet or less. These wells will be shut in and the casing pressures bled down. Well D-46 will not encounter any shallow gas since it is downstructure in the water column. 3. Well D-46 will penetrate oil bearing zones that contain anerobic bacteria that gives off H~S. There is no possibility of a large volume of H2S entering the (~ellbore of Well D-46. 4. All el's in the 3" vent line and inlet line to the poor boy degasser will be replaced with targeted tee's prior to spudding Well D-46. 5. The diverter line is 10-3/4" O.D. with a 3/8" wall. Since this line is downstream of the 10" divert valve and-is of sufficient size that minimizes the possibility of plugging, no high pressures will be encountered. If you should have any further questions, please call me. Sincerely, V. R. Nimbalkar JRW/aem\DOCS\DD19 Enclosure RECEIVED A subsidiary of USX Corporation gUN 2 ]989 Naska 011 & Gas Cons. ' ..,.~ ~ohorage PERMIT TO DRILL 20 AAC 25.005 la. TyPe of work Drill I~~ Redri,l F-IIib. Type of w(;ll. Exploratory [] Stratigraphic Test [] "Development Oil I~ ' Re-Entry [] Deepenr-II Service [] Developeme.nt Gas [] Single Z.one D Muir!pie Zone [] '2. Name of Operator ' 5'i' Datum Elevation' (DF or KB) 10. Field and P~ol UNOCAL (Maratho.n Oil Company. Sub,Operator) 106' KB above .MSL. feet. .~cArthur River Hemlock 3. Address 6. Property Designation Zone P.O. 190247 Anchora~e~ ~ 99519-0247 ADL 18729 r 4. Location o~ well at surface Leg A-2 Cond. ¢'/.6' Dolly 7'."U'nit or property Name 11. Type B~rtd(,ee2OAAC25.02S) ~arden 752' FSL, 1138' FWL, Sec 6, T8N, R13W, Trading Ba~ Unit Statewide At top of productive interval S.M. 8. Well number Number 5194234 2100' FWL, 1750' FNL, Sec. 8, 'T8N, R13W, S.M. D-46 Safeco Insurance Co. ......... _of America At total depth La 9409' ~D 9. Approximate spud date ,~mourrr- ~ . oQ,ooo ' ' ', , ;T~_rD~ .June 20~ .......... i2. Distance to n'~arest 13, Distance to ~earest Well. 14. Number of acres in p'~'0pert¥ '~'5, Proposed depth(Mo property line 10,000 5100feet .~ 1400feet 3085. acres . 12. ,,31,5 ~D feet 16. To be completed for deviated W~lls ..... 17. Anticipated pressure (se. 2o AAC 25.03s Kickoff depth 830 feet Maximum hole angle39 0 Maximum surface 3328 ,,~g^t,ot,,d,,mrrvD) 4010....~g' 181 Casing'program .... s. et.t.ing Dep,.thl ..... size Specifications Top Bottom Quantity of ce/nent "' Hole Casing Weight 'Grade Coupling Lengih' MD ' TVD MD T~jD (include stage data) 26" . 20" :94.0 H-40 8RD 803' Surfac( 803 803' I'a. place ' ' .. "' . "17-1/2" 13-3/8" 61'.0 K-55 BTC 3000' Surfak( 3000' 2746' 2442 ax 12.,!/4" 9-5,/8!' 43.5 N-80 BTC, '4~00' Surfac~ '4,000' 3525,',2411 sx . _12-1/4" ,9-5/8" 47.0 N-80, B~C 2000' 400,0' 35~Z5";' ,6000' 5082' ,12-i/4" 9-5/8" 53.5 N-80 UTC 5500' 6000' 5,08.2' 11500' 9366' 8-1/2" 7" 29.0 N-80 BTC 1015" 11200' 9132' 12315' 10000' 1~2 mx , , RECEIVED · JUN ],,989 20. Attachments Filing fee [] ProPerty plat [] 'BOP Sketch [] DiVerter Sketch [] Drilling program:~3 , Drilling fluid program I~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25,050 requirements 21. I hereby certify that the i'~)regoing is true and correct to' the best of my knowledge '~ ....... , /signed/~"/~"~..~z~x~':I: Title Environmental ..... Engineer Date 6/19/89 Roy.' "~~D.. Roberts ,'7, , Commission Use Only ,, Permit Number } APl number I Approval date I See ~o~er leiier {~. ~ / 50-- 73 ,~' -'~ O,/~' .~"~ / 0 6/3 0 / ~ 0 for other requirements ~onOiti0ns Of approval SampleS"requ. ire. d [] Yes ~5:;No Mud log requi~ecJ [] Yes ,~N° Hydrogen sulfide measures [] Yes ~r~'No Dimctronal survey required x,]~Yes DN~ Required working p~re for~ilOPE~,,,l~/2M.;,,~r-I ;:~M; ,~ [] 5M; [] 10M; '~-15M- Other: // ~ /~~ , , e~~~ bY order of . Approved by ~, / , (. ' ~~~~ Comm'ss'oner theCo, mm!.ssion Dat FOrm 10-401 Rev.. 12-1-85 MARATHON OIL COMPANY ALASKA REGION WEL.L:~:~ "D-46 ~ .... .' - FIELD.', "~' Trading Bay Unit' Dolly varden Platform ..: ...... :'.- · : -. . ....... . - , .............. SLOT: -.- 6 TYPE: Hemlock ProduCer REVISION NO.: 0. DATE..'. 06115/89 SURFACE LocATI°N 752FSL, 1138'FWL,Soo. O,TON,R13W,S.M. ' · .- TARGE.TLOCATION: 2100'FWL, 1750'FNL, Sec.8,T8N,R13W.,S.M.@9409'-TVD BO~O.MHOLE LOC~ATION.: 2259'FWL, 1818'FNL,Sec.8,TSN,R13W,S.M,@10000' .. . KB ELEVATION; 106 ft. GL ELEVATION: 0 ft. MSL FORMATION .... · .... · _ ~.:.~ ~ ....... .. . .-. :.~: ...."G'-Zone Hemlock Benches: HB-1 . . ~ HB-2 .... ::: - HB-3 : '"-~-':~" HB-4 .. HB-5 ESTIMATED FQRMATION TOpS POTENTIAL DEPTH(M,,D) DEPTH(TVD) CONTENT 10960 8946 oil/water 11549 9404 oil/water 11616 9456 oil/water 11802 9601 oil/water 11892 9671 oil/water 12046 9791 oil/water CASING pROGRAM .SIZE W'l:. GRADE 20' 94.0 H-40 13~3/8" 61.0 K-55 SET THREAD FROM 8RD Surf BTC Surf SET TO, 803' 3000' N-80 BTC Surf 4000' N-80 BTC 4000' 6000' N-80 BTC 6000' 11500' N-80 BTC 11300' ,, 12315' HOLE SIZE 26' 12-1/4" opened to 17-1/2' 12-1/4' 8-1/2' O DIVERTER SYSTEM O The diverter system will consist of a 29-112" x 500 psi Hydril MSP annular preventer with two 10" diverter lines. One of the diverter valves will be preselected to open when the diverter is closed, The valves can be operated ~i,:-~_~:~;;.~..i~/~i~. to change the direction of flow without opening the diverter. : ~:-~:~: ' ' .............................. BLOWOUT, pREVENTERS, .i The blowout preventer stack will consist of a 13-518" 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 3-1116" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included isa 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 EQUIPMENT The solids control equipment consists of an Brandt dual tandem shale shaker, a 2-cone desander and a desilter. t "EEEIY/ED · 41as~ 011 & Gae Con~. COm~l~lon Anchorage CEMENTING PROGRAM SURFA,CE: 13-3/8" @ 3000 ft. LEAD. SLURR¥,,TYPE; Class 'G" w/2% A2 extender and 1% calcium chloride. .. WEIGHT: 13 ppg. YIELD: ' 2 cu.ft/sk WATER REQ.: .......... 13 gai/sk PuMpING TIME: 9:40 hrs:min EXCESS(%): 100 oeo SLURRY TOP: Surface EST. QUANTITY: 1838 sx TAIL SLURRY TYPE: Class "G" wi 2% A2 1% calcium chloride. WEIGHT: 16 ppg. YIELD: I cu,ft/sk WATER REQ.: 5 gallsk PUMPING TIME: 3:00 hrs:min EXCESS(%): 100 % SLURRY TOP: 2500 ft. EST. QUANTITY: 604 sx RUNNING AND CEMENTING DETAILS: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Remove thread protectors and visually inspect connections. Pickup shoe joint. M/U float shoe and float collar. (Baker-lok float shoe and top and bottom 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 2205 sx. lead slurry. Mix and pump 604 sx. of tail slurry. Displace cement. Check floats. WOC 12 hours. N/D diverter and make rough cut on 13-3/8". "', Weld on csg head and N/U BOPE. INTERMEDIATE: 9- @ 11500 ft. _ ..... LEAD SLURRY TY?E: Class "G" w/2.5% prehydrated gel, .95%R-1 and l gal/100sx FP-6L WEIGHT: 14 ppg. YIELD: 2 cu.ft/sk WATER REQ.: 9 gal/sk (FIW) PUMPING TIME: 3:25 hrs:min EXCESS(O/o):, 30 SLURRY TOP: 2800 ft. EST. QUANTITY: 1203 sx TAIL SLURRY TYPE: Class "G" w/.55% R-l, .3% CD-31,40gal/100sx FL-45L, lgal/100sx FP-6L, and. 1 O/o LWL WEIGHT: 16 ppg. YIELD: I cu.ft/sk WATER REQ.: 5 gal/sk (FIW) PUMPING TIME: 3:30 hrs:min EXCESS(%): 30 % SLURRY TOP: 8000 ft. EST. QUANTITY: 1208 sx RUNNING AN,D CEMENTING DETAILS: I Remove thread protectors and visually inspect connections. 2 Pickup shoe joint. 3 M/U float shoe and float collar. (Baker-lok float shoe and top and bottom of float collar) 4 Rig up to circulate and check floats. 5 Run remaining casing. 6 Circulate and condition mud. 7 Pump 10 bbls. fresh water spacer. 8 Mix and pump 30 bbls. of 11.0 ppg scavenger slurry. 9 Mix and pump 2205 sx. lead slurry. 10 Mix and pump 604 sx. of tail slurry. 11 Displace cement. 12 Check floats. 13 WOC 12 hours. 14 N/D diverter and make rough cut on 15 Weld on csg head and N/U BOPE. LINER: 7" from 11,300'to 12,315' SLURRY TYPE: and.1%LWL Class "G" wi .55%R-1, .3% CD-31,40gall100sx FL-45L, 1gal/100sx FP-6L WEIGHT: 16 ppg. YIELD: 1 cu.ft/sk WATER REQ.: 5 gal/sk (FIW) P,UMP!NG, TIME: 3:30 hrs:min EXCESS(%): 30 % SLURR~.T..~)P: 11300 ft. EST...QUANTITY: 142 sx RUNNING AND CEMEN ~AILS: 3 4 8 9 10 11 12 13 14 15 16 17 18 Remove thread protectors and visually inspect connections. Pickup shoe joint. MIU float shoe and float collar. (Baker-lok float shoe and top and bottom 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. Reciprocate and rotate liner while cementing. Pump 10 bbls. fresh water spacer. Mix and pump 20 bbls. of 11.0 ppg scavenger slurry. Mix and pump 142 sx. slurry. Displace cement. Set liner' hanger. Release liner setting tool. Reverse out drillpipe volumn. POOH. WOC 12 hours. MUD PROGRAM DEPTH DEPTH WEIGHT VISC. WATER MUD TYPE FROM T.O,. DD~ sec/qt LOSS Surf 3,000' 8.8-9.2 60-80 <30cc's Spud 3,000' 11,500' 9.2-9.8 60-80 <15cc's Polymer 11,500' 12,315' 9.2-9.8 40-50 <15cc's Polymer SPECIAL CONSIDERATIONS: MUd discharges will be monitored and reported per EPA requirements. DIRECTIONAL PLAN , NORTH EAST DESC MD TVD INCL ,~.I'M ~OORD COORD Kickoff ! ......... 830l ' '830"1 ....... ~ 0'17 N71'07'~'1 ......... i"00NI .... ,~)~00~' End of bUild ToD of HemlOck ......... TOta ' DePth ................. i SECTION 0 505 6258 6738 D-46 will cross 14 existing as follows: WEL..L TVD, RKB CD. oQ D-4~ D-19 236 847 D-05 4653 875 D-42 627 957 D-9RD 725 974 D-20 1316 1402 D-30RD 885 1426 D-30RD2 853 1437 D-2RD 1292 1527 D-18 952 1553 D-10 922 1586 D-4RD 1455 1818 D-6RD 1765 2047 D-46 will approach other wells as follows: WELL DISTANCE At TVD RKB D~Sta2~' mi ;~-, 830 ~5~ ~ ~ ~ 830 830 D-2RD 47 1500 D-25RD 30 1400 D-26 36 1400 ~2g o; ~ ~ 1384 D-27 39 1370 D-46 is: 611 ft. below 3778 ft. ft. above 330 ft. below 249 ft. below 86 ft. below 541 ft. below 584 ft. below 235 ft. below 601 ft. below 664 ft. below 363 ft. below 282 ft. below INTERMEDIATE: LINER: COMPLETION: ,LOGGING GRISPICalIDILILSS from 11500' to 3000'. FDC/CNL/CaI/GR 11500' to 3000'. GRISP/CalIDILILSS from T.D. to 11500'. FDC/CNL/Cal/GR from T.D. to 11500'. A Cement Bond log (CBL/GR) and a directional gyro- survey will be run prior to perforating. No cores are planned for this well. CORING PROGRAM TESTING PROGRAM No open hole tests are planned for this well. ~LOT RECOVERY: Cut and pull 9-5/8" and 7" casing to 1100'. Metal munch 13-3/8" casing to 1000'. Lay a balanced plug from 1150'-750'. SURFACE: Polish off cement plug with 17-1/2" bit to 805'. Directionaily drill 12-1/4" hole 804'-3000', Open hole to 17-112" from 805'-3000'. Run 13-3/8" surface casing to 3000' and cement with 2442 sx, Woc 12 hrs. Nipple down diverter and cutoff casing. Weld on bradenhead. Nipple up BOPE and test to 250 psi and 3000 psi. I,NTERMEDIATE: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14,0 ppg. equivalent test pressure, Drill 12-1/4" hole from 3000' to 11500' per the directional program. Run E-logs. Run 9-5/8" casing to 11,500' and cement with 2411 sx. WOC. Land casing as cemented and nipple up BOPE. Test BOPE, choke manifold, and casing to ~teee 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 11500' to 12315' per the directional program, Run E-logs. Run and cement 7" liner with 142sx. WOC. Test BOPE, choke manifold, and casing to ~N~e, psi. ..COMPLETION: Cleanout casing to PBTD. Run gyro and CBL, Perforate and flowtest 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. GREAT LAIRD DIRECTIONAL DRILLING,INC for MARATHON OIL COMPANY Well .... ...: D46 830 MD KOP FROM D-19 Sect Direct: S 67.07 E Mag Decln..: 23 deg 0 min E RKB Elev...: 106.0 ft Data file..: C:D46.DAT WELL PLAN KB ......... .. ..... : mmmmm mmmm! mmmm! mmmmm --mmm! MEAB INCLN TVD SUB SECT DEPTH ANGLE BKB SEA DIST ----mmm m~------ ~m--~ mm--~ ~--m~m 0 0.00 0 -106 0 50 0.25 50 -56 0 75 0.25 75 -31 0 100 0.25 100 -6 0 125 0.25 125 19 0 6-13-89 Computation: RADIUS OF CURVATURE Build 1 .... : 2.5/100 to 39.63 deg ,, ., mmmmmm m mmmm -- mmmmmmmmmmmmmmm mmm! DIRECTI ON RELATIVE COORD DOG ANGLE FROM WELLHEAD LEG N 0.00 E 0 N 0 E 0.0 N 58.00 E 0 N 0 E 0.5 N 65.00 E 0 N 0 E 0.0 N 51.00 E 0 N 0 E 0.0 N 50.00 E 0 N 0 E 0.0 150 0.17 150 44 0 N 49.00 E 0 N 0 E 0.3 175 0.25 175 69 0 N 30.00 E 0 N 0 E 0.3 200 0.17 200 94 0 N 42.00 E 0 N i E 0.3 225 0.42 225 119 0 N 3.00 W i N 1 E 1.0 250 0.08 250 144 0 N 65.00 E i N i E 1.3 275 0.25 275 169 0 N 15.00 E i N I E 0.7 300 0.33 300 194 0 N 30.00 E i N i E 0.3 325 0.08 325 219 0 N 37.00 E i N i E 1.0 350 0.08 350 244 0 N 48.00 E I N i E 0.0. 375 0.25 375 269 0 S 78.00 E i N i E 0.7. ! 400 .0.25 400 294 0 S 49.00 W i N i E 0.0, 415 0.33 415 309 0 S 78.00 W i N i E 0.6 468 0.00 468 362 0 S 0.00 W i N i E 0.6, 531 0.08 531 425 0 S 72.00 W i N i E 0.1. 595 0.00 595 489 0 S 0.00 W i N i E 0.1 688 0.00 688 582 0 S 0.00 W i N i E 0.0 782 0.25 782 676 0 N 89.00 W i N 0 E 0.3 813 0.17 813 707 0 N 66.00 W i N 0 E 0.3 823 0.17 823 717 0 N 66.00 W I N 0 E 0.0 828 0.17 828 722 0 N 66.00 W i N 0 E 0.0 D46 830 ID KOP FROM D-19 SIDETRACK KOP .... .: mmmmm MEAS DEPTH ----mmm 830 923 1023 1123 1223 1323 1423 1523 1623 1723 1823 1923 2023 2123 2223 END OF BUILD. .... .: TOP HEMLOCK/TARGET: HEMLOCK BENCH #2..: HEMLOCK BENCH #3..: 2323 2409 11652 11720 11908 HEMLOCK BENCH #4..: 11999 HEMLOCK BENCH #5..: 12155 T.D ...... . ........ : 12426 RECEIVED JUN 2 1989 WELL PLAN mmmmm mmmmm mmmmm mmmmm mmmmmmmmm INCLN TVD SUB SECT DIRECTION ANGLE BKB SEA DIST ANGLE 0.17 830 724 0 N 71.07 W 2.50 923 817 0 S 67.07 E 5.00 1023 917 7 S 67.07 E 7.50 1122 1016 17 S 67.07 E 10.00 1221 1115 33 $ 67.07 E 12.50 1319 1213 52 S 67.07 E 15.00 1416 1310 76 S 67.07 E 17.50 1512 1406 104 S 67.07 E 20.00 1607 1501 136 S 67.07 E 22.50 1700 1594 172 S 67.07 E 25.00 1792 1686 213 S 67.07 E 27.50 1881 1775 257 S 67.07 E 30.00 1969 1863 305 S 67.07 E 32.50 2055 1949 357 S 67.07 E 35.00 2138 2032 412 S 67.07 E 37.50 2218 2112 471 S 67.07 E 39.63 2285 2179 525 S 67.07 E 39.63 9404 9298 6421 S 67.07 E 39.63 9456 9350 6464 S 67.07 E 39.63 9601 9495 6584 S 67.07 E 39.63 9671 9565 6642 S 67.07 E 39.63 9791 9685 6741 S 67.07 E 39.63 10000 9894 6915 S 67.07 E m m mm m mm m mm mm mm m m m mm mm m RELATIVE COORD FROM WELLHEAD iN 0 E 1 S OW 38 6E 7 S 16E 13 S 30 E mm~m DOG LEG 0.0 2.5 2.5 2.5 2.5 21 S 48 E 2.5 30 S 70 E 2.5 41 S 95 E 2.5 54 S 125 E 2.5 68 S 158 E 2.5 83 S 196 E 101 S 236 E 119 S 281 E 140 S 328 E 161 S 380 E 184 S 434 E 205 S 483 E 2502 S 5913 E 2519 S 5953 E 2566 S 6064 E 2588 S 6117 E 2627 S 6209 E 2695 $ 6368 E 2.5 2.5 2.5 2.5 2.5 2.5 2.5 0.0 0.0 0.0 0.0 0.0 0.0 6-13-89 ! Kill Llno 3' 5000 pti ° I · Drill Dock Floor --'/~," .... i~-, .--.?~..: I Pipe llama Dlhtd llama 0 ~ 0 ! o : Spool rlecel Io Califluhoad 13 5/8'x 5000 pal Annular Pravanler -- Claml~ Conn!clor 13 5/8' $000 pti Doublo Flares · Llno 3' $000 psi ,o DOLLY VARDEN PLATFORM DIVERTER SYSTEM SPECIFICATIONS Riser: 30" O.D. rated to 500 psi. BOP: 30" Hydril MSP Annular, rated to 500 psi. Dtverter Spool : 30" O.D. w/2-10" outlets rated to 500 psi. Diverter Valves : 2 each 10" full opening ball valves w/hydraulic actuators 600 ANSI rating Diverter Line: .2.50mm nominal schedule 40 ID = 9.80" O.D. 10.53" It is requested that the Alaska Oil and Gas Conservation Commission approve a variance from 20 AAC 25.035(b)(1) Structural Casing BOPE Requirements. The planned Dolly Varden Platform diverter system will have two 10-inch vent line outlets in the spool immediately below the 30-inch annular preventer. The annular preventer and diverter valves may be functioned from the main BOP panel, remote BOP panel or Koomey unit. The primary diverter valve's hand control will be mechanically linked to the hand control of the annular preventer on the Koomey unit. In this way, the diverter valve will react in a fail-safe manner such that the valve will open upon closure of the annular preventer or close when the annular preventer opens thus preventing a complete shut-in of the wellbore. MARATHON OIL COMPANY DOLLY VARDEN PLATFORM DIVERTER STACK .~ FIo.wllne I I' 2g 1/2'x500 psi l ' J Annular Preventer ~I Im...-: m... . '. ~ ; +~oo~ 30 8pool Pieces Boom Rig ted Tee Pipe Rack Quarters ~,i~RAT, I-IO['I OIL COMPANY ~~LY V AI'IDEI'I PLATFORM' CHOKE ,MANIFOLD (~) 3' Ilowco Lo Torque SO00 pll Valve All FI.ngee are 3' SO00 pal 3' Venl Line Flamole AdJuslable Choke · · 3/4' Manual Choke I 3e 1/2' Manual (Choke Pro I ll~re Senior · t 31 Rig Floor · · · - .-}. - . · · Choke Line 3' 5000 pal · 0 0 0 · ,, Slop Cock Volvo (To 13o Loll Open) 3' Bull Plug Blind' Flange ' I PRESSURE DETERI~NATION HEHLOCK RESERVOIR The maximum pressure to be en6ountered while drilling Well D-46 is 'exPected to occur in the Hemlock reservoir. A pressure of 4010 psi a= 9350'$$ is predic=ed based upon a static reservoir pressure of 3660 psi at 9350'SS measured in Well D-17RD triM arch, 1988. o The max/mum surface calcula=ed for the Hemlock reservoir is 3,328 psi. This pressure was calculated using =he following formula: Ratio = 1 - ~.018 x T~) ,oo0 - Ratio = 1 - (.018 x 9450') 1,000 - =0.830 Maximum Surface Pressure = Ratio x FormationPressure = 0.830 x 4010 = 3,328 psi ...... LIST OF'SOLIDS COF/~OL EQUIFI~EL~ 2 each - Brand~ Dual Tandem Shale Shakers 1 each - Pionee~ Desander 1 each - P~oneer Disilter ! each '- Degasser " A To=co mud system has been designed in=o =he driller's, console. Each =he active pl~s are equipped wi=h probes which ac=ua=e bo=h visual a~d o£ audio alarns-a= =he driller's console. 24 + KING SALMON De- t 3O 31 ADL 17594 L- GRAYLING { '='-' DOLLY VAR:DEN o 6 ADL 17602 ~ , . ,, TRADING DAY UNIT BOUNDAt .. I'M,md' 22 · · , · + ADL 18772 · 27 + ' _: -.' el-emi ADL 18729 23 2~ 17 4 ADL 17579 *1 MARATHON OIL COMPANY TRADING BAY UNIT McARTHUR RIVER FIELD lCdlLf,' f' · II'l'f' 41;II11'1!, · & TIh,.~ Pl~,l lO&,,,,. ill, I , , t 4- 3O 13 D&TUM: dl, l.&~KA I'tA~ IsL~ COO~Dt#ATE I~'ITIIL. ZON~ 4 , u,m, q. .... +~. ;.." 22 27 e-,, · 32 e-,, ~' u, Mr -I I I 8 .:.1 ' I I I I I I I I I I I ,.6. "1 lO I I I I I ~- ........... 15 Ll~OIrNO MARATHON OIL COMPANY TRADING BAY UNIT McARTHUR RIVER FIELD 1' * lO00' AUTNOI: , ALASKA OIL AND GAS CONSERVATION COMMISSION STEVE COWPER, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 Telecopy No. (907) 276-7542 June 30, 1989 ADMINISTRATIVE APPROVAL NO. 80.54 Re: The application of Union Oil Company Oil Company of California, operator of the Trading Bay Unit (TBU), to drill, complete, and produce the TBU D-46 well as part of the pressure maintenance project approved by Conservation Order No. 80. Mr. Kevin Tabler Union Oil Company of California P 0 Box 190247 Anchorage, AK 99502-0247 Dear Mr. Tabler: Your application letter of June 29, 1989 stated that the drilling, completion, and production of the TBU D-46 well will provide additional oil recovery from the Hemlock Oil Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion, and production of the TBU D-46 well pursuant to Rule 5 of Conservation Order No. 80. Yours very truly, Commissioner BY ORDER OF THE COMMISSION dlf/3.AA80 CHECK LIST FOR NEW WELL PERMITS ITEM A~PROVE DATE ,, (f' thru 8) ' (9 thru 10. (10 and 13) 12 13 (4) Cas $ ~K,~.~. ~ -/f-~ (14 thru 22) (23 thru 28) e 3. 4. 5. 6. 7 8 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Lease & Well No. ~A/~7~ ~-'~ NO REMARKS Company ~06~/ d/~~ YES · Is su. rfiCient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ [..~_ Is operator the only affected party ............................... Can permit be approved before fifteen-day wait ...................... operator have a bond in force .................................. Does Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate .. Does the well have a unique name and number ......................... . Is the permit fee attached .......................................... Is well to be located in a defined pool ............................. Is we~l] located proper distance from property line .................. Is We~ located proper distance from other wells ................ ' ... Is conductor string provided ......................................... .;Z~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... ~ Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ........................ y~ Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. ~ Is old wellbore abandonment procedure included on 10-403 ............ ~ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate ~ Are necessary diagrams and descriptions of diverter and 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 H2S gas probable ................................. (29 thru 31) rev: 01/30/89 6.011 Fo r 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 ............................................. Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE · .¢~ ,,OR ~o · 5"-7/ 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. PROGRAM: L REVISION: 5.1 Start of execution: Fri 30 MAR 90 8:50a PART NUMBER: W5790-PE32 **** REEL HEADER **** 6ITLIS 90/03/26 FSYS 01 DRESSER ATLAS LIS CUSTOMER TAPE --- CREATED BY SDS PROGRAM R 2.0 **** TAPE HEADER **** X S03B 90/03/26 FSYS 01 HKROFILM ED FILE # 1 .)~ S03B.001 2.1 85/11/20 1024 . LO **** FILE HEADER **** · * , ;. ,, * MESSAGE * RECORD TYPE 47 NOT oEcOO. ED APIN : 50-733-20165-01 CN : MARATHOM OIL CO. WN : T.B.U. D-46 FN : MC ARTHER RIVER COUN : ~KENA I STAT : ALASKA FL : DOLLY V. ARDEN PLATFORM FL : COND. 6, LEG A-2 FL : 752'~ FSL 1138'~ FWL SECT : 6 TOWN : 8N RANG : 13W PDAT : MSL EPD (FT ) : 0.0 LMF : K.B. APD (FT ) : 106,0 DMF : KELLY BUSHING EKB (FT ) : 106.0 0S1 : DIFL/GR/SP 0S2 : BHC-AL/GR/CAL DATE _. CI~'-~A-;'Q'-tl · - RE. .EIVED MAY - 2 1990 DL (FT ): 12439.0 BLI CF,T ') : 12436,0 TLI (FT ) : 10920,0 CSIZ (IN ) : 9.625 CBD (FT ) : 10933.0 BS (IN ) : 8.5 BHF : POLYMER DFD (LB/G) : 10.8 DFV (CP ) : 58.0 DFPH : 8.0 DFL (C3 ) : 5.0 MSS : MUDTANK: RMS (MMHO') : 0.95 MST (OEGF) : 71.0 RMF (MMHO) : 0.854 MFST (DEGF:) : 71-0 RMC ~MMH'O) : 1.19 MCST (DEGF) : 71.0 MFSS : MEAS. MCSS : CALC. RMB (MMHO) : 0.397 BHT (DEGF) : 170.0 TSC (HR ) : 14.0 MRT ~(DEGF) : 170.0 LUN : HSL-8571 L. UL : :K, ENA I ENGI : CAIN WITN : PARSONS/CO~X LCC : 1 50 * COMMENT RECORD * REPEAT SECTI~ON RECORDED U!PHOLE DUE TO TOOL STICKI:NG * COMMENT RECORD * REPEAT SECTION WAS ATTEMPTED ON BOTTOM * COMMENT RECORD * BOREHOLE VOLUME IS CORRECTED FOR 7~ CASING * .FORMAT RECORD (:TYPE# 64) FRAME SPACE = 30 * .lIN ONE DEPTH PER FRAME TAPE DEPTH U!NIT : FT 13 CURVES : NAME 1 SSD 68 1 CPS 2 LSD 68 I CPS 3 CAL 68 I IN 4 SSN 68 I CPS 5 LSN 68 I CPS 6 GR 68 I AP1 7 CHT 68 I LBF 8 TTEN 68 I LBF 9 SPD 68 I F/MN. 10 DEN 68 I G/C3 11 CORR 68 I G/C3 CODE SAMPLE# UNIT BY'T ES 4 4 4 4 4 4 4 4 FORMAT RECORD (TYPE# 64) FRAME SPACE = 30 * .lIN ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 13 CURVES : NAME CODE 1 SSD 68 2 LSD 68 3 CAL 68 4 SSN 68 5 LSN 68 6 GR 68 7 CHT 68 8 TTEN 68 9 SPD 68 0 DEN 68 1 CORR 68 2 CN 68 3 CNC 68 SAMP 1 1 1 1 1 1 1 1 1 1 1 1 1 L.E# UNIT CPS CPS CPS CPS LBF LBF F/MN G/C3 G/C3 PU PU * DATA RECORD DEPTH LSN DEN 12443.000 0.0000000 2.000000 12393.000 258.7905 2.534807 (TYPE#: O) SSD GR CORR 0.0000000 0.0000000 -0.5000000 122.4301 42.89783 0.1209354 E-01 1014 BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 BYTES LSD CHT CN 0.0000000 0.0000000 -15.00000 56.85381 -11498.85 5.039922 CAL TTEN CNC 6.000000 2000.000 0.0000000 8. 6001 57 -4592.352 8.713089 1 2343. 000 1 25. 0482 64.86110 8. 690704 1 21.0808 65.06143 -11498.85 734.1169 2.470037 -0.4506111E-02 13.48190 16.86530 12293. 000 142. 3762 69.89742 9.048605 102. 7665 54. 84827 -1t498.85 -2678.455 2.496321 0.9984303E-01 i 5. 321 43 18-36671 12243.000 130.6755 205.0084 48.41'212 2.557456 0.6318855 E-01 59.54851 -11498.85 8.018951 12193. 000 130. 2791 64.60580 1 97. 5053 38. 44061 -11498.85 2.498841 O. 2958775E-01 8.938648 8. 674395 -2239.8t9 11.56641 8.513981 1396.418 12.55524 SSN SPO 0.0000000 0.0000000 359.8799 27.99721 258.1782 26.99730 235.2276 27.39760 340.2297 27.39760 343.7534 27.95560 TOTAL DATA RECORDS : 66 STARTING TAPE DEPTH = 12443.00 **** FILE TRAILER **** ENDING TAPE DEPTH = 12147.25 FILE # 2 X S03B.003 **** FILE HEADER **** 2.1 85/11/20 1024 LO CN ~N FN COUN STAT FL FL FL SECT TOWN RANG PDAT * MESSAGE * RECORD TYPE 47 NOT DECODED APIN : 50-733-20165-01 : MARATHOM OIL CO. .' T.B.U. 0-46 : MC ARTHER RIVER : :KENAI : ALASt~A : DOLLY V~ARDEN PLATFORM : COND. 6, LEG A-2 : 752' FSL 1138" FWL : 6 : 8N : 13W! : MSL EPD (FT ) : 0.0 LMF : K.B. APD (FT ) : 106.0 DMF : KELLY BUSHING EKB (FT ) : 106.0 0S1 : DIFL/GR/SP OS2 : BHC-AL/GR/CAL DATE : 03-26-90 SON : 42335 DD (FT ) : 12493.0 DL (FT, ) : 12439.0 BLI (FT ) : 12436.0 TLI (FT ) : 10920.0 CSIZ '(IN ,) : 9.625 CBD (FT ) : 10933.0 BS (IN ) : 8.5 BHF : POLYMER DFD (LB/G) : 10.8 DF¥ (CP ) : 58.0 DFPH : $. 0 ' OFL ~(C3 0 : 5.0 MSS : MUDTANK RMS (MMHO) : 0.95 MST (DEGF) : 71.0 RMF (MMHO) : 0.854 MFST (DEGF) : 71.0 RMC (MMHO,) : 1 . 19 MCST (DEGF') : 71.0 MFSS : MEAS. MCSS : CALC. RMB (MMMO) : 0.397 BHT (DEGF) : 170.0 TSC ~(HR ) : 14.0 MRT (DEGF) : 170.0 LUN : HSL-8571 LUL : KENAI ENGZ : CAIN WITN : PARSONS/COX LCC : 1 50 * COMMENT RECORD ·~ ~ : * COMMENT RECORD * REPEAT SECTION MAS ATTEMPTED ON BOTTOM * COMMENT RECORD * 80REHOLE VOLUME IS CORRECTED FOR 7~ CASING * FORMAT RECORD (TYPE# 64) FRAME SPACE = 30 * .lIN ONE DEPTH PER FRAME TAPE DEPTH UN[T = FT CURVES : NAM.E 1 SSD 68 2 LSD ~8 3 CAL 68 4 SSN 68 5 LSN 68 6 GR 68 7 CHT 68 8 TTEN 68 9 SP'D 68 10 DEN 68 !1 OORR 68 12 CN 68 13 CNC 68 CODE SAMPLE# UNIT I CPS I CPS I IN I CPS I CPS I API I LBF I LBF I F/MN I G/C3 I G/C3 I PU 1 PU BY'TES 4 4 4 4 4 4 4 4 4 4 4 4 4 * FORMAT RECORD (TYPE# 64) FRAME SPACE : 30 * .lIN ONE DEPTH PER FRAME TAPE DEPTH U~NIT : FT I 3 CURVES : NAME CODE SAMPLE# UNIT B¥'TES 1 SSD 68 I CPS 4 2 LSD 68 I CPS 4 3 CAL 68 I IN 4 SSN 68 I CPS 4 5 LSN 68 I CPS 6 GR 68 1' AP1 4 7 CHT 68 I LBF 4 8 TTEN 68 I LBF 4 9 SPD 68 1 F/MN 4 10 DEN 68 I G/C3 4 11 CORR 68 I G/C3 4 12 CN 68 1 P~ 4 13 CNC 68 I PU 4 * DATA RECORD (TYPE# O) 1014 BYTES * DEPTH SSD LSD '.LiSNi-~ i ~/G-R~m~ ~ ~ ~C;~N~T'~ 12206.000 0.0000000 2.000000 12156.000 175.1579 2.436288 12106.000 118.6424 2.381831 12056.000 218.7697 2.559010 12 006.000 173.4100 2.477975 11 956.000 171.7129 2,467822 11 906.000 132.6292 2.428059 11856.000 158.0632 2.474894 11806.000 201.5018 2.527521 11756.000 92.27029 2.362200 11706.000 24.27791 2.113743 11656.000 54.15060 2.357742 11606.000 95.43060 2.548567 11556.000 53,93491 2.587465 11506.000 92.92960 2.483978 11456.000 157.7500 I .726493 0.0000000 0.0000000 -0.5000000 127.9331 44.38588 -0.6170273 E-02 124.0592 54,81204 -0.5298042 123.0398 51.17493 0.3441238 E-01 E-01 123.6234 42.14607 -0.2412796 E-02 126.9811 44.30756 O. 6092072E-02 129.3430 46.66379 -0. 2562523E-02 126.6112 45.60524 0.6027222 E-02 119.4450 44.20601 -0. 3512383E-02 140.1855 43.35565 0.1056957 E-01 162.5975 67,68919 -0. 3031158E-01 159.8484 84.08002 0.1234074 126.1257 49.17897 0.3813362 E-01 118.5470 94.16258 0.1638412 E-01 125.8864 58.06905 0.1025009E-01 221.4547 53.6693-0 -0.1711750 E-01 0.0000000 0.0000000 -15.00000 69.96751 -11498,85 10.96036 77.17641 -11498.85 15.94748 53,65111 -11498.85 7.548470 62.11819 -11498.85 9.568272 65.06471 -11498.85 10.57950 71.27182 -11498.85 14.01395 64.51050 -11498.85 10.58190 56.23351 -11498.85 8.1 48386 86.1 7841 -11498.85 17,76425 159.4947 -11498,85 50,90651 93.06242 -11498,85 31.45967 57.24319 -11498.85 18.60007 50.67671 -11498,85 27.98920 62.31651 -11498.85 21.28923 384.8330 -11498.85 12,53996 6.000000 2000.000 0.0000000 8.668491 14.42728 9.562176 5936.625 18.54317 8.935101 2901.686 10,96707 8.678383 -858.6895 13,06792 8.648989 400.2468 14,06976 8.684103 80.36230 17.38860 8,831499 -972.9631 13.95188 8. 768614 -872,4368 11.63820 703,2512 20.29800 11.16779 762.6194 51.25737 10.01435 50.42456 32.99352 11.69119 -187,7659 19.747,24 11.04835 4298.191 28.91505 11.14241 -346,2493 22.55367 9.973175 5620.105 15.04481 0.0000000 0.0000000 335.6118 277.8779 27.99721 353,9453 27.99721 311.3481 28.10640 323.3640 29.23289 288.8215 28.99710 297.6921 28,99710 336.7136 28.99710 230.3296 28.99710 116.8845 28.99710 196.0272 28.99710 244,9721 28. 997.10 180.5568 28.99710 259.6462 28.76131 323,6655 28.99710 11 356,000 59,46181 2,634172 11306,000 50,02281 2,613833 11256,000 65.42480 2,5?880? 11 206,000 125,5781 2,4?2504 11156,000 62,15401 2.604905 11106,000 88,07191 2,48529? 11056,000 80,83290 2,592980 11006,000 68,27521 2,5?365? 10956,000 63,73151 2,639315 1O9O6,00O 24,48010 2,000000 0,5656528E-01 129,2771 67,55913 0,8631229E-01 125.3916 69.18364 0,6038094E-01 132,4973 81. 16216 0,7753372E-01 140,2493 49,98784 0,5521393E-01 123,4138 105,0740 O. 4456234E-01 148,1663 62,35150 0.1082182 13t ,4946 80,66861 0.8457565E-01 130.3000 80.66982 0,5370045E-01 129.6905 89,03052 0,1013098 38.03680 29.74245 -O.5000000 15,83983 54.15651 -11498.85 26,58667 52.96411 -11498.85 29.68361 59.73502 -11498.85 22.83498 75.33870 -11498.85 13.55276 52.68181 -11498,85 26.52707 77.08420 -11498.85 20,09552 57,28030 -11498.85 20.45949 60.56480 -11498.85 24.2~2220 52,51221 -11498.85 25,34326 32,98260 -11498,85 43.68008 1 591,977 19,32326 11,67937 2201.780 27,15117 10,42813 2327.793 30.97699 10,21420 1166,955 24.58775 8,490927 -1772,647 17,08577 11,01184 -574,6765 27,55464 9.086796 -3 044 · 913 22,94679' 10,85739 -300.6787 21 · 95381 11,4 7733 2884,872 25.07442 .12.02547 -392,1-116 25.75418 8.601000 697,3411 46,73912 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 296 12206,00 ENDING TAPE DEPTH = 28.99.710 192,3067 28,99710 174,1979 29,99701 191.2844 29,76120 268.5271 29.99701 200,7114 29.10631 237.2137 29,34210 220,1980 29.99701 207,5151 29,99701 199.6174 29,99701 108.6585 30.10620 10878.25 FILE # 3 ~:× S03B,004 2,1 85/11/20 1024 LO * MESSAGE APlN CN WN FN COUN **** FILE HEADER **** * RECORD TYPE 47 :NOT DECODED 50'733-20165-01 MARATHOM OIL CO. T,8.U. D-46 MC ARTHER RIVER FL .' 'COND. 6~, LEG FL .' 752~ FSL 1138' FW.L SECT : 6 TOWN : 8N RANG : 13W PDAT : MSL EPD (FT ) : 0,0 LMF : K.B, APD (FT ) : 106.0 DMF : KELLY BUSHING EKB (FT ) : 106.0 0S1 : DIFL/GR/SP 0S2 : BMC-AL/GR/CAL DATE : 03-26-90 SON : 42335 DD (FT ) : 12493.0 DL ~(FT ) : 12439.0 BLI (FT ) : 12436,0 TLI (FT ) : 10920,0 CSIZ (IN ) : 9.625 CBD (FT ) : 10933,0 BS (IN ) : 8.5 BHF : POLYMER DFD (LB/G) : 10.8 DFV (CP ) : 58.0 DFPH : 8.0 DFL (C 3 ) : 5.0 MSS : MU'DTANK~ EMS (MMHO) : 0,95 MST (DEGF) : 71,0 RMF (MMHO!) : 0,854 MFST (DEGF) : 71.0 RMC (MMHO) : 1.19 MCST (DEGF) : 71.0 MFSS : MEAS. MCSS : CALC. RMB (MMHO) : 0,397 BHT (DEGF) : 170.0 TSC '(HR :) : 14.0 MRT (DEGF) : 170-0 LUN : HSL-8571 LUL : KENAI ENGI : CAIRN WITN : PARSONS/CO.X. CCC : 150 * COMMENT RECORD * REPEAT SECTI~ON :RiECORDED UPHOLE DUE TO TOOL STZC~'ING * COMMENT RECORD , REPEAT SECTION WAS ATTEMPTED ON BOTTOM * COMMENT RECORD · BOREHOLE VOLUME IS CORRECTED FOR 7~ CASING * FORMAT RECORD (:TYPE# 64) FRAME SPACE : 30 , .lIN ONE DEPTH PER FRAME : 13 CURVES : NAME 1 SSD 2 LSD 3 CAL 4 SSN 5 LSN 6 GR 7 CHT 8 TTEN 9 SPD 0 DEN 1 CORE 2 CN 3 CNC CODE SAMPLE# UNIT 68 I CPS 68 I CPS 68 .1 IN 68 I CPS 68 I CPS 68 I API 68 I LBF 68 I LBF 68 I F/MN 68 I G/C3 68 I G/C3 68 I PUi 68 I PU BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 FORMAT RECORD FRAME SPACE = ONE DEPTH :PER (~TYPE# 64,) 30 * .lIN FRAME TAPE DEPTH UN:IT : FT 13 CUR~VES NAME I SSD 2 LSD 3 CAL 4 SS'N 5 LSN 6 GR 7 CMT 8 TTEN 9 SPD 10 DEN 1t CORE 1 2 C'N 13 CNC CODE SAflPLEi# UNIT 68 I CPS 68 I CPS 68 1 68 1 CPS 68 I CPS 68 1 API 68 I LBF 68 I LBF 68 1 F/MN 68 1 G/C3 68 1 G/C3 68 t PU .68 I PU * DATA RECORD DEPTH LSN DEN 11'135.000 0.0000000 2.000000 11085.000 48.13260 2.346761 11035.000 72.95511 2.878893 10985.000 72.32750 (TYPE# O) SSD GR COR, R 0.0000000 0-0000000 -0.5000000 153.0892 91.56894 0.3901577 E~.01 129.6694 65.52400 0.2548771 115.9308 1014 BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 BYTES * LSD CHT CN: 0.0000000 0.0000000 -15.00000 102.5637 -11498.85 26.4.0048 34.67590 -11498.85 24.61441 47.36121 CAL TT EN CNC 6. 000000 2.000- 0.00 '0-0000000 9.899763 3038.655 28.1 9844 11.63303 -781.0784 25.33762 12.02350 SSN SPD 0.0000000 0.0000000 154.935,2 24.55560 224.1128 24.03329 223.8694 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 41 11135.00 ENDI~NG FILE # 4 ~X S14N.001 2.1 85/11/20 1024 LO * MESSAGE APIN CN WN FN COUN STAT FL FL FL SECT TOWN RANG PDAT EPD ~(FT ) LMF APD (FT ) DMF EI(B (FT ) 0S1 0S2 DATE SON O0 (FT ) DL (FT BLI (FT ) TLI (FT CSI'Z! (IN ') CBD (FT ) BS (IN') BHF DFD (LB/G,) DFV (CP ) DFPH DFL (C3 ) MSS RMS (,MMHO) MST (DEGF) RMF (MMHO,) MFST (DEGF) RMC ,(MMHO) MCST (DEGF) MFSS MCSS RMB (MMHO) BHT (DEGF) TSC (HR ) MRT **** FILE HEADER **** * R : 8N : 13~ ~: MSL : 0.0 : ~.B. : 106.0 KELLY BUSHING 106.0 : DIFL/GR/SP BHC-AL/GR/CAL : 03-26-90 : 42335 1 2493.0 12439.0 : 12436.0 1,0920.0 9.625 10933.0 :8.5 : POLYMER : 10.8 : 58.0 : 8.0 : 5.0 : MUDTANK : O' 95 : 71.0 : 0.854 : 71.0 : 1.19 : 71.0 : MEAS. : CALC. : O. 397 : 170.0 : 14.0, ECORD TYPE 47 NOT DECODED 50-733-20165-01 MARATHOM OIL CO. T.B.U. D-46 MC AETHER RIVER KENAI AL A SKA DOLLY VARDEN PLATFORM CONO. ~-:~' LEG A-2 752'~ FSL 1138'~ FWL TAPE DEPTH = 10951.25 ENGI : CAIN WITN : PARSONS/CO-X LCC : 150 * COMMENT RECORD * REPEAT SECTION RECORDED UPHOLE DUE TO TOOL STICKING * COMMENT RECORD * REPEAT SECTION WAS ATTEMPTED ON BOTTOM * COMMENT RECORD * BOREHOLE VOLUME IS CORRECTED FOR 7~ CASING * FORMAT RECORD (TYPE# 64) FRAME SPACE = 30 * .lIN ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 12 CURVES : NAME CODE SAMPLE# UNIT 1 CILD 68 2 SP 58 3 GR 68 4 CAL 68 5 CMT 68 6 TTEN 68 7 SPD 68 8 ACQ 68 10 RFOC 68 11 RILM 68 12 RILD 68 I MMMO I MVI 1 API I IN 1 LBF I LBF I F/MN I DIM I US/F I OHMM I OHMM I OHMM BYTES 4 4 4 4 4 4 4 4 4 4 4 4 * FORMAT RECORD (TypE#- 64) FRAME SPACE = 30 * .lIN ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 1 2 CURVES : NA~M E CODE SAMPLE~# UNIT 1 CILD 68 '2 SP 68 3 GR 68 4 CAL 68 5 CHT 68 6 TTE'N 68 7 SPD 68 8 ACQ 68 9 AC 68 10 RI=OC 68 11 RILM 68 12' RILD 68 I MM. HO I M~ I API 1 I LBF 1 LBF 1 F/~M.N 1 OIM 1 US/F I OHMM I OHMM 1 OHMM BYTES 4' 4 4 4 4 4 4 4 4 4 4 4 DATA RECORD (TYPE# O) 994 BYTES DEPTH CILD SP GR CHT, TTEN SPD ACQ RFOC RILM RILD 12555.000 O. 0000000 0.0000000 O. 0000000 2000.000 0.0000000 O. 2000000 O. 2000000 0.2000000 0.0000000 0.0000000 1 2505 . 000 1 59. 5902 241 · 5691 -11498.85 4423, 523 48,98921 ,9 · 21 3013 8. 665838 6. 266047 0.0000000 0.0000000 I 2455,000 184.6526 249· 8311 -11498.85 -651 6. 270 50·47261 7. 6381 77 5.1 I 8.953 5. 415576 59·55226 0.0000000 12405,000 52. 36555 21 7. 5919 -11498.85 3506,183 51. 9591 t 26.65154 21 · 81062 I 9.09653 111.2373 0.0000000 I 2355. 000 52.2t518 206.2451 -1 1498.85 4700. 523 51 , 95911 28.61856 23.42699 19. !5152 46,95245 0,0000000 I 2305.000 38. 75269 227. 9202 '11498.85 -234. 9670 51. 43681 37. 33095 16. 09613 25.80466 48-30360 0.0000000 I 2255.000 35.3'9891 199. 5531 '11498.85 295.3281 51 · 99481 36. 49144 28,14064 28,24945 45.07884 0.0000000 I 2205. 000 55. 85628 192. 3461 -11498.85 -2247.644 53. 99460 38,21 584 59. 76906 17" 90309 45,32933 0.0000000 12155. 000 41. 94427 1 80.30'36 -11498.85 -340.6853 52,03641 62.43326 24. 28703 23.84116 44,05852 0.0 000000 121 05. 000 O, 0000000 O. 0000000 0.0000000 2000.000 0.0000000 O. 2000000 0'. 2000000 0 · 2000000 38·48515 0,0000000 TOTAL DATA RECORDS : 102 STARTING TAPE DEPTH = 12555.00 **** FILE TRAILER **** ENDING TAPE DEPTH FILE # 5 **** FILE HEADER **** ~,X S14N.O02 2.1 85/11/20 1024 LO .* MESSAGE API N * RECORD TYPE 47 NOT DECODED CAL AC 6.000000 50.00000 6.000000 76,14114 8.887663 76.13525 8.923277 71,41 553 8.918972 63,4:6712 9,005285 93.90045 8. 777479 64,46230 9.1 24092 63·15488 9·518402 59,34479 9.490715 50.00000 1 2075,25 ~N : MC ARTHER RIVER COUN : KENAI STAT : ALASKA FL : DOLLY VARDEN PLATFORM FL : CO'ND. ~,~ LEG A-2 FL : 752* FSL 1138' FWL SECT : 6 TO~N : 8N RANG : ~ 3~ PDAT : HSL EPD (FT ) : 0.0 LMF : K.B. APD (FT ) : 106.0 DMF : KELLY BUSHING EK, B ;(FT ) = 106.0 0S1 : DIFL/GR/SP 0S2 : BHC-AL/GR/CAL DATE = 03-26-90 SON : 42335 DO (FT ) : 1 2493.0 DL (FT ) : 12439.0 BLI (FT ) : 1 2436.0 TLI (FT .) .: 10920.0 CSIZ '¢IN ) .' 9.625 CBD (FT ) : 10933.0 BS (IN ) : 8.5 B'HF : POLYMER DFD (LB/G) : 10.8 OFV (CP )' : 58.0 DFPH : 8.0 DFL (C3 ) : 5.0 MSS : M'UDT A'N~ RMS (MMHO) : 0.95 MST '(DEGF) : 71 RMF CMMHO) : 0.854 MFST (DEGF:) : 71.0 RMC (MMHO) : 1.19 MCST (BEGF!) : 71.0 MFSS : MEAS. MCSS : CALC. RMB (MMHO) : 0.397 BHT ~(DEGF) : 170.0 TSC (MR :) : 1,4.0 MRT (DEGF) : 170.0 LUN : HSL-8571 LUL : r't~ ENA I ENGI : CAIN W, ITN .' PARSONS/COaX' LCC : 150 * COMMENT RECORD * REPEAT SECTION RECORDED UPHO'LE DUE TO TOOL ST?I.C~:'ING * COMMENT RECORD . REPEAT SECTION ~AS ATTEMPTED ON BOTTOM * COMMENT RECORD · BOREHOLE VOLUME IS CORRECTED FOR 7~ CASIN~G ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 1 2 CURVES : NAME CODE 1 CILD 68 2 SP 68 3 GR ~ 68 4 CAL 68 5 CHT 68 6 TTEN 68 7 SPD 68 8 AC'Q 68 9 AC 68 10 RFOC 68 11 RILM 68 12 RILD 68 SAM .'1 &N PLE# UNIT 1 MMHO I MV I API 1 IN I LBF 1 LBF I F/MN I DIM I US/F I OHMM 1 OHMM I OHMM FORMAT RECORD CTYPE# 64) FRAME SPACE = 30 * .lIN ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 12 CURVES : NAME 1 CILO SP 3 GR 4 CAL 5 CHT 6 TT E'N 7 SPD 8 AC~ 9 AC 0 RFOC I RILM 2 RZLD CODE SAMPLE# 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 ! 68 1 68 1 68 I UNIT MMHO MV API I~N LBF L;B F F/M N DIM US / F OHMM OHMM OH:MM * DATA RECORD DEPTH CHT RFOC 12521.000 0.0000000 0.2000000 12471.000 -11498.85 26.21965 12421.000 -11498.85 26.21901 (T Y P E # O) CILD TTEN RI:LM 0.0000000 2000'000 O. 2000000 55.10686 -144.3562 13.29056 55.16882 5364.457 13.30438 994 BYTE S 4 4 4 4 4 4 4 4 4 4 4 4 BYTE S 4 4 4 4 4 4 4 4 4 4 4 4 BYTES SP SPD RILD 0,0000000 0.0000000 O. 2000000 120.1211 49.99501 18.14656 126.7614 79.99202 18.12617 GR AC~ 0.0000000 0.0000000 0.0000000 0.0000000 56.416756 0.0000000 CAL AC 6.000000 50.0000:0 6.0O00:O0 61.061 52 9.006010 61.08983 12321.000 -11498.85 19.23416 12271.000 20.51279 12221.000 -11498.85 14.18695 12171.000 -11498.85 31.10489 12121.000 -11498.85 22.07941 8.202990 62.18687 -3310.571 12.36536 70.36426 -229.7671 14.25968 73.40163 1437.685 I 2.7'8506 40.14604 3814.014 23.31630 59.79039 703.96'83 16.36812 7.749879 185.4489 35.34151 16.08057 132.9768 35.99640 14.21176 135.2682 3'5.99640 1 3.62368 121.8292 36.10561 24.90906 125.5501 36. 99631 16.72510 O. 0000000 78.16016 0.0000000 36.03369 0.0000000 52.59123 0.0000000 42.51991 0.0000000 51.11299 0.0000000 72.19441 8.416582 68.88454 8.573885 68.67674 8.871599 73.48767 8.987568 68. 35052 9.046768 68.44260 12071.000 -11498.85 19.87579 12021.000 -11498.85 40.97437 11971.000 -11498.85 40.57625 11921.000 -11498.85 15.48018 11871.000 -11498.85 13.18451 68.$8229 1845.994 15.85832 39.22313 368.1~55 24.62971 33.11578 32'16. 483 29.13303 82.62689 -262.4426 13.53247 99.42757 -2342.087 10.27051 129.,4360 38.88690 14.62367 131.0759 38.76030 25.49516 122.2790 37.99622 30.19708 153.4589 32.88750 12.10260 173.1985 34.34160 10.05757 41.09302 O. 0000000 41.97862 0.0000000 41.06715 0.0000000 42.77095 0.0000000 93.19981 O. 0000000 9.000240 73.84651 9.123474 60.93068 9.096569 66.84277 9.011051 71.72978 9.088032, 75.84186 11821.000 -11498.85 20.41913 11771.000 -11498.85 12.35571 61 · 78448 -3295.773 16.58177 114.2312 -1 087. 004 11.65664 t47.9573 33.65160 16.18529 1 41. 4983 34.99651 8.754177 44.35329 0.0000000 46.88547 0.0000000 8.994991 72.52904 8.975328 80.49852 11721.000 -11498.85 33.91093 56.54248 -5030.859 21.18433 126.4054 35.01392 17.68582 35.85287 0.0000000 11.41579 73.32878 11671.000 -11498.85 17.91614 11621.000 -11498.85 6.021758 59.50142 61 · 75360 2.764381 181 '4022 156.7236 5. 730430 141.1081 29.23289 16.80632 .173.4298 26.99730 5.512611 59.71251 O- 0000000 44.16081 0.0000000 10.93350 73.47650 10.20152 73.60088 11571.000 -11498 91.39026 174.2954 64.62311 8.354029 I I 521 ,000 98,17244 17'7,8105 71.56290 -11498,85 41 26,512 27,99721 O, 0000000 I 2,1 3647 10, I 321 5 10. 1 8616 11471 , 000 62'. 51 630 I 73,0328 76. 73618 '11498.85 -3696. 378 28. 34221 O. 0000000 30,56345 13.38641 15,99583 11421 · 000 105,7595 159,8445 51 · 03735 -11498.85 -2282,129 27.45151 0.0000000 I 4,99536 10.51 978 9,455414 11 371 · 000 179,4412 181.4'255 -1 1498,85 -3185,587 27.01471 5,728207 5,288979 5. 572855 11321,000 85,43721 -11498,85 648,5950 18,23448 13,37356 11271.000 65.93808 -11498,85 -3217,350 16,33447 14,82364 11 221,000 29.48506 -11498,85 -1 382,094 32,81 534 27. 00948 11171,000 101,9403 -11498,85 -183,3826 14,15901 10,20927 tl I 21 · 000 46.31770 -11498,85 -2027,234 19,13098 17,80385 11071,000 113,9906 -11498,85 1427,088 11,97453 9,182955 11021,000 51,21884 -11498,85 1721,265 17,54231 10,11220 10971,000 42,00459 '11498, 85 -1 ?49,444 27,25786 10,20087 178,6590 29,10631 tl ,70450 153,9478 29,99701 15,16574 157,8946 29.99701 33,91548 181.2970 29,88780 9.809666 t48.3557 30,65190 21,59001 143,1993 2.9,01450 8.772652 180.1032 25,99741 19,52406 126.9056 30,99690 23,80692 10921,000 424,4141 189,2135 -11498,85 -801 · 2451 30. 99690 5,511966 4,408286 2,356190 10871 · 000 0.'0000000 0.0000000 O, 0000000 2000,000 O, 0000000 O. 2000000 O. 2000000 0.2000000 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 44.48976 0.0000000 49.69942 0,0000000 52.24728 O.O000000 40.26630 0.0000000 84.24945 0.0000000 46.12978 0.0000000 67.63390 0.0000000 29.45613 0.0000000 37.38930 0.0000000 42.77222 2.000000 28.45973 ,0.0000000 354 12521'00 ENDING TAPE DEPTH 8,422623 71,96765 8,275398 8.436518 72.43826 8.417425 70.92297 8.204288 120.5980 8,424713 67.89561 8.326283 75.87126 8.298937 76.22260 8.375660 77.70422 8.927221 76.90031 10.20052 126.3069 11.45280 135.0293 8.542061 90..08984 8.534939 50.00000 108141.25 FSYS 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 907 **** REEL TRAILER **** BITLIS 90/03/26 ~SYS 01 DRESSER ATLAS LIS CUSTOMER TAPE --- CREATED BY SDS PROGRAM R 2.0 TOTAL RECORDS IN THIS LOGICAL REEL : 908 TOTAL RECORDS IN THIS PHYSICAL REEL: 908 End of e~xe'cut'ion: Fr'i 30 MAR 90 8:53a Elapsed e~.ec.~'~ion ti'me = 3 'minute:s, 23.0 seconds. SYSTEM RETURN CODE = 0