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176-086
1~C~.,.Gl v cv u~ `~~~~ '~ STATE OF ALASKA FEB 2 6 2009 3-.~~ ALA~OIL AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPOF~s~~~~~t°~• Commission 1 a. Well Status: Oil ^ Gas ^ Plugged Q . Abandoned 0 Suspended ^ zoa~c zs.~os zoa~c zs.>>o GINJ^ WINJ ^ WDSPL^ WAG ^ Other^ No. of Completions: 1 b. Well Class: Development Q ' Exploratory^ Service ^ Stratigraphic Test^ 2. Operator Name: Union Oil Company of California 5. Date Comp., Susp., or ' Aband.: 2/23/2009 12. Permit to Drill Number: rs~r, 176-086 - 30Fs-~~~ " - 3. Address: PO Box 196247, Anchorage, AK 99519 6. Date Spudded: 2/10/1978 13. API Number: 50-283-20055-00 - 4a. Location of Well (Governmental Section): Surface: 773' FNL, 495' FEL of sec 33, T14N, R8W, S.M. 7. Date TD Reached: 4/8/1978 14. Well Name and Number: Stump LK Unit (SLU) 41-33- Top of Productive Horizon: (straight hole) 773' FNL, 495' FEL of sec 33, T14N, R8W, S.M. 8. KB (ft above MSL): Ground (tt MSL): 39.37' 15. Field/Pool(s): Stump Lake Field - Total Depth: (straight hole) 773' FNL, 495' FEL of sec 33, T14N, R8W, S.M. 9. Plug Back Depth(MD+TVD): 3,026' MD (3,026' ND) Beluga Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 375867.5 y- 2655269.1 Zone- 4 10. Total Depth (MD + ND): 11,650' MD (11,650' ND) 16. Property Designation: ADL0058790 [Stump Lake] TPI: x- 375867.5 y- 2655269.1 Zone- 4 Total Depth: x- 375867.5 y- 2655269.1 Zone- 4 11. SSSV Depth (MD + ND): N/A 17. Land Use Permit: N/A 18. Directional Survey: Yes No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (tt MSL) 20. Thickness of Permafrost (ND): N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): N/A 22. CASING, L INER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING D EPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 30" N/A N/A Surface 77' Surface 77' N/A Driven 20" 94# H-40 Surface 424' Surface 424' 26" 540 sacks 13-3/8" 72# N-80 Surface 2,512' Surface 2,512' 17-1/2" 2,050 sacks 9-5/8" 43.5# N-80 Surface 6,427' Surface 6,427' 12 1/4" 1 115 k 9-5/8" 47# P-110 6,427' 8,667' 6,427' 8,667' - , sac s 7" 29# P-110 8,563' 9,700' 8,563' 9,700' 8-1/2" 335 sacks 23. Open to production or injection? Yes^ No~ If Yes, list each 24. .TUBING RECORD interval open (MD+TVD of Top t3< Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) N/A N/A N/A N/A N/A N/A ~~i` ~Y &~ ~(`j~;C; ~. c 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. . c > ~-'~ i~.~..-^ 1 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4,210'-6,364' 48 bbl 15.8# LXT cement 3,260'-4,022' 55 bbl 15.8# LXT cement 26. PRODUCTION TEST Date First Production: N/A (Plugged & Abandoned) Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: N/A Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~ Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^~ Sidewall Cores Acquired? Yes ^ No ^~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 09 __ . Form 10-407 Revised 2/20 ` CONTINUED ON REVERSE ~{~ ~.~ • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Top N/A N/A needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base Formation at total depth: 30. List of Attachments: Operation) Summary, Current Wellbore diagram. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola 263-7640 Printed N~e: Timothy C. Brandenburq Tifle: Drilling Manager Signature: Phone: 263-7600 Date: 2/26/2009 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ORIGINAL RI ELEVATIONS RKB-GL 14.00' - RKB-MSL 39.37 424' Csg 466.55' Bowl J 2,512' Csg 1805' Calc TOC 3,024' DV Collar 330 sx DV Collar TOC @9610' 9,700' Csg 8-1/2" open hole 11650' TD SLU 41-33 Stump Lake Unit 33,T14N,R8W,SM 176-086 ADL-058790 ud Date: 2/10/78 7:00 AM )ther: Suspended May 1978; WO Jan 1990; Comp Mar 1990; Cm~ ~, 1993; Reperf Aug 1996; Reperf Oct 2000; Reperf Od 2004; Tag Jun 2007; SL Tag May 2008; P8A 2-23-09 l' 0 Grade Conn ID Len th To Btm TOC H. N/A Weld NA 77' 0' 77' Driven 32.0 H-40 BTC 19.124" 424' 0' 424' Surf 77.5 Chevron Chevron -Alaska Daily Operations Summary Well Name legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SLU 41-33 STUMP LK UNIT 41-33 ADL058790 5028320055 OB1675 39.37 _ ,- -- Jobs ~ -_ -- __ - Primary Job Type Job Category - Objective ~ ~ iuwal start Data _ Ardual End Date Plug -Permanent Abandon Plug and Abandon, Prep well for Rig 9/17/2008 10/2/2008 Primary Wellbore Affected Wellbore UWI Well Permit Number SLU 41-33 5028320055-00 1760860 -- - __ _ Dally Operations. ., 9/17/2008 00:00 - 9/18/2008.00:00. _ _ _ --- --__ -- _ Operations Summary Move in & rig up pumping equipment and tanks 9/18/2008 00:00 - 9H 9/2008 00:00 -___ Operations Summary ______... ___ Pum d 14 Bbls water down reduction tubin 2.5 BPM, ressured up to 4,000 psi. Drift tubing with 2.80" gauge ring to 5,267' RKB SLM. Mix FCO Fluids. Notification given to AOGCC of upcommg tes . """""` __._ 9/19/2008 00:00 - 9/20/2008 00:00 _ __ _ _ __ _ __ - _ ----- ---~- _ __ - ~ ~ _ Operations Summary MIRU CTU, test BOPE 250~si l_o_w/ 4000 psi high (witness waived by AOGCC Jim Regg) RIH clean out fill from 5054' to 5931'. Circ hole clean, POOH to 4980 and shut In well, Inlec- t a In o we or ~"HbTs' sf"ging up pump ra e o .5BPIVI @ 2100psi, POOH and secure well @ 0300hrs. --- - -- -- - 9/20/2008400:00 = 9/21/2008 00:00 _ _ Operations Summary PT 9-5/8" x 3-1/2" annulus to 2000 si for 30 minutes (good). Performed infectivity test down 3-1/2" tubing @ 2.5 BPM 1800 psi, 3.5 BPM @ 2600 psi. PU TT cemen re alner an ere Iner and erform in'ectivi test. Retainer not holdin POOH for slick line. MIRU slick line and retrieve faul cement retainer. _ - -- --- 9/21I2008 00, 0 - 9/22/2008 00;00 -_-- _ Operations Summary - Recover cement retainer; RD slick line. RU CTU w/2nd cement retainer, set retainer @ 4210', pertorm in'ectivity test @ .5 BPM 1000 psi, 1 BPM 1820 psi, 1.5 BPM 2800 psi, 2 BPM 4350 psi. Mix and pump 52 Bbls 15.8 ppg cemen w e o6~w Elie re~ne~4 afiove. Dress TOC to 4020' CBU & - -__-- -- 9/2212008' 00:00 - 9123!2008 00.00 _ _ _ _ _ _ __ _ _ Operations Summary - - _ - _ MIRU E-line /test 3-1/2" tubing to 2000 psi for 30 minutes (pressure test waived by AOGCC Jim Regg) 9/23/2008 00:00 - 9124120.08 00:00 _ _ _ _ _ _ _ _ _ _ _ Operatlons Summary RIH and tubing punch 3987' - 3993' pressure upon tbg to 3000 psi no communication with annulus. POOH. RIH and tubing punch 3942' - 3948' pressure upon tbg to 3000 psi with no communication with the annulus. POOH 9/24/2008 0 '00 =`9/25/200.8__ 00:00 _ - __ _ _ __ _ _ Operations Summary ~_ ~- RIH and tubin unch 3960' - 3966' break circulation and recover 115 Bbls of diesel from the annulus. POOH. RIH with cement retainer and set @ 3260' veri ability to circulate through. 9!23/2008.00:00_- 9/26!2008 00:00 - _ _ ____ _ _____ _ ~ _ Operations Summary Rig up cement head to well head above swab. Batch mix 64 Bbls of 15.8# LXT Cement. Puma 5 Bbls water ahead. 55 Bbls cement drop foam wiooer ball and displace with 28 Bbls of water bumped plug with 2,000 psi. Shut in annulus and bled WHP to 500 psi: cement in place @ 18:45 hrs. WOC 9/26/2008 00:00 - 9I27120Q~'OOc00 _ _ __ ______ ____ ___ Operations Summary Wait on cement and clean/prep site and equipment for demob - -- - - --- 9127/2008 00:00 - 9/28/2Q08 00:00 _ _ Operations Summary Test tubing to 3000psi, annulus to 2000psi, RIH with tubing cutter tagged @ 3015', POOH and RIH with CCL and 2 wt bars. Tag @ 3026' ,POOH and rerun u Ing cu er, cu u In a - Ine. ump s. wa er to displace well. Reverse 120 bbls diesel and allow to U-tube. Secure well and RDMO. 9/28/2008 00:00 - 9/29/2008 00:00 __ - - _ __ Operations Summary ~~ ~ Clean & backload equipment from Stump Lake location. 9/29/2008 00:00 - 9/30/2008 00:00 _ _ _ _ _ Operations Summary Continue work on Stump Lake Pad 9/3012008 00:00 -10/_1/2008 00 : 0 0 _ _ . _ __ __ _ _ _ _ _ __ _ Operations Summary _ _ ~ -~ -- Clean 65 Bbls from junk tank & Demobe off Stump Lake pad 10/1/2098 00:00 -10/2/2008 00:00 __ _ ____ -~ -~ Operations Summary Chevron Chevron -Alaska Weekly Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SLU 41-33 STUMP LK UNIT 41-33 ADL058790 5028320055 QB1675 39.37 _ - i Jobs Primary Job Type Job Category Objective Actual Start Date ActuaV End Date Well Preparation Major Rig Move Rig On, Pull Tubing, Set Whipstock. 2/14/2009 2/23/2009 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SLU 41-33 5028320055-00 1760860 Daily Operations 2/17/2009 00:00 - 2/18/2009 00:00 Operations Summary Clean and organize rig and yard. R/U circulating lines. Pump fresh water down 3-1/2", taking returns out the annulus. Diesel returns changed to water at 105 bbl away, pumped 120 bbls water total. Pump fresh water down 3-1/2", taking returns out the heater string. Pump total 5 bbls. Pump 4 bbl soap pill (Dirt Magnet) down heater string, follow w/ 6 bbl water. Pump 16 bbl soap pill down 3-1/2", taking returns out the annulus. Soak for 30 min. Continue down 3-1/2" out the annulus, total of 210 bbls pumped. Returns clean. Transport 140 bbl displaced fluid (diesel/water) to Lewis River D-pad. Set BPV in long string and heater string. N/D tree. Hanger threads OK. N/U BOPE. 2/18/2009 00:00 -2/19/2009 00:00 Operations Summary Continue N/U BOPE. AOGCC notified 07:40 2/17/09. Witness waived b Chuck Scheve. Test BOPE. Found several leaks during test. Chased down leaks and tightened connections. Test BOPE 250/4000 psi for min - tes a ut lower pipe rams and Upper IBOP. Could not get test joint to center across ram cavity. Able to open upper IBOP manually only, could not actuate w/ pneumatic controls. 2/19/2009 00:00 - 2/20/2009 00:00 Operations Summary Continue BOPE test. Could not get test of upper IBOP and lower pipe rams. Contact AOGCC (Chuck Scheve and Lou Grimaldi) and receive waiver to test failed components after testing casing and pulling tubing strings. UD test joint. Pull TWCs in Ion and heater strin s. R/U to test 9-5/8" caisn .Test to 2000 si for 15 min -test OK. Install BPV in Ion strip . R/U to ull heater strip .Pull and UD heater strip , 58 ' s tots . o pu ong s ring. P/U and pull 60k overpull on long string - no joy. R/U a-tine. Pull 15k overpull on tubing and set slips. RIH w/ R/ L. ag at 3045' WLM. POOH. M/U jet cutter. RIH nd make cut at 3023' WLM. Good indit:ation of cut. POOH. Confirmed jet cutter had fired downhole. Pull 80k ov r ull and tubin me free. UD hanger. UD long string, 93 full jts and 1 cut jt tota . 4 test assembly for BOPE. Wellbore has fresh water = 8.33 ppg. 2/20/2009 00:00 - 2/21 /2009 00:00 Operations Summary Test BOPE on 4" test assembl .Test annular, upper pipe rams, and lower pipe rams to 250/4000 psi for 5 mins -test OK. Could not get test to upper IB P. Remove upper IB an service top drive. Wellbore has fresh water = 8.33 ppg. 2/21/2009 00:00 - 2/22/2009 00:00 Operations Summary Service top drive. R/U and test upper IBOP to 250/4000 psi for 5 min -test OK. P/U mill assembly and HWDP. RIH w/ mills on 4" drillpipe t/2789'. Break circ. Wash down f/2789' t/3000', rotate at 35-40 rpm at 7 bpm. Stop rotation an tap tubing stub at 3018' MD. Change over fresh water to mud. POOH. UD mills. Rack back drillpipe. R/U wireline. RIH w/ bridge plug and tag tubing stub at 3012' WLM. P/U and locate collar at 2897' WLM. P/U 5' and sit bridge lug at 2892' WLM. POOH w/ setting tool. R/D wireline. Prep to N/D tubing head. MW = 9.8 ppg. 2/22/2009 00:00 - 2/23/2009 00:00 Operations Summary N/D tubin head. Dress 9-5/8" casin stub. N/U new casin s ool and BOPE. Test lower spool flange to 3000 psi -test OK. Change out upper IBOP. Test to 250/4000 psi for 5 min -test OK. Set test plug and shell test BOPE and upper spool flange to 250/4000 psi for 5 min -test OK. Pull test plug, set wear bushing. P/U whipstock assembly. Troubleshoot UBHO orienting sub. RIH w/ whipstock. P/U 6-1/2" drill collars. MW = 9.7 ppg. 2/23/2009 00:00 -2/24/2009 00:00 Operations Summary RIH w/ whipstock. Run gyro. Orient w/ rotary table. RIH t/ 2878'. Run gyro taking surveys between 317 and 324 deg azimuth. RIH w/ whipstock. Tag bridge plug at 2891' MD. Trip anchor. Pull 11 k overpull to verifty set. Set down 35k to shear whipstock retaining bolt. Mill lug off top of whipstock. Mill window in 9-5/8" 43.5# f/ 2867' t/2884'. Drill formation (/2884' t/2899'. Work mill assembly thru window, rotating and straight pull. No torque or drag~rllr formation f/2899' 02908'. Pump hi-vis sweep. R/U BJ cementers to perform FIT. Test lines to 2200 psi. Attempt to perform 11.0 ppg FIT 2 times w/o success. Perform LOT t/ 10.6 EMW w/ 9.3 mud and 200 psi surface pressure. Contact Lou Grimaldi and Tom Maunder w/ AOGCC. Reviewed LOT results and determine a 2nd L T/FIT is necessa on Ina anne o ml s o watermelon mill 60% worn. Upper watermelon mill in gauge. MW = 9.3 ppg. FW: SLU 41-33 -Update • • Page 1 of 1 Maunder, Thomas E (DOA) From: Barbee, Marcus [Consultant] [Marcus.Barbee@chevron.com] Sent: Tuesday, October 28, 2008 9:24 AM To: Maunder, Thomas E (DOA) Cc: Tyler, Steve L; Kanyer, Christopher V Subject: FW: SLU 41-33 -Update Attachments: Schematic_SLU 41-33_current 10-13-08.x1s; SLU 41-33 Daily Operational Summary.pdf Mr. Maunder, t~`o -~~(,o As per our phone conversation regarding Stump Lake Unit 41-33; here is an up ated schematic & operational summary depicting the state of suspension that the well is currently in. This well is awaiting final abandonment by the rig, scheduled in late January 2,009. If you have any questions please do not hesitate to call. «Schematic_SLU 41-33_current 10-13-08.x1s» «SLU 41-33 Daily Operational Summary.pdf» Here is the current schedule for Rig 129 on the West side: Ivan River 13-31 Workover 11/14/08 - 12/9/08 Ivan River 14-31 x Grass roots Well 12/10/08 - 1 /29/09 SLU 41-33RD Abandon & Redrill 1/30/09 - 3/4/09 ~~ " ~'bl ~~. ,~~ a~L.>~" 4/8/2009 • s __ ___ Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SLU 41-33 -- -- - _ STUMP LK UNIT 41-33 ADL058790 5028320055 061675 39.37 - - __ Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Abandon Well -Permanent Abandon Plug and Abandon, Prep well for Rig 9/17/2008 10/2/2008 Primary Wellbore Affected Wellbore UWf Well Permit Number SLU 41-33 5028320055-00 1760860 __ -- - Dail O erations 9117/2008 00:00 - 9118!2008 00:00 _ _ --- - _ _ - __ Operations Summary Move in & rig up pumping equipment and tanks 9/18/2008 00:00 - 9!19/2008 00:00 I _ _ _ _ _ - __ -- OperationsSummary - - - _-- Pumped 14 Bbls water down production tubing @ 2.5 BPM, pressured up to 4,000 psi. Drift tubing with 2.80" gauge ring to 5.267' RKB SLM. Mix FCO fluids 9119/2008 00:00 - 9!20/2008 00:00 _... Operations Summary -- - _ - - _ __ _._. -._... _ MIRU CTU, test BOPE 205 psi low/ 4000 psi high (witness waived by AOGCC Jim Regg) RIH clean out fill from 5054' to 5931'. Circ hole clean, POOH to 4980' and shut in well, inject water into well for 61 Bbls. staging up pump rate to 3.5 BPM @ 2100psi, POOH and secure well @ 0300hrs. 9/20/2008 00:00 - 9/21/2408 00:00 _ Operations Summary PT 9-5/8" x 3-1/2" annulus to 2000 psi for 30 minutes (good). Performed injectivity test down 3-1/2" tubing @ 2.5 BPM 1800 psi, 3.5 BPM @ 2600 psi. PU TTS cement retainer and RIH. Set retainer @ 4200' and perform injectivity test. Retainer not holding POOH for slick line. MIRU slick line and retrieve faulty cement retainer. 9/21/2008 00:00 - 9/22/2008 00 :00 -__ _ _ _ _ Operations Summary _ Recover cement retainer; RD slick line. RU CTU w/2nd cement retainer, set retainer @ 4210', perform injectivity test @ .5 BPM 1000 psi, 1 BPM 1820 psi, 1.5 BPM 2800 psi, 2 BPM 4350 psi. Mix and pump 52 Bbls 15.8 ppg LXT cement w/48 below the retainer & 4 above. Dress TOC to 4020' CBU & POOH __ - - _ __ 9/22/2008 00:00 - 9/23/2008 00:00 _ _ Operations Summary MIRU E-line /test 3-1/2" tubing to 2000 psi for 30 minutes (waived by AOGCC Jim Regg) 9/23/2008 00:00 - 9/24/2008 00:00 _ -- Operations Summary RIH and tubing punch 3987' - 3993' pressure upon tbg to 3000 psi no communication with annulus. POOH. RIH and tubing punch 3942' - 3948' pressure up on tbg to 3000 psi with no communication with the annulus. POOH '9/24/2008 00:00 - 9/25/2008 00:00 Operations Summary RIH and tubing punch 3960' - 3966', break circulation and recover 115 Bbls of diesel from the annulus. POOH. RIH with cement retainer and set @ 3260' & verify ability to circulate through. __ 9/25/2048 00:00 - 9/26/2008 00:00 _ Operations Summary Rig up cement head to well head above swab. Batch mix 64 Bbls of 15.8# LXT Cement. Pump 5 Bbls water ahead, 55 Bbls cement drop foam wipper ball and displace with 28 Bbls of water bumped plug with 2,000 psi. Shut in annulus and bled WHP to 500 psi. cement in place @ 18:45 hrs. WOC --- __ _ 9/26/2008 00:00 - 9/27/2008 00:00 Operations Summary Wait on cement and clean/prep site and equipment for demob .9/27/2008 00:00 - 9/28/2008 00:00 __ _ _ _ _ _ _ - ---. Operations Summary ~- Test tubing to 3000psi, annulus to 2000psi, RIH with tubing cutter tagged @ 3015', POOH and RIH with CCL and 2 wt bars. Tag @ 3026' ,POOH and rerun tubing cutter, cut tubing @ 3015' POOH abd R/D E-line. Pump 200bb1s. water to displace well. Reverse 120 bbls diesel and allow to U-tube. Secure well and RDMO. 8/2812008 00:00 - 9/29/2D08 00:00 Operations Summary Clean & backload equipment from Stump Lake location. _ 9/29/2008 00:00 - 9130/2008 00:00 Operations Summary Continue work on Stump Lake Pad 9/3D/2D48 00:00 - 10/1/2008 00:00 - - ~het~eons s~~mm~ry _ -- - - Clean 65 Bbls from junk tank & Demobe off Stump Lake pad .10/1/2008 00:00 - 10/2/2008 00:00 Operations Summary clll.nevron ORIGINAL RIG ELEVATIONS RKB-GL 14.00' RKB-MSL 39.37' 424' Csg 466.55' Bowl TOC @ 9610' 9.700' Csg 8-1 /2" open hole 11650' TD 141-33 Lake Unit FNL 8 495' FEL 33,T14N,R8W.SM to Drill#: 176-086 S Serial#: ADL-051 BTC-Mod Dale: 2/10!78 7:00 AM Suspendetl May 1978: WO Jan 1990; Comp Mar 199C Cmt Aug 1993: Reperf Aug 1996; Reperf Oct 2000; Reperf Oct 2004; SL Tag Jun 2007: SL Tag May 2008 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ / DATE: September 27, 2008 P. I. Supervisor I~~~ ZZ ~~1~~~~Q" FROM: Jeff Jones SUBJECT: P&A Petroleum Inspector SLU 41-33 Unocal ~ PTD-1760860 Stump Lake Unit September 27, 2008: I traveled to Unocal's Stump Lake Unit 41-33 well site on the west side of Cook Inlet to witness the pressure test and wire line tag of a cement plug for abandonment / re-drill of this well. Sam Menapace was the Chevron representative for the tests today. The calculated top of cement was 3260' MD and the Schlumberger slick line unit was only able to reach a depth of 3026' MD, where it tagged hard bottom with approximately 350 pounds of down weight. The tubing was then pressured up to 3000 PSI and the IA to 2000 and I noted no significant pressure drop during the 30-minute test. Summary: I witnessed a wire line tag and pressure test of a cement plug for ~ abandonment / re-drill of Unocal's well SLU 41-33. Attachments: N~ j~ ~~~~~~~~ ~'~,~-~- Non-Confidential P-A SLU 41-33 9-27-08 JJ.doc ,Uct 0'L 08 O'L:10p AOGCC NORTH SLOPE INSPECT 9076592717 • • North Slope Office: 659-2714 a • Nikiski Duty Station: T/6-5277 i o ~ e m, ,,~~ , ~ ; , ~? ~ ,0\2 ~~~ ~ To: Jim Regg Froea9: Jeff Janes Fax: 907-27&7542 Pages: 2 including cover p,1 P 907-793-1236 C1ate: 1012/2008 Re: SLIT 4.=33 P &A pressure test data D L3rgeeu# En For 9tevaewv ^ Please Coananeret ©Please FteEeiy ^ Please 6Zecycfe Hello Jim, Attached is the pressure test data from Stump Lake Unit 41-33 P&A. Thanks, Jeff Chevron ~~i~1~* SLU 41-33 P~i ~ ~'j(o °U~~ 2200941571 9-27-08 a o_ N O O N O U ~ ©Schlumberger 1994-2007 09:13:20 09:30:00 09:46:40 10:03:20 10:20:00 Time - hh:mm:ss r: Maunder, Thomas E (DOA) Page 1 of ~ n.~. From: Tyler, Steve L [tylersl@chevron.com] Sent: Monday, September 22, 2008 10:04 AM To: Maunder, Thomas E (DOA) Cc: Barbee, Marcus [Consultant]; Harness, Evan; Walsh, Chantal [Petrotechnical]; Kanyer, Christopher V; Bonnett, Nigel (NigeLBonnett); Brandenburg, Tim C Subject: RE: SLU 41-33 (176-086) - (Sundry #308-270) Update Forward plan is to tag TOC. Punch tbg. Set poppet valve retainer above tbg punch. Circulate/balance 60 bbls of cmt in tbg and tbg x csg annulus. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, September 22, 2008 9:32 AM To: Tyler, Steve L Cc: Barbee, Marcus [Consultant]; Harness, Evan; Walsh, Chantal [Petrotechnical]; Kanyer, Christopher V; Bonnett, Nigel (Nigel.Bonnett); Brandenburg, Tim C Subject: RE: SLU 41-33 (1?6-086) - (Sundry #308-270) Update Steve, ~~~J~~ ~~~ ~a 7Q~~ Thanks for the information. Is the 4000' TOC what was originally planned?? As I remember, the intent was to cement both the tubing and annulus. I look forward to your reply. Tom Maunder, PE AOGCC From: Tyler, Steve L [mailto:tylersl@chevron.com] Sent: Monday, September 22, 2008 9:24 AM To: Maunder, Thomas E (DOA) Cc: Barbee, Marcus [Consultant]; Harness, Evan; Walsh, Chantal [Petrotechnical]; Kanyer, Christopher V; Bonnett, Nigei (Nigel.Bonnett); Brandenburg, Tim C Subject: SLU 41-33 (Sundry #308-270) Update Tom Just to update you on where we are currently at on Stump Lake Unit # 41-33. • Coil cleaned out light sand bridges from 5054' to 5931' CTM (top perf @ 5921' DIL). Established injection rates @ 3.5 bpm @ 2100 psi down tbg. Pump 61 bbls. • Set back-up retainer Q 4210' CTM (1st retainer set failed). NOTE: Approved Sundry procedure depth for retainer was at 5800'. • Pumped/Inject 48 bbls of 15.8 cement below retainer. Lay-in 4 bbls of cement from retainer to 3900'. • Polished off top of cmt to 4020'. POOH. Currently Waiting on Cement. -. + Alaska Wellbore Maintenance Team Leader Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, AK 99501-3322 Office: (907) Z63-7649 9izzizoos _ _ Page 1 of ~~ • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, September 15, 2008 2:50 PM To: 'Ross, David A. [Petro Technical Resources of AK]' Subject: RE: SLU 41-33 (176-086) Program Revision r David, Sorry for the confusion. Unfortunately that can happen with multiple changes to a procedure. The change involves using retainers to more positively achieve the cement placements planned. Since you already have an approved sundry, it is acceptable to make this latest revision. Please note that any pressure tests planned should be for 30 minutes and charted. Call or message with any questions. Tom Maunder, PE AOGCC From: Ross, David A. [Petro Technical Resources of AK] [mailto:rossda@chevron.com] Sent: Tuesday, September 02, 2008 3:46 PM To: Maunder, Thomas E (DOA) Subject: SLU 41-33 Program Revision Tom, As per our conversation attached please find the revised work-over program for SLU 41-33. Sorry for the confusion, I thought I had sent this last Friday. I'll await to here from you regarding your decision as to whether or not we need to re-file. Regards, David Ross Ataska WeBbore Maintenance Team Chevron North America Exploration & Production (MCA) Office: (907) 283-7696 Cell: (281) 660-2493 Fax: (868)244-1439 Email: rossda~chevron.com ~~ S~~' ~ ~ 7~~~ From: Maunder, Thomas E (b0A) [mailto:tom.ma Sent: Thursday, August 28, 2008 7:57 AM To: Ross, David A. [Petro Technical Resources of AK] Subject: RE: PC4_injectivity_problem_050206.doc 9il sizoos Chevron • SLU 41-33 • API # 50-283-20055-00 P and A Procedure PTp 176-086 ADL - 058790 Objectives: Clean sand from production tubing to a depth adequate to achieve injection into the upper perforations; set retainer in tubing above top pert and squeeze cement below to abandon productive zones; cement production tubing and production casing above production packer; cut production tubing above top of cement; circulate freeze protect fluid and turn over to rig for side track Pressure Test Inner Annulus and Attempt to Displace Fill: Pump • Rig up to Tubing x Casing annulus and pressure test casing to 2000 psi Pump • Rig up to pump down tubing and attempt to displace fill in tubing to uncover sufficient perforations which would permit Infectivity • Verify fill depth with Slick -Line If successful: CTU Clean Out Contingency: CT • RU CTU and clean out well bore to below top perforation CTU Cement Abandondonment: CT • With CT @ 5800' establish a minimum injection with water of 2 BPM @ 1000 psi E-line •RIH and set retainer with slide valve @ 5800' above top perforation CT • RlH with CT and stab into retainer CT cement • Batch mix, pump and squeeze 50 Bbls of 15.8#Igal tXT cement below retainer to final pressure of 1500 psi • Sting out of retainer and lay in 100' of cement on top of retainer • Pull up to 5000' and circulate excess cement to surface until returns are clean • Shut-in CT x Tbg annulus and pressure test tubing to 1500 psi Punch Tubing Above Production Packer: E-line • Log to depth and tubing punch above production packer @ 4022' Pump • Establish circulation down production tubing with retums from production casing Cement Tubing x Casing Annulus E-line •RIH and set retainer with poppet valve @ 4000' above tubing punches and production packer Pump • Batch mix, pump and displace 48 Bbls of 15.8#/gal LXT cement below retainer and up tubing casing annulus • WOC & pressure test tubing and retainer to 3000 psi & casing plug to 2000 psi E-Line & pump: • RIH with tubing cutter / iog to depth and position cutter above TOC in annulus • Pressure up production tubing tq +-3,500 psi and open production casing to take returns at the surface • Cut tubing • Establish circulation down production tubing taking retums from the production casing circulate freeze protect fluids and tum over fluids to prep for RWO Procedure (rev2) 9-5/8" Csg "0" psi; Fluid level 0' after completion of work SLU tump Lake Unit h e~ rO n ~ ~ °'~ ~'~ Permit to DAII#: 176-088 Lease 8 Serfal#: ADL-058790 Field: Stum Lake Unit API#: 5428&20055-00 ORIGINAL RIG ELEVATIONS Surface Location: Well Classification: Develo ment Gas Well 773' FNL 8 495' FEL Total De the 11,850' Sec 33,T14N,R8W,SM pBTD: 3250' wttubin stub 3245' RKB•GL X: ASP4 375,769 Tubin 3'/:", 9.2#, N-80, BTGMOd 14.00' ~ V: ASP4 2,655,292 prod pkrs~ 3 9-5/8" Otis "VST" Wire line Set Pkr RKB-MSL Well Status: SI 39.37' Ocerator: Chevron Ownership: Chevron 100% 7T Csg 424' Csg 488.55' gowA 2,512' Csg 1805' Calc TOC 3,024' DV Collar 330 sx DV Collar 5800' Retainer 5921' TOC =_ 50 bbls J 1 2 3 4 _ 5 8 7 8 ~_ A'p 9 10 ~_ 11 12 ~_ 13 ^ 14 Q 15 1e 17 9^ 18 19 R-T 11 12 w A U-W B r1'~~i:r}: ry r i ~ C D 7,6os TOJ ~~~±:~ ~ E 7,841' TOC ~ ~ F 7,950' BP ~, G ,~~ Y H 8,443' TOC ' B I 8,583 TOL J K 8,88T Csg L M 9,380' BP _- - N = P AB O TOC (Bt 9610' R 9,700' Csg - S T U V 8-12" open hole V~ X 11850' TD Y Z a BHP: 1840 si 1434' Cmt Aue 1993; Reperf Aug 1998; Reped Oa 2000; Repert Oct 2004; SL Tag Jun 2007; SL Tag May 2008; P 8 A August 2009 510.0 ,NwN ry 8 RINI U ~~ scri ikon De th Lee-~.:> OD Baker SSSV w/ x" control line 311' 9-5/8" Casin Bowl Ada ter set over wt casin Aril, 197 8 466.55' - 935/8" DV Collar (gum 330 sx Gass G Cmt March, 197 8 3,024' 9-5/8" Otis VST packer set Februa , 1990 4,022' - Fluid Level (Found 531-2008 ) 2,200' Tubin Cement Retainer ~'~ -o >csetl' 5.800' Fill st CT Gean out 5.970' 9-5/8" Otis VST aaker set Februa , 1990 8,565' Otis XA slidin sleeve 2.813" ID Closed 8,580' - Carbide blast do s w/ a 5' ove rfap 8,585' Otis XA slidin sleeve 2.813" ID O n 6,710' 9-5/8" Otis VST aaker set Februa 1990 8,718' Otis X Ni le rofile 6,735' WLEG 6,739' - Fish: PNX lu 8 pron w/Misc Retainer'unk left Februa 1990 7,605' Fish: bit, bit sub, 3 - 6" drill collars 8 2 X-O's 8,345' Tubin Cement Retainer 4,000' Tubin cut ~'- 3,675' Tubin unch 48 (.37" holes (Pro osetl -4,012' Note: unable to locate hard c opy of the tubing detail for this well Psrt orstlona Zone Top Btm Amt Gun Size SPF Phase Status Date Beluga(r onek Belu a 5,921' 5,938' 17' 2.5 6 60 S zd 8/1/2008 Bel a 5,978' 5,991' 13' 2.5 6 60 S zd 8/112008 Belu a 6,010' 8,030' 20' 2.5 6 60 Sqzd 811/2008 Belu a 8,030' 8,045' 15' 2.5 6 80 S zd 8N/2008 Belu a 6,070' 6,098' 28' 2.5 6 60 S zd 811/2008 Belu a 6,176' 6,184' 8' 2.5 6 BO S zd 8/1/2008 Belu a 8,190' 8,196' 6' 2.5 8 80 S zd 811/2008 Belu a 6,210' 8,218' 6' 2.5 6 80 Sqzd 8/1/2008 Belu a 6,220' 8,234' 14' 2.5 8 80 Suui 811/2008 Belu a 6,241' 8,261' 20' 2.5 6 60 Sqzd 811@008 Belu a 8,284' 8,274' 10' 2.5 8 80 Sqzd 8/1/2008 Belu a 6,282' 6,310' 28' 2.5 8 80 S zd BH/2008 Belu 6,333' 6,353' 20' 2.5 8 80 Sqzd 8/112008 Belu a 8,369' 6,389' 20' 2.5 8 80 Sqzd 8/1/2008 Belu a 8,414' 6,430' 16' 2.5 8 80 S zd 811/2008 Belu 6,484' 6,502' 18' 2.5 8 60 S zd 8/1/2008 d 8,544' 8,554' 10' 4.5 4 90 S zd 5l78 DST#8 , Belu a 6,638' 8,844' 8' 4.5 4 90 S zd 8N/21108 Belu a 6,880' 6,685' S' 4.5 4 90 S zd 8/1/2008 Belu a 8,695' 6,705' 10' 4.5 4 90 S zd 811/2008 Belu a 8,740' 6,758' 18' 2.125 8 80 Iso 8/1/2008 Belu a 8,786' 8,790' 24' 2.125 8 80 Iso 81112008 Belu a 6,860' 6,878' 18' 2.5 8 80 Iso 8/1/2008 T onek 7,795' 7,833' 36' 4.5 4 90 Iso 4(/ DSTr14, T onek 8,160' 8,180' 20' 4.5 4 90 Iso 4/78 DST#3, T onek 9,230' 9,280' 30' 4.5 4 90 Iso 4!7 DST#2 , zd 9,488' 9,490' 2' 4.5 4 90 S zd 4l78 9-5/8" Csg "0" psi; 3-1/2" tbg "535" psi; Fluid level Lei Chevron [ F~ ORIGINAL RIG ELEVATIONS Su n se RKB-GL X: 14.00' Y: RK&MSL Wi 39.37 ~ Oc TOC ~ 9610' 9,700' Csg 8.1/2" open hole 11650' TD !00'; P TOF " SLU 41- ump Lake Unk c.!uai 33,T14N,R8W,SM as of 05-31-2008 Permit to Drib/: 776-086 Lease & SerialM: ADL-058790 I 2N 0/78 7:00 AM Suspended May 1978; WO Jan 1990; Comp Mer 1990 Cmt Aug 1993; Reperf Aug 1998; Reperf Oct 2000; Reperf Oct 2004; SL Tag Jun 2007; SL Tag May 2008 • • cc,~~dd SARAH PALI N, GOVERNOR °'~~ OI~ ~ t7[t>•.~7 333 W. 7th AVENUE, SUITE 100 COI~SERQATIOl~T COrII~iISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 w~ Re: Stump Lake Field, Undefined Gas Pool, SLU 41-33 Sundry Number: 308-270 Dear Mr. Brandenburg: k~~;~!)V1V~ AUi ~ ~ 2008 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~~ Chair DATED this ?- sday of August, 2008 Encl. - . ~, . <;~.~ STATE OF ALASKA ~~~~ AL OIL AND GAS CONSERVATI ~~)s @~ ~ ~v~~ ON COM~ION ~ APPLICATION FOR SUNDRY APPROVALS - < ~• °~ 1. Type of Request: Abandon^~ Suspend ^ Operational shutdown^ Perforate^ Waiver -~ Other^ Alter casing^ Repair well ^ ~ Plug Perforations^J Stimulate ^ Time Extension ^ Change approved progran^ Pull Tubing[ erferforate New Pool^ Re-enter Suspended Well^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 176-086 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 196247 Anchorage, AK 99519 50-283-20055-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q Stump Lk Unit (SLU) 41-33 " 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0058790 [Stump Lake] 39.37 Stump Lake /Beluga - 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,650' 11,650' 7,641' 7,641' 7,641', 7,950', 8,443', 9,360' 7,605' Casing Length Size MD TVD Burst Collapse Structural 77' 30" 77' 77' Conductor 424' 20" 424' 424' 1530 psi 520 psi Surface 2512' 13-3/8" 2512' 2512' 5380 psi 2670 psi Intermediate na na na na na na Production 8667' 9-5/8" 8667' 8667' 6330 psi 3810 psi Liner 1137' 7" 9700' 9,700' 11220 psi 8530 psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: 1 ~~~ ~ Tubing Grade: Tubing MD (ft): See attached schematic See attached schematic 3-1 /2" & 1-1/4"~ ' N-80 6733' & 2010' Packers and SSSV Type: Packers and SSSV MD (ft): (3) 9-5/8" Otis VST packers /Baker SSSV nipple profile 4022', 6565', 6716' / 311' 13. Attachments: Description Summary of Proposal ^/ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 8/10/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged Q Abandoned Q 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Barbee 263-7605 Printed Name Timothy Brandenburg Title Drilling Manager Signature _ ~-- Phone 276-7600 Date 7/28/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ~-~~~ ,~, `~~`~'1 ©~ Other: e l W~C~\~"~E ~V~~ SL '~~~ ~~~1`i~.~\J~~ ~~~~ ~~~ mor ~ 1 ~ ~y (~ a,~~ ,~ ~ ~ A - i ~,,,., yam. - R ~ r Subsequent Form Required: ~i _ ~ W ~ ~~ ~ ~~~ APPROVED BY ' Approved by: COMMISSIONER THE COMMISSION Date: L •• • ~..~ Form 10-403 Revised 06/2006 ~,i~~ Submit in Duplicate 0 R i G I NA L c~a,ti s ~F~ ~~~ ~ 2noB Page 1 of 2 • • Maunder, thomas E (DOAj From: PORHOI.A, STAN T [stan.porhola@chevron.com) Sent: Monday, August 25, 2008 9:11 AM To: Maunder, Thomas E (DOA) Cc: Tyler, Steve L, Ross, David A. [Petro Technical Resources of AK]; Barbee, Marcus [Consultant] Subject: RE: SLU 41-33 (176-086) Attachments: SLU 41-33 Procedure rev1.xls Tom, Attached is the revised procedure for Stump Lake 41-33, which now includes the rig work planned for this well with Nabors 129. Stan Porhola Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tef 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 Stan. porhola@chevron, com Mail Confrdential Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7640. From: Maunder, Thomas E (DOA) [mailtp:tom.maunder@alaska.gov] Sent: Friday, August 15, 2008 11:56 AM To: PORHOLA, STAN T; Tyler, Steve L Subject: FW: SLU 41-33 (176-086) Gentlemen, Could you have a look at this matter? Thanks, Tom From: Maunder, Thomas E (DOA) Sent: Sunday, August 03, 2008 11:20 AM To: Barbee, Marcus [Consultant] Subject: SLU 41-33 (176-086) 8/25/2008 Page 2 of 2 • • Marcus, As a follow-up to our message last week regarding the plug back work, by the convention used by the Commission the work to be authorized by the new drilling permit does not include the workover work to pull the tubing and other work prior to milling the window. I do not know if you have the rig selected, but if you could provide the workover part of the procedure then that can be included with this approval. Thanks, Tom Maunder, PE AOGCC 8/25/2008 Chevron • SLU 41-33 • API # 50-283-20055-00 P and A Procedure PTD 176-086 ADL - 058790 Objectives: • Remove sand from production tubing; Cement production tubing & casing from tubing tail to production packer; cement production tubing and production casing above production packer; cut production tubing above top of cement; circulate freeze protect fluid and tum over fluid for rig side track Pump truck and Slick -Line: • Attempt to pump fill back into perforations to a depth of 6739' • Verify fill depth with Slick -Line If successful: E-Line: • Log to depth and tubing punch above production packer @ 4022' • Establish circulation down production tubing with retums from production casing Cement mixer and pump: • Batch 100 Bbls of 15.8#lgal cement and pump 78 Bbls into formation with final squeeze pressure of 1500 psi • open retums from production casing and pump 22 Bbls cement and drop wiper plug • displace wiper plug with 33 Bbls of lease water • R1H with pressure temperature gauges 6 hours after cement is in place S`-~ • WOC 24 hours & pressure test tubing plug to 3000 psi & casing plug to 2000 psi ~~SCc.. ~S~s If unsuccessful pumping away sand into formation: S~o,J~ c~ ~ ~ CTU Contingency: ~`1 `_ ' - / CT • RU CTU and clean out well bore to 6739' ~~a~ E-line • log to depth and tubing punch above the production packer @ 4022' CT cement • Batch and pump 100 Bbls of 15.8#/gal IJCT cement and lay in 1:1 from 6739' to 3790' Gose in chokes and squeeze to final pressure of 1500 psi • open retums from production casing and pump remainder of cement holding 100 psi back pressure on the chokes Slick -line •RIH w/ pressure temperature gauges 6 hrs after cement is in place • WOC 24 hours & pressure test tubing plug to 3000 psi & casing plug to 2000 psi ~ESCc E-Line 8 pump: - • RIH with tubing cutter /log to depth and position cutter +- 5' above TOC in annulus • Pressure up production tubing to +-3,500 psi and open production casing to take retums ~ at the surface "-'-' • Shoot tubing cutter ~3 • Establish circulation down production tubing taking retums from the production casing circulate freeze protect fluids and tum over fluids to prep for RWO Nabors 128: • MI RU Nabors 129, NU and Test BOPs (Rig to mobilize late 2008/early 2009) • PU tubing hanger and pull cut tubing • MU and RIH w/ 7" casing scraper assembly to prep for running whipstock • RU slickline and run casing caliper tog above PBTD to surface • RU E-line and run 7" bridge plug and set at +/- 3000' RKB • MU and RIH w/ 7" whipstock assembly and mills • Set whipstock and orient. Begin milling window (well to be re-named SLU 41-33RD). Procedure (rev1) Chevron • SLU 41-33 • API # 50-283-20055-00 P and A Procedure PTD 176-086 ADL - 058790 Objectives: • Remo sand from production tubing; Cement production tubing & casing from tubing tail to production packer; ent production tubing and production casing above production packer; cut production tubing abo top of cement; circulate freeze protect fluid and turn over fluid for rig side track Pump truck and Slick - L • Attempt to pump back into perforations to a depth of 6739' • Verify fill depth wit lick -Line C ~+C C If successful ~.. E-Line: • Log to depth and tubing p~ • Establish circulation down Cement mixer and pump: production packer @ 4022' tubing with returns from production casing • Batch 100 Bbls of 15.8#/gal cement a pump 78 Bbls into formation with final squeeze pressure of 1500 psi • open returns from production casing and n • displace wiper plug with 33 Bbls of lease w • RIH with pressure temperature gauges 6 hou • WOC 24 hours & pressure test tubing plug to If unsuccessful pumping away sand into CTU Contingency: 22 Bbls cement and drop wiper plug after cement is in place ~0 psi & casing plug to 2000 psi CT • RU CTU and clean out well bore to 6739' E-line • log to depth and tubing punch above the produ n packer @ 4022' CT cement • Batch and pump 100 Bbls of 15.8#/gal LXT ceme and lay in 1:1 from 6739' to 3790' close in chokes and squeeze to final pressure of 1 psi • open returns from production casing and pump rema er of cement holding 100 psi back pressure on the chokes Slick -line • RIH w/ pressure temperature gauges 6 hrs after cement in place • WOC 24 hours & pressure test tubing plug to 3000 psi & ing plug to 2000 psi E-Line 8 pump: • RIH with tubing cutter /log to depth and position cutter +- 5' above TOC in nulus • Pressure up production tubing to +-3,500 psi and open production casing to a returns at the surface • Shoot tubing cutter • Establish circulation down production tubing taking returns from the production ca ' g circulate freeze protect fluids and turn over fluids to prep for RWO Procedure 9-518" Csg "0" psi; 3-1/2" tbg "535" psi; Fluid level 2,200'; HP ~ TOF "1,840" psi as of OS-31-2008 Chevron SLU 4 - Stump Lake Unit Permit to Drillq: 176-086 Actual Lease 8 Serial#: ADL-058790 ORIGINAL RIG ELEVATIONS RKB-GL 14.00' RK8-MSL 39.37 7T Csg ;_~~ ~~ [ 424' Csg 466.55' Bowl ~{-~~ 2,512' Csg 1805' Calc TOC 3,024' DV Collar 330 sx DV Collar 5086' T( 5878' Calc TOC 815 sx TOC ~ 9610' 9,700' Csg 8-1/2" open hole 11650' TD FNL & 495' FEL 33,T14N,R8W,SM Chevron 100q 2/10/78 7'.00 AM Suspended May 1978; VJO Jan 1990; Comp Mar 1990 Cmt Aug 1993; Reperf Aug 1998; Reperf Oct 2000; Reperf Oct 2004; SL Tag Jun 2007; SL Tag May 2008 9-5/8" Csg "0" psi; 3-1/2" tbg "0" psi; Fluid ~ Chevron ORIGINAL RIG ELEVATIONS RKB-GL 14.00' RKB-MSL 39.37' 7T Csg .-,. _',,~ . 424' Csg 466.55' Bowl 2,512' Csg 1805' Calc TOC 3,024' DV Collar 330 sx DV Collar 5086' Tf 5676' Calc TOC 815 sx TOC @9610' 9,700' Csg 8-1/2" open hole 11650' TD SLU 4~~.fStump Lake Unit ~~ Proposed ~~ ', to Drill#: 176-086 8 Serial#: ADL-058790 BHP'. 1840 5i 1434' Cmt Aug 1993; Repeif Aug 1996; Reperf Oct 2000; Repert Oct 2004; SL Tag Jun 2007; SL Tag May 2008, P 8 A August 2008 BHT: 75° F 3245' ~0 Descriotion Weioht Grade Conn ID Lenoth Too Btm TOC w:e ISec 33,T14N,R8W,SM pgTD: 3250' w/tubing stub CrD 3245' Page 1 of 2 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, August 01, 2008 3:01 PM To: 'Barbee, Marcus [Consultant]' Subject: RE: SLU 41-33 (176-086) Thanks Marcus. I had transposed a number in my volume calculation. With regard making the cut without the rig on location, most of the cuts I see done on the slope are without the rig there. However, all that is indicated in the procedure is "cut tubing at some depth". Maybe some pressure is held during those jobs as well. Best regards, Tom Maunder, PE AOGCC From: Barbee, Marcus [Consultant] [mailto:Marcus.Barbee@chevron.com] Sent: Friday, August Ol, 2008 2:36 PM To: Maunder, Thomas E (DOA) Subject: RE: SLU 41-33 (176-086) Tom, Thank you for looking at my procedure closely! My intended TOC in the Annulus is 3,702.43' which is 20 Bbls or 319.56' of cement. My intended TOC in the tubing is 3,792.10' which is 2 Bbls or 229.89' above the packer. 2. My intended tubing cut will be +-10' above TOC in the Annulus 3,690' 3. My calculations indicate 34.9769 (35)Bbls from surface to the intended tubing punch above the packer (using id2/1029.4*4022). This would allow me to achieve complete cement displacement into the formation and tubing below the packer and still allow for sufficient cement above the packer to meet regulations. By displacing with 33Bbls of water it should place my cement top in the tubing just under 100' below my cement top in the casing which would allow me enough room to locate the annular TOC with a temperature log. 4. It is more than likely not necessary to do this but the thought process here is to induce ballooning in the 3- 1/2" production tubing and force a tension effect at the point of cut. We would norma-ly place the tubing in tension when making a cut but without the rig on location it is the only way I could think of to accomplish this without actually pulling on the tubing. Please let me know if you have any more questions about our plans or intentions. Thank you, Marcus Barbee From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, August 01, 2008 10:34 AM To: Barbee, Marcus [Consultant] Subject: SLU 41-33 (176-086) Marcus, 1 am reviewing the sundry submitted for the plugging back for redritl and had some questions , _. 8/1/2008 Page 2 of 2 !- ! 1. Do you have an intended TOC in the tubing and annulus above the packer? I calculated that the 22 bbls intended to be above the tubing punches at 4022 if balanced in the annulus and tubing would fill to 3700' See further comments in 3 below. 2. Do you have an intended tubing cut depth? 3. Could you reconcile the cement and displacement volumes? Based on the information you have given, 1 calculated ~ 30.3 bbls tubing capacity from tubing to the intended punch at 4022'. If you are successful in pumping away the fill, you plan to pump 78 bbls below the punches (20.5 bbls in the tubing and ^~ 57 bbls into the formations) and then place the remaining 22 bbls in the 9-5f8" x 3-112" annulus by displacing with 33 bbls of water. The stated displacement volume (33 bbls) is in excess of volume 1 have calculated (30.3 bbls) and will result in totally displacing the cement into the annulus. 4. It is planned to cut the tubing holding 3500 ps'r on it. What is the thought process here? I have seen pressure held while cutting, however not 3500 psi. Thanks in advance. I look forward to your reply. Tom Maunder, PE AOGCC 8/1/2008 . . Chevron- III -----~--------- Kevin A. Tabler Manager, Land & Government Affairs MidContinent! Alaska Chevron North America __ Exploration and Production 909 West 9th Avenue P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7600 Fax 907 263 7698 Email tablerk@chevron.com February 13, 2007 Mr. Kevin Banks, Acting Director Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 800 Anchorage, AK 99501-3560 Sl(.;?\NNEIi fV1 Pr1{2 9 2007 STUMP LAKE UNIT AREA STATE OF ALASKA THIRTIETH PLAN OF DEVELOPMENT AND OPERATIONS \~<O~~Co , .~,? ,_ '. ,_....,.,J;::: ''0 Dear Mr. Banks: Pursuant to the current State of Alaska regulations governing submittal and approval of Unit Plan of Development and Operations, 11 AAC 83.343/11 AAC 83.346, Union Oil Company of California (Union), a Chevron company, as Unit Operator, submits the following as the Thirtieth Plan of Development and Operations for the Stump Lake Unit (SLU) Area: 1. PERIOD This Plan shall cover the period from May 15, 2007 to May 14, 2008. II. WORK REVIEW A. TWENTY-NINTH PLAN WORK Union has undertaken work requirements including the interpretation and integration of the newly available Chevron seismic and seismic interpretations, and legacy Union data and integrated this with net/gross values of the Beluga Formation from Beluga River Unit. These reinterpretations were integrated with the updated view of the production data and well logs. This work shows the remaining potential gas zones. Most of the remaining potential will require a new well or a re-drill of the current well. As a work product of the Twenty-ninth plan, Attachment 1 will provide the following items: o Structural contour maps on the key horizons (top Beluga and base Beluga Conglomerates, top Tyonek and an appropriate deep Tyonek marker) providing a structural frame work for the field. Union Oil Company of California I A Chevron Company http://www.chevron.com . . Mr. Kevin Banks, Acting Director ---February-!-3,z-007 Page 2 o Maps showing known extents of those hydrocarbon bearing sands that are likely to be economic (assuming no winter time operations) with estimates of hydrocarbon contacts in relation to PA and unit boundary, and explanation of basis for map; o Digital seismic data (None available) o Geologic well cross-sections through the other three West Side Units (IRU, PCU, LRU); o Oil and gas resource estimates of those objectives that are likely to be economic (assuming no winter time operations), including calculations accounting for past production of those objectives. B. THIRTIETH PLAN WORK During the Thirtieth plan period Union will evaluate installing a plug in Well SLU 41-33 to isolate the Upper Beluga perforations at 5921-6098' from the remaining open perforations in the well and flow test the well. If the flow test is successful, work will begin to evaluate the facility modifications that will be needed to return the well to production. Long Term Development Plan Beluga and Tyonek potential exists in the Stump Lake Unit, which is supported by the documents in Attachment 1. Development of the potential will require the side-tracking of Well SLU 41-33 and the possible drilling of a new well. ADF&G has restricted our drilling at Stump Lake Unit to the months of November through March. Due to the remote location of the gas fields on the west side of the Cook Inlet, a winter drilling program may strand a drilling rig on the west side for the winter. The economics of the development opportunities at Stump Lake Unit cannot support the added cost of winter time, remote location drilling, and the high cost of having a drilling rig and all its ancillary equipment on standby for months. If a large enough work program can be developed and we determine that it can be safely and economically implemented through the winter months, we may be able to overcome the added burden that the ADF&G work season restriction presents. Union is working on a west side drilling/workover program that would include project(s) at the Stump Lake Unit. Any drilling program on the west side of Cook Inlet must coordinate with drilling activity anticipated at other nearby west side fields. No one Unit alone can absorb the mob, demob and standby cost incurred by a stand alone operation. The largest gas field on the west side is the Beluga River Unit. It is anticipated that a rig will be mobilized to conduct in-field drilling activities in this Unit in the 2008/2009 timeframe, which would be the earliest that drilling activity is contemplated on the west side. With this activity, there may be an opportunity to utilize this rig in conjunction with other drilling activity on the west side. The timing of the Beluga Union Oil Company of California I A Chevron Company http://www.chevron.com . . Mr. Kevin Banks, Acting Director February 13, 2007 Page 3 River Unit drilling activity is expected to coincide with the Beluga River operator's market requirements. Regardless of the activity at the Beluga River Unit, Union's multi-well, multi-unit west side development program evaluation has a similar timing profile, e.g., planning will occur in 2007 with budgeting/drilling in 2008-2009. Market conditions will have the biggest influence and ultimately dictate drilling activity on the west side. Whether or not Agrium can secure a sufficient volume of gas to maintain seasonal operation of its Nitrogen Fertilizer Plant, the outcome of Marathon and ConocoPhillips LNG export license extension application and commitments to the unfilled utility markets are the market unknowns at this time. The range of possible outcomes of these events alone will have a significant influence and impact on the timing of any west side development thus, making long range commitment forecasting difficult at best to plan. III. PRODUCTION Production was initiated July 1990. Cumulative gas production through December 31, 2006 is as follows: Date Mo-Yr Gas Cum MMCF 12/31/90 12/31/91 12/31/92 12/31/93 12/31/94 12/31/95 12/31/96 12/31/97 12/31/98 12/31/99 12/31/00 12/31/01 12/31/02 12/31/03 12/31/04 12/31/05 12/31/05 528 2,135 3,639 4,417 4,871 5,159 5,345 5,476 5,557 5,611 5,642 5,643 5,643 5,643 5,643 5,643 5,643 IV. SURFACE AND FACILITY OPERATIONS A. FACILITIES No facilities were added during the Twenty-ninth plan period. A detailed plan to upgrade facilities will be initiated upon a successful economic test Union Oil Company of California I A Chevron Company http://www.chevron.com . . Mr. Kevin Banks, Acting Director February 13, 2007 Page 4 of the upper Beluga zone(s) being conducted within the Thirtieth plan period. B. ROADS/PAD/BRIDGES/CONSTRUCTION/REMEDIATION Union was notified by the Alaska Department of Environmental Conservation (Solid Waste Program) that all post closure water quality monitoring requirements for the Stump Lake 41-33 reserve pit had been met and no additional water quality monitoring was required. The Unit Operator respectfully requests the Department of Natural Resources to approve the foregoing as the Thirtieth Plan of Development and Operations for the Stump Lake Unit Area. Kevin A. Tabler Manager, Land & Government Affairs APPROVED: ALASKA DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas This day of , 2007 By: KAT:GAO:dma cc: Gary Orr, CVX Daniel T. Seamount, AOGCC Dave Whitacre, CVX Union Oil Company of California / A Chevron Company http://www.chevron.com ) ) Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com UNOCAL /7~-O ~c;, Debra Oudean G & G Technician Date: March 9, 2005 . To: AOGCC Helen Warman 333 W. 7th Ave. Ste#lOO Anchorage, AK 99501 STUMP LAKE 41-33 "STUMP LAKE 41-33)COMPLETION RECORD 2.5 HSD POWERJETS 6 SPF GAMMA RAY/CCL · . . : :: : · t ¡ " : · , . · . . · , . · .. . · , . ">:»»».w~»».."'f.~'«'O>"">>>"""'':''\\'I\\'>>>>>>>>>.>~.......,>>,-,,w>>>>x«>w>>>l.o,;>'>:.>>)>>>>~> ~NED JUN 2 '7 2005 rpi ,.,,11 .mum..~ 1 I.'. 1]. I I I Date: :3lt-> , STATE OF ALASKA ALAS.'bIL AND GAS CONSERVATION COMML )ON REPORT OF SUNDRY WELL OPERATIONS Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 0 .47 MMCFPD 170 BWPD 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: OilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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 7. KB Elevation (ft): 39' 8. Property Designation: Stump Lake 11. Present Well Condition Summary: Total Depth measured 11,660 feet true vertical 11,660 feet Effective Depth measured 7,605' feet true vertical 7,605' feet Casing Length Size Structural 77' 30" Conductor 424' 20" Surface 2,512' 13-3/8" Intermediate Production 8,667' 9-5/8" Liner 1 ,137' 7" Perforation depth: Measured depth: 5,921 to 9,528' True Vertical depth: 5,921 to 9,528' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenb~rg ,..---;; Signature? --aC ~ . "C~ Form 10-404;~ 0412004 ~ Plug Perforations U Perforate New Pool D Perforate 0 4. Current Well Class: Development 0 Stratigraphic D StimulateU Other U Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 76-1086-0 . - , .-_~ Service D 6. API Number: 50-283-2005500 9. Well Name and Number: SLU 41-33 10. Field/Pool(s): Stump Lake Field/Beluga Plugs (measured) 7,641' TOC, 7,950 BP, 8,443' TOC Junk (measured) 7,605',9,360 BP MD 77' 424' 2,512' TVD 77' 424' 2,512' Burst Collapse 1,530 psi 4,500 psi 520 psi 1,670 psi 8,667' 9,700' 8,667' 9,700' 8,700 11 ,220 psi 4,430 8,510 psi SCANNED DEC 2 720D4 3-1/2",9.2#, N-80 @ 6,739' RECEIVED DEC~ 2 ïOO4 Afaska Oil & GIS Cons. Commission DEC 2 3 2004 Anchorage See schematic n/a RBDMS BFL Tubing Pressure 450 Service D GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 304-386 Title Drilling Manager Phone 907-276-7600 Date 12/16/2004 0 RIG I N A LSubmit anginal Only ) UNOCAL 30" driven to 77' L 20", 94#, HAO @ 424" L Bowl adapter @ 490' 13-3/8",62#, N-89 @ 2,512'L DV collar @ 3,024' Retainer junk @ 7,605' 3 DCs and bit T~hnical Schematic Stump Lake 41-33 Completed as of 3/13/90 last revised 11/30/04 - DED ~, 3-1/2",9.2#, N-80 AB Modified 1. Baker SSSV @ 311' 2. Otis VST production packer @ 4,022' 3. Otis VST production packer @ 6,565' 4. Otis XA sliding sleeve @ 6,580' 5. Carbide blast rings with a 5' overlap 6. Otis XA sliding sleeve @ 6,710' 7. Otis VST production packer @ 6,716' wI Otis packer seal bore extension @ 6,730 8. Attempted jet cut @ 6,733' 9. Otis X nipple @ 6,735' 10. Wireline re-entry guide @ 6,739' 11. Heater string 1-1/4" CS Hydril @ 2,010' ~ 11 ~ - .2 5,921 to 5,938' perf 10/04 5,978 to 5,991' perf 10/04 6,010 to 6,045' perf 10104./ 6,070 to 6,090' squeezed 6,076 to 6,098' perf 10/04., 6, 176 - 6,184' 6,190 - 6,196' 6,210 - 6,216' 6,220 - 6,234' 6,241 - 6,261' 6,264 - 6,274' 6,282 - 6,310' 6,333 - 6,353' 6,369 - 6,389' 6,414 - 6,430' 6,484 - 6,502' 6,544 to 6,554' squeezed -.JII 3 5 6,636 to 6,644 6,680 to 6,685' 6,695 to 6,705' 7 L - 6,740 to 6,758' - 6,766 to 6,790' - 6,860 to 6,876' TOe @ 7,641' 7,795 to 7,833' Drillable BP @ 7,950' 8,160 to 8,180' TOe @ 8,443' 9,230 to 9,260 ~ Drillable BP @ 9,360' - 9,488 to 9,490' =I 9,518 to 9,528 squeezed ~ 9-5/8",43.5-47#, P-110 @ 8,667'L ì 7",29# liner, P-110 @ 8,563 to 9,700' PBTD: 7,541" TD: 11,660' RKB: 39', 0 degrees inclination .. .. 10/27/04 ) ) Rigged up and pressure tested 3000 psi. WIH with GRICCL and gun # 1 (22 ft). Tied in wI Schl. CBL 5/11/78. TP@ 2340 psi. Perforated 6076-6098 (22 feet). 2.5 HSD PJ, 6spf. POOH. TP@ 2355. WIH with GR/CCL and gun # 2 (15 foot). Tied in wI Schl. CBL 5/11/78. TP@ 2440 psi. Perforated 6030-6045 (15 foot). 2.5 HSD PJ, 6spf. POOH. 10/28/04 Picked up lubricator and stabbed on well with gun #3. WIH with GR/CCL and gun #3 (20') 2.5 HSD PJ, 6spf. TP@2440#. Tied in as before. Perforated 6010-6030 (20 feet). POOH. WIH with GRICCL and gun #4 (13') 2.5 HSD PJ, 6spf. TP@2445#. Tied in as before. Perforated 5978-5991 (13 feet). POOH. WIH with gun #5 (17') 2.5 HSD PJ, 6 spf. TP@ 2445. Tied in as before. Perforated 5921-5938 (17 feet). POOH. TP@ 2445 psi. POOH and rigging down. SLU 41-33 morning report summary, CONFIDENTIAL: last revised 12/16/2004, Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: 8,667' 9-5/8" 1,137' 7" Perforation Depth TVD (ft): 6,010 to 9,528' see schematic for detail , Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 39' 1. Type of Request: 8. Property Designation: Stump Lake 11 . Total Depth MD (ft): 11,660' Casing Structural Total Depth TVD (ft): 11,660' Length 77' Conductor Surface 424' 2,512' Intermediate Production Liner Perforation Depth MD (ft): 6,010 to 9,528' Packers and SSSV Type: /)~ k~é) /0/2((<7-- Suspend U Repair well 0 Pull Tubing 0 Perforate ~ Waiver U Annular Dispos. U Stimulate 0 Time Extension 0 Other 0 Re-enter Suspended Well 0 5. Permit to Drill Number: v/' Development Stratigraphic 0 0 Exploratory 0 76-0086-0 Service 0 6. API Number: v/ 50-2832005500 9. Well Name and Number: SLU 41-33 10. Field/Pools(s): Stump Lake Field/Beluga PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 7,641' 7,641' Plugs (measured): 7,641' Junk (measured): 7,605' Size MD TVD 77' 77' 424' 424' 2,512' 2,512' 8,667' 8,667' 9,700' 9,700' Burst Collapse 30" 20" 1,530 psi 4,500 psi 520 psi 1,670 psi 13-3/8" 8,700 4,430 11,220 psi 8,510 psi Tubing MD (ft): 6,733' see schematic for detail Tubing Size: 3-1/2" Tubing Grade: 9.2#, N-80 Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: 10/27/2004 Oil 0 Gas 0 Plugged WAG 0 GINJ 0 WINJ Abandoned WDSPL 0 0 0 Service D 0 0 Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Tim C. Brandenburg Title Drilling Manager , ~ Signature ~. C ~ c ~. " Phone Date p COMMISSION USE ONLY Contact Steve Tyler 263-7649 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Sundry Number: ';;0'-( - 3ð'~ Mechanical Integrity Test 0 Location Clearance 0 Other: ~\J~ ~\;jf:J 1\\\"- d~ , d<6-'\ I OCT 1 9 2004 Approved by: Form 10-403 RevisW2003 SCANNED OCT 2 7 2004 OR \ G \ N L BY ORDER OF Date to/£:~¥ I THE COMMISSION I - COMMISSIONER - SUbm=licate --- ~ONS ON REVERSE á~ ~ RE: Stump Lake 41-33--PTD 175-086 Subject: RE: Stump Lake 41-33--PTD 175-086 From: "Walsh, Chantal -Petrotechnical" <walshc@unoca1.com> Date: Wed, 20 Oct 2004 14:07:24 -0800 To: tom - maunder@admin.state.ak.us CC: "Tyler, Steve L" <tylersl@unoca1.com> Tom, You are correct on both counts. The following schematic includes the perforations added to the well in October of 2000. My apologies they were not on the original schematic submitted to you. The new proposed perforations will be shot through the casing and the tubing. The production packer providing isolation is above these perforations at 4022'. Please let me know if you have any additional questions or if we need to resubmit for this sundry. Thank you, Chantal Walsh PRA Engineer Unocal #263-7627 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, October 20 ,"""-2"Ö'O¡---"g: 41 AM ........-...... To: Steve Tyler Subject: Stump Lake 41-33--PTD 175-086 Steve, I am reviewing your perf proposal and was checking our well file. It appears that you will perforate the tubing as well as the casing, is that correct?? Based on the information in the file, it does not appear that your well drawing is correct. Unocal submitted a 404 in early January, 2001 which reports perforations not included on your drawing. The perforations you show were reported in Would you have a look at your file and let Thanks, Tom Maunder, PE AOGCC December, 1996. me know your assessment? , Content-Description: SLU41-33Schematic20041020.pdf . SLU41-33Schematic20041020.pdf Content-Type: application/octet-stream Content-Encoding: base64 1~1 SCANNED OCT 2 &1 2004- 10/20/20042:12 PM 30" driven to 77' L 20",94#, H-40 @ 424" L Bowl adapter @ 490' 13-3/8", 62#, N-89 @ 2,512'L DV collar @ 3,024' Retainer junk @ 7,605' 3 DCs and bit 9-5/8",43.5-47#, P-110 @ 8,667' 7",29# liner, P-110 @ 8,563 to 9,700' ..J, - 11 !IIIIIIIIIIIIII~ 4 I I I I ~ r 5 I î ~6 9_8 10 r----\ Technical Schematic Stump Lake 41-33 Completed as of 3/13/90 last revised 10/19/04 - DED ~ 3-1/2",9.2#, N-80 AB Modified 1. Baker SSSV @ 311' 2. Otis VST production packer @ 4,022' 3. Otis VST production packer @ 6,565' 4. Otis XA sliding sleeve @ 6,580' 5. Carbide blast rings with a 5' overlap 6. Otis XA sliding sleeve @ 6,710' 7. Otis VST production packer @ 6,716' w/ Otis packer seal bore extension @ 6,730 8. Attempted jet cut @ 6,733' 9. Otis X nipple @ 6,735' 10. Wireline re-entry guide @ 6,739' 11. Heater string 1-1/4" CS Hydril @ 2,010' ~ ~ 2 -- 6,010 to 6,020' squeezed =- 6,070 to 6,090' squeezed 6,176 - 6,184' 6,190 - 6,196' 6,210 - 6,216' 6,220 - 6,234' 6,241 - 6,261' 6,264 - 6,274' 6,282 - 6,310' 6,333 - 6,353' 6,369 - 6,389' 6,414 - 6,430' 6,484 - 6,502' 6,544 to 6,554' squeezed 3 6,636 to 6,644 6,680 to 6,685' 6,695 to 6,705' 7 == 6,740 to 6,758' 6,766 to 6,790' - 6,860 to 6,876' TOe @ 7,641' 7,795 to 7,833' Drillable BP @ 7,950' - 8,160 to 8,180' TOe @ 8,443' 9,230 to 9,260 /~ .', ~I ~ .~"~ '. Drillable BP @ 9,360' 9,488 to 9,490' =I 9,518 to 9,528 squeezed ~ L PBTD: 7,541" TD: 11,660' RKB: 39', 0 degrees inclination SCANNED OCT 2 7 2004 . ~ UNOCAL(; Technical Schematic Stump Lake 41-33 Completed as of 3/ŸG/90 last revised 10/19/04 - DE U, 30" driven to 77' L 20",94#, H-40 @ 424" L ~ ~ 1. Bake SSSV @ 311' 2. Oti ST production packer @ 4,022' 3. 0 s VST production packer @ 6,565' 4. tis XA sliding sleeve @ 6,580' 5 Carbide blast rings with a 5' overlap . Otis XA sliding sleeve @ 6,710' 7. Otis VST production packer @ 6,716' wI Otis packer seal bore extension @ 6,730 8. Attempted jet cut @ 6,733' 9. Otis X nipple @ 6,735' 10. Wireline re-entry guide @ 6,739' 11. Heater string 1-1/4" CS Hydril @ 2,010' Bowl adapter @ 490' 13-3/8",62#, N-89 @ 2,512'L DV collar @ 3,024' 11 - 6,010 to 6,020' squeezed 6,070 to 6,090' squeezed 6,544 to 6,554' squeezed 6,636 to 6,644 6,680 to 6,685' 6,695 to 6,705' 7 9 10 3 DCs and bit == 6,740 to 6,758' 6,766 to 6,790' - 6,860 to 6,876' TOe @ 7,641' 7,795 to 7,833' Drillable BP @ 7,950' - 8,160 to 8,180' TOe @ 8,443' 9,230 to 9,260 9-5/8", 4ti.5-47#, P-110 @ 8,667' /~ Drillable BP @ 9,360' -= 9,488 to 9,490' 9,518 to 9,528 squeezed 7",29# lin,ér, P-110 @ 8,563 to 9,700' L ~ PBTD: 7,541" TD: 11,660' RKB: 39', 0 degrees inclination SCANNED OCT 2 7 2,004 . '. SLU 41-33 Work Summary Perforate Shallow Beluga Sands . MIRU Slickline. Tag fill. RIH wi dummy gun. RD Slickline. . MIRU Eline. RIH wi 2-1/2"guns (HC, 6spf, 6Oophasing). . Perf Beluga sands 6076'md to 6098'md (GR log will determine DIL depth for perf). 6010'md to 6045'md 5978'md to 5991 'md 5921 'md to 5938'md . RD Eline. . Turn well over to production. SCANNED OCT 2 7 2004 RE: Stump ~ake 41-33--PTD 175-086 Subject: RE: Stump Lake 41-33--PTD 175-086 From: "Walsh, Chantal -Petrotechnical" <walshc@unoca1.com> Date: Wed, 20 Oct 2004 14:07:24 -0800 To: tom - maunder@admin.state.ak.us CC: "Tyler, Steve L" <tylersl@unoca1.com> Tom, You are correct on both counts. The following schematic includes the perforations added to the well in October of 2000. My apologies they were not on the original schematic submitted to you. The new proposed perforations will be shot through the casing and the tubing. The production packer providing isolation is above these perforations at 4022'. Please let me know if you have resubmit for this sundry. any additional questio " if ""'-~~ O~c:s ....~ "- f5)<:¿~ we need to Thank you, Chantal Walsh PRA Engineer Unocal #263-7627 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, October 20, 2004 9:41 AM To: Steve Tyler Subject: Stump Lake 41-33--PTD 175-086 ....--..~_._--_../ Steve, I am reviewing your perf proposal and was checking our well file. It appears that you will perforate the tubing as well as the casing, is that correct?? Based on the information in the file, it does not appear that your well drawing is correct. Unocal submitted a 404 in early January, 2001 which reports perforations not included on your drawing. The perforations you show were reported in Would you have a look at your file and let Thanks, Tom Maunder, PE AOGCC December, 1996. me know your assessment? .' Content-Description: SLU41-33Schematic20041020.pdf .:SLU41-33Schematic20041020.pdf. Content-Type: application/octet-stream Content-Encoding: base64 SCANNED OCT 2 '1 2.004 1 of 1 10/20/20042:12 PM ~1r~1rŒ lID~ {¡\ II f~\ ((0 n/7 1M ..\.. I',' .w,q ~"\ fir, ¡." ,1-01\,. '\\' /o-¿\ f ¡f"\J\ I ~ I rd n ¡ i i .\\\ f ¡---.", \ L ~W U ,~l w\...~t-! ~....í FRANK H. MURKOWSKI, GOVERNOR AIßASIiA. OIL AND GAS CONSERVATION COMMISSION 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: Stump Lake SLU 41-33 Sundry Number: 304-386 DearMr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. (~&/ ~uairman BY ORDER OF THE CO)1MISSION DATED this"" Jay of October, 2004 Encl. SCANNED OCT 2 7 2004 ~ í / FRANK MURKOWSKI GOVERNOR DEPT. OF ENVIRONMENTAL CONSERVATION DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM 410 WILLOUGHBY AVENUE JUNEAU, ALASKA 99508 http://www.state.ak.us/dec/deh Telephone: (907) 465-5153 Fax: (907) 465-5164 April 17, 2003 Laura Hammond Unocal Corporation PO Box 196247 Anchorage, Alaska 99519-6247 ~({"L\1I;.~If¡~:;:;'ìt\ ì !;2JU~D\::i'\Jb"""'~/ t ¡ , c. , t: Reference: Issuance of Permanent Closure Approval for Inactive Reserve Pits located at Lewis River 13-2 and Stump Lake 41-33 \ '\Co--O%G Dear Ms. Hammond: The Alaska Department of Environmental Conservation (ADEC) has completed review and public notice for pennanent closure approval of the inactive reserve pits located at the above reference sites located on the west side of Cook Inlet. The closure applications and corrective action plans provided the required infonnation describing the history and conditions of the reserve pits(s), results of required water sampling, an assessment of the potential risks posed by the drilling waste to human health and the environment as well as proposed corrective actions. Corrective actions are completed at these sites. The reserve pits at both sites were capped with gravel and overburden such that ponds will not develop in the capped area. Water quality monitoring will continue at these sites for three years in accordance with requirements of the Alaska Department of Fish and Game (ADF&G) under their Susitna Flats State Game Refuge management authority. ADEC has detennined that these sites present no material or probable risk to the public health or the environment. Public notice requesting comments on the closure requests was published March 7 and 8, 2003 in the Anchorage Daily News and posted on the state web site March 7, 2003. The Alaska Department of Fish and Game requested that we postpone closure until they inspect the revegetation success at the sites. They stated that if ADEC proceeds with closure approval, then ADF&G would continue with management of the sites under their refuge management authority and pennit stipulations. The ADEC closure requirements do not have a revegetation standard; ADEC has detennined that the reserve pits at these sites meet the closure requirements of 18 AAC 60.440. e e Ms. Laura Hammond Unocal Corporation April 17, 2003 Page 2 of3 Closure Approval Under authority of 18 AAC 60.440 (j), ADEC grants pennanent closure approval to Unocal for the inactive reserve pits at the following sites: Well Name API Number MTRS Landowner Lewis River 13-2 50-283-20011-00 Section 02 T14N, R09W, SM DNRJADF&G Stump Lake 41-33 50-283-20055-00 Section 33, T14N, R08W SM DNRJADF&G Terms and Conditions This pennanent closure approval is subject to the following tenns and conditions: 1) In accordance with 18 AAC 60.440(1), the Department will require additional investigation, assessment, monitoring or remediation if new infonnation regarding conditions at the reserve pit facilities indicates that further actions are necessary to protect human health or the environment. 2) The approval granted by this letter is for the inactive drilling waste reserve pit(s) only. Closure for the pad as a whole (if required) must be coordinated between the owner/operator and the appropriate land owner/manager. Any person who disagrees with this decision may request an adjudicatory hearing in accordance with 18 AAC 15.195- 18 AAC 15.340 or an infonnal review by the Division Director in accordance with 18 AAC 15.185. Infonnal review requests must be delivered to the Division Director, 555 Cordova, Anchorage, Alaska, 99501 within 15 days of the pennit decision. Adjudicatory hearing requests must be delivered to the Commissioner of the Department of Environmental Conservation, 410 Willoughby Avenue, Suite 303, Juneau, Alaska 99801, within 30 days of the pennit decision. If a hearing is not requested within 30 days, the right to appeal is waived. Sincerely, ELECTRONICALLY TRANSMITTED Glenn Miller Solid Waste Program Manager Glenn _ Miller@dec.state.ak.us cc: electronic only Tom Maunder, AOGCC, Anchorage (Tom_Maunder@admin.state.akus) Bruce Webb, ADNR, O&G Division, Anchorage (Bruce_ Webb@dnr.state.akus) Kaye Laughlin, DGC, Anchorage (klaughli@jpo.doi.gov) e e Ms. Laura Hammond Unocal Corporation April 17,2003 Page 3 of3 Linda Nuechterlein, ADEC, Anchorage (Linda_Nuechterlein@dec.state.ak.us) Wayne Dolezal, ADF&G, Anchorage (Wayne_Dolezal@fishgame.state.ak.us) Unocal Corporation P,O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager 12/O7/0O Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Stump Lake Unit Well SLU 41-33 APl No. 50-283-20055-00 10-404 Perforate Beluga Zone Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the Beluga zone in well SLU 41-33. The following intervals were perforated on 10/9/00: Bench Top Bottom Feet Beluga 6176 6184 8 Beluga 6190 6196 6 Beluga 6210 6216 6 Beluga 6220 6234 14 Beluga 6241 6261 20 Beluga 6264 6274 10 Beluga 6282 6310 28 Beluga 6333 6353 20 Beluga 6369 6389 20 Beluga 6414 6430 16 Beluga 6484 6502 18 Total: 166 If you have any questions, please contact Ralph Holman at 263-7838. Drilling Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C JMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 39.37' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Stump Lake P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 733' SNL, 495' WEL of Sec. 33, T14N, R8W, SM 41-33 At top of productive interval 9. Permit number/approval number Straight hole 76-86 At effective depth 10. APl number Straight hole 50-283-20055-00 At total depth 11. Field/Pool Straight hole Stump Lake Field 12. Present well condition summary Total depth: measured 11650 feet Plugs (measured) 7641 true vertical 11650 feet Effective depth: measured 7641 feet Junk (measured) 7605 true vertical 7641 feet Casing Length Size Cemented Measured depth True vertical depth Structural 77' 30" Driven 77' 77' Conductor Surface 424' 20" 540 sx 424' 424' Intermediate 2512' 13-3/8" 2050 sx 2512' 2512' Production 8677' 9-5/8" 1115 sx 8667' 8667' Liner 8563' 7" 335 sx 8563'-9700' 8563'-9700' Perforation depth: measured 6176-6184, 6190-6196, 6210-6216, 6220-6234, 6241-6261, 6264-6274, 6282-6310, 6333-6353, 6369-6389, 6414-6430, 6484-6502, 6636-6644, 6680-6685, 6695-6705, 6740-6758, 6766-6790, 6860-6876 true vertical Same (Straight hole) Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 buttress, AB-modified to 6739' Packers and SSSV (type and measured depth) Baker SSSV @ 311', Otis VST packers @ 4022', 6565' & 6716' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 110 0 0 1080 Subsequent to operation 0 0 0 0 1420 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~_,,~,~J(~tle: ~//q[~~///~~ Date: /~"~~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICAT,~ ...... STATE OF ALASKA --' ALASKA O,,_ AND GAS CONSERVATION ~OMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: x Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X 39.37 feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Stump Lake 4. Location of well at surface 8. Well number 733' SNL and 495' WEL of Sec. 33, T14N, R8W, SM 41-33 At top of productive interval 9. Permit number/approval number 76-86 At effective depth 10. APl number Straight Hole 50- 283-20055-00 At total depth 11. Field/Pool Stump Lake Field 12. Present well condition summary Total depth: measured 11650' feet Plugs (measured) 7641' true vertical 11650' feet Effective depth: measured 7641' feet Junk (measured) 7605' true vertical 7641 feet Casing Length Size Cemented Measured depth True vertical depth Structural 77" 30" Driven 77' 77' Conductor Surface 424' 20" 540 sxs 424' 424' Intermediate 2512' 13-3/8" 2050 sxs 2512' 2512' Production 8677' 9-5/8" 1115 sxs 8667' 8667' Liner 8563' 7" 335 sx 8563'-9700' 8563'-9700' Perforation depth: measured 6636-6644, 6680-6685; 6695-6705; 6740-6758; 6766-6790; 6860-6867 true vertical Same on 7/3/96 reperf'd 3 intervals See attached for details Tubing (size, grade, and measured depth) 3-1/2", 9.2'~, N-80 buttress, AB-modified to 6739' 0RIOI J, L Packers and SSSV (type and measured depth) Baker SSSV @ 311' Otis VST packers @ 4022', 6565', 6716' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 6~96 0 455 0 0 0 Subsequent to operation 8/96 0 482 0 0 0 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: ,X, Suspended: Service: lnject~ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: RE6E~VE0 r'--'- 0 4 1996 /~ Oi~ & G-~s Con~. commission Signed: Dale Haines . ~, ~ i Cb,J,- Title: Drilling ManagerAl'3$k~ AllOhOr~gO Date: November 26, 1996 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Spud: 2 10 7a La.,t Work Over: 5/15/90 SLU 41-,55 Slump Lake Field APl No.: 50-28d-20J.u,~,-O0 Top of Prod' Ft, MD Ang e @ Parrs: Degs. Hanger: 6010,0 - 6020.0' SQUEEZE PERFS Sqz'd 5/8/78 6070,0 - 6090.0' SQUEEZE PERFS Sqz'd 5/9/78 0.0 - 6427.2' 9 5/8cm OD 45,50#/ft P-110 PROD CSG 6544.0 - 6554.0' SQUEEZE PERFS Sqz'd 5/7/78 6945.0 - 6960.0' PERFS Potential Beluga 17' RECEIVED Alaska Oil & Gas Cons. Comm!ssio~ '~ '~ 1' n ,..,,rtuho. -~c:c.O ,;bL~5. ' ' '" /uuu - u' FluL.,/,~u/¢ i Taggea_ Fill -~-. xa, .., ,~, ~,,. fl., - 7605.0' FILL,.,,,~/°x, =~,..,/ao~= Tagged ?,¢'"~,/~ 1 ,...' ~"?" Sar. , ,~, ~ ,¢,. ~ : ~ . ~. ~ ,.. ~ ¢ 764i.0- 7950.0' CEMENT PLU,3 ! KB ELEV: 3,~.o,, PBTD: 7641' TD' 11650' 6754.6 - 6756.n'~,, 6716.0 - 6729.8' 6579.2 - 6579,9' 19.9 - 6758,1' 6577,5- 6577.9' 6565.8 - 6577,5' 6565.5 - 6579.2' ~?,9 - , ,7' 6os .... 8 6,595 2.75cm ID LANDING NIPPLE Otis X RETRV. PACKER O[is VST #1 Pkr. CROSSOVER SBE x .5 1/2" Butt Pin 5.500cm OD g.20#/ft N-80 TB6 L. STRING MULESHOE Otis 5.88cm OD 2.ggcm ID SEALS Otis RETRV. PACKER Or. is VST #2 Pkr. I --~ S~_EE?E Otis XA 6656.0 - 6644.0' PERFS 66-4, 8HPF, 8', 5/78, 1/51/90 6680,0 - 6685.0 6695,0 - 6705,0 674_0.0.- 6758,0' 6740.0-6758.0' 6766,0-6790.0' 6860.0-6876.0' ___6_a6_,0.0 -~_ 6876.0' 6651.0-6649.0' 6675.0-6/80.0 ~71~, ~, - 672~ 6' 6729.8 - 67.50,? 6755.0 - 675.5.0' 0/oo.i-~,~,/ .... ~x., ' PERFS 66-8, 8HPF, 5', 5/78, 1/28/90 ' PERFS 66-8, 8HPF, 10', 5.,/78, I//28/90 PERFS 67-4, 8HPF, 18', 4/78, 1/36/'90 PERFS 67-4, 4HPF, 24', 1/26//90 PERFS 68-6, 8HPF, 16', 4/78, 1/26/90 ~ / "' I ~ ' I ' PERFS 68-6, ;/5, 95 6HPF, 16, z I~2 Ener et ......... BLAST JOINT Carbide Protected Blast Rings BLAST JOINT Carbide Protected Bias! Rings ,, -.¢ -,, ~ ~ 5.88cm OD '2.990m ID SEALS Otis 5.8cmOD ? qgcm ID r,p, ncq(-~x,,,rn~ SBE x Butt ¢2i2t;7 HOLE Attempted ,Jet Cut 5.75cm nD ? 99~'' -~s: ..... dLIll',~i ~..'L~3 xe-Fq!rv ,~/., ~. · .... Oas We!! Beluga Datum' .00' MD' .00' TVD; 6741.00' SS .... STATE O F ALAS KA --" · AI~, , OIL AND GAS CONSERVATION COMb. ION REPORTOF SUNDRY WELL OPERATIONS I i Perforate 1. Operations performed: Operation shutdown Stimulate P ugg ng Pull tub!'ng Alter'--~aslng' __ --'~epalr' well __X -- Pull tubing' __ -- Other__ 2. Name of Operator 15. Type of Well: 6. Datum elevation (DF or I × UNION OIL COMPANY OF CALIFORNIA (UNOCAL) I Exploratory m 39.37' 3. Address I Stratigraphic-- 7. Unit or Property name P.O. BOX 196247 ANCHORAGE, AK 99519 I Service -- STUMP LAKE , Location of well at surface T14 N, R8W, SM At top of productive interval 733' SNL AND 495' WEL OF SEC. 33 At effective depth STRAIGHT HOLE At total depth 8. Well number 41-33 9. Permit number/approval number 76 -86 10. APl number 50-283 -20055 11. Field/Pool STUMP LAKE FIELD 12. Present well condition summary Total depth: measu'ed true vertical 11,650' 11,650' feet Plugs (measured) feet Effective depth: measured 7,641' feet Junk (measured) true vertical 7,641' feet Casing Length Size Cemented Measured depth True vertical depth Structural 77' 30" DRIVEN 77' 77' Conductor Surface 424' 20" 540 SXS 424' 424' Intermediate 2512' 13-3/8" 2050 SXS 2512' 2512' Production 8677' 9-5/8" 1115 SXS 8667' 8667' Liner 8563' 7" 335 SXS 8563'-9700' 8563'-9700' Per~oration depth: measured true vertical SEE ATTACHED 13. Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 BU'I-I'RESS, AB-MODIFIED Packers and SSSV (type and measured depth) BAKER SSSV @ 311' OTISVST PACKERS @ 4022', 6565', 6716' Stimulation or cement squeeze summary Intervals treated (measured) SEE ATTACHED HISTORY Treatment description including volumes used and final pressure I~E~Ei v LL~ $ E P - B 199;5 Alaska Oil & Gas Cons. CommissiO~ Anchorage 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure NO CHANGE Tubing Pressure Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily~eport of Well Operations X_ 17. I herel~c~ruetl Signed G. RUSSELL SCHMIDT 16. Status of well classification as: Oil __ Gas X_ Suspended __ Service and correct to the best of my knowledge. Title DRILLING MANAGER Date 9-1-93 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE WELL HISTORY STUMP LAKE 41-33 8-16-93 8-17-93 MOVED DOWELL CEMENT UNIT, BATCH MIXER, CEMENT SILOS AND WATER TANKS TO LOCATION. RIGGED UP TO THE SHORT STRING. PRESSURE TESTED LINES TO 2500 PSI. UNABLE TO PRESSURE TESTANNULUS DUE TO LEAK IN WING VALVE. SHUT DOWN FOR NIGHT. RIGGED UP TO THE 13-3/8" x 9-5/8" ANNULUS. ESTABLISHED INJECTIVITY WITH 20 BBLS OF WATER, 110 PSI AT 2 BBLS/MIN. PUMPED 120 BBLS OF 15.8 PPG CLASS 'G' CEMENT WITH NO ADDITIVES. INITIAL PRESSURE 110 PSI AND FINAL PRESSURE 670 PSI AT 2 BBLS/MIN. MONITORED THE 9-5/8" x TUBING ANNULUS DURING THE ENTIRE JOB WITH NO INDICATIONS OF PRESSURE. RIGGED DOWN AND MOVED OFF LOCATION. RECEIVED S E P - 't99; Aia~k~ Oil & Gas Cons. OommJss~Oi~ Anchorage STUMP LAKE 41-33 30" Driven to 77' 20" 94# @ 424' Bowl adaptor @ 490' 13-3/8" 62# @ 2512' "DV" Collar @ 3024' · 0 DEG. INCLINATION Retainer Junk @ 7605' 3 D.C.'S & BIT 9-5/8" 43.5-47# @ 8667' 7" 29# liner 8563'-9700' 1. 2. 4. 5. 6. 7. 3-1/2' 9.2# N-80 AB-MODIFIED BAKER SUB-SURFACE SAFETY VALVE AT 311' OTIS VST PRODUCTION PACKER 4022' ' OTIS VST PRODUCTION PACKER AT 6565' OTIS XA SLIDING SLEEVE AT 6580' CARBIDE BLAST RINGS WITH A 5' OVERLAP OTIS XA SLIDING SLEEVE AT 6710' ORIS VST PRODUCTION PACKER AT 6716' 8. OTIS PACKER SEAL BORE EXTENSION AT 6730' 9. A'i-I'EMPTED JET CUT AT 6733' 10. OTIS X NIPPLE AT 6735' 11. WIRELINE RE-ENTRY GUIDE AT 6739' a. HEATER STRING 1 1/4" CS HYDRIL AT 2010' 6010'-6020' SQZ'D 6070'-6090' SQZ'D 6544'-6554' SQZ'D 3 6636'-6644' 6680'-6685' 6695'-6705' 6740'-6758' 6766'-~790' 6860'-6876' Top of cement @ 7641'. 8160-8180 '~ ii'" ~ ~'~" Top ~f cement m ~3' Drillable B.P. ~ 9360' Anchorage 9488'-~' 9518'-9528' SQZ'D GRB 1~/92 APPLICAI'ION FOR SUNDRY APPROVALS 1. Type of request: Abandon__ Suspend __ Operations shutdown Alter casing__ Repair well X_ Plugging __ Change approved program Pull tubing Variance 2, Name of Operator "' 15. T~e of Well: -- ! Development X UNION OIL COMPANY OF CALIFORNIA (UNqCAL) Execrate./ 3. Address / Stratig raphic P.O. BOX 196247 ANCHORAGE, AK 99519 ~ se~e 4. Location ofwell at surface733' SNL and 495'wEL of Sec. 33 T14N, R8W, S.M. At top of productive interval RECEIVED At effective depth Straight hole At total depth 12. Present well condition summary Total depth: measured true vertical 11,650' 11,65O' Re-enter suspended well Time extension Stimulate Perforate Other 6. Datum elevation (DF or KB) 0CT 2 6 1992 Nasl~3_ 0il & Gas Cons. 60mm'tssi0o feet feet 39.37' 7. Unit or Property name Stump Lake 8. Well number 41 -33 9. Permit number 76-86 10. APl number 50-283-20055 11. Field/Pool Stump Lake Field Plugs (measured) See Schematic Effective depth: measured 7,641' feet true vertical 7,641' feet Junk (measured) Retainer Junk 7605' Casing Length Size Cemented Measured depth True vertical depth Structural 77' 30" Driven 77' 77' Conductor Surface 424' 20" 540 sxs 424' 424' Intermediate 2512' 13-- 3/8" 2050 SXS 2512' 2512' Production 8677' 9-- 5/8" 1115 SXS 8667' 8667' Liner 8563' 7" 335 SXS 8563'-- 9700' 8563'-- 9700' Perforation depth: measured true vertical See attached feet Tubing (size, grade, and measured depth) 3--1/2", 9.2#, N-80 buttress, AB-modified Packers and SSSV (type and measured depth)Baker SSSV @ 311' Otis VST packers @ 4022', 6565', 6716' 13. Attachments Description summary of proposal __ Detailed operations programX__ BOP sketch __ 14. Estimated date for commencing operation 115. Upon approval 16. If proposal was verbally approved Oil __ Gas X_ Name of approver Date approved Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Gary S. Bush (,.~ ~, (~,.~,.~Title Regional Drilling Manager /~ d'~ FOR COMMISSION USE ONLY Conditions of approval: Notity C~m~ssion so representative may witness Plug Integrity __ BOP Test Location clearance Mechanical Integrity Test__ Subsequent form required 10- '~7'o ~' Approved by the order of the Commission Form 10-403 Rev 06/15/88 Status of well classification as: Suspended 0RI~INAL SIGNED BY ,,~,e~m I A_ DOUGLASS Date Approval No. - CS~rnmissioner Date// SUBMIT IN TRIPLICATE STUMP LAKE 41-33 ANNULUS ISOLATION PROCEDURE 1. Shut in the gas production from the 2-7/8" tubing and close the master valve. 2. Shut in the 1-1/4" heater string. Rig up to the 9-5/8" x tubing annulus. 3. Pressure test the 9-5/8" casing and the OTIS VST packer at 4022' to 1500 psi for 30 min. 4. Rig up a cement unit to the 9-5/8" x 13-3/8" annulus. 5. Establish injection with +/- 20 bbls of water. 6. Pump 156 bbls of Class 'G' cement down the annulus at +/- 2 bbl/min. The 156 bbls is enough to fill the 9-5/8" x 13-3/8" annulus with cement to 2512'. Monitor the pressure on the casing tubing annulus. Pump pressures are not to exceed 2470 psi (80% of the burst rating of the 13-3/8" casing). If the pressure builds up above 1000 psi, the pressure is not to be bled off quickly, bleed it off over a period of at least 10 minutes. If cement returns are seen at surface cease pumping cement. 7. Rig up to the 9-5/8" x tubing annulus. 8. Pressure test the 9-5/8" casing and the OTIS VST packer at 4022' to 1500 psi for 30 min. 9. Rig down the cementing unit 10. Return the well to production. RECEIVED OCT 2 6 1992 Alaska Oil & Gas Cons. 8ommission Anchorage STU M P LAKE 41-33 COMPLETION AS OF 3/13/90 30" Driven to 77' 20" 94# @ 424' Bowl adaptor @ 490' 13-3/8" 62# @ 2512' "DV" Collar @ 3024' 3-1/2" 9,2# N-80 AB-MODIFIED 1. BAKER SUB-SURFACE SAFETY VALVE AT 311' 2. OTIS VST PRODUCTION PACKER 4022' 3, OTIS VST PRODUCTION PACKER AT 6565' 4. OTIS XA SLIDING SLEEVE AT 6580' 5. CARBIDE BLAST RINGS WITH A 5' OVERLAP 6. OTIS XA SLIDING SLEEVE AT 6710' 7. ORIS VST PRODUCTION PACKER AT 6716' 8. OTIS PACKER SEAL BORE EXTENSION AT 6730' 9. A'I-I'EMPTED JET CUT AT 6733' 10. OTIS X NIPPLE AT 6735' 11. WIRELINE RE-ENTRY GUIDE AT 6739' A. HEATER STRING 1 1/4" CS HYDRILAT 2010' 0 DEG. INCLINATION Retainer Junk @ 7605' 3 D.C.'S & BIT 9-5/8" 43.5-47# @ 8667' 7" 29# liner 8563'-9700' J 6010'-6020' 6070'-6090' 6544'-6554' 3 6636'-6644' 6680'-6685' 6695'-6705' 7 6740'-6758' 6766'-6790' 6860'-6876' SQZ'D SQZ'D SQZ'D Top of cement @ 7641' 7795'-7833' _ Drillable B.P. @ 7950' / ~,~-,60'-8~0' ~.~~~~'~ Top of cement at8443' k,'~",,,~~[: 9230'-9260' ~ Drillable B.P. @ 9360' 9488'-9490' 9518'-9528' SQZ'D RECEIVED OCT 2 6 1992 Alaska 0il & Gas Cons. 6ommissioi~ Anchorage GRB 1/7/92 emorandum Stale of Alaska To: David W. Joln~st_;~_R~...~....... flt.~,~ ate: October 21 1992 Telephone: 279-1433 From.' Sr. Petroleum Engineer Fax number: 276-7542 Subject: Cement Volumes for Stump Lake 41-3 3 Well Calculated cement volumes for Stump Lake 41-33 were 696 cf for the 20" cm~ductor casing set at 424' ( Vol Used 1118 cf)and .1758 ct' for the 13 3/8" surface casing at 2512' ( Vol Used 2666 cf). CMculafions indicate that a sufficient quantity of cement was used to fill annular space to the surface. The cement volmnes were mpoRed on the 3/7/78 Monthly Report Of Drilling And Workover Operations (copy included.) but as stated on the report, there were no cement returns on either string of casing and additional cement was placed in annulus from the surface (top job). The top job quantifies were included in Volume Used quantity and were 278 cf on 20" with 58 cf'on 13 3/8" ). I have included my calculations but they assmne in gage hole and formations able to support hydmuhe head created by cement. There are no logs for this portion of the well; without cement bond logs it will be difficult to ascertaining the existing condition of cement outside casings. STATE OF ALASKA r~ ALASKA OIL AND GAS CONSERVATION ,.,,~M MISSIOI~ · .WELL COMPLETION OR RECOMPLI=TION RE ORT AND Classification of Service Well 1. Status of Well OIL r--~ GAS ~] SUSPENDED ~ ABANDONED ~.~ SERVICE [] :2. Name of Operator 7. Permit Number Union Oil Company of California (UNOCAL) 76-86/9-927 3. Address 8. APl Number P.O. BOX 190247, Anch, AK., 99519-0247 50- 283-20055 4. Location of well at surface 773· SNL & 495· WEL of Sec. 33, T14N, R8W, S.M. At Top Producing Interval Straight hole At Total Depth 6. Lease Designation and Serial No. ADL 58790 14. Date Comp., Susp. or Aband. 5. Elevation in feet (indicate KB, DF, etc.) 39.37 12. Date Spudded 02-10-78 17. Total Depth (MD+TVD) 11~660' 13. Date T.D. Reached 05-17-78 18.Plug Back Depth (M~TVD) 7641' 03-13-90 19. Directional Survey YES [] NO [] 9. Unit or Lease Name Stump Lake 10. Well Number 41--33 11. Field and Pool Stump Lake IlS. Water Depth, if offshore /16' No. of Completions T ----feet MSLJ --- 20. Depth where SSSV set 1 21. Thickness of Permafrost 311· feet MDI N/A 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD CASINGSlZE HOLE SIZE AMOUNT PULLED SETTING DEPTH MD WT. PER FT. GRADE TOP I BOTTOM 94~ .q-4o o I ' 6_~ ~-89 0 I ~" ~9~ ~zo I es~, I 9~oo' Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) (Straight hole) 24. 6636'-6644' 6680'-6685' 6695'-6705' 6740'-6758' 6766'-6790' 6860'-6876' CEMENTING RECORD iT-i/~" 1~-1 /~" · R-1 ~" Driven 1115 Saek~ TUBING RECORD None None None None 25. SIZE DEPTH SET (MD) PACKER SET (MD) 6733' 4022' 6565'- · 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED fi070'-90'; 60!()'-20' 94 szs cmt ~ 3050 p~i 27. PRODUCTION TEST IMetho~b~vj~e~:~a~on (Flowing, gas lift, etc.) GAS-lV~0 tPRODUCTION FOR ]OIL-BBL TEST PERIOD I~ CALCULATED 24-HOUR RATE "~ WATER-B~L Date. F i rst P roductj~ n ~pprox. dune 1990 Datelo/f2T~s/9 01 Hours T:~s_t~/2 tCHO~[-?,~b~%AS'O'L OIL GRAVITY-APl (tort} Flow Tub~.r~00[ Casing Pressure GAS;~/~i~0 WATER~~L Press. J 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RATIO Form 10407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME GEOLOGIC MARKERS MEAS. DEPTH 30. FORMATION TESTS TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS Daily report of operations, perforation record, 2 schematics. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. 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 (D.F, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item, 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 LEAS~ STUMP LAKE UNO~-~L DRILLING RECORD ...... ASKA REGION PAGE NO 1 oK 7 WELL NO. 41-33 FIELD STUMP LAKE DATE 01/04/90 01/05/90 01/06/90 01/07/90 01/08/90 01/09/90 01/10/90 01/11/90 01/12/90 01/13/90 01/14/90 01/15/90 E.T.D. 5658' 5658' 5658' 6335' 6523' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS MIRU Worked'on road and snow removal. Drove mouse hole. Rigged down equipment at L.R. 1-A location. Uncovered the rat hole. Set pit liner, rig pads, sub base, mud pumps pit, and misc equipment. Set the drawworks and motors. Pinned the derrick to the subbase. Raised the A legs. Continued move in and rig up. Strung blocks. Hooked up water and stream lines and compounds. Moved in medic, UOC, and Grace trailers. Set generator and communications module. MIRU. MIRU. MIRU. Accepted Grace riq ~158 @ 1200 hrs. Tested 13-5/8" x 9-5/8" slip seals and pack off to 1500 psi. Removed the blind flange & 12" 3000 x 10" 5000 TC spool. Installed the pack off for the CIW DCB spool for 47# Pll0 casing. Installed the 12" 3000 x 10" 5000 CIW DCB spool and tested the pack off to 3000 psi, OK. Installed a flange plug on the DCB spool. Built mud volume. Continued to build mud volume. This was hampered by white out conditions. Installed the BOPE. Tested the Hydrill to 3000 psi. Tested all other BOPE to 5000 psi. Ail testing was witnessed by Mr. Bobby Foster of the AOGCC. Set the wear busing and made up BHA #1. RIH to 240'. Displaced diesel with 80 PCF mud. RIH and tagged cement at 5658'. Circulated and conditioned mud. Drilled hard cement to 5725'. Drilled hard cement from 5725'-5845'. Tested the casing to 1500 psi surface pressure, OK. Drilled hard cement from 5845'-5935'. Fell and washed to the retainer at 5959'. Drilled retainer and chased to 6330'. Drilled junk from 6330'-6335'. Circulated. POOH for a new bit. RIH with an 8-1/2" bit. Drilled junk from 6335'-6340'. RIH to 6620' and circulated bottoms up. POOH. RIH with an 8-1/2" bit and a 9-5/8" casing scraper and tagged the drillable bridge plug at 6620'. Circulated bottoms up. POOH. RIH and set an ESZV at 6523'. Tested surface manifold and lines to 3000 psi. A~chora,~a LEASE STUMP LAKE DRILLING RECORD LASKA REGION PAGE NO. 2 o~ 7 WELL NO. 41-33 FIELD STUMP LAKE DATE 01/16/90 01/17/90 01/18/90 01/19/90 01/20/90 01/21/90 E.T.D. 5965' 6687' 6834' 7465' 7944' 7587' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Established breakdown at 3 BPM and 3300 psi. Squeezed the perforations from 6544'-6554' with 100 sacks of Class "G" cement and 0.6% FL10, 0.75% A-7, 1 gal 100 sx FPGL. Picked up and reversed out. Spotted a high viscous pill from 6508'-6100'. Established a breakdown on the perforations from 6010'-6020', and 6070'-6090'. Layed a cement plug (same recipe) from 6100'-5800'. Braiden head squeezed the perforations from 6010'-6020', and 6070'-6090' with 56 sacks of cement. Waited on cement. Circulated and conditioned the mud. RIH and washed cement stringers from 5912'-5945'. Drilled soft cement from 5945'-5965'. Circulated bottoms up. Cement returns were green. Waited on cement 2 hrs. Drilled cement from 5965'-6025' Circulated and tested the perforations to ~00 psi surface pressure, OK. Drilled cement from 6099' to the EZSV at 6523'. Drilled the EZSV at 6523' Drilled firm cement to 6549' Washed t~ the retainer at 6620'. Circulated and tested the perforations to 500 psi surface pressure. Drilled the EZSV @ 6620'. Drilled the retainer at 6670' and chased to 6687'. POOH for a bit change. RIH with on 8-1/2" bit and tagged junk at 6687'. Drilled and pushed the junk to the retainer at 6730'. Drilled retainer at 6730'. Circulated out gas. Drilled and pushed the junk from 6730'-6832'. Circulated out gas, sand and small pieces of coal. Drilled junk from 6832'-6834'. POOH for a bit change. RIH with a new 8-1/2" bit. Drilled junk from 6834'-6835'. Drilled the retainer at 6835'. Pushed junk to 6881'. Circulated bottoms up. Pushed junk to 7040'. Drilled junk from 7040-7043. Drilled the retainer at 7043'. Chased the junk to 7069' and circulated bottoms up. Tagged junk at 7465'. Drilled and pushed junk from 7465'-7630' . Circulated out gas. Drilled and pushed junk from 7630'-7944'. Circulated bottoms up. Performed the weekly BOP test. RIH with an 8-1/2" bit and a 9-5/8" casing scraper to 7930'. Circulated. POOH with the scraper. RIH and set an EZSV , at 7587 . Stabbed into the EZSV and established breakdown on the perforations from 7795'-7833' at 4750 psi and 0.6 bbl/min. Saw flow in the drillpipe casing annulus. Stopped pumping, the pressure bled to 4000 psi. The well bled back 11 bbls of 33 bbls injected. Unstabbed from the EZSV and circulated bottoms up, no gas. Tested the drill pipe to 4500 psi, OK. Stabbed back into the EZSV and began injecting. Saw flow in the 9-5/8" drill pipe annulus at 4500 psi and 0.5 bbls/min. Unstabbed and circulated. POOH. LEASE STUMP LAKE UNO~J~ DRILLING RECORD ASKA REGION PAGE NO. 3 o~ 7__ WELL NO. 41-33 FIELD STUMP LAKE DATE 01/22/90 01/23/90 01/24/90 01/25190 01/26/90 01/27/90 E.T.D. 7938' 7641' 7641' 7641' 7641' 6720' DETAILS OF OPERAT!0~, DESCRIPTIONS & RESULTS RIH with an 8-1/2" bit and drilled the EZSV at 7585 and chased the junk to 7938'. Circulated. POOH. Rigged up Schlumberger and ran a Dia-Log multi-arm caliper log from 7850' to surface. Rigged down wireline. RIH with open ended drill pipe to 7935'. Circulated bottoms up. Rigged up B-J Titan and equalized 130 sx of Class "G" cement w/0.6% FL-10, 0.75% A-7, from 7935'-7575'. POOH to 6900' and reversed out. Began changing over to clean calcium chloride. Filtered Calcium chloride, built new calcium chloride and cleaned the pits. RIH and tagged the cement at 7641'. Began to change the well over to 80 pcf calcium chloride brine. Pumped 460 bbls 80 PCF calcium chloride. It will take 520 bbls to change over. Continued to build volume and filter used brine. Continued to filter brine. Reverse circulated. POOH. RIH with TCP guns and a packer. Hung up on the wear bushing with the packer. POOH. Pulled wear bushing. RIH with 4-1/2" 37 gm 4 SPF TCP guns and a packer. Rigged up wireline for neutron correlation. Ran a correlation log and set the packer at 6702'. Re-correlated. Rigged down wireline. Rigged up nitrogen. Pressure tested the surface lines to 4000 psi, OK. Displaced fluid to 150' above the firing head. Bled the tubing down to 2094 psi. Dropped the bar and fired the guns. Reperforated 6740'-6758', 6860'-6876'. Perforated 6766'-6790'. Flared at a rate of 7.12 MMSCF/D with 2300 psi back pressure. Shut in and the pressure built to 2824 psi surface pressure and stabilized. Bled the lines to the separator. Mixed and pumped a 30 bbl sized salt pill. Continued to pump the 30 bbl sized salt pill against the perforations. Released the packer and circulated the well until dead. POOH. RIH and set an EZSV at 6720'. Circulated. POOH. RIH with 4-1/2" 37 gm TCP guns and a packer. LEASE STUMP LAKE DRILLING RECORD % ~LASKA REGION PAGE NO. 4 of 7 WELL NO. 41-33 FIELD STUMP LAKE DATE 01/28/90 01/29/90 01/30/90 01/31/90 02/01/90 E.T.D. 6720' 6720' 6660' 6660' 7605' DETAILS OF OPERATIO~ DESCRIPTIONS & RESULTS Finished RIH with the guns. Ran a correlation log and set the packer at 6642' Ran a confirmation log, OK. POOH wit~ wireline. Rigged up the surface manifold and pressure tested to 4000 psi with nitrogen. Opened the by-pass in the packer and displaced the 4-1/2" 16.6~ D.P. to 150' above the firing head. Closed the bypass and bled the surface pressure down to 2861 psi surface pressure. Dropped the bar, no detonation. Began to reverse circulate when the guns fired. Reperforated 6680'-6685', 6693'-6705' with 4 SPF. When the guns fired there was +/-1900' of fluid in the tubing. Attempted to flow the well, negative. Opened the bypass and circulated. Rigged up and retested the surface manifold to 4000 psi with nitrogen. Displaced the drill pipe to 6600'. Closed the bypass and flowed the well. Continued to flow the well to the test separator at 1.5 MMSCF/D with a 150 psi back pressure. Choked the well back to 1.2 MMSCF/D with a 1010 psi back pressure. Pumped a 10 bbl sized salt kill pill against the formation. Shut the well in and the surface pressure bled from 2700 psi to 2400 psi. Bled off at the surface and released the packer. Circulated through the choke. Continued to circulate through the choke. Rigged up wireline and fished the drop bar. Circulated. POOH with TCP guns. RIH with an EZSV and set at 6660'. Circulated. POOH. Picked up TCP guns and RIH. Rigged up wireline and ran a Gamma Ray correlation log. Set the packer at 6597'. Ran a second correlation log, OK. Rigged down wireline. Rigged up nitrogen and pressure tested the surface equipment to 4000 psi. Displaced the tubing with nitrogen to 6440'. Closed the bypass in the packer. Bled the nitrogen to 1875 psi. Dropped the bar and fired the guns. Perforating 6636'-6644' with 4-1/2" SPF using 37 gm charges. The well came on slowly and built to 1.87 MMCF/D with 1050 psi surface pressure in 7 hrs. Shut in for a pressure buildup the pressure built to 2355 psi in 4 hrs. Bullheaded a 20 bbl sized salt kill pill against the formation. Released the packer and circulated out gas. POOH with the guns. RIH with an 8-1/2" bit and tagged the EZSV at 6660'. Drilled EZSV's at 6660' and 6720'. Chased junk to the top of the cement at 7605'. LEASE ,, STUMP LAKE --~OCAL DRILLING RECO. % ALASKA REGION PAGE NO. 5 ol 7 WELL NO. 41-33 FIELD. STUMP LAKE DATE 02/02/90 02/03/90 02/04/90 02/05/90 02/06/90 02/07/90 02/08/90 E.T.D. 7605' 7605' 7605' 7605' 7605' 7605' 7605' DETAILS OF OPE.RATION, DESCRIPTIONS & RESULTS Circulated the hole clean. POOH. RIH with an 8-1/2" bit and a 9-5/8" casing scraper to 7600'. Circulated the hole clean. POOH. RIH with packer #1, correlated the depth with a CNL. Dropped the ball and set the Otis "VST" packer at 6716' DIL. Sheared out of the packer. Tested the annulus, OK. POOH. RIH with 3-1/2" 9.2# tubing, carbide blast rings and packer #2. Hydrotested the 3-1/2" tubing to 3000 psi while RIH. Stabbed into packer ~1 and set packer #2 at 6565'. RIH hydrotesting the 3-1/2" tubing. Stabbed into the packer at 6565' and attempted to set packer #3 at 2104', neg. The packer was pinned too low for the weight of the tubing plus the hydraulic force applied when setting the packer. The packer sheared off of the running tool before it was set. POOH. RIH with a retrieving tool and caught the packer. POOH. i jt. of drill pipe and 3 joints of tubing were buckled. Finished POOH with the tubing tail assembly. Picked up and RIH with a new packer #3 and stabbed into packer #2. Set packer #3 at 4022'. Sheared out of packer #3. Circulated. POOH laying down 4-1/2" drill pipe, jars and 6-1/4" D.C.S. Changed to 3-1/2" pipe rams. RIH with 3-1/2" tubing and 1-1/4" CS hydril. Spaced out and landed. Tested the seals, OK. Pressure tested the annulus, OK. Tested the SSSV line, ok. Set BPV's. Removed the BOPE. Installed the tree. Continued installing the tree. The tree did not test. Replaced the control line seals and the hanger seals 3 times. The tree continued to leak. Ordered out new hangers. Installed the BOPE. Pulled the old hangers. Set the new hangers. Tested the SSSV control line to 5000 psi, OK. Relanded the tubing in the hangers. Tested the top hanger to 2500 psi, OK. Removed the BOPE. Finished installing the tree and tested to 5000 psi, OK. Rigged up and displaced the annulus with diesel going down the annulus and up the 1-1/4" heater string. Rigged up wireline and RIH with a SSSV retrieving tool. Tagged an ice plug at 57'. POOH. RIH with a sinker bar and spudded to 67'. POOH. Rigged up coiled tubing and RIH. Circulated calcium chloride brine while cleaning out to the SSSV. POOH. Rigged up wireline. RIH and pulled the SSSV. Rigged up coiled tubing. Pressure tested the stack and flow lines to the seperator to 4000 psi, OK. RIH and kicked-the well off with nitrogen. Flowed the well to clean it up. LEASE STUMP LAKE /'~OCAL DRILLING RECO! ~ ALASKA REGION PAGE NO. 6 ol 7 WELL NO. 41-33 FIELD STUMP LAKE DATE 02/09/90 02110/90 02/11/90 02/12-20/90 02/23/90 02/24/90 02/25/90 02/26/90 02/27/90 E.T.D. 7605' 7605' 7605' 7605' 7605' 7605' 7605' 7605' 7605' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued to flow the well to clean up. Shut in. RIH with a PX plug and hung up at the SSSV nipple. POOH. Redressed the plug. RIH and set the plug in the "X" profile at 6735'. RIH and attempted to set the equalizing prong. The PX .plug and prong dropped out the tubing tail. POOH. RIH and set the new PX plug in the"X" profile at 6735'. POOH. RIH and set the equalizing prong. Bled the surface pressure off to 2640 psi. RIH and opened the XA at 6710'. POOH. Attempted to flow the well. Continued to flow the well with no significant flow. RIH and attemped to pull the equalizing prong out of the PX plug at 6735'. Note: there was a 2200 psi differential on the plug at this time. The tubing pressure equalized but the prong could not be retrieved. Coarse grit was found on the retrieving tool. Installed back pressure valves. Released Grace Rig ~158 at 1200 hrs. Rigged down and moved out. Pulled the back pressure valves. Rigged up the coiled tubing unit. Tested the BOPE to 4000 psi, ok. RIH with 1.75" wash nozzle and circulated Nitrogen at 1,500 SCFPM. Tagged the PX plug at 6735'. POOH. Rigged down coiled tubing. Rigged up slickline. RIH with 2.70" pulling tool and were unable to get past 4730'. POOH. Attempted to flow the well through the 1/8" ports in the PX plug to clean it up. Neg. RIH with an XA shifting tool and hung up at 4730'. POOH. Rigged up coiled tubing. Pressure tested the BOPE to 5000 psi, ok. RIH with a 2.5" wash nozzle. Washed the well to the XA plug at 6735' with 100 bbls of 3% KCL. POOH. RIH with slickline and shifting tool. RIH and hit heavy mud and stopped at 6560'. Unable to close the sleeves. POOH. Rigged up coiled tubing. Pressure tested the BOPE to 2300 psi, ok. RIH with coiled tubing and a 1.75" wash nozzle. Ice plugging prevented pumping. POOH and de-iced the coiled tubing. RIH and tagged the PX plug at 6735'. Washed with 100 bbls of 3% KCL. POOH. RIH with slickline and closed the XA sleeve at 6580'. Unable to get deeper. Rigged up coiled tubing and pressure tested the BOPE to 2500 psi. RIH with a 1.75" wash nozzle to 6735' and washed the plug with 105 bbls 3% KCL. POOH. RIH with slickline and verified that the XA at 6580' was closed and closed the XA at 6710'. Tagged fill at 6715,. Coiled tubing unit injector head was inoperable. Shut down until a new injector head arrives. NOTE: The zone behind the XA's is still producable but will require some time to clean up. LEASE STUMP LAKE DRILLING RECORD J~ASKA REGION PAGE NO. 7 of WELL NO. 41-33 FIELD_STUMP LAKE DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 03/02/90 03/03/90 03/08/90 03/09/90 03/12/90 03/13/90 7605' 7605' 7605' 7605' 7605' 7605' Rigged up coiled tubing. Pressure tested the BOPE to 5000 psi. RIH with coiled tubing to 6735' and set down on the plug. Pumped N2 at 1000 SCF/M until returns were dry POOH. RIH with slickline and pulled the equalizing prong at 6735'. Unable to latch the plug. No good. RIH with a new tool and attempted to latch the plug. No good. Rigged down wireline. Secured the well. RIH with a 2.75" pulling tool on coiled tubing and attempted to latch the plug. No good. POOH. RIH with a 2.721" pulling tool to the plug at 6735'. Washed with 30 bbls of Calcium Chloride. Jarred down on the plug in an attempt to latch. No good. POOH. Rigged up wireline to shoot the tail off. Unable to get through an ice plug in the wellhead. De-iced the wellhead and RIH to 108' and tagged another ice plug. Dumped Methanol and removed the 2.70" cutting tool. RIH with 1-11/16" sinker bars and hung up at 108'. Attempted to flow the well. Neg. Dumped Methanol. RIH with 1-11/16" sinker bars to 6735'. RIH with 2.70" cutting tool to 6735'. Attempted to cut the tail at 6733'. The cutting tool did not fire. POOH. Changed out cutting tool. RIH and cut the tail at 6733'. Verified that the tail had fallen away. POOH. Flared the well to clean up. STUMP LAKE 41-33 PERFORATION RECORD 5/08/78 5/09/78 5/07/78 5/06/78 5/05/78 5/05/78 4/30/78 4?30/78 4/29/78 4/20/78 4/17/78 4/15/78 4/19/78 1/31/90 1/28/90 1/28/90 1/26/90 1/26/90 1/26/90 60 60 65 66 66 66 67 67 68 77 92 94 94 95 10 70 44 36 8O 95 40 66 60 95 30 88 90 18 '-6020' SQZ'D · '-6090' SQZ'D '-6554' SQZ'D '-6644' OPEN. '-6685' OPEN '-6705' OPEN '-6758' OPEN '-6790' SQZ'D '-6876' OPEN '-7833' SQZ'D '-9260' ISLT'D '-9489' SQZ'D '-9490' SQZ'D '-9528' CMT'D DST DST DST DST-PRODUCTION DST-PRODUCTION DST-PRODUCTION DST-PRODUCTION DST DST-PRODUCTION DST DST ISOLATION ISOLATION DST 4/ft 4/ft 4/ft 8/ft 8/ft 8/ft 8/ft 4/ft 8/ft 4/ft 4/ft 4?ft 4/ft 4/ft STUMP LAKE 4 1-33 COMPLETION AS OF 5/13//90 - ,,, 30" Driven to 77' /1 20" 94# @ 424' Bowl adaptor @ 490' ~-~/~" ~2~ ~ 2~ 12' "DV" Collar @ 3024' 0 DEG. INCLINATION Retainer Junk @ 7605' 3 D.C.'S & BIT 4 3-1/2" 9.2~ N-80 BUTRE$S AB-MODIFIED 1. BAKER SUB SURFACE SAFETY VALVE AT 311' 2. OTIS VST PRODUCTION PACKER 4022' 3. OTIS VST PRODUCTION PACKER AT 6565' 4. OTIS XA SLIDING SLEEVE AT 6580' 5. CARBIDE BLAST RINGS WITH A 5' OVERLAP 6. OTIS XA SLIDING SLEEVE AT 6710' 7. OTIS VST PRODUCTION PACKER AT 6716' 8. OTIS PACKER SEAL BORE EXTENSION AT 6730' 9. TUBING TAIL CUT WITH A JET CUTTER AT 6733' .A. HEATER STRING 1 1/4" CS HYDRIL AT 2010' % 6010'-6020' SQZ'D = 6070'-6090' SQZ'D 6544'-6554' SQZ'D 6656'-6644' I ~ 6680'--6685' -- 6695'--6705' 7 __ 6740'--6758' 6766'--6790' 6860'--6876' Top of cement @ 7641' 7795'-7835' Driilable B.P. @ 7950' 8160'-8180' Top of cement at 8443' 9230'-9260' 9-5/8" 43.5-47¢ @ 866~.~_% 7" 29¢ liner 856J'-9700' / %Drilleble B.P. @ 9560' 9488'-9490' L9518'-g528' SQZ'D STUMP COMPLETION 50" Driven to 77' Z~ / 20" 94# @ 424' /_. Bowl adoptor @ 490' 13-3/8" 62# @ 2512' z~ "DV" Colior ~ 5024' 0 DEG. INCLINATION Reteiner Junk @ 7605' II I I I IIII LAKE 4 1- 55 AS OF 2/' 19,/90 3-1/2" 9.2~ 1~-80 BUTRESS AB-MODIFIED 6010'-6020' 6070'-6090' 6544'-6554' 3 6636'-6644' 6680'-6685' 6695'-6705' 6740'-6758' 6766'-6790' 6860'-6876' 1. BAKER SUB SURFACE SAFETY VALVE AT 311' 2. OTIS VST PRODUCIIOK PACKER 4022' 3. OTIS VST PRODUCTION PACKER AT 6565' 4. OTIS XA SLIDING SLEEVE AT 6580' 5.- CARBIDE BLAST RINGS WITH A 5' OVERLAP 6. OTIS XA SLIDING SLEEVE AT 6710' 7. OTIS VST PRODUCTION PACKER AT 6716' 8. OTIS X NIPPLE AT 6735' 9. WIRELIKE RENTRY GUIDE AT 6739' A. HEATER STRING 1 1/4" CS HYDRIL AT 2010' SQZ'D SQZ'D SQZ'D Top of cement @ 7641' 7795'-7835' Drillable B.P. @ 7950' 3 D.C.'S & BIT / , ,T 8160'-B180' ~xxNXXXNXN~xx~_ To p o fcemen t at t~.4:3' ~xxxxxxxx-~ 92:30'-9260' ~-~/~" 4~.~-~¢/~ ~%~:j~ ~ 7" 29# liner 8563'-@700' ./' Drillable B.P. (D 9360' 9488'-9490' 9518'-9528' SQZ'D STATE OF ALASKA 0 ~ ALASKA OIL AND GAS CONSERVATION COMMISSION l::lEPOl OF SUNDRY WELL OPE .TIONS 1. Operations performed: Operation shutdown m Stimulate __ Plugging Pull tubing __ Alter casing __ Repair well __ Perforate ~ Other 2. NameofOperator Union Oil Company ~ California fUNOCAL' 3. Address P.O. Box 190247, Anch, Ak., 99519-0247 5. Type of Well: Development ~ Exploratory __ Stratigraphic __ Service ~ 4. Location of well at surface T14N, RSW, S.M. At top of productive interval 733' SNL and 495' ~effectivedepth straight hole At total depth WEL of Sec. 33, 12. Present well condition sUmmary Total depth: measured true vertical 11,650' feet 11,650' feet Plugs (measured) Effective depth: measured 7641 ' feet true vertical 7641 · feet Junk (measured) Casing Length Size Cemented Structural 77 · 30" D riven Conductor 424 ' 20" 540sxs Surface 2512 ' 13-3/8" 2050sx Intermediate 8677' 9-5/8" l115sxs Production 8563 ' 7" 335sx Liner Perforation depth: measured See Attached true vertical 3-1/2", 9.2#, Tubing (size. grade, and measured depth) Baker SSSV @ 311' Packers and SSSV (type and measured depth) N-80 Otis 7641 ' IGJ A 6. Datum elevation (DF or KB) 39,37 7. Unit or Property name Stump) Lake 8. Well number 41-33 9. Permit number/approval number 76-86/9-927 10. APl number 50_283-20055 11. F..Jeld/PooL , ~ump ~.a~e Field .iVlAR 2 8 lfi :0 7605' .... ;,~:,, 0il & Gas Cons, C0m~iss[o[~, Ar~ch0rag¢ Measured depth True vertical depth 77' 77' 424' 424' 2512' 2512' 8667' 8667' 8563'-9700' 8563'-9700' buttress, AB-modified VST packers @ 4022', 74sxs 13. Stimulation or cement squeeze summary 6544'-6554' squeezed with Intervalstreated(measured) 6510'-6020', 6070'-6090' squeezed Treatment description including volumes used and final pressure @ 4250 psi 94sxs @ 3050 psi 14. with Service Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 Waiting on Surface Facilities Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __x Daily Report of Well Operations x.~ 16. Status of well classification as: Oil __ Gas ~ Suspended __ 6565', 6716' 17. I hereby certify that the foregoing is tru_,e and correct to the best of my knowledge. ROy~D. Roberts ~itle Environmental Engineer Signed Form 10-404 Rev 06/15/88 Tubing Pressure N/A Date 3/2 6/9 0 SUBMIT IN DUPLICATE feet ~,~' LE~$E ~ L~KE UNOCAL DRILLING RECORD ~ASKA REGION ~ PAGE NO. i of -- WELL NO. 41-~ FIELD STUMP LAK~ DATE 01/04/90 01105190 01/06/90 01/07/90 01/08/90 01/09190 O111019O 01111~90 01/12/90 01/13/90 01/14/90 01/15/90 ~.T.D. 5658t 5658' 5658' 6335' 6523' D~TAILS 0F OpSRATION. DESCRIPTIONS & RESULTS MIRU Worked on road and snow removal. Drove mouse hole. Rigged down equipment at L.R. 1-A location. Uncovered the rat hole. Set pit liner, rig pads, sub. base, mud pumps pit, and misc equipment. Set the drawworks and motors. Pinned the derrick to the subbase. Raised the A legs. Continued move in and rig up. Strung blocks. Hooked up water and stream lines and compounds. Moved in medic, UOC, and Grace trailers. Set generator and communications module. MIRU. MIRU. MIRU. Accepted Grace rig ~158 @ 1200.hrs. Tested 13-5/8" x 9-5/8" slip seals and pack off to 1500 psi. Removed the blind flange & 12" 3000.x 10" 5000 TC spool. Installed the pack off for the CIW DCB spool for 475 Pll0 casing. Installed the 12" 3000 x 10" 5000 CIW DCB spool and tested the pack off to 3000 psi, OK. Installed a flange plug on the DCB spool. Built mud volume. Continued to build mud volume. This was hampered by white out conditions. Installed the BOPE. Tested the Hydrill to 3000 psi. Tested all other BOPE to 5000 psi. Ail testing was witnessed by Mr. Bobby Foster of the AOGCC. Set the wear busing and made up BHA 51. RIH to 240'. Displaced diesel with 80 PCF mud. RIH and tagged cement at 5658'. Circulated and conditioned mud. Drilled hard cement to 5725'. Drilled hard cement from 5725'-5845'. Tested the casing to 1500 psi surface pressure, OK. Drilled hard cement from 5845'-5935'. Fell and washed to the retainer at 5959'. Drilled retainer and chased to 6330'. Drilled junk from 6330'-6335'. Circulated. POOH for a new bit. RIH with an 8-1/2" bit. Drilled junk from 6335'-6340'. RIH to 6620' and circulated bottoms up. POOH. RIH with an 8-1/2" bit and a 9-5/8" casing scraper and tagged the drillable bridge plug at 6620'. Circulated bottoms up. POOH. RIH and set an ESZV at 6523'. Tested surface manifold and lines to 3000 psi. LEASE STUMP LAKE UNOCAL DRILLING RECORD ?-~ASKA REGION ~ PAGE NO. ~ of _ WELL NO. 41-3~ . FIELD STUMP LAKE DATE 01/16/90 01/17/90 01/18/90 01/19/90 01/20/90 01/21/90 E.T.D. 5965' 6687' 6834' 7465' 7944' 7587' DETAILS OF OPERATION. DESCRIPTIONS & RESULTS Established breakdown at 3 BPM and 3300 psi. Squeezed the perforations from 6544'-6554' with 100 sacks of Class "G" cement and 0.6% FL10, 0.75% A-7, i gal 100 sx FPGL. Picked up and reversed out. Spotted a high viscous pill from 6508'-6100'. Established a breakdown on the perforations from 6010'-6020', and 6070'-6090'. Layed a cement plug (same recipe) from 6100'-5800'. Braiden head squeezed the perforations from 6010'-6020', and 6070'-6090' with 56 sacks of cement. Waited on cement. Circulated and conditioned the mud. RIH and washed cement stringers from 5912'-5945'. Drilled soft cement from 5945'-5965'. Circulated bottoms up. Cement returns were green. Waited on cement 2 hrs. Drilled cement from 5965'-6025'. circulated and tested the perforations to 500 psi surface pressure, OK. Drilled cement from 6099' to the EZSV at 6523'. Drilled the EZSV at 6523'. Drilled firm cement to 6549'. Washed to the retainer at 6620'. Circulated and tested the perforations to 500 psi surface pressure. Drilled the EZSV @ 6620'. Drilled the retainer at 6670' and chased to 6687'. POOH for a bit change. RIH with on 8-1/2" bit and tagged junk at 6687'. Drilled and pushed the junk to the retainer-at 6730'. Drilled retainer at 6730'. Circulated out gas. Drilled and pushed the junk from 6730'-6832' Circulated out gas, sand and small pieces o~ coal. Drilled junk from 6832'-6834'. POOH for a bit change. RIH with a new 8-1/2" bit. Drilled junk from 6834'-6835'. Drilled the retainer at 6835'. Pushed junk to 6881'. Circulated bottoms up. Pushed junk to 7040'. Drilled junk from 7040-7043. Drilled the retainer at 7043'. Chased the junk to 7069' and circulated bottoms up. Tagged junk at 7465'. Drilled and pushed junk from 7465'-7630' Circulated out gas. Drilled and pushed ~unk from 7630'-7944'. CirCulated bottoms up. Performed the weekly BOP test. RIH with an 8-1/2" bit and a 9-5/8" casing scraper to 7930'. Circulated. POOH with the scraper. RIH and set an EZSV at 7587'. Stabbed into the EZSV and established breakdown on the perforations from 7795'-7833' at 4750 psi and 0.6 bbl/min. Saw flow in the drillpipe casing annulus. Stopped pumping, the pressure bled to 4000 psi. The well bled back 11 bbls of 33 bbls injected. Unstabbed from the EZSV and circulated bottoms up, no gas. Tested the drill pipe to 4500 psi, OK. Stabbed back into the EZSV and began injecting. Saw flow in the 9-5/8" drill pipe annulu~ at 4500 psi and 0.5 bbls/min. Unstabbed and circulated. POOH. LEASE STUMP LA~E UNOCAL DRILLING RECORD ~ SKA REGION ...... PAGE NO. ]... of . . WELL NO. 41-33 _ FIELD STUMP LAKE DATE ~- T- D. 01/22/90 7938' 01/23/90 7641' 01/24/90 7641' 01/25/90 7641' 01/26/90 7641' 01/27/90 6720' D~TAILS OF OPERATION, DESCRIPTIONS & RESULTS RIH with an 8-1/2" bit and drilled the EZSV at 7585 and chased the junk to 7938'. Circulated. POOH. Rigged up Schlumberger and ran a Dia-Log multi-arm caliper log from 7850' to surface. Rigged down wireline. 'RIH with open ended drill pipe to 7935'. Circulated bottoms up. Rigged up B-J Titan and equalized 130 sx of Class "G" cement w/0.6% FL-10, 0.75% A-7, from 7935'-7575'. POOH to 6900' and reversed out. Began changing over to clean calcium chloride. Filtered Calcium chloride, built new calcium chloride and cleaned the pits. RIH and tagged the cement at 7641'. Began to change the well over to 80 pcf calcium chloride brine. Pumped 460 bbls 80 PCF calcium chloride. It will take 520 bbls to change over. Continued to build volume and filter used brine. Continued to filter brine. Reverse circulated. POOH. RIH with TCP guns and a packer. Hung up on the wear bushing with the packer. POOH. Pulled wear bushing. RIH with 4-1/2" 37 gm 4 SPF TCP guns and a packer. Rigged up wireline for neutron correlation. Ran a correlation log and set the packer at 6702'. Re-correlated. Rigged down wireline. Rigged up.nitrogen. Pressure tested the surface lines to 4000 psi, OK. Displaced fluid to 150' above the firing head. Bled the tubing down to 2094 psi. Dropped the bar and fired the guns. Reperforated 6740'-6758', 6860'-6876'. Perforated 6766'-6790'. Flared at a rate of 7.12 MMSCF/D with 2300 psi back pressure. Shut in and the pressure built to 2824 psi - surface pressure and stabilized. Bled the lines to the separator. Mixed and pumped a 30 bbl sized salt pill. Continued to pump the 30 bbl sized salt pill against the perforations. Released the packer and circulated the well until dead. POOH. RIH and set an EZSV at 6720'. Circulated. POOH. RIH with 4-1/2" 37 gm TCP guns and a packer. LF_~$E ~ I~,gE UNOCAL DRILLING RECORD -~%SKAREGION .... PAGE NO. ~. of - WELL NO. 41-33 FIELD STUMP LAKE 01/28/90 01/29/90 01/30/90 01/31/90 02/01/90 ~.T.D. 6720' 6720' 6660' 6660' 7605' DETAILS 9F OP~RATION.'DESCRIPTIONS & RESULTS Finished RIH with the guns. Ran a correlation log and set the packer at 6642'. Ran a confirmation log, OK. POOH with wireline. Rigged up the surface manifold and pressure tested to 4000 psi with nitrogen. Opened the by-pass in the packer and displaced the 4-1/2" 16.6# D.P. to 150' above the firing head. Closed the bypass and bled the surface pressure down to 2861 psi surface pressure. Dropped the bar, no detonation. Began to reverse circulate when the guns fired. Reperforated 6680'-6685', 6693'-6705' with 4 SPF. When the guns fired there was +/-1900' of fluid in the tubing. Attempted to flow the well, negative. Opened the bypass and circulated. Rigged up and retested the surface manifold to 4000 psi with nitrogen. Displaced the drill pipe to 6600'. Closed the bypass and flowed the well. Continued to flow the well to the test separator at 1.5 MMSCF/D with a 150 psi back pressure. Choked the well back to 1.2 MMSCF/D with a 1010 psi back pressure. Pumped a 10 bbl sized salt kill pill against the formation. Shut the well in and the surface pressure bled from 2700 psi to 2400 psi. Bled off at the surface and released the packer. Circulated through the choke. Continued to circulate through the choke. Rigged up wireline and fished the drop bar. Circulated. POOH with TCP guns. RIH with an EZSV and set at 6660'. Circulated. POOH. Picked up TCP guns and RIH.~ Rigged up wireline and ran a Gamma Ray correlation log. Set the packer at 6597'. Ran a second correlation log, OK. Rigged down wireline. Rigged up nitrogen and pressure tested the surface equipment to 4000 psi. Displaced the tubing with nitrogen to 6440'. Closed the bypass in the packer. Bled the nitrogen to 1875 psi. Dropped the bar and fired the guns. Perforating 6636'-6644' with 4-1/2" SPF using 37 gm charges. The well came on slowly and built to 1.87 MMCF/D with 1050 psi surface pressure in 7 hrs. Shut in for a pressure buildup the pressure built to 2355 psi in 4 hrs. Bullheaded a 20 bbl sized salt kill pill against the formation. Released the packer and circulated out gas. POOH with the guns. RIH with an 8-1/2" bit and tagged the EZSV at 6660'. Drilled EZSV's at 6660' and 6720'. Chased junk to the top of the cement at 7605'. LEASE STUMP LAKE UNOCAL DRILLINC RECORD --'- ALASKA REGION -~ PAGE NO. 5 of -- WELL NO. 41-33 FIELD STUMP LAKE PATE 02/02/90 02/03/90 02/04/90 02/05/90 02/06/90 02/07/90 02/08/90 ~.T.D ..... 7605' 7605' 7605' 7605' 7605' 7605' 7605' D~TAILS OF OPERATION. DESCRIPTIONS & RESULTS Circulated the hole clean. POOH. RIH with an 8-1/2" bit and a 9-5/8" casing scraper to 7600'. Circulated the hole clean. POOH. RIH.with packer 21, correlated the depth with a CNL. Dropped the ball and set the Otis "VST" packer at. 6716' DIL. Sheared out of the packer. Tested the annulus, OK. POOH. RIH with 3-1/2" 9.2~ tubing, carbide blast rings and packer $2. Hydrotested the 3-1/2" tubing to 3000 psi while RIH. Stabbed into packer $1 and set packer $2 at 6565'. RIHhydrotesting the 3-1/2" tubing. Stabbed into the packer at 6565' and attempted to set packer $3 at 2104', neg. The packer was pinned too low for the weight of the tubing plus the hydraulic force applied when setting the packer. The packer sheared off of the running tool before it was set. POOH. RIH with a retrieving tool and caught the packer. POOH. i jt. of drill pipe and 3 joints of tubing were buckled. Finished POOH with the tubing tail assembly. Picked up and RIH with a new packer #3 and stabbed into packer #2. Set packer #3 at 4022'. Sheared out of packer ~3. Circulated. POOH laying down 4-1/2" drill pipe, jars and 6-1/4" D.C.S. Changed to 3-1/2" pipe rams. RIH with'3-1/2" tubing and 1-1/4" CS hydril. Spaced out and landed. Tested the seals, OK. Pressure tested the annulus, OK. Tested the SSSV line, ok. Set BPV's. Removed the BOPE. Installed the tree. Continued installing the tree. The tree did not test. Replaced the control line seals' and the hanger seals 3 times. The tree continued to leak. Ordered out new hangers. Installed the BOPE. Pulled the old hangers. Set the new hangers. Tested the SSSV control line to 5000 psi, OK. Relanded the tubing in the hangers. Tested the top hanger to 2500 psi, OK. Removed the BOPE. Finished installing the tree and tested to 5000 psi, OK. Rigged up and displaced the annulus with diesel going down the annulus and up the 1-1/4" heater string. Rigged up wireline and RIH with a SSSV retrieving tool. Tagged an ice plug at 57'. POOH. RIH with a sinker bar and spudded to 67'. POOH. Rigged up coiled tubing and RIH. Circulated calcium chloride brine while cleaning out to the SSSV. POOH. Rigged up wireline. RIH and pulled the SSSV. Rigged up coiled tubing. Pressure tested the stack and flow lines to the seperator to 4000 psi, OK. RIH and kicked the well off with nitrogen. Flowed the well to clean it up. LE~S~. STU~i~ ~OCAL DRILLING RECORD ALASKA REGION PAGE NO. § of WELL NO. 41-33 FIELD STUMP LAKE DATE . E,T.D. 02/09/90 7605' 02/10/90 7605' 02/11/90 7605' 02/12-20/90 7605' 02/23/90 7605' 02/24/90 7605' 02/25/90 7605' 02/26/90 7605' 02/27/90 7605' DETAILS OF OPERATION. DESCRIPTIONS.& RESULTS Continued to flow the well to clean up. Shut in. RIH with a PX plug and hung up at the SSSV nipple. POOH. Redressed the plug. RIH and set the plug in the "X" profile at 6735'. RIH and attempted to set the equalizing prong. The PX plug and prong dropped out the tubing tail. POOH. RIH and set the new PX plug in the"X" profile at 6735'. POOH. RIH and set the equalizing prong. Bled the surface pressure off to 2640 psi. RIH and opened the XA at 6710'. POOH. Attempted to flow the well. Continued to flow the well with no significant flow. RIH and attemped to pull the equalizing prong out of the PX plug at 6735'. Note: there was a 2200 psi differential on the plug at this time. The tubing pressure equalized but the prong could not be retrieved. Coarse grit was found on the retrieving tool. Installed back pressure waives. Released Grace Ria #158 at ~00 hrs. Rigged down and moved out. Pulled the back pressure valves. Rigged up the coiled tubing unit. Tested the BOPE to 4000 Psi, ok. RIH with 1.75" wash nozzle and circulated Nitrogen at 1,500 SCFPM. Tagged the PX plug at 6735'. POOH. Rigged down coiled tubing. Rigged up slickline. RIH with 2.70" pulling tool and were unable to get past 4730'. POOH. Attempted to flow the well through the 1/8" ports in the PX plug to clean it up. Neg. RIH with an XA shifting tool and hung up at 4730'. POOH. Rigged up coiled tubing. Pressure tested the BOPE to 5000 psi, ok. RIH with a 2.5" wash nozzle. Washed the well to the XA plug at 6735' with 100 bbls of 3% KCL. POOH. RIH with slickline and shifting tool. RIH and hit heavy mud and stopped at 6560'. Unable to close the sleeves. POOH. Rigged up coiled tubing. Pressure tested the BOPE to 2300 psi, ok. RIH with coiled tubing and a 1.75" wash nozzle. Ice plugging prevented pumping. POOH and de-iced the coiled tubing. RIH and tagged the PX plug at 6735'. Washed with 100 bbls of 3% KCL. POOH. RIH with slickline and closed the XA sleeve at 6580'. Unable to get deeper. Rigged up coiled tubing and pressure tested the BOPE to 2500 psi. RIH with a 1.75" wash nozzle to 6735' and washed the plug with 105 bbls 3% KCL. POOH. RIH with slickline and verified that the XA at 6580' was closed and closed the XA at 6710'. Tagged fill at 6715'. Coiled tubing unit injector head was inoperable. Shut down until a new injector head arrives. NOTE: The zone behind the XA's is still producable but will require some time to clean up. LEASE ~rUMP LAKE UNOCAL DRILLING RECORD .~LASKAREGION ~ PAGE NO. 7 of _ WELL NO. 41-33 FIELD ST%rMP LAKE DATE 03/02/9o 03/03/90 03/08/90 03/09/90 03/12/90 03/13/90 E.T.D. 7605' 7605' 7605' 7605' 7605' 7605' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Rigged up coiled tubing. Pressure tested the BOPE to 5000 psi. RIH with coiled tubing to 6735' and set down on the plug. Pumped Nz at 1000 SCF/M until returns were dry POOH. RIH with slickline and pulled the equalizing prong at 6735'. Unable to latch the plug. No good. RIH with a new tool and attempted to latch the plug. No good. Rigged down wireline. Secured the well. RIH with a 2.75" pulling tool on coiled tubing and attempted to latch the plug. good. POOH. No RIH with a 2.721" pulling tool to the plug at 6735' Washed with 30 bbls of Calcium Chloride. Jarred down on the plug in an attempt to latch. No good. POOH. Rigged up wireline to shoot the tail off. Unable to get through an ice plug in the wellhead. De-iced the wellhead and RIH to 108' and tagged another ice plug. Dumped Methanol and removed the 2.70" cutting tool. RIH with 1-11/16" sinker bars and hung up at 108'. Attempted to flow the well. Neg. Dumped Methanol. RIH with 1-11/16" sinker bars to 6735'. RIH with 2.70" cutting tool to 6735'. Attempted to cut the tail at 6733'. The cutting tool did not fire. POOH. Changed out cutting tool. RIH and cut the tail at 6733'. Verified that the tail had fallen away. POOH. Flared the well to clean up. STUMP LAKE 41-33 PERFORATION RECORD 5/09/78 5/07/78 5/06/78 5/O5/78 5/05/78 4/30/78 4/3 4/2 4/2 4/1 4/1 4/1 O/78 9/78 0/78 7/78 5/78 9/78 1/31/90 1/28/90 1/28/90 1/26/90 1/26/90 1/26/90 6070'-6090' SQZ'D 6544'-6554' SQZ'D 6636'-6644' OPEN 6680'-6685' OPEN 6695'-6705' OPEN 6740'-6758' OPEN 6766'-6790' SQZ'D 6860'-6876' OPEN 7795'-7833' SQZ'D 9230'-9260' ISLT'D 9488'-9489' SQZ'D 9490'-9490' SQZ'D 9518'-9528' CMT'D DST DST DST-PRODUCTION DST-PRODUCTION DST-PRODUCTION DST-PRODUCTION DST DST-PRODUCTION DST DST ISOLATION ISOLATION DST 4/ft 4/ft 8/ft 8/ft 8/ft 8/ft 4/ft 8/ft 4/ft 4/ft 4/ft 4/ft 4/ft STUMP LAKE Zl- 1-35 COMPLETION AS OF 2/19/90 ! ii 30" Driven to 77' I / 20" 94# @ 424' Z.. Bowl adap[or ~; 490' 13-5/8" 62# @ 2512' Z "DV" Collar @ 3024' 3-1/2' 9.2~ N-80 BUTRESS AB-MODIFIED 1. BAKER SUB SURFACE SAFETY VALVE AT 311' 2. OTIS VST PRODUCTION PACKER 4022' 3. OTIS VST PRODUCTION PACKER AT 6565' 4. OTIS XA SLIDING SLEEVE AT 6580' 5. CARBIDE BLAST RINGS WITH A 5' OVERLAP 6. OTIS XA SLIDING SLEEVE AT 6710' 7. OTIS VST PRODUCTION PACKER AT 6716' 8. OTIS X NIPPLE AT 6735' 9. WIRELINE RENTRY GUIDE AT 6739' A. HEATER STRING 1 1/4" CS HYDRIL AT 2010' 0 DEG. INCLINATION 9 Re[ainer Junk @ 7605' 3 D.C.'S & BIT 9-5/8" 45.5-47# @ 7" 29# liner 8563'--9700' /' 6010'-6020' SQZ'D 6070'-6090' SQZ'D 6544'-6554' SQZ'D 6656'-6644' 6680'-6685' 6695'-6705' 6740'-6758' 6766'-6790' 6860'-6876' Top of cement @ 7641' 7795'-7833' Drillable B.P. @ 7950' 8160'-8 180' Top of cement at 8443' : 9230'-9260' Drillable B.P. @ 9360' 9488'-9490' 9518'-9528' SQZ'D STUMP COMPLETION LAKE 41- 33 AS OF ,3/1.3/90 30" Driven to 77' /I 3-1/2" 9.2, .N-80 BUTRESS AB-MODIFIED 20" 94# @ 424' Bowl edeptor @ 490' 15-5/8" 62# @ 2512' "DV"' Collar @ 5024' 0 DEG. INCLINATION Retoiner Junk @ 7605' !- 1. BAKER SUB SURFACE SAFETY VALVE AT 311' 2. OTIS VST PRODUCTION PACKER 4022' 3. OTIS VST PRODUCTION PACKER AT 6565' 4. OTIS XA SLIDING SLEEVE AT 6580' 5. CARBIDE BLAST RINGS WITH A 5' OVERLAP 6. OTIS XA SLIDING SLEEVE AT 6710' 7. OTIS VST PRODUCTION PACKER AT 6716' 8. OTIS PACKER SEAL BORE EXTENSION AT 6730' 9. TUBING TAIL CUT WITH A JET CUTTER AT 6733' A. HEATER STRING 1 1/4" CS HYDRIL AT 2010' 6010'-6020' SOZ'D 6070'-6090' SQZ'D 6544'-6554' SOZ'D 6636'-6644' __r 6680'-6685' 6695'-6705'- 6740'-6758' 6766'-6790' 6860'-6876' Top of cement @ 7641' 7795'-7833' Drilleble B.P. @ 7950' 3 D.C.'S &: BIT / T 8160'-8180' ~.xxx,,xxxx'~: 9230'-9260' 9-5/8"43.5-47# @ 8667~. ~ ~ Drilloble B.P. @ 9360' ' 9488'-9490' 9518'-g528' SQZ'D 7" 29# liner 8563'--9700' ,,-' % GRB 5/13/'90 · · · · · · · · · 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. STUMP LAKE 41-33 DETAILED WORKOVER PROCEDURE Move in and rig up. Remove the blind flange from the wellhead. Install and test the BOPE to 5000 psi. Notify the AOGCC 24 hfs prior to testing. This test could be done in conjunction with the official mechanical integrity test on Lewis River D-1. Run in the hole with an 8-1/2" bit to 200' and displace the 15 bbls of diesel with 80 pcf gel mud. pressure test the casing to 1500 psi. Run in the hole and clean out the cement at 5680' and the bridge plug at 5960'. Tag the bridge plug at 6620'. Make a 9-5/8" bit and casing scraper run. Run in the hole and set a drillable bridge plug at 6535'. Stab into the drillable bridge plug at 6535'. Squeeze the perforations from 6544'-6554'. Pull 6ut of the bridge plug but do not trip to the surface. Spot a high viscous pill from 6535'-6100'. Perform a breakdown on the perforations from 6010'-6020' and 6070'-6090'. Lay a balanced plug from 5800' to 6100' (124 cuft). Pull up to 5500' and reverse circulate. Braidenhead squeeze the zones from 6010'-6020' and 6070'-6090'. Pull out of the hole and make up a bit. Wait on the cement. Run in the hole and drill out the cement and retainer to 6600'. Pressure test the perforations to 500 psi surface pressure as the zones are drilled out. 30" Driven to 77' ~ 20" 94# ~ 424' 13-3/8" 62# ~ 2512' // 6695'-6705' 7" 29# liner 8563'-9700' / Top of Cemen[ ~ 5680' - Drilloble B.P. ~ 5960' T 6110'-6020' -- 6070'-6090' ~'" 6544'-6554' ' Drilloble B.P. ¢ 6620' 6'- 665 6644' ~ Drilloble B.P. ~ 6670' - 6680'-6685' ----6695'-6705' : ' Drilloble B.P. @ 6750' --- 6740'-6758' ~ Drilloble B.P. ¢ 6835' = 6860'-6876'. ~ , Drilleble B.P, $ 7045' -':- 7795'-7833' Drilloble B.P. @ 7950' ----8160'-8180' ~;==--~==:- ' Drillable B.P. @ 8443' '- 9230'-9260' x, /, Drilloble B.P, ¢ 9360' 9488'-9490' Top of cement @ 9610' 9518'-9528' STUMP LAKE 41-33 CURRENT COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: GRB SCALE: NONE DATE: 9- 12-89 21. Continue to drill out to +/- 7950' with gel mud. a) Haliburton drillable bridge plug at 6620' b) Haliburton drillable bridge plug at 6670' c) Haliburton drillable bridge plug at 6730' d) Haliburton drillable bridge plug at 6835' e) Haliburton drillable bridge plug at 7045' 22. Lay a 75' cement plug on top of the drillable bridge plug at 7950'. 23. Make a 9-5/8" bit and casing scraper run and tag the top of the cement at +/- 7875' 24. Run in the hole and set an EZSV at +/- 7600'. 25. Change the hole over to 80 PCF calcium chloride brine. 26. Stab into the EZSV at 7045' and inject the gel mud approximately 750 bbls. 27. Inject +/- 350 sxs "G" cement leaving 25 sxs on top of the EZSV at 7600'. 28. Pull out of the hole. 29. Run a cased hole neutron log from 7200' to 2500'. 30. Rep~rforate and test the zones from 6740'-6758' and 6860'-6876'. 31. Kill the well. 32. Set an EZSV at 6730'. 33. Reperforate and test the zones from 6680'-6685' and 6695'-6705'. 34. Kill the well. 35. Set an EZSV AT 6670'. 36. Reperforate and test the zone from 6636'-6644'. 37. Kill the well. 38. Drill out the bridge plugs at 6670' and 6730'. 39. Make a bit and scraper run to 7045' 40. Run a 2-7/8" production string to 6890'. 41. Run an 1-1/4" heater string to 2000'. 42, Displace 1900' of 2-7/8" tubing with nitrogen. 43. Change the top 2000' of annulus over to diesel. 44. Rig down and move out. COMPANY DRILLING FOREMAN'S INSPECTION CHECK LIST FOR BLOWOUT PREVENTER EQUIPMENT 18~ 19. 20. 21. 22, 23, 24. '25. 26. 27. 29, Does each crew have regularly scheduled BOP drills? .... _,_ .... ~ 5 · Are "on bottom" drills, "while tripping" drills, "drill collar" drills, and "out-of-hole' drills held at interva.~6, and are the times and results entered on the daily drilling report? ~ ~ Are pit level indicator, flow sensor and stroke counter working properly? ~S Do alarms work and are they set close enough to sense immediate loss or gain? Is there a specified procedure for hole filling {number of stands) and is this done more often when drill collars and heavy-wate pipe are pulled? Are charts posted on the rig showing barrels tn ~ .~umped from pits ,with various amounts of pipe removed from hole? How is hole fill-up measured? Are crews instructed as to procedures during trip if swabbing or lost circulation is detected? ~ .. ~ · Has each crew been instructe, d on proper emergency back-up operation of BOP system using nitrogen bottles? Are maximum surface pressures allowed in well specified and posted?__~_._~JO___ Has mud program been posted on location? ~=_~,e~ Is sufficient mud stock available? , .~ ~_~S The BOP equipment,r.m-~nrms to specifications with the followin~ approved exceptions: ................. __~ ( ~ Indicate time in seconds to perform the following: a) Open choke manifol..d b) Close Hydril -- c) Close pipe rams d)' Close blind rams Sec. ~ Sec, - Sec. · _ Check accumulator pressure before and after above operations and record' Before .... _._.~Cx_~PSI, After ~2 ~(~3(~) PSI, · UNOCAL WSD FAX 263-?82? PAGE 03 CONTRACT TOOL~ =,ER_'__S_..I_NSP.E..CT_ION CHE_C_~_..L.,I, ST FO_R_.,.OWOUT. P,.R,E,VENTER E~UIFN6NT WELL NANE & NUMBER ~~ ~~ ~'~1-~ $IZE AND SERIES OF BLOWOUT ~EVENTER: ..... ~.~ ~' ~ ~ The following list is to be checked by the Contract Toolpusher, signed and turned in to the Drilling Foreman as soon as possible after nipplfng up blowout preventers. It must be done prior to drilling out shoe. 1, Arc Kelly cocks in working order?_ _ . ..~ Is Kelly cook wrench available and easily io~ated? 2, Is a Lower Kelly cook with lifting device on the floor? Cross-over subs to drill collars? 3I !S the accumulator fluid level. O.K.? 4. Is a test plug available? · 7 ¢ s Znside aoP? _ _¥4~ 5. Are 80P hand wheels installed and properly braced? ~/~ 6. Are kill line, full-up line, and choke line properly installed according to specifications? H~ 7. Arc all outlets equipped with high pressure fitting~? ~ ~ 5 8. Does equipment hold accumulator pressure without leaking or unusual amount of pump operation? ~ % 9. Does accumulator pump operate without leaking? ~~ 10. Are 80P's properly braced to prevent wobble as drilling proceeds? il. Casing head inspection: (a) Did all bolts have nuts?~__.., _~.~ ........... (b) Were all nut threads fl-~lled? (o) Did you see nuts t&ghtened by appl&oation of hammer or w=ench? This equipment has been tested to ~'0~ PSI with ,, found to be in good order, vO~ ~-~K and was (ty'~e of flu---~-~) Signed by: Contract Toolpus~~ Represonttng (Contractor) 13, 14. Ex=en~e~ Page 4. 1 uo ~ney operate pr~rly'! ..... . .,_=___ ~ ~-~ Does accumulator hold pressure without leaking or unusual amount of pun)p operation? Are all valves between accumulator and BOP valves kept open at all times? 16. 17. Chokes on locatio~-~No. & Size)., .... _ Indicate below the p~sltion of the rams in the BOP stack. Size Ex=enUed Page ~,1 UNOCAL WSD FAX 263-?82? - Z- COMPANY DRILLING FOREMAN'S INSPECTION CHECK LIST FOR BLOWOUT PREVENT£R F_qUIPMEN? PAGE 05 BLOWOUT PREVENTERS The following equipment has been tested with water: Hydri 1 ~ 2. 4. 5. 6. Pi pe rams Blind rams Choke mani fold valves Kill line and valves Kelly cock · Standpipe valves ~, _.. ~- .. Safety Valves Rotary hoes MISCELLANEOUS CHECK LIST Are choke lines installed properly? Are hand wheels installed and braced? Can rams be locked in closed position from outside substructure?. ~._ 4~ 6~ Are all outlets equipped with high pressure fittings? ..~ Are relief lines of !ar, qe capacity available, if needed to hold pressure down -. on surface casing? .:, ~, Jjl Do valves operate properly? ~- ~. ....... Are handles installed and within easy reach? · g, lO. ll~ 12. 13, 14. 15, Are BOP's properly braced? Are bolts in all bolt holes? Do all bolts have nu~s? Are all threads filled? Are choke lines and emergency flowline tied into mud gas separator? Can gas separated from the mud be safely discharged or flared? __ Are there separate fill-up and kill lines? What chokes are in manifold? L. ,. UNOCAL WSD FAX 263-?829 PAGE 04 COMPANY DRILLING fOREMAN'S INSPECTION CHECK LIST FOR BLOWOUT PREVENTER EQUI_PMENT · '- . - DATE' ~_,., ~., lq ~ 0 TOP CASING HEAD FLANGE SIZE AND SERIES- __~__1_~0 ~, ....... ~,. SIZE AND SERIES OF B~O,P. EQUIPMENT' _ %he following list is to be checked by the drilling foreman, and turne~ in to the Br~ll~n~ Superintendent as soon as ¢oss~ble a~tor dr~l]~n~ out. GENERAL Is there a set of drawings available to the rig showing the DOP stack, lines, valves, and manifolds required? 2, Do all items meet or exceed the pressure rating of the B.O.P. assembly? 3~ . 5~ , 2~ ~ ~ lQ, is the B.O.P. assembly rating equal to or greater than casing burst pressure or formation b)~akdown pressure, whichever is the lesser? Is there available a step-by step set of illustrations showing how to test all BOP items, including top casing joints, in a minimum number of steps? Are these step.s followed after each nipple-up and at specified intervals thereafter?___,_. '-_ ~, ....... . What intervals? . I ~.[~_/.. ACCUMULATOR Is accumulator properly installed? ~luid capacity : Pump capaci ty__=.~ Fluid level - ~'/~ Fluid type Pressure on accumulator before operation __Standby Nitrogen bottles . ~...~._ Pressure immediately after operation Does Hydril regulator control valve operate properly? ¥~s Are al_.]_l controls properly marked?~.. , tl. Are remote control valves properly installed? ~ ...... ~,¢:~ MEMORAND..M State of Alaska ALAS~A OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Smith z::~'%'~'!-'- /' , '/ i/'/ DATE: January 17 1990 C ommis s ioner roLE NO: D. BDF. 178 TELEPHONE NO: THRU: Michael T Minder SUBJECT.' Sr Petroleum Engineer FROM: Bobby D Foster Petroleum Ins p~'Ct~ BOP Test 5Lgi Unocal S~mnp--Lake 41-33 Permit ~76-86 Stump Lake Field ~rday, January 13, i990: After witnessing an MiT on Lewis River D-i,'~ SnbjeCt Of' An.o~her ~Yport, I went to Union's Stump Lake 41-33 and witnessed the BOP test on Grace Drilling Co's rig #158. As the ~ttached BOP test report shows, there were no equipment failures. There were, however, some non-compliance items which are to be corrected and the AOGCC office notified. In summary, I witnessed the BOP test on Union's Stump Lake 41-33. Attachment M0nda ,~nuary 15, 1990: I was noti£ied this date by Larry R-~-f%ist~r~ un{6n re~p~ ~hat the well sign had been installed. 02-001A (Rev. 8/85) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMHISSION BOPE Inspection Report / Location: Sec D~ T lqd R~ Drlg contrctr ~~~ Location (general) ~ Well sign General housekeeping Reserve pit ://~ Rig j MUD SYSTEMS: Visual Trip tank Pit gauge Flow monitor Gas detectors BOPE STACK: Test Pressure Annular preventer Blind rams Choke line v,lves Kill line valves Check valve Audio DATE ~ 7 ,z Casing set Rig #_L_~_~_-- Rep ACCUHULATOR SYSTEM: ft Full charge pressure ~C2Z~) psig Press after closure /~¢FO psig Pump incr clos press 200 psig - min ~(~) sec Full charge press attained ~-/ min j~ sec Controls: Master ~C~ Remote_~ Blind switch cover VcE~ KELLY AND FLOOR SAFETY VALVES: Upper Kelly / Test pressure~'~/~-~ Lower Kelly Ball type / Test pressure Inside BOP / Test pressure Choke manifold ~,~ Test pressur~OO Number valves / /~ Number flanges Adjustable chokes Hydraulically operated choke TEST RESULTS: Failures ~ Test time 5 .. hfs Repair or replacement of failed equipment to be made within/~f~ and Inspector/Commission office notified. C.004 (rev 03/17/89) STATE OF ALASKA l"l ALASKA OIL AN D GAS CONSERVATION COM M ~bSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well .~ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulat' e __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator / 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNO~AL) Development X 39.37 KB ! Exploratory __ 3. Address L Stratigraphic __ 7. Unit or Prop?t,/name P.O. Box 190247, Anch, Ak., 99519-02~7 Service__ Stump ~.aKe feet 4. L0ca73~$w~lb~5.~af~lyti~nn~l~teHff¢¢ and 495' Westernly at right angles from the northeast corner of Sec. 33, T14N, RSW, S.M. At top of productive interval At effective depth At total depth Straight hole 8. W~I l.tn._u~ e r 9. Per,git 8~mber 10. APl number 50-- 283-20055 11. Field/Pool Stump Lake Field 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length measured true vertical ?7' 11,650' feet 11,650' feet 5,680' feet 5,680, feet Plugs(measured) 5680, 6620, 6670, 7045, 7950, 8445, Junk (measured) 6730, 6835 9360, 9610 Size Cemented Measured depth True vertical depth 30" Driven 77 ' 77 ' 424' 20" 540sxs 424' 424' 2512' 13-3/8" 2050sxs 2512' 2512' 8667' 9-5/8" lll5sxs 8667' 8667' 8563' 7" 335sxs 8563' 8563' See Attached Tubing (size. grade, and measured depth) N/A Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal __ RECEIVED OCT 1 91989 Al~$ka Oil& 8as Co.s. Commisslotl 'Anchorage Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation November 1, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas ..,%. Suspended __ Service 17. I hereby certify that the foregoing i¢[rue~and correct to the best of my knowledge. Signed ~er~-s~' ' Environmental Engineer ~FOR COMMISSION USE ONLY Date 10/18/89 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form required 1"~'-. '~ ~' 4 Approved by order of the Commission ORIGINAL LONNIE Commissioner JApprovalNo. ¢ _,/E,;~.-7 .' '..'~ '-.'-';,':'.' ~ Co[3y r:' ::-;: .![-iq Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 30" Driven to 77' t 20" 94# @ 424' Z 6695'-6705' . Top of Cement ¢ 5680' ' Drillable B.P. @ 5960' 6110'-6020' ~ 6070'-6090' i 6544'-6554' Drilloble B.P. ct 6620' 6656'-6644' ~ Drilloble B.P. Ct 6670' 1- 6680'-6685' .. ' ~ 6695'-6705' Drillable B.P. ct 6730' 6740'-6758' ' Drillable B.P. ct 6835' -- 6860'-6876' i ~ Drilioble B.P. ct 7045' == 7795'-7853' ~ Drilioble B.P. ct 7950' == 8160'-8180' : Drilloble B.P. ct 8443' Drillable B.P. ct 9360'~,_, OCT 1 f~( 9488'-9~90' Top of cement @ 9~;'~1~~'a Oil & 8as Cons. 9518'- 9528' Anchorage STUMP LAKE 41-35 CURRENT COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' GRB SCALE' NONE DATE' 9- 12-89 ED STUMP LAKE 41-33 PERFORATIONS MD COMMENTS 6,110 6,070 6,544 6,636 6,680 6,695 6,740 6,860 7,795 8,160 9,230 '-6,020' '-6,090' '-6,554' '-6,644' '-6,685' '-6,705' '-6,758' '-6,876' '-7,833' '-8,180' '-9,260' Drill Stem Test I! I! I1 II II !1 II II II II II II II I1 II II I! II II II II II II I! I! I1 II Covered by cement plug · · · · · · · · ~ 10. 11. 12. 13. 14. 15. STUMP LAKE 41-33 DETAILED WORKOVER PROCEDURE (Originally drilled and suspended in 5/78) Move in and rig up. Note: Tides greater than 33' will cover the ground surrounding the pad. Remove the blind flange from the wellhead. Install and test the BOPE to 5000 psi. Notify the AOGCC 24 hfs prior to testing. This test will be done in conjunction with the official mechanical integrity test on Lewis River D-1. Pick up the drill pipe and drill out to ~ 6600'. Run in the hole and set an EZSV drillable bridge plug at + 6535'. Squeeze the interval from 6544'-6554'. Braidenhead squeeze the zones from 6010'-6020', 6070'- 6090'. Drill out to 7045'. Lay a 75' cement plug on top of the bridge plug at 7045' Reperforate tubing conveyed and flow test as directed. Run a 2-7/8" completion with a "VST" packer @ 6600' and the tail at 6680'. Run a 3-3/8" heater string to 1800' Remove the BOPE. Install the production tree. Rig down and move out. Anticipated Static Bottom Hole Pressure' 3400 PSI Well Control Fluid CACL or NaBr BELL NIPPLE I FLOWLINE 15 5/8" 5000 psi ANNULAR 15-5/8" 5M FLANGE PIPE RAMS BLIND RAMS 2" KILL LINE WITH (2) 2" 5M VALVES KILL LINE FROM MUD PMP ,,, DOUBLE GATE 5M J 15-5/8" 5M FLANGE 1 3" CHOKE LINE WITH ONE REMOTE .... AND ONE MANUAL .3" 5M VALVE CONNECTED TO CHOKE MANIFOLD '1 I PIPE RAMS I I' I 1,5-5/8" 5M FLANGE SINGLE GATE 5M 1,5-5/8" 5M FLANGE 10" 5M x 13-5/8" 5M ADAPTER CAMERON 5M DCB SPOOL 15-5/8" DOPE 5M STACK WEST SIDE OPERATIONS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: GRb SCALE: NONE DATE: 10%11'~89 , ~. ,. ,~ ,,-, , -'a-T~AC -}L"'~h"1' NO. 5 GR~,,.. DNIL~,N~ CO~PANY RIG #158 : ' ' ' , CHOKE MANIFOLD ,!.'..'-~) ~ i ? ...~ "":.:..:......, _ !1 '-, -- ...-.-~. [ ,:~- ~.:~-. ::; ,,.'-t-.--.-,..:, .~ ..... ~ ...~ ..~,. f , .;::,.: .::..:. ~....... ,,:. '-...-' ,-- .,,.: ~' ~'.-.:.:-;.'" ':~.'"-G ..~.' - "_X,- i- '" ' ', '.?.' 'T" :~T_.~.'r. '~";': ' [~ ' i' -'. · ..'..?:, ".:-..i '.':" i i. ?'. .,..-~ -'; '-~ -;:';,~ .':.'-,-.: '.. "'~.' '~.' ' "'"'.: ,' .'. · / ~,'~'r ~ ~' ..': :" "" :L-'.:'.":..'.' 'T.'] i: ;",ii : · " "" .... '""':'":'":"" ':::?:" '":'" ":":: '""'°"' '::::" "?"":"'"i''':'tI!/..:.. ,,:,,,, '"I ' ~.'" '7-"--I'.~':'.'-' :.:...., i i .5 · 1~. "Il I'" i"."':'"1:::"'".'". :.:., i ; "'.;'-',' · o -'. .5:. . · ,..' !" ' I ' '1 o.-'.~iz-., :. · .,. · · ,..:: .~. ~ '"" I' "]' t :- ~..~ .... '-.. ' '.:, · . ,.:.. ,; ' .~..~. evron Chevron U.S.A. Inc. P.O. Box 107839, Anchorage, AK '99510 · Phone (907) 786-6600 September 10, 1986 Extension of Suspended Status Ivan River Unit Well No. 14-31 Stump Lake Well No. 41-33 Mr. L. C. Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Smith: In response to your letter of July 15, 1986 concerning the suspended status of Ivan River Unit Well No. 14-31 and Stump Lake Well No. 41-33, Chevron U.S.A. Inc. as operator is requesting a time extension of the suspended status of the two subject wells. There currently is no economic market for potential gas production from these wells and surface facilities have not been installed. Ivan River Unit Well No. 14-31 was suspended on August 18, 1975. Stump Lake Well No. 41-33 was suspended on May 14, 1978. Both wells were suspended under Alaska Oil & Gas Conservation regulations and statutes which were effective at that time. The regulation that applied to both wells was Regulation No. 2106 (Temporary Abandonment) in the 1973 Oil & Gas Conservation regulations and statutes. It states "If a well is to be temporarily abandoned and no casing pulled, then, subject to approval by the Committee, the operator shall place a plug at the top and bottom of the casing in such a manner as to prevent the intrusion of any foreign matter into the well and shall leave the well full of mud." Both wells were supended and subsequent well site inspection by AOGCC personnel were done and the sites were found satisfactory. Chevron, as operator, feels that any additional well work to meet the current regulations regarding properly plugging the subject wells is unwarranted. The wells were suspended according to regulations at the time. Both wells are in a safe, non-hazardous condition. Stump Lake Well No. 41-33 is currently shut-in with eight bridge plugs isolating perforated intervals, and a 280 ft. cement plug above the top bridge plug. Ivan River Well No. 14-31 has no open perforations and a 158 ft. Cement plug isolating the lowest fresh water sand (3420') from the top hydrocarbon sand (5840'). It should also be noted that Well 14-31 is being reviewed as an abandoment candidate. If additional work is to be done on Well 14-31, Chevron requests that it be delayed until after the abandonment review has been completed. Mr. L..C. Smith Alaska Oil & Gas Conservation Commission September 10, 1986 Page 2 Chevron welcomes any AOGCC personnel to inspect the well sites for location clearance at their convenience. Please contact Mr. G. R. Molesworth at 786-6638 to set up a time for these inspections, or if you have any further questions. Sincerely, M. K. Hauser Acting Area Operations Superintendent GRM:fr Attachments ---~- STATE OF ALASKA AL. ,A OIL AND GAS CONSERVATION CC ISSION APPLIC.ql'ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown [] Re-enter suspended well !:'.] Alter casing i3 Time extension ~ Change approved program '~ Plugging ~ Stimulate ~ Pull tubing _~ Amend order ~; Perforate ,r_; Other 2. Name of Operator Chevron U.S.A. Inc. 3. Address P. O. Box 107839, Anchorage, AK 99510 4. Location of well at surface 775' S. & 495' W., N.E. Corner of Sec. 33,.T14N, R8W, SM At top of productive interval At effective depth Same (Straight Hole) At total depth Same 5. Datum elevation (DF or KB) 25.37' G.R. feet 6. Unit or Property name Stump Lake 7. Well number 41-33 8. Permit number 76-86 9. APl number 50-- 283-20055 10. Pool N/A 11. Present well condition summary Total depth:' measured true vertical 11,650 feet 11,650 feet Effective depth: measured 9,610 feet true vertical 9,610 feet Plugs (measured) Cmt Plug @ 9610' Bridge Plugs @ 9360', 844Y, 7950', 7045', 6835', 6730', 6670', 6620', 5960' dunk (measured) @ 8345', Bit, bit sub, 3-6" drill collars, 2 x-over subs. Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 77' 30" - 77' 77' Surface 424.4' 20" 240 sacks. 424.4' 424.4' Intermediate 2512' 13 3/8" 400 sacks. 2512' 2512' Production 8667' 9 5/8" 1145 sacks. 8667' 8667' Liner 1137' 7" 335 sacks 9700' (Top @ 8563) 9700' Perforation depth: measured 6010'-6020', 6070'-6090', 6544'-6554', 6636'-6644', 6680'-6685, 6695'-6705', 6740'-6758', 6860'-6876', 783Y-7795', 8160'-8180', 9230'-9260', 9488'-9490', 9518'-9528' true vertical - Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) none 12.Attachments Description summary of proposal ~ Detailed operations program ~2 BOP sketch ' ' See cover letter. 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15.1hereby c:~tif,y th~t the foregoing is true and correct to the best of my knowledge. Signed /~__ Title ~¢r/'~'. ~ ~4~a¢ Commission Use Only Conditions of approval Notify commission so representative may witness Approval No. ~ Plug integrity ~ BOP Test ~ Location clearanceI Approved by Date ( ! ,-,,,~,'/.. -- Commissioner by order of the commission Date ~'/ --,, Form 10-403 Rev 12-1-85 Submit in triplicate STATE OF ALASKA ALA, ,A OIL AND GAS CONSERVATION COl,. ,~ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well _F;J Alter casing Iii Time extension IX Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order 1-3 Perforate [i] Other Ill 2. Name of Operator 5. Datum elevation (DF or KB) Chevron U.S.A. Inc. 25.37' G.R. feet 3. Address 6. Unit or Property name P. O. Box 107839, Anchorage, AK 99510 Stump Lake 4. Location of well at surface 775' S. & 495' W., N.E. Corner of Sec. 33,.T14N, R8W , SM At top of productive interval At effective depth Same (Straight Hole) At total depth Same 7. Well number 41-33 8. Permit number 76-86 9. APl number 50-- 283-20055 10. Pool N/A 11. Present well condition summary Total depth: measured true vertical 11,650 feet 11,650 feet Effective depth: measured 9,610 feet true vertical 9,610 feet Plugs (measured) Cmt Plug @ 9610' Bridge Plugs @ 9360', 8443', 7950', 7045', 6835', 6730', 6670', 6620', 5960' Junk (measured) @ 8345', Bit, bit sub, 3-6" drill collars, 2 x-over subs. Casing Length Size Cemented Measured depth True Vertical depth Structural ..... Conductor ??' 30" - . ??' ??' Surface 424.4' 20" .240 sacks. 424.4' 424.4' Intermediate 2512' 13 3/8" 400 sacks. 2512' 2512' Production 8667 ~ 9 5/8" 1145 sacks. 8667' 8667' Liner 1137' 7" 335 sacks 9700' (Top @ 8563) 9700' Perforation depth: measured 6010'-6020', 6070'-6090', 6544'-6554', 6636'-6644', 6680'-6685, 6695'-6705', 6740'-6758', 6860'-6876', 7833'-7795', 8160'-8180': 9~30'-9260', 9488'-9490', 9518'-9528' true vertical i~, ~ '3 ~' '~ ,. Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) none 12.Attachments Description summary of proposal iX Detailed operations program [] BOP sketch See cover letter. 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby c~e~tif,y that the foregoing is true and correct to the best of mY knowledge Signed //'~_ Title ,,4~r/w'¢, ~ Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate TI&CT 0 PIIB, IIllG~r I~l FII&L EL£VATIOI: I~lllto ~ M&T IOIl~l[ FIJOI _ ~ IETI OI BENMI8 /TrV: Z.C ~7 ITATIOI ~l'II I)IITAICf lille ' ' COllII IOIITII ItlTI 'UIT · H~rr ' i _ '' ~ L'. I, , , ,_ · · C.C. DIV. FILE PIIITII II U,I,A. IUl¥[YOlC,-,~ta ~,/a:~:' GILT. iN. NIIIT. IPT. / ! PRO. 3l 2 (2 5OD.CD,. I. 58) July 15, 1986 Mr. R. L. Thomas Area Engineer Chevron U.S.A. Inc. P. O. Box 107839 Anchorage, AK 99510 Telecopy No. (907) 276-7542 Extension of Suspended Status Ivan River Unit Well No. 14-31 Stump Lake Well No. 41-33 Dear Mr. Thomas: A review of our record~ shows that the above referenced wells are suspended. Section ll0(a) of the regulations states the Commission will, in its discretion, approve the suspension of a well if the well is capable of producing hydrocarbons in paying quantities or is reasonably demonstrated to have future value as a serivce well. Section 105(e) states that "[e]ach well to be abandoned or suspended must be plugged...to prevent the movement of fluid either into or between freshwater and hydrocarbon sources and to prevent al! other fluid migration within the well bore." In compliance with Section 170(a) of the regulations, "It]he location of an abandoned well onshore or upon a historically stable island must be cleared within one year following well abandonment .... " Section 170(b) provides the means for an extension of time if a valid reason exsists, and the wellbore is properly plugged. We are, therefore, requesting you to submit Form 10-403, Application for Sundry Approval, with a program which will bring the status of these wells into compliance with the new regulations and provide a schedule for this summer when our field inspectors can accompany your representatives to the well sites for location clearance inspection. Please call Harold J. Hedlund at (907) 279-1433 if you have any ,.questions. Comm£ss±oner jo/A.HJH.22 STATE OF ALASKA ALASKA ,oiL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 76-86 3. Address 8. APl Number P.O. Box 107839, Anchorage, Alaska 99510 50-283-20055 4. Location of Well 773' southerly and 495' westerly at right ahgles from the N.E. Cor., Sec. 33, T14N, R8W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 25.37 C.R. 6. Lease Designation and Serial No. ,~ .,-1~ ADT,-58790 12. 9. Unit or Lease Name Stump Lake 10. Well Number 41-33 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ', Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other E~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) OTHER [] .~ Suspended ~ i 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Due to the fact that surface facilities have not been installed to enable the production of this well, Chevron U.S.A. Inc. requests a one-year extension of regulation 20 AAC 25.170, location cleanup. The location has been left in a clean and orderly condition. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: R~turn~d By Order of the Commission Date Date Approved by COMMISSIONER Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate M EMORAi 'DUM State of Alaska TO: THRU: FROM: ALASKA OIL AND GAS CONSERVATIOI] COI~R. iISSION 6. V~. C~/tterton DATE: October 17, 1984 Oh~"i~',,.,~.~// ~/¢,_.,!,~ FILE NO: ~. ~ ~. ~ ~ Lonnie C. Smith / -~ Co, is s ioner ~ ~ ~~TE~E~HO~E ~O: Ben LeNo~an ~~~' SU8OECT: Inspect Chevron' s Petroleum Inspector .,¢j" Suspended Well, ~"~ Stump Lake ~41-33, Sec. 33, T141~',RSW,SM. Tuesda-,, .October 16, 1984: I departed my home at 12:30 pm for a ~~ ~ndl~O0-Pm departure via Chevron chartered Troy Air Piper Seneca for Beluga Airstrip arriving at 1:30 pm. ! was accompanied 'on this trip by Chevron representatives Ron Thomas and Nancy Blackman. inspection of Well Stump Lake #41-33 and two additional wells was completed by 4:00 pm. Suspended well and location report is attached. I departed Beluga. Airstrip at 4:30 pm, arriving in Anchorage at 5:00 pm and at my home at 5:15 pm. In s~amary, I inspected Chevron's suspended Well Stump Lake ¢~41-33. 02-001A(Rev. 10179) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: ~-~t--~ ' ~/~-¥~ o~/' _g/_.~ ~-- ~._ Da te Suspended ~-/~- ~ Address -~o~ ..~ ~ ~. ~~~~~-'~ ~. Surface L~ation Of W~ Permit No... _~-~, ~Ft. F ~z~. L, ~~ Ft. F~Z . L API No. 50~ Sec.~, T~~, R~-~ ,' ~ M. Unit or Lease Name ~~ Well No. _ ~--~ Field & Pool ~~~ ~~ Condition of Pad _ ~~m~' ~ Condition of Pi ts . ,, f~,~~ Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard · Attached to ...~?--~-~-/~ /~'_. Information correct ~ No Ye s No Ye s No ~ No Cellar - Opened Yes No Fi 1 led Ye s No Covered ~ No WaterWell - Plugged off Rat Hole Open Yes No Fi 1 led Ye s No Covered ~ No Capped Open Explanation Photographs taken to verify above conditions~ No Explanaton Work to be done to be acceptable., ~/~~ This well and location is _~cept~le~ (unacceptable) to be classi.fied as suspended for the perio~ of /~~~ 19~thru /~-/~. 19~ ' Inspected by:~~ ~2~ Da te :/~ ~ ~ t ~ Revised 8/24/82 £epte~nber 28, 1983 Chevron U.S.A. Inc. R. L. Thomas, Area Lngineer P. O. Box 107839 Anchorage, Alaska 99510 Cleanup Inspection of Suspended b'elis: Pretty Creek Unit }::o. 2~' Sec. 33, I14~', R9~, S.~<.. Ivan River i4-3l, Sec. 1, ~.~, , . . Stump Lake 41-33, Sec. 33, T14N, RSW, S.r~. [~ar ~]r. Thomas Cur representative inspected th~se well sites cn September 7, 1983 and it was found that cleanup, was satisfactcry for sus~nae~ locations. Returned are approved 10-403's, Sundry- X~otices and ~:eports on Wells, for ~ one ~'ear extension. A subsequent inspection will be necessary' by August, 19S4. Sincerely, L0nnie C.! Smitt~ : ~ ~Commissioner>': LC £/J'..~2 :lc~ 103L ~-~ ""'- STATE OF ALASKA ALASK~:.~. AND GAS CONSERVATION COt.,,VlISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator Chevron U.S.A. Inc. 3. Address P. O. Box 7-839, Anchorage, Alaska 99510 4. Location of Well 773' southerly and 495' westerly at right angles from the N.E. Cor., SeC. 33, T14N, RSW, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 25.37 G R. I 6. Lease Designation and Serial No. ADL-58790 12. 7. Permit No. 76-86 8. APl Number 50-- 283-20055 9. Unit or Lease Name Stump Lake 10. Well Number 41-33 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Suspended NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ', Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonmen.t [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Due to the fact that surface facilities have not been installed to enable the production of 'this well, Chevron U.S.A. Inc. requests a one year extension of regulation 2© AAc 25.170, location cleanup. The locatio~~ ~-~ ~-~{ a clean and orderly condition. Approved Cop~ Returned Date OTHER:~ ~' ~ 14. I hereby certify t,~t the fo,~~e and correct to the best of my knowledge. Signed . ~:~, v~ Title Area Engineer The space below for Commission use Conditions of Approval, if any:This well site w~s inspected by our representative on September 7, 1983 and cleanup was satisfactory. A subsequent inspection will be necessary by August, 1984. 'g[~iG!~A[ SIGN[Il ' ~. '' ByOrdero, Approved by ~Y "': C.SMITI! COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TRANSMITT,\I,~"~ND ACKNO~,EDGEMENT OF RECEIPT -~'~ ?D\TERIAL - DATE · :, ..... THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. -- _ FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blu~line PLEASE CHECK AND ADVISE IMMEDIATELY. -_5'p o/ 3 g '- P'~ c ~ ; /.2 t/ M 3/z.' -? ,', ,,. "' 3z3-- ? _'.'_ ." ,, ",. ,? 9'3 - 3 ': _9 ,,_ U , , ,RECEIVED REMARKS ON OTHER SIDE, THIS SHE'ET AF,,K~ORAGE, ALASKA 99510 MEMORANDUM State of Alaska TO: atterton DATE: September 9, roLE NO: 108B:BB Thru: Lonnie C. Smith~C~ Commi s s ioner FROM: Bobby Fost~r?'>'~ Petroleum Inspector TELEPHONE NO: SUBJECT: Inspect Suspended Chevron Locations Listed Below for Clean Up. Wednesday, September 7, 1983: I traveled this date with Bill Siefke and Bob Kloppenburg, Chevron representatives, to the locations listed below and inspected for wellhead status and clean up. Attached to this report are pictures showing locations and wellheads. Pretty Creek No. 2 Ivan River 14-31 Stump Lake 41- 33 It is my recommendation to the Commission that these locations be accepted as suspended from September 1983 to September 1984. Attachments 02-001 A( Rev.! 0/79) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: -- ~ 0pe'ra~r ~ ~~/~/t3 . ~.~_. _ _ Date Suspended Address ~-'~ ~- ~ .~ ~~~~ ~ .......... Surface m6ca~o~ ~f ~e[[ ..... ~ ,~ ~~$~er~i% N~. Ft. Ft. F L' API No. Sec.~, T~ ~ ~ R~ ~/,~ ~M. Unit or Lease Name ~U~ Well ~o. Field & Pool J~~Z~ Condition of Pad ~ .~ .......................... , . Condition of Pits Well head - Ail outlets plugged Well sign - Attached to well head Yes No Attached to wel~ g.uard Yes No Information correct ~e~ No Cellar -' - Wa t e rWe 1 1 Opened Yes No Rat Hole Open Yes No Fil led Yes No Fil led Yes No Covered ~ No Covered ~ No capped Open Explanation - Plugged off Photographs taken to verify above conditions~ No Explanaton Work to be done to be acceptable This well and location is (ac__cept~ble) (~unacccpta~le) ~o Inspected by:_~ _/~., -~- ~ ~ _ ...... classified as Revised 8/24/82 · . STATE OF ALASKA ' ALASK. )IL AND GAS CONSERVATION ~ MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL I-I OTHER ~ Suspended 2, Name of Operator Chevr0n U.S.A. ;[nc. 3. Address P. O. Box 7-839, Anchorage, Alaska 4, Location of Well 9951 0 773' southerly and 495' westerly at right angles from the N.E. Cor., Sec. 33, T14N, R8W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 25.37 G.R. 12. I6. Lease Designation and Serial No. ADL 58790 7, Permit No. 76,R6 8. APl Number 50-283 -2 0055 9, Unit or Lease Name ,. Stump, Lake_ 10. Well Number 41-33 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing I"l . Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans I-1 Repairs Made Pull Tubing [] Other ~] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) I-] Altering Casing I-] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see :20 AAC 25.1'05-170). Due to the fact that surface facilities have not been installed to enable the production of this well, Chevron U.S.A. Inc. requests a one year extension of regulation 20 A/kC 25.170, location cleanup. The location has been left in a clean and orderly condition. Approved Copy Returnec~ RECEIVED SEP 2 ].982 Alaska 0tl & Gas Cons. C0mmissl~n Anchorage 14. I hereby/~e, rtify that the foregoing is true and correct to the best of my knowledge. Signed_ 'Title , Area Engineer D.te 9/21/82 The space b(~lov~ for Commission us? . Conditions(Yf-Approval, ifany: ~ur representative inspected this suspended site on 'July 8, [982. De- ficiencies were found; barrel on location and in. pit, cellar uncovered, rat hole uncov- ered, water to be diverted, well sign needed, logs to be removed. It is understood these corrections have been made. A reinspection will be necessary by August 1983. By Order of O a t e .__/_'.~./. _~... _~_~. ~.~_ -- Approved by_ a, ,,' . COMMISSIONER the Commission Form 10-403 ,, Dit i ~ ii~t)' ~ .... ""~ . i a~ir.U Submit "Intentions" in Triplicate Rev. 7-1-80 DY L~(;(IE C. S~tTH and "Subsequent Reports" in Duplicate MEMOR, .,,DUM ALASKA OIL AND GAS CONSERVATION COMMISSION of Alaska To:C- V. Chatterton C ha i~~ ~~/· HRU Co--ne r FROM: Bobby Foster~'~.' Petroleum Inspector DATE: July 22, 1982 FILE NO: 108A/I TELEPHONE NO: SUBJECT: Inspect Chevron Suspended Location Listed Below for Clean-up in Compliance with A.O.G.C.C. Regulation 20 AAC 25.170 Thursda_y, Jul_y 8,. _1982 - I traveled this date to Beluga River with Bill Sieske, Chevron representative and inspected the following locations: Pre_..t_ty Creek #2 - As the attached pictures show, this lOcation, is clean., and free of any trash. The well sign is posted, the cellar is covered and the well head secure. There is no reserve pit at this location. It is my recommendation to the Commission that this location be accepted as a suspended location for one year from the date of this report, at which time another inspection will be performed. S..tump Lake #1 - As the' attached pictures show this location is level and small areas of vegetation growing on the pad .. area. The cellar is open, there is no well sign, there is a 10" pipe sticking up' near the cellar which was used as a rat hole for the kelly during the drilling of the well and there is a drum that needs to be removed from the location. The well head is secure, the reserve pit contains water and some trash -- empty barrels and cable -- and the burn pit is empty and clean. There is a flowing freshwater well on this location and at the southeast corner of the pad a 4" plastic pipe is sticking up out of the pad and what appeared to be a buried tank. Apparently this was used as a septic tank during the drilling of the well. It is my recommendation to the Commission that this location not be accepted until the following work has been' .completed: . Barrels removed from location and reverve pit Cellar covered 02-00iA(Rev.10/79) C. V. Chatt~'~n 2 .... July 22, 1982 0 4. 5. 6. 7. Rat hole cove red Septic tank vent., capped Water well flow diverted off location Well sign put up Logs .removed off location Ivan River 14-31 - As the attached pictures show this location is level and smooth. There are two suspended wells and an abandoned well on this pad. There is a water well that is flowing a very small amount of freshwater on the location- There is an open cellar and some mud pallets on location. The reserve pit contains water and there is a small amount of cable at the south end of the pit. I recommend to the Commission that this location not be accepted until the following work has been completed. . . 3. 4. 5. 6. Blind flanges or plugs be placed on well head openings. Cellar covered Well signs put on wells Mud pallets and cable removed from location Water well flow be diverted off location P & A marker be extended so all information bead welded on same is above ground level. · , . In summary I inspected the above listed locations for compliance with A.O.G.C.C. regulation 20 AAC 25.170. 20 AAC 2'3, ':<T[CI.E 2 Surface l,oca~/ol: of I4ell 20 AAC 25.120: Wlil,h ABA?:I)ON>IENT NARKi':R: Field & Pool Dia. Steel Pos~ (4"H~n.) iieiahc Above Final 6fade hutv<~l (4' Top of Marker Pipe Closed with: Cement PieS Set: On Well }lead , On Ctttoft' Cnsi~)g Distance Below ~'inal grade Level .Side Outlets: All Valves and NipI~les Re:noved All Openings Closed , With 151:Lncls , With Cement , Other INFOF. NAT!OI,i i{E,\DWr']I,DI,iI) l) ltt' '"'~' I'.C,,'.I,Y TO 'u, NF.E[~ (List I~q~ere Different from File lnfo~m,u~ion) Well Number , Sul'f,'~ce Location o~ Ft. F L, FL., F 1., Sec , T 20 AAC 25,170: i. OCATION CLt~,,\N-UP PITS · .' gilled In ":~ } i'S:%: , Liners Removed or Buried ~ , Debris Re~noved k"' .:, SURFACi'] OF PAD AND/OR I. OCAT[t,,, ..... Rough Other , Smooth L.-~-'7, ~' Con tou red Fiat CLEAN UP OF PAD AND/OR I,OCA'FI()N' Clean w./, Pipe Scrap __, Iron Scrap , Wood , Hud Paper.. , Other SURI{C)IJNI) IN(; ARt%\: Wooded , Brush , Tundra './/~-, Grass , Dirt Sand , Other , Gravel CON[) ['?ION SU ,.,~,,Us' [N(; ARI':A' Clean l~,/~;l"rash from Site · Other , Tc(_:es and/or Brust~ from C:[oav£ng Site ACCESS ROAD' ..... , Gravel !~',-- Ice __ Dirt , Otl~cr COND£TION ACCESS ROAD AND SURR()L~riI)LNG: Clean ~', Roush __, Smooth ____, Trash l:r()m (')t)et-;~t'ions; .... , Trees and/or Brush from Clearing Road , Spoil from ClearinS Road Other RECOMNENIT APPIIOVAL OF /C,/::244~2,>II,5:;'F: Yes , No ~' ]"inal l. nspec t ion INSPF. CTED 05/26/81 U.¥.ier separat~ cover, we are fo~-aAdi~g t".~;· following material, via . ~ material is not and che~e~ by: A~,.,.~,,, nil ~ f~as Cons. Coi'n~lis$iori ~nchora~e EXP-I~n Printe~ ~n U.S.A. TR~\NSHITTAL AND ACKNO~EDGEbUZNT OF RECEIPT OF }[ATERI~kL - (ALASKA) : ?nAcE: '- 'THE' FOLLOWING IS A LIST OF MATERIAL ,ENCLOSED HEREIN. PLEASE COM2ANY SCALE XEROX SEPIA o CtlECK AND ADVISg I}~[EDIATELY. · INDUCTION ELECTRICAL LOG DUAL INDUCTION LATEROLOG BOREHOLE COMPENSATED SONIC BOREHOLE COI{P. SONIC w/caliper BOREHOLE COb~. SONIC' w/gamma~ BO~HOLE TELEVIEWER CONTINUOUS DIPI'~TER- High Res. CDH- POLI%~OG PLOT CEb~NT BO~ LOG CASING COLLAR LOG - Perf. Rec. CO}~ENSATED FOP&~TION DEN. COb~ENSATED NEUTRON FOF~TION ~ALYSIS LOG __ FO~L4TION DENSITY LOG F F FO~.~TION TESTER FO~b%TION FACTOR F F _G~-~ ~Y -' G~L~ ~Y - NEUTRON G~ ~Y COLL~ LOG MICRO- LOG - " " MI CROLATEROLOG ~D LOG NEUTRON LOG PROXIHITY MICROL~ RWA COMPARISON PLOT S~NDSTONE ~ALYS IS S~,q~D SIDEWALL NEUTRON POROSITY SOHIC ~<!~ / ~ /o'-IZ TEI~E~TUF~ LOG ~/~ ~ ~z / ~~ CO:-~LETION I~t'ORT DIreCTIONAL SURVEY CORE DATA BLUELINE · Anchorage I I IOO 200 DEPARTMENT OF NAT[~RAL RESO[~RCES MINERALS AND ENERGY MANAGEMENT June 3, 1982 C.V. Chatterton Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 JAYS. HAMMOND, GOVERN 555 CORDOVA STREET POUCH 7-005 I- - ~ g:]~ '-~ ANCHORAGE, ALASKA 9951~~ -" (907) 276-2653 . STAr r=c Refernce: Release of Confidential Well Records Dear Chat: The following wells were granted extended confidentiality by the Commissioner of Natural Resources pending the offering of adjacent unleased acreage for competitive leasing. Operator Well Union Oil Co. Chevron U.S.A. Chevron U.S.A. Chevron U.S.A. Clam Gulch Unit No. 1 Well Pretty Creek Unit No. 2 Well ~mp_ Lake Unit No, Soldotna Creek Unit No. 33-33 Well The data from these wells no longer qualifies for extended confidentiality. Therefore, these data should be released to the public at your earliest convenience. Please call if you have any questions. Sincerely, D~rY~tor, DMEM cc: Bill Van Dyke April 26, 1982 MINERALS AND £AIERGY MAAIAGEMEN'T Mr. 3. J. Anders Chevron U.S.A., Inc. P.O. Box 764) San Francisco,.CA .94120 Reference: Soldotna Creek Unit No )5-5) Well Dear.Mr. Anders: JAY S. HAMMOND, O0 VERNOt~"~ POUCll 7-005 - -' {907) 276-2653 i:," ]3 ~i" ' The Division of Minerals and Energy Management recently completed a review of all wells which have been granted extended confidentiality in accordance with the provisions of AS ~1.05.0~5(c). Our records indicate that the Pretty Creek and Stump 'Lake wells were granted extended confidentiality pending the offering of adjacent unleased acreage for competitive leasing in Sales No. 33 and No. 32. Those sales were conducted on May I~, 1981 and August 25, i981, respectively; as a result, we believe the wells no longer qualify for extended confidentiality. The Soldotna Creel< well was granted extended confidentiality pending the offering off unleased acreage in the Federal OCS Sale 60 in Cook Inlet. A reasonable amount of time has lapsed since that sale was held; as a result, we believe this well no longer qualifies for extended confidentiality. Accordingly, it is my intention [o request that the Alaska Oil and Gas Conservation Commission make public data from these wells on May ~1, 1982. Should you have any questions regarding this decision, or if you feel that ~h~r~ are extenuating ' ~ czrcums~ances which should be considered prior to the release of these data, please contact me prior to May )t. Sincerely, q<ay Brown Director cc: John Katz, Commissioner, ONR C. V. Chatterton, Chairman, AOGCC June 4, 1981 Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 995].0 Re: Alaska Oil and Gas Conservation Commission Regulations Article 2, ADANDON~E~.~T AI~D PLUC, CING, 20 AAC 25~.120 ~.r:~LL ABANDON~'~ENT MAPKEE. and 20 AAC 25.170 LOCATIO~.~ CLEAN UP. : Gentlemen: In regard to the above referenced regulations, your attention is called to an attached list of wells which, according to our records, have not received a final location inspection and approval of clean up. In compliance with 20 AAC 25.170 Section (a), "~'~ithin one year of suspension or abandonment of an on- shore well", all clean up work is to l:e finished. Section (b) provides the means for an eY~tension of time if a valid reason exists. Section (c) provides for on site inspection. Consequently, we are presenting the following list of your abandoned and/or suspended wells. ~any of these are now more than one year old and are not in compliance with regulations. Others should have the final inspection completed this summer while weather permits. This list covers the years 3~75 to date. There may be some earlier wells that also need inspec- tion. If you have any earlier ~ells to be inspected this summer please infozv~ us. Therefore, we are requesting a schedule from you for this summer when our field ins~ectors can accompany your representa- tives to these sites for the final clean up inspection. urs truly? Lonnie C. Smith Commissioner LCS IJtiT: t:~ CI{EVRON U.S.A. INC. SUSPENDED Ivan River Unit 14-13 Pretty Creek Unit ~2 Soldotna Creek Unit 13-3 Stump Lake Unit 41-33 PLUCCED & ABANDOMED Eagle Creek #1 Tiglukpuk $1 (STANDARD OIL) Cape Espenberg #1 June 11, 1980 J. J. Anders Land Department Western Region Chevron, U.S.A.-, Inc. PO Box 7643 San Francisco, California 94105 Request for Extended Confidentiality - Stump Lake Unit Well f/41 - 33. · . Dear Mr. Anders: I am granting your request of March 25, 1980, for extended confidentiality pursuant to AS 31.05. 035(c) for data from the Stump Lake Unit Well f~41 - 33, Section 33, T14N, R8W, S.B.W. With respect to this well, there is considerable amount of unleased State land 1.5 miles to the southeast of the location as well as 1.0 mile to the north of the location. The well data currently on file and being held confidential by the State has significant bearing on the value of these unleased lands. Data from this well will be held confidential until a reasonable time after the issuance of leases which may be granted as the result of the Competitive Oil and Gas Lease Sale No. 33 (Upper Cook Inlet/Susitna Area). It is the Department's intent to offer open acreage within the vicinity of the Stump Lake Well f/41-33 during this sale. Anc, horafle DRAFT FOR COMMISSIONER' S SIGNATURE JUne 11, 1980 Page Two: Subsequent to the 'conduCt of the Sale No. 33, the Department will review all' wells in the Upper Cook Inlet area which are subject to extended confidentiality pursuant to AS 31.05. 035 (c) and determine which well data, if any, should be made public based upon the granting, of additional leases in the Upper Cook Inlet Area. · Sincerely, Commi s s ioner CC: Hoyle Hamilton,. Chairman Alaska Oil and Gas Conservation Commission Ross Schaff, Acting Director Division of Minerals and Energy Management Chevro. L~nd Department Western Regi(m Chevron U.S.A. Mr. Robert E.~.~.E'~.sche, Commissioner Depar tmcn.t~,~' Na tura 1' Resources S t at_e~'Alaska M Peat' Mr. LeResche: March 25, 1980 Request for Extended ConfJdent~al~ Stump Lake Unit Well I .. ])lease refer to your letter dated December 5, 1978 regarding the above well. Chevron U.S.A. Inc. again respectfully requests that all data submitted to the State of A. laska regarding the Stump Lake Unit Well //4].-33, Section 33, T14N, RSW, S.B.M. be held confidential indefinitely. This request is made pursuant to Alaska Statute 31.05.035'(c) (as amended by H.B. 815), which provides in part: ~'If 'the commissioner finds that the required reports and information contain significant information relatiug to the valuation of unleased ].and in the same v~cin~tv, shall keep the reports and information confidential for a reasonable time after the disposition of ali. affected unleased land, unless the owner of the well gives written permission to release the reports and information a.t an earlier date," Reports and information on said well, filed pursuant to A.S. 31.05.035(;~), contain significant information relating to the valuation of unleased land in the same vicinity. Specifically, an offshore/onshore sale in the Upper Cook Inlet is scheduled for December 2, 1980. (Refer' no ]?age 5 of the State Five Year Leasing Program presented to the Second SessJ. on, Eleventh Alaska Legislature, January, 1980.) Stump Lake Unit Well #4].-33 ~s el. early ~n the same vicinity as the proposed sale area of unleased land, in that the unleased land is less than one mile away. We expect that these .].ands will. be offered for sale in the December 2, 1980 sale. Thus, the valuation of these unleased lands will be directly affected by the release of this information prior to the disposition of ali. unleased lands. At present, the release date for Stump Lake Unit Wail #41-33 is June ]_3, 1980. 100 Years Helping to Create the Future Hr. Robert E. LeEesche -2- ?.Iarch 25, i980 The proximity of this date to the date of the Upper Cook Inlet sa]e, con~bined with the physical proximity of Stump Lake Unit Well ~41-33 to the unleased ].and scheduled to be sold, greatly enhances the significance of the informati~on that is the subject of this request. In fact, the c~[rcumstances outlined above clearly appear to us to be the very situation A.S. 31.05.035(c) was designed to cover. Although we understand that there may be forthcoming regulations to implement and clarify A.S. 31.05.035(c), we believe that the well data should immediately be given extended confidential, status for the reasons recited above. ~Te would appreciate your early attention to this request. Please acknowledge receipt of this letter by signing the dupli, cate copy and · ! return~.ng it to the undersigned in the enclosed envelope. Thank you for your consideration of this matter. Very truly yours, Original Signe'd By J, J. ANDER$ J. J. Anders RECEIPT ACKNO[~%EDGED THIS DAY OF , 1980 STAZE OF ALASKA COMMISSIONER OF NATURAL RESOURCES By SK2~/cm Enc io sure cc: Mr. James K. Guild, Southern California Gas Company Mr Hoyle H ttamilton, Com~pmssioner, Alaska Oil and Gas Conservation Commis s ion / · i J~ . " · j. J. Andcrs "~' D ~ O~ ~jhavr,::.~ U.S.A.~ Inc. . :_ox 7g<13 Francisco ~ California 9.4120 ! au1 tFrl~lng ill fcc?I.:,.". .. to your .!:''''-~'~''''',_~ o~ .... J~nulr,z~ , 4 , ]~79 , '-'~O ;' ~3-33 and to ~':c couccrni;~,.? ~>u ...... rna Creek U:~it i;all ',;<i uh r:..::-:; ~c'[: to, .~:o~.. .,.,~,._. ........ ,,,.,,~ r,,~,.;~.,,,~- Unit ~'?"!I,.,~ :;~. 33-3.'] a.n.:i u, cli .. v J;'ro:,~ '/<:ils suck ns t:.kis one to ;,.:.? hold <-~',nfid,,~-tial b:',v~-,:: . '- tlono for AS 31.':', ,,3.uc t~xc De'~art':,"uant .~::sucs final regula-' "~ ,,,~. ~" ,, ' ' ,-,,, ,i- a.::~andc.:-..~ 7.>./ HJ {]l~. As soon as o,,c,~ r~:gulatioDs beco ;.c .c. l' wi:"~ ~::::,:::c'c t,:.~t you file an a;~-Jl. Jcotion fo~' conf'~,'~,',:~i:iaiit:v '33--,33 ,~5 ...... ~t .... '~iO].,.l con'ri.<IcnL, lal Y¥' t'~' event you do fi" '-' .... .~.~ {-~.:~-~ a.j2l.!cat].or~ wit,:in .;O ..;alrs after Bite rccrulatJ.,_)n:'; beco:.::~:-: final ...... I ' '~ q ~ ~.~re~~ ~ ~'k ~ :': ,::! '.: '-~.,,.,. infor~:'~a'tion Do ~ .... '1,'-;" ..... '"'.' , January 5, 1979 Chevron U.S.A., Inc. P. O. Box 7-839 Anchorage, AK 99510 Attention- C. F. Kirkvold Reference: LO 78-163 (76-107) Gentlemen- Thank you for your letter of November 29, 1978. The referenced lease operations to remove the drilling rig and all materials and equipment from the well location as outlined in your letter is approved, subject to the following stipulations- · The ice and snow road is not to be built before there is one foot of ground frost and one foot of snow in the area involved. o Use of the ice and snow road shall terminate 15 March 1979 unless an extension is authorized. · When in use, the road is to be maintained in a condition so that the ground is sufficiently frozen and protected by ice to prevent any disturbance. · · Only snow and ice shall be used in constructing the winter road. Vegetation, soil, rocks or any other extraneous material is prohibited. The bridge pilings are to be sheared off at or below mud line before 15 March 1 979. · IO-J3LH Bridge abutments must be topsoiled and vegetated with indigenous coastal grasses at abandonment. e A completion report must be submitted within 15 days upon termination of permit activities. This report shall 'contain the following information. Ae Actual routes of travel and actual location 'of all camps depicted on USGS topo map. Be Ce List the vehicles used for any off-road travel that may have taken place. All-additions to original application. Statement of clean up activities. Ee F® Time spent in each campsite Methods of disposal of garbage and other camp debris. Sincerely, Ethel H. Nelson Leasing Manager Decam~ber 5, 197S .Mr. J. J. ~nders Manager Alaska Division Land - Western Region Chevron U.S.A. inc. 575 Market Street San Francisco, California 94105 Dear ~4r. Anders: I ga writing in reply to your letter of October 16, 1978, in which you request that I authorize holding data confidential under AS 31.05.035(c) as amended by ~B 815. I hereby deny your request for Soldotna Creek Unit Well 33-33. ~his well is located in ~he middle of a fully explored unit and is quite some distance from the nearest unleased state lands. Z believe to authorize indefinite confidentiality for that well would certainly bean abuse of the confidentiality provision contained in ~B 815. Stump Lake Unit well ~41-33 a . _ . . , poses more difficult problem However, I have determine~Yto deny your request at ~his time. i have directed the Division of ~4inerals and Energy Management to begin preparation of regulations to clarify and i~plement this provision of ~B 815. After those r~gu- lations are completed, you may wish to again file a request for confiden'hiality of the StUmp Lake Unit well. I would then consider your request in ~he. light of those regulations. I do not believ~ ~his should pose any problem, s for you as the existing confidentiality on the Sttmlp Lake well does not expire until June 13, 1980. · .. bcc: Tom C6ok Hoyle }iamilton REL:FHB:bll Chevron Chevron U.S.A. Inc. P. O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 August 2, 1978 State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99511 Mr. Harry W. Kugler: CHEVRON U.S.A. STUMP LAKE #41-33 SECTION 33, T14N, R8W, S.M. Wire line logs of subject well were hand delivered this date, completing State log and sample data requirements. We request all information on this well be kept "Confidential". Sincerely, DNH:adh C. F. Kirkvold C[-IEVROihl 1.:I.$. A. IN_F,. r~-,c ~ TRA.NSMITTAL .~ ^CKNO~rI.EDGEM'.£NT OF RECEIPT OF . .~TERIAL - (AI..A.S~) _ ~ .L-SS 5" $'-!¥' PML '5"' ~qt$'- ~/.z,~'~' 't~OLL tOF'2. ! I - r PLEASE CHECK AND AD~FiSE I~2~DL&TELY. APt 5o-~6~- '~o05¢ 'PiE AR RoW PLOT '~IPMETE~ (ALL I~1 C.t<S)' /'L" RECEIVED ..... .t.,,O,~q.~DCE.[E,~F OF RECEIPT OF ~TERIAL (ALASKA) TRA~SMIT'FAL ,MY ..... """ = '" .... - .... Mop Leo...e~. 4s~seeo' MCP Le4 :,/'C"- II.~:~ %P PLEASE CILECK Z,~.\*~D ADVISE I>D~DIAYELY. 'CEIVED BY Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTtiER Exploratory 2. NAME OF OPERATOR CHEVRON U..S.A. , INC. 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage, AK 99510 4. LOCATION OF WELL 775' South and 495' West from the Northeast Corner of Section 33, T14N, R8W, S.M. 5. AP! NUMERICAL CODE 50-283-20055 6. LEASE DESIGNATION AND SERIAL NO; ADL - 58790 7. IF INDIAN'ALOTTEE OR TRIBE N/~ME 8. UNIT FARM OR LEASE NAME Stump Lake Unit 9. WELL NO. 41-33 10. FIELD AND POOL, OR WILI)CAT Wildcat 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 33, T14~, 12. PERMIT NO. 76-86 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. May 1 - 2nd Continue DST #5 with pkr at 6800'. Wireline set bridge plug at 6835'. Perforated 9 5/8" csq from . .6'740' - 6758' , with four holes per foot.. May 3rd- 5th DST ~5A with pkr at 6678'. Set bridge plug at 6730'. Perforate four holes per foot 6680' to 6685' & 6695' to 6705'. DST 96 with pkr at 6610'. Set bridge plug at 6670'. May 6 - 8th Perforate four holes per foot 6636' to 6644'. DST #7 with pkr at 6580'. Set bridge plug at 6620'. Perforate four holes per foot 6544' - 6554'. DST #8 with pkr at 6488'. May 9 - 10th Perforate additional four holes per foot 6010' to 6020'. DST 99 with pkr at 5955'. Make bit run. Circ. & condition mud. Perforated four holes per foot 6070' to 6090'. DST ~10 with pkr at 5970'. ~.~Q~,;~th Ran CBL from 6114' to 3700'. C/o fill & bridges to top of ~7%_~.~ ~, ~,.~ ~ plug at 6620'. DST #10 A with pkr at 5954'. S~t bridge plug at 5960'. ~an open end dr~ll p~pe to 5960'. Equalized 100 Sx. Class G ...,. -' c,~..,~.~,,~,~,,G,~ent. Pulled 4 stands & reversed out. Pulled 4 stands. ~ay 12 - 14~h ~elt ~or cement, ~ound top at 5680'. ~illed 200' in 13 3/8" x 9 5/8" annulus w~th diesel. ~lled 200' in 9 5/8" csq w~th diesel. RemoTed ~O~E. Installed 10" - 5000 -CO~ID~I~- ps~ blank flange on top of the head. Suspend well. Release ~ R~ease rio at 6100 p.~. ~ May 14. 1978. - --' 14. ,herebycertifythat~r~~fe~o,~c~ -Area Operations SIGNED ~ ~~~~ TlTLE Superintendent DATE ~O--/3--V~ NOTE-R~ort on this fo~is r~quired for ~ach calendar month, r~ardl~ of th~ status of o~ratJons, and most bo fdhd Jn do~ficato with tho oil and ~as con~rvation committ~ by th~ ~Bth of th~ succ~din~ month,onl~ oth~rwis~ directS. DR L STEH TEST BASIC DATA REPORT WELl. NO. W.L ~, ,~ RMr Iqo~ MECHANICAL DATA ~EST NO. I ,NTERVAL~'~_..~.J?~ "('~_ CONVEN..rX~: STRADDLE J-~; OI'HER (TYPE) su..c.o,E_ '/~_" .OT.C~O~E~'/e~ ~.,~ .o~.. ~.~. qz,& ,.~,. Z74 ',,~/~,..ooAR DRILL PiPE SIZE & ~PE. ~ 'j " ~' TOP PACKER (S) SET AT: . AND AMT.PERF. ANCHOR ROT.PACKFRC~ ~,O, .q ~ RAT HOLE VOL. (BBLS.) 2 ~ ~GL% ~.. g ~O HOLE SIZ~ ~Y~' RAT HOI_E SIZE ' CSC. SIZI & WT. q~"/~" ~:~ ~'~".7 FT.:SIZE ~ WT.~(~ ~ FT. ;NO. REC.~ Fy ~&~ TEST DATA ~;IP. J tlR.~0 MIN.; 5FSI ~ HR. ~ MIN.: FFP~ HR.__ MIN.; FSIP__ HR. __ MIN.; BLOW. , CUSHION TO SURFACE -- HR., - ,, MIN., GAS TO SURFACE,- HR._ ~ MIN. ~S RATE: INITIAL ~ MCF/DAY: MAXIMUM ~ MCF/DAY: FINAL -- MCF/DAY FOi~IATION FLUID J~tru',k)L~ ..... TO SURFACE IN~ HR. ~.MIN. J AM()tJNT IF1- CiR RJLjJ C; ~ J"~FCPDIDTIff'~sl '~ ......................... : :- - : :: L~RAVI'IY ' $^LINI1Y Rw )(, , ,, C , !~. @ °F , , 0 ~ °F. V .... ~ OF. E 3OTAL FO~ATION FLUID RECOVERED O ............... ;~ R REMARKS~ ~ L~. ~ ~ . ~u~~;<' Y GAUGE LOCATION SETTING DEPTH MAX.CLOCK TIME INITIAL H.H. INITIAL F.P. INITIAL S.i.PRESS. SECOND F.P. SECOND S. I.PRESS. l- INAL F.P. FINAL S.I.PRESS· FINAL H.H. [Jilt ADDI 1' I ONAL REK~RK$ 9470 ~"- /3~. - 2C-. 7 42/3 -~ 2~-~ PRESSURE DATA OF. c~440 ~T. : 2_4~ HRS .: 273 -.3.~0 .... v Pr~,~ 'T~GHT. OF. O MAX. REG. BHT F. TEST SUCCESSFUL? MECHANICALLY ~J~'YLF S [] Nc, PRESSURES J~J YFS /Ami; 0~'~ ~ ~UA~ . T1CKFT NO. GEOLOG I ST l)A r, DR[ c STEM TEST REPORT BAS ! C DATA ~. <.~ WELl. NO ' STATE ' , ....... / -r;4~ ~.~. ' - '"~ - -' 1 c/ ../~c" ~(] / Of ~'~ ~ COUNTY ~ ~ V F I ELD ~')~'~ ~ i~ t FORMATION ..... ~A~D ELEV. 3~,3V _ ~{~e TYPE CUSHION ,~/3~ AMOtJNT t · MECHAN I CAL DATA TEST NO.--2---.INTERVAL ~/,2~-~ 0' ~,2~0 CONVEN.~:: S~RADDLE D: 07HER (TYPE), ' ~.. BOT.CHOKE DRILL COLLAR LENGTH ~.. I _ ~ ~OP PACKER (S) SET AT: . AND . _ AMT.PERF. ANCHOR ROT.PACKER,S... '&'~D. ?~¢~) ' _ HOLE SIZE, ,:~ ~ RAT HOLE 512E . ~ '~ ~ . RAT HOLE VOL.(BBLS.) ?,O~'' '5~4.~ .., ' ,'C, ~:; _:~(.~:~ FT.:SIZE & WT. 7 ~ ~7~ .- , _ _ '_ ' ~ ~ FT.:NO.REC.__ ~__ . &= : REMARKS_ ~E~' ~_.'/'~ ~'O~ ~O~:~(~ ~,~0~ .~,~__, (, ~,.,,pO~)O ~LS/F~'), ....................... TEST DATA (~_ .---m,.., 4-- ~r') '7 15"' ~,J (P.M.) IFP HRS. . MIN.; ISI-- HR. MIN. MIN.: FFP~ HR.~ MIN. :F$1P .... HR. ~ MIN.;~LOW :;11' '~ HR._ ~ MIN.: R CUSHION 'TO SURFACE -- GAS RATE: INITIAI'L. HA~J ~'30 MCF/DAY: MAXIMUM FORMATIC~N FLUID _ ~.~ · /0,:~.;:, ~ ~i- ~. &:-, ..... · .... _ HR.., - MIN. UCF/DAY: FINAL MCF/DAY N~Y'~"')[) TO SURFACE IN~ HR..~0 MIN. CC OF. : ,~, OF. OF. °'f-I TOTAL FOI:~ATION FLUID RECOVERED ' '~ GAUGE LOCATION C"~.,;'r'~:/~-' [.it) t'-.-~, L~, .· z.': "/')~/~:" MAX REG BHT F. MAX.CLOCK TIME , , ., , . H... . ..... srco~o r.~. 203<~-/Tz~ 2~7 -/6.qO /77 -tTL 146 14y~ . '-Z' '-' ....... - , , x- - 0~ .,-~¥'. ~,:~ ~ 5 s[coN~ s. ~. ............ . ........... , . FINAL F.P. ........ / FINAL S.I.PRESS. TESTING CO. : . . BHT ~)F. OF- OF. OF. TICKET NO. GEOL UA ri. DR _L STEH TEST' REPORT · BAS lC DATA MECHANICAL DATA ._~c~.~_-..,,~._~.,.~ _==.~..,_~',..,,' CONVEN.'~ STRADDLE []: OILIER (TYPE)~, SUR.CHOKE~ BOT.CHOKE ~ /' ' ' DRILL PIPE SIZE E ~PE ¢~' ~-/I It~ II lOP PACKER (S) SET AT: · AND AMT.PERF.ANCHO~ BOT,PACKER¢) =.O.~-9:~0 HOLE SIZE__~ ~ RAT HOLE SIZE ~~'~ RAT "OLE VOL.(BBLS.) 3, 4 ~ ,,. , , '~ , .... l , ' . i- ~ '. ~ 7 I i TEST DATA SE1 f'ACKER O~ OPEN TOOL ~? !0_____ J'"~'~'M~'.)(P.M,) IFP----~,,,i,~ HRS.~]~j~'''~ MIN.; t;IP. J HR, ~ MIN.: SFSI__ HR,__ MIN,: FFP.__ HR,~ MIN,:FSIP ltR._ MIN.~BLOW~ ~" . ~h' ~ ~Z ~ ~ " ~ '7, ' ,;~,~J 4~ %. c.k~e de~. 40 Lq t:,~,~ i n ~,',~ r_ ... ~,~ F~.,..,-, -.-,.~.,, .-. ,~ h~ :"-~, CUSHION TO SURFACE__ .R.__.IN.__ 6AS TO SURFACE_ ! ...~.,.. dcel +d o' ~S RATE: INITIAL ~Cr/DAY: ~AXi~u~ ~Cr/BAY; FINAL Ri At',aOLn~i (l-i. v~ I~uL..). i uLa,,.,i~,li' I|Ooi GNAVllY bALIINIIY KW ,~'~ E .......... ~C','7":" '~ .... - ..... , ,, ~ _ e .~F' 5: ~ OF. , @ OF. O ..................... · . @ OF. V ......... ~ .............. P';' ~L ....... -, ~ ~ ~ . [ ..............-- ~ ~~'~ /'~ .'., ,. ..... , ...... . _ ...... R ~ To-' o' ~~RESSURE DATA - ............... ~=~~ · ,. , , . ........ SETTING DEPTH .... FT. ., t , t ' FT. ' f / ET %[ t r ,' · FT TEST SUCCESSFUL? ' . - ; . ~ ' r .... ' ........ ' "AX.CLOCK TIME .,,%_~, ,,HRS,. , 4~'~;~HJJS' _ *7% HR.t' %~ HRS. MECHANICALLY ~YES ~ NO INITIAL H.ft. PRESSURES ~ YFS ~ NO INITIAL F.P. INITIAL S.i.PRESS. SECOND F.P. SECOND S.I.PRESS. FINAL F.P. FINAL S.I.PRESS· FINAL FI.ti. BHT , Iq__O_l, 'z fir , OF. .,~4_&c, , 'T :~8 ~,~'-.3Ff, ! 5'.3 0 (.:, ,'-/ OF. .~ EMARK S · TICK[T NO. ADDITIONAL REMARKS GEOLOGIST DArl DR.LL STEM TEST REPORT BAS lC DATA NO. ~__/-[ -- "~ '~' ' . . ~l'i~ ~ ..... I DATE~...:~-7¢ MUD 1YPEL,%;,o. WT. ~b ...... VIS._~¢~'¢~_ W.L. ~, ¢ 6~ RMF ~ ,,f. I FORMATION ~OD~ . Et. EV.~7__ ~ TYPE CIJSItlON ., ~C)~ (~ AMOHN] MECHANICAL DATA TEST NO.__~ INTERVAL..~..~O~_~__~ CONVEN.,~ STRADDLE [~; OTtlER (TYPE) ..... y~ " ~/.~ ,, SUR.CHOKEL : BOT.CHOKE : : DRILL COLLAR LENGTH ~ I.D. ~ "BIlLS/FT. DRILL PIPE SIZE & ~PE, .~2 / /' ~/~ LFNn~H ~T./~ II1.,.0,~ "eeLS/Fr. OP PACKER (S) SET AT:~O~[~' AND ~ ~ / AMT. PERF. ANCHOR ~_~ __ ROT.PACKER~_ _ T.D. O,~qS HOLE SIZE RAT HOLE SIZE ~-'~'lC~ RAT HOLE VOL.(BeES.) · //i'~/,,, ...................... TEST DATA (P.M.) I rP ~ S[-'l I'ACK£R ~o__~0~0 OPEN TOOL 8 2~__(~G H.S. ~ MIN.; ,SI ~ H. ~ MIN. ~;1'1'~ "R.~ MIN.: S¢S1~ tt". MIN.: rrP~HR. MIN.:FSIP HR. MIN.:BLOW _. ~3~ -- ~,~ - . CUSHION TO SURFACE ~ HR._ ~ ~IN.. CAS TO SURFACE., J_HR.. ¢ . ~N. ~ FOMATI~ FLUID ~ ~% TO SURFACE IN / HR. ~ MIN. 'R 'AM0-~iN--~ (F-T. OR BE~LS~) ..... DES'CRIPTION GRAVITY SALINITY Rw R ..................... [970 /:7-,, ..... ",.}'~*/ .... .: : ...... OF' O ..................., ~.; I ...... .... " @ OF"' . @ "OF.' V ..... : - ............ o.... . . ~ ,, , .- . . · ' "-Z; E .......... : · TOTAL .FORMATI ON FLUID RECOVERED ............ PRESSURE DATA SETTING DEPIH ~04-~ .... FT. ~O't'O rT. ~) C/ rT. F'S']<~Z rT. TEST SUCCESSFUL'. , . .... JNI~IAL S.i.PRESS. ~4~ 4~{~A - Zt4~: _ 4.46/ ~~oa vino. _ s~co~ ~,,. ... .3oz-.~ ..,2q~ -..s:~ ~- ¢ INAL F.P. ................ , ........ ....... , F iN~ H.H. ~O 4,~-,5-~ ~ TESTER j. c,.. ~oLcsI¢¢~ .... ,. .......... J _. . [¢tT °r °F. °F °F . , · · TICKET NO . , ,, , ,, ,, .... ~ ........ , , ,,,, .... , ...... ADDITIONAL REMARKS ~FFII f~¢. 1% T / Il^Il .L STEM TEST BAS lC DATA REPORT OPERA1OR_~_.~E3J_J:~O~I~ LEASE _.~_~"~P ~..Jl~ LOCATION__~~'~___~ ~ F,~~~COUNTY DAlE ~g~ MUD 1YPE ~L~ WT. __.~__ VIS. fORMATION _ ~b ELEV.~I,, .~: TYPE CUStilON MECHANICAL DATA , , TEST NO. 4', , INTERVAL_-~']C[~'°"'~ 8 3_~:J ::: CONVEN.~: STRADDLE D: O~HER (IYPE)_ 5UR.CHOKE ROT.CHOKE _ . DRILL COLLAR LENGTH I.D. ~ 'BBLS/FT. TOP PACKER (Si SET AT: ~~ I j lJOT.PACKER~, AND ~~. PERF. ~NCttOR ~ ~ ~T.D. ~O HOLE SIZE~ RAT HOLE SIZE ~/L~ RAT HOLE VOL.(BBLS.) .. RLMARKs ~ g~ t~~ ~~ ~~P~ ~~&O ~tPP~ ., . ., , , TEST DATA sci I'^c,~ER ~.'_J_L.~m""'"-- OPen TOOL 6. q:o'L'"'--O...~(,.,.) ,r,. -- .RS..-,.L~'" ,,,., ,S, t .R. ;;,'1' ~ Hr.~mlN.: srsl ~) tlR. ,~ MIN.: FrP HR.~MIN.:I-'SIP__HR.__MIN.:BLOW~Jt'~-TL.- CUSHION 'TO SURFACE HR.__ MIN.__ GAS TO SURFACE__HR. MIN. GAS RATE: INITIAL MCF/DAY; MAXIMUM MCF/DAY: FINAL MCF/DAY FORMATION FLUID (..,~ ~..~'t,.~"~ '"~;~..~J~.~(&'~ '"~./~_'I'I~_~ ~'~g'~_. . TO SURFACE IN~ HR. ,-, ,, -' ' ~ ,C" 0 F. , ,., ~,~ - ,. ~ °F. ,., O " C~ F. , , ~ °F ,, .... , : ': TOTAL FO~ATI~ FLUID RECOVERED 'l~2.~ 5'q ~7._~..h-q PRESSURE DATA ~7__~ ~ GAUGE LOCATION Q'.'~k.~ "~ ~k O E,(~ ~ '~,.~, ~ ~.,, ~ ~L~ J~[~ J MAX. REG. BHT~° F. ,NIliAL F.P. .... tgt-I] I 11 FINAL S.I.PRESS. %~ t 3.~ &~ tesT,n~ co.~N~BQ~o~ ' BH T oF 0 F o ~. GEOLOG I ST I~A r~ . DI LL STEM TEST REPORT BASIC DATA LOO'T,ONZZZ_F/VZ ~ q?.~F/=-l_ 6'~3~ T/"/J'/F. 8~COUNTY /"/~ }' ~, MUD TYPEJ--/..~/)O .... WT. __ VIS. EL[¥.~ ~ IYPE CUSHION.._ MECH/W ICAL DATA lEST NO._ NTERVAL~'O- ~''~7~ . CONVEN.J~. STRADDLE BI: OTHER JTYPE) SUR. CHOKE _F("] r; BOT]CHOKE ~f DRILL COLLAR LENGTH I.D. ~ 'DBLS/rT. __ DRILL PiPE SIZE & ~PE ~'~ 1/~/~ I. FNOTH ' ,T./~, (~ ,,.,.3,~2G "BBLS/Fr._,OJ4~ . __TOP PACKER (S) SET AT: ~'00, . AND_ ~ AUT.P[RF.ANCHOR .~~ HOLE SIZE RAT HOLE SiZE . ~, RAT HOLE VOL. (BBLS.)..k~' CSO. GIZI fi <. ~¢ FT.:SIZE & WT. ~ ¢. , FT. ;NO. REC.__ ~__ __&: . Xo/e : ,., .... , , rACKER TEST DATA OPEN TOOL IFP ./~ ' _ CUSHION TO SURFACE. HR. IN.__ GAS TO SURFACE HR.__MIN. GAS RATE: INITIAL MCF/DAY; MAXIMUM MCF/DAY; FINAL ': ' MCF/DAY R ....................... - v~..~. ...... v,. GRAV I TY SAL I N I TY Rw TOTAL FO~ATiON FLUID RECOVERED ~/Ol ~ .~ j~ 0 i / qj l - _ , , REMARK S ......... PRESSURE DATA SETTING DEPTH ~~ FT. ~; Z~F rT. ~/~ rT. ~7~ rT. TEST SUCC~SSrUL* MAX.C~OCK TIME 7~ HRS. ~ HRS. ~ HRS. 2~ HRS. MECHANICALLY ~ YES ~ NO , , -. INITIAL 'F.P. ~O~-~C ~ /~Z-- ~ ~,~Z ~O-~ ~.~ ~ ~CK~ -~O REMARKS SECOND S. !. PRESS. ~o/)p~d ~~e ~ FINAL F.P. ' ..... , r, .... E~NAL S.I.PRESS. ~00 ~~ Z[ST~O CO. ~r~AL' H.'H'.' ' ' ' · TtCK[T ,, ADD I T I ONAL REMARKS iqrcii (')r. I C,T llA ~I !I~--L STEH TEST REPORi BASIC DATA _ __ RM¢ .... AMOUNT MEC}-tAN I CAL DATA ~NTERVAL ~?Z'~._ CONVEN,I~: S~R^ODL£ El; OT"ER ~ .... . ......... SuR.c.o~~ BOT.C.O~, ~/~" ,, _DRILL COLLAR LENGTH I.~. eg8LS/ft._ . ToP ,AC~ is) SET.AT: '_GG~g .... ~o~,.~.,[,,.,.c.o,~ .o~.,,c~[., ....... CSG, 512[ & , ~_ ~~ ~ _ : _ _. ._.. ti --. ~ __ - .... , .... , _~ .... ~, ,,E' ,.:-~., , ' , ........ ' (. - ,. _ ....... TEST DATA CUSHION TO SURFACE HR. ~{IN. GAS TO SURFACE____HR. I~i_ s~~__ ~,~- 3-~.~ ~ ! ! '- ~_" ........... J 1470 I~° - : -"'O' 2' ~ , , . . , . , J j ~o~ ~o~,~ .~.,~ .~o~.~.... · ...... ~ ~q ¢2a~7 PRESSURE DATA ____ , ....... ~ _ _ M,*X. t~£G. _.. MAX.CLOCK TIME 7~ '_""~'.__ ~_ ""~'_. _~ """ .. A~ .~S.] -~.,,,C,,,, ~'~ U,O .,,, , ...... ~ °F- °F. °F. °F. Tm~[~ ~0. _ , , ........ . . .. · ~OLOGIST · . L~ l-~t STEH TEST REPOR.' . " ... -' · . · ' BASIC DATA ~v ~$~_~c~ ,~ . WT. ~ VIS...'~.? W.L "ur ~ OF. ~ TYPE' CUSHION . /V~<::~/~ ~- AMOUNT · o- MECHAN ! CAL DATA · ' TEST 'NO. INTERVAL_~/,O--_.._r.~_-t-(~--_L CONVEN.J~ STRADDLE ~; OTHER (~PE) .......... ~R.CHOK/~ BOT. CHOKE: ~/~ DRILL COLLAR L'EHGTH ~iLL PiPE SIZE & ~P[ ~-~/2 "FH T.B~~'HOLE SIZE RAT HOLE SIZE ~'~ / RAT ttOLE VOL. (BBLS.) ..... ............... . .... ....... , ............. ,, TEST DATA OPEN' TOOL #.l~'/'-'~C) (~..~)(p.u.} llrp ~ ,, .ns.-~~- ~lN.= ~ H.. / ~ ~1.. . ~SHI~ TO ~JRFACE HR. _ MIN .... 8AS TO SURFACE~HR.~MIN. RATE: INITIAL_~_~. .CF/OAY: U.XlUU.~'7 ,"'._ ' _ UCF/OAY, ~laAL~~ .C¢/O.Y FOI~ATIC~I FLUID 'rD SURFACE Iii HR. -- MIN. PRESSURE DATA ' IrT. SETTING DEPTM ~. '3'~ FT. ~3~' FT. ~_~.~c:~ FT. C~:.__~_.~ . . TEST SUCCESSFUL? ~X.CLO~ TIME ~ N"S. ~ . HRS. .~ HaS. 4~ HRS. M[CHANIC4LLY ~ YES ~ NO .... SEC~D S.I.PRESS. FINAL F.P. .................................... , FINAL S.I.PRESS. ~EST~N~ CO.~ , , , ..... ::: ......... ,, . ~ , , - ~T Or. or: oF. or. t, c~ ~ t .o .... ................. ADOI TIONAL REMARKS 'I..~I-LI. STEM TES:r · o '. · BASle DATA REPORT FORMATION_ 3~WO ELEV. ~ .?-~' T ~,CL,. .0. 4'/-./3 /.4~-'r W. L I · AMOtlNT , =~ I MECHAN ! CAL DATA YE' ~/~ " SUR.CHOKE . _ eOT. CHOKE ~., .._ DRILL COLLAR LENGTH I.J~. "eeLS/rt. TOP PA~ER (S) SET AT:~~O AND ~G* AMT. P[RF. ANCHOR RO T.P ACK[ R~ '~ _~ ._ FT.;NO.REC.~ f~ TEST DATA sr-~.,,^c.,~rR,,~d;..~gO opm T'OOL ,~_/O.'ZS" (,..,.!(.,..~.) ,E,~ ~,. - ..., -,.,..: s,s, - _ ...~- .,..: rF,.u.~ ,,. ~ .,..:,'s,.--~--... ~SHI~ TO SURFACE_. HR. ~N. GAS TO SURFACE,- ..HR. /~__ MIN. ' ~:~ ...... f,,T (FT. OR eeLS.} J OESCRtPT~ , , -TOTAL FO~AT! ~ FLU! D RECOVERED ,_ , ,,, , , ,, GAUGE LOCAT I ON SETT i NG DEP TH MAX. CLOCK TI ME INITIAL H;H. INITIAL F.-P. INITIAL S.i.PRESS. SECO~ID F.P. SECOND S.I.PRESS. FINAL F.P. FINAL S. i .PRESS. f INAL H.H. BHT ADDITIONAL REMARKS O u T ~6J.D ~ 9,.HRs, 370q 30_~ 7 47o- 9oo 3037 o .Z4 -"~-48 -.~-, A4-- , OUT oF. i | .~7/9 t J? oo __ o F. or-. MECHANICALLY ~ Y[S [] NO PRESSURESF YES ~ NO ~~1~. ~CSTl"~ co. TICK£T NO. I UATI' C,E. OI. OG I S T DR L STEM TEST REPORT BASIC DATA DATE ~_~ _ MUD TYPE ?_~_~~ WT. ,, _~/ -VIS. FOm,~AT,ON__~_~.D ELEV..;23'%17 ~ TYPE cus.,ou MECHANICAL. DATA SUR. CHOKE BOT. CttOK E DRILL PIPE SIZE ~" TEST DATA Sl_'l PACKER ~¢._~s~>~_._.__OPEN TOOL ¢_ /0:0(~ ~,-~,~)(P.lvl.) ,rp -~ ..... H,S. ~ ~IN.; ,SI-7 HR. -. SIP ..... / HR.~MIN : SF51 __ HR .__ MIN.: FFP~ HR, ~ MIN . ;FSIP ~ tlR. __ MIN . ;HI. OW CUSHION TO SURFACE_ _HR. M~N. GAS TO SURFACE_ HR.~MIN. ~S RATE: INITIAL ~ MCF/DAY: MAXIMUM MCF/DAY; FINAl. MCF/DAY E _ . . ~ O ?F. ,f-" ,~' r ....... (,~ OF. ¢.' oF. , , ~' OF. E i '- , ............... , TOTAL FORMATION FLUID RECOVERED .......... !R ........ >= ....... REMARK S Y · _,,~ .~.~ ,~ ............. GAUGE LOCATION SETTING DEPTH MAX.CLOCK TIME INITIAL H.H. INITIAL F.P. INITIAL $.i.PRES5. SECOND F.P. SECOND S.I.PRESS. ~INAL F.P. FINAL S.I.PRESS. FINAL H.H. BHT nit'. OF. OIV' , 3(,,o ,,07 3¢/.7 OF. MAX, REG. BHT~ F. TEST SUCCESSFUL? MECHANICALLY ~'YE5 [] NO PRESSURES '~ YES ~ NO TI'CKF T NO. GEOLOG I S T [J A 'r I DR .L STEM TEST REPORT BAS IC DATA LOCATION 7____~' ~/ qg~'' J9j. ¢'~i~..JVE (Z:~. ~~ COUNTY_ ~~ FIELD ~F~P:_.~_~ ~ DATE_~-~-7~ ~ MUD TYPE kt~O WT. 7~~ VIS. W.L. RMF .... ~ OF. J FORMATION ELEV.~~ TYPE CUSttlON . ~~ , AMOUNT MECHANICAL DATA SUR. CHOKE I/~" BOT. CHOKE, ~/~" ...... DRILL COLLAR LENGTH I .D. . ..... "BBLS/FT. DRILL PiP[ SI2E ~ ~P[ -. ~[" FI~ ,~,~,, ' ,,._!~'4 ,,,.,. ~ ",,,~/~,.~~ . TOP PACKER (S) SET A-T: ~ffS~ AND AMT.PERF.ANCHOR ~ I 'OT.PACKER~ REMARK TEST DATA q. ..s. ~ ,.,,..: ,s, _ 2_ HR. .... ,GO ~ MIN.:FSIP ~ HR. ~ MIN. ;BLOW CUSHION TO SURFACE~HR.~MIN.~ GAS TO SURFACE.._~HR.., ~MIN. ' GAS RATE: INITIAL MCF/DAY: N1AXIMUM MCF/DAY: FINAL MCF/DAY ';' TO SURF'ACE IN ~ HR, ~ MIN. ~V ,. . IOTAL [O~ATl~ FLUID RECOVERED ...... ;'. ....... ~R REMARKS Y .................. GAUGE LOCATION SETTING DEPTH MAX. CLOCK T I ME INITIAL' H.H, INITIAL F.P. INITIAL $. i.PRESS. SECOND F. P, SECOND S. I.PRESS. ~L , FINAL F.P. FINAL S.I.PRESS. FINAL H.H. BHT PRESSURE DATA ~ - ~ ~ 7. F~. TEST SUCCESSFUL? - ...... ', , · ..!_~7- Z~/? '"~ ~,f'b 3 ~ s-t ,.. OF. OF. ADDITIONAL REMARKS GEO[/J)G I ST l,a ,, LL STEM TEST BAS lC DATA REPORT DATE ~O'7~ MUD IYPE Ll6gO WT. ~ VIS. ELEV. 2~_~7 ~ TYPE CUSHION FORMATION . .._ MECHANICAL DATA 1EST NO../O__ 'NTL'RVAL_~O?/~I_-~_Of~?20JO'~J~ CONVEN~- STRADDLE' J-J: OTHER {TYPE) 5UR.CHOKE , , BOT. CHOK DRILL COLLAR LENGTH I.fJ. BOLS/FT. . _ , !!O T. P ACK [ R~ , REMARK S. , TEST DATA PACKER t~¢ O ~_OO OPEN TOOL CUSHION TO SURFACE HR MIN. GAS TO SURFACE HR. MIN :' GAS RATE: INITIAL MCF/DAY; MAXIMUM MCF/DAY: FINAL MCF/DAY FOt~VIAT I ON FLU I D TO SURFACE IN ~ tlR. __~ MIN. AI. InIIIXlT /FT /-sD ~[.,i ~ ~ i'lLcf-plp'rlt~&t ................... ' ~..' · v~~ ~%~t~ " ,~/oo p~{ ~ o~. . ~ , .. .: ~ o F. TOTAL FO~ATION FLU I D RECOVERED ~¢ . , Y - J i- g~ -- t . a~S7 .~ ,~ j~.,,~_~ V ~'~r PRESSUI~E DATA GAUGE LOCATION SETTING DEPTH MAX. CLOCK TIME I-NIIIAL H.H. INITIAL F.P. INITIAL S.i.PRESS. SECOND F.P, SECOND S.I.PRESS. FINAL FINAL S.I.PRESS. f INAL H.H. BHT o r. ?_Ze I , OF. o F. __5977 rT. , 7.~ 0~. o MAX. REG. BHT .,. F'. TEST SUCCESSFUL'/ M£CHANICALLY J~ YES [-] NO PR£SSUR[S ~ Y[S ~ NO DA ri C ' ~ Df ~'-L .... STEH TEST BAS I C DATA REPORT ' ~,A~E ~~g ._ MuD TY,E /-~,A/O wT. ~2!:::~_ -: v,s. W.L. JOR.MATIO" r. LEV. 2¢,37_~ TYPE CUSHION HU P RM F i FIELD ~_~.0j~p ~'~,~,.,.~' . I o I AMOtJN T __~ I~m t J I .I~E~E5 r MECHANICAL DATA ~ESl' NO._~:)_ : 'NIERVAL~_OZ~:'?_0;Z~ CONVEN.J~ STRADDLE E]: OTHER (TYPE) ....... SUR.CHOKE ., : BDT.CHOKE DR~LL COLLAR LENGTH I.D. ~ *BOLS/FT.--- DRILL PiPE SIZE ~ ~PE_ _yI/~" ~ brNnTH ' ,,./~,( ,,,.,.~.,0~,/,,.~ lop PACKER (5) SET AT: AND AMT.PERF. ANCHOR _ flOT.PACKER~... ¢. ~ HOLE SIZE_ RAT HOLE SIZE :~¢~': ¢,~_ RAT HOLE VOL.[BBLS.) . REMARK $ _ _ ............... ..................... ....... TEST DATA PACKER ~"Jg/_O_ OPEN TOOL ~C9 /Z;I~ , (A.M. )~ I FP ~IN.: FFP__ HR. __ 2 ..~._¢2.,.., ,,, o MIN,: FSIP__ HR. __ MIN, ; BLOW CUSHION TO SURFACE~HR .... MIN.~ GAS TO SURFACE_ HR.__MIN. !~ GAS RATE: INITIAL MCF/DAY: MAXIk1UM MCF/DAY; FINAL MCF/DAY t,~ FORMATION FLUID_._~ .~ ....~.~--'~,,~ '~_~ .,,~'~J.~' '~a__¢__~ TO SURFACE ,N~ HR. ~M,.. E ............. : ........... TOTAL FO~4ATION FLUID RECOVERED ~l(,~. ..... .-, :~ - ,~ R R~ARK S Y ..... , .............. GAUGE LOCATION SETTING DEPTH MAX.CLOCK TIME INITIAL H.H. INITIAL F.P. INITIAL S.i.PRESS. SECOND F.P. SECOND S.I.PRESS. FINAL F.P. FINAL S.I.PRESS. FINAL H.H. l'/ H R S O MAX. REG. BHT~ F. TEST SUCCESSFUL? MECHANICALLY eYES [] NO PReSSUReS ~Yr.S [] .o .... OEj~EOG I ST ;Afl COMPLETION REPORT .X,,Original Well Redrill CHEVRON U.S.A. INC. AREA: Beluga River, Alaska LAND OFFICE: Anchorage PROPERTY: Stump Lake LEASE NO: ADL-55790 WELL N0: Stump Lake #41-33 API NO: 50-283-20055 LOCATION AT SURFACE: 775' South and 495' West from NE corner of Section 33, T.14N., R.SW., SM LOCATION AT DEPTH: ELEVATION: 25.37' GR Straight Hole '-G. Matiuk/ Area Eng~fleer DRILLED BY: Brinkerhoff Rig #58 (contract) DATE COb~Z~NCED DRILLING: February 10, 1978 DATE C0~LETED: May 14, 1978 DATE OF INITIAL PRODUCTION: Suspended Producer SU~tARY TOTAL DEPTH: 11,650' EFFECTIVE DEPTH: 9610' 30" Conductor at 77'. CASING: 20" cemente~ at 424 ~0' 7" Liner cemented at 9700' (1137') with top at 8563' 9-5/8" Casing cemented at 8667' 13-3/8" Casing cemented at 2512' PLUGS:Bridge Plug 5960' Bridge Plug 6620' Bridge Plug 6670' Bridge Plug 67~0' Bridge Plug 68B5' Bridge Plug 7045' Bridge Plug 7950' Bridge Plug ~43' · Bridge Plug 9300' Cement Plug 9610' JU~K LEFT IN HOI,E: Cone. 3 ea. 8" drill Collars, one stab, one cross-over, one 12¼" bit. Bit~ bit sub, 3 - 6" drill collars, 2 X-over subs. CASING DETAIL 1 joint 20" 94# Buttress H-40 Rg.3 T&C B~d<er Stab-in shoe 9 joints 20" o~ Buttress H-4.0 Rg 3 Cemented at 19.40 3.20 401. ~0 424.40 ' Baker Shoe 1 joint 7" 29# Buttress P-110 Rg 3 T&C Float Collar 27 joints 7" 29# Buttress P-110 Rg.3 T&C , , , , , Liner tlanger Top 8563' Bottom 9700' 1.75' 36.64' 1.60' 1094.51 ' 2.50' 1137.00' Baker Shoe 1 joint 9-5/8':, 47#, Buttress, P-110, Rg.3, T&C Bsdzer Float Collar 30 joints 9-5/8", 47#, Buttress, P-110, Rg. 3, T&C X-over, Buttress Pin to 8Rd. 23 Joints 9-5/8", 47~~, Buttress, P-110, Rg. 3, T&C 1.80' 42.93 ' 121~2.24 ' 5.95' 945.26' (incluOes cross-over) 83 Joints 9-5/8", 43.5#, Buttress, P-110, Rg. 3 T&C 3403.24' (at 3024') DV collar 1.72' 62 Joints 9-5/8", 43.5#, Buttress, P-il0, Rg. 3 T&C 2527.74' Tri-State Bowl Adapter 4.97' 12 Joints 9-5/8", 43.5#, Buttress, P-110, Rg. 3 T&C 489.57' Cemented at 8667.00' 65 Joints 13-3/8", 72/I, Buttress, N-80, Rg. 3, T&C Casing Cemented at 2512' PERFORATIONS: 6010' - 6020' 6070' - 6090' 6544' - 6554' 6636' - 6644' 6680' - 6685' 6695' - 6705' 6740' - 6758' 6860' - 6876' 7833' - 7795' 8160' - 8180' 9230' - 9260' 9488' - 9489' 9490' 9518' - 9528' LOGS: Schlumberger Dual Induction-SFL with Linear Correlation Dual Induction Latero!og Borehole Compensated Sonic Long Spaced Borehole Compensated Sonic Compensated Neutron-Formation Density Compensated Formation Density High Resolution Dipmeter Proximity Microlog Cement Bond Cement Bond-Variable Density 424' - 2530' ~.. Run 1 2513' - 8659' 2" ~h~n 2 8659' - 11,654' 2" Run 3 424' - 2530' 5" Ru~ 1 2513' - 8659' 2': Run 2 8659' - 11,654' 5" Run 3 424' - 2530' 2" & 5TM P, un 1 8659' - 11,659' 2" & 5" Run 3 2513' - 8660' 2" & 5" Run 2 8658' - 11,658' 2" & 5" Run 2 2513' - $664' 5'~ Run 8659' - 11,661' 5" Run 3 2513' - 8664' 5" t'~ur~ 2 8659' -11~661' ~"~, Run 3 2513' - 8664' 5" Ru~ 1 8658' - 11,659' 5" Run 2 2513' - ~664' 5" Run 8659' - 1].,658' 5" Run 2 6000' - 9~12' 5" Run 1 8563' - 9609' 5" Run 2 3700' - 6123' 5" Run 2 Febr~uary 8, Rigged up. Drove 30" conductor to 46'. FebrRary 9, 19,78 Drove 30" conductor to 77' and cut off. Welded on 30" rotating head and flow line. Set rotary table. February !0 Spud in at 7"00 a.m. Drilled 17~" hole to 431'. Circulated hole clean. 431~' (431') 71 pcf mud February 11, 1978 Opened 26" hole 23' to 429'. · Circulated hole clean. 72 pcf mud Februar}[. 1.2, !978 Ran 426 75' 20" 94# H-40 Buttress casing ~rith stab-in shoe at 424' Ran 4~" drill pipe and stabbed into shoe at 422!. Circulated. Pumped. 450 cu. ft. Class'G cement mixed with 2.~ Gel. Circulated· P~ped 400 cu. ft. 34 CU. ft. mud. Circulated. Ran 100' drill pipe in annulus. Cemented 20'~ x 30" annulus }~ith 240 sacks Class G cement mixed with od CalciuP. Chloride ~' · Cut o~ 20" ~n~ 30" c~in~. In~t~lt~d 20" h,~d. February .13, 1978 Nippled up Class II-B B.O.P.E. and tested to 900 psi. Installed for 5000 psi service. Cleaned out cement in shoe 420' - 424'. Drilled 1~'~?'l~u hole. 431' - 696' (265') 69 pcf mud February 14 - 15~. 1978 Drilled 17~'' hole. 696' 2166' (1470') 71 pcf mud February, ,16, 1~78 Drilled 17~'' hole to 2342'. Cone left in hole· Unable to sidetrack cone. Ran in with Tri-State 15~'' junk basket. 2166' - 2343' (177') 71 pcf mud ~br~¥~ 17~ 1978 Drilled with junk basket. No recovery. Milled fish with 14" junk · mill 2346' 2356' Reamed 2290' 2356' ~ - . - . ~o recovery. Fish left in hole~ S.T. 2343' 2356' (13') 71 pcf mud Fe.bruar.yL 18, 1978 Drilled 17~'' hole to 2541'. Circulated for logs. Logged Schlumberger Dual Induction, Borehole Compensated Sonic and Dual Induction with Linear Correlation interval 424' - 2530'. 2356' - 2541' (185') 71 pcf mud Februar~.lg~ 1978 Ran 2516' of 13-3/8", 72#, N-80 Buttress casing to 2512'. Cemented with 1600 sacks cement mixed with 2 4% Gel, followed by 400 sacks Class G cement. No cement returns. Good mud returns. February 20~ 1978 Located cement in annulus at 40'. Cemented annulus to surface with 50 sacks Class G cement. Cut off 20" casing. Installed 13-3/8'~, 5000# Cameron head. Tested to 5000 psi. ~ebruary 21~ 1978 Installed Class IV B.O.P.E. per D-17 Spec. Februs~ry 22 ~ 1~78 Tested blind rams and pipe rams to 5000 psi, all valves to 5000 psi, Hydril bag to 3000 psi, Kelly and cocks to 5000 psi and 13-3/8" casing to 3000 psi. February 2~_~_ ~1~78~ Drilled out stab-in collar at 2472'. Cleaned out cement to shoe at 2512'. Drilled out shoe. Tested B.O.P.E. to 5000 psi per D-17 Spec. Drilled 12~'' hole. 2541' - 3486' (945') 71 pcf mud February 24 ~ 1978 Drilled 12~" hole to 3990'. Wash out in 8" drill collar. Drill pipe stuck at 3990'. Worked pipe· Pin broke on 8" drill c611ar. Left 96' fish in hole (3 ea. 8" drill collars, one stab, one cross-over and 12-~r,'' bit). Top of fish at 3894'. 3486' - 3990' (504') 71 pcf mud February 25, 1978. Ran in hole with Tri-State 10-5/8" overshot with 7-7/8': grapple, bumper sub and jars. Unable to jar fish loose. Mixed [:.0 sacks Black Magic oil base, 3 barrels water~, 50 barrels diesel and 125 sacks bar to 71 pcf. Discovered. pill around stuck drill collars. Jarred fish and moved pill 1/2 barrel/10 minutes. Jars quit working. Released from fish. Februar~ 2~, 1978 Laid down fishing tools Pumped in 250 sacks Class G cment mixed with 2~.( Calci~ Chloride· Displaced with 282 cu. ft. mud. Worked over cement. Top of cement at 3584'. Cleaned out cement to 3616'. Plug held at 2500# wt. 278' of plug above fish; sidetracked fish 3894' - 3991'. 71 pcf mud February 27~ 1978 Drilled off plug at 3616' with Dyna-Drill. ])yna-Drilled ahead to 3659'. Drilled with locked assembly to 4043' (53' below bottom of fish). 3616' - 4043' (427') 71 pcf mud February 28, !9_~ Drilled 12~" hole. Surveyed 404'3' - 5256'· 4043' - 5256' (1213') 77 pcf mud March 1, 1978 Drilled 12~" hole to 6136'. Reamed 6076' - 6136' 5256' - 6151'(895') · 76 pcf mud March 2 - 4, ~97_8_ Drilled 12~f," hole· 6151' - 6905' (754') 77-78 pcf mud March 5.~ 1978. Reamed 6875' - 6905'. Drilled 12~" hole. 6905' - 7428' (523') 79 pcf mud March 6 - 11, 1978 Drilled 12-~4'' hole. 7428' - 8555' (1127') $0-~6-93 pcf mud March 12, 1,,97,8 Drilled 12~," hole. to 8669'. Circulated. Made wiper trip. Circulated hole clean. 8555' - 8669' (114') 93 pcf .. March 13,. 19,78. , Logged Schlum, berger Dual Induction Laterolog and Dual Induction Laterol°g with Linear Correlation interval 2513' - 8659' Long Spaced Sonic and Borehole Compensated Sonic interval 2~1q~_~' - 8660' , Compensated Neutron-Formation Density, Formation Density and ,v_igh Resolution Dipmeter interval 2513' - 8664'. Logged Schlumberger Proximity Micro!og interval 2513' - 8664'. Shot 90 sidewall samples. Recovered 58; left 32 in hole. March 15~ .1~78 Circulated and conditioned mud. Rigged up to run 9-5/8" casing. 93 pcf mud March 1,6,,,, 1978 Ran 9-5/8" casing to 8667'. Float collar at 8621'. DV collar at 302~1'. Cemented through shoe with 815 sacks Class G cement mixed with 2.1,~ Ge].. Displaced with 664 barrels mud. Bumped plug with 1800 psi. Opened DV collar. Cemented through DV collar with 330 sacks Class G cement mixed with 2.1~ Gel. Displaced with 230 barrels mud. B~nped plug with 1600 psi. Closed DV collar. Landed 9-5/8" casing at 8667'. Tested seals to 5000 psi. Installed B.O.P.E. Marc]~ 18, 1978 Installed choke and kill line and tested per D-17 Spec. Tested top and bottom kelly cocks, pipe and blind rams to 5000 psi. Tested ~dril to 2500 psi. Retrieved bridge plug. Cleaned out DV 3024'. Cleaned out to top of baffle at 8671'. Cleaned out cement to 86B4'. Tested casing to 1~00 psi. Circulated and conditioned mud. 93 pcf mud March 19~ 1978 Cleaned out through shoe at 8667'. Pressured 'to 500 psi. Leaked off test equal to 110 pcf mud. Drilled in 8~" hole. 8669' - 8679' (10') 94 pcf ~ud March 20 - April 4~ 1978 8~'~ Drilled ~a hole. 8679' - 11,232' (2553') 9l~.-97 pcf mud April 5, 1978 Drilled $~" hole to 11,361' Twisted off pin on Kelly. 11,232' - 11,361' (129') 99.5 pcf mud April 6, 1978 4~~ Recovered fish. Circulated. Laid down three crooked joints -m drill pipe. Drilled 8~" hole. 11,361' - 11,379' (18') 99.5 pcf ~ud Apri_~ 7~ 1978 Drilled ~-2 hole. 11,379' - 11,520' (141') 104 per mud April 8, 1978 Drilled 8~'' ~ hole. Circulated and conditioned mud for logs. 11,520' - 11,650' (130') 104 pcf mud April 9, 1978 Logged Schlumberger Dual Induction Laterolog with Linear Correlation and Dual Induction Laterolog interval 8659' - 11,654', Borehole Compensated Sonic interval 8659' - 11,659', Long Spaced Borehole Compensated Sonic interval 8658' - 11,658', Compensated Neutron-Formation Density and Compensated Formation Density interval 8659' - 11,661'. Circulated and conditioned mud. 101 pcf mud April. 10, 1978 Logged Schl~berger Long Spaced Borehole Compensated Sonic interval 8658' - 11,658', High Resolution Dipmeter interval 8658' - 11,659' and Proximity Microlog interval 8659' - 11,658'. 103 pcf mud ~, ~ ~ ........ Shot 37 sidewall samples. Circulated and conditioned mud. 104 pcf mud Aori! .].2, 1978 Ran 1137' of 7" liner. Landed liner at 9700' with top at 8563'. Float collar at 9620'. Cemented 7" liner with 335 sacks Class G cement mixed collars and heavy wall drill pipe. 105 pcf mud April 13, 1978 ' to $100' Ran in hole with 9-5/8" casing scraper. Stringers of cement from 7724 · Firm cement beyond. Cleaned out cement to ~474'. 104.1 pcf mud April. 1~, 19_78 Cleaned out cement 8474' to top of liner at 8563'. Circulated and conditioned mud. Closed pipe ram~s. Tested at !000 psi for 30 minutes. Cleaned out inside of liner from 8563' to 8603'. Ran to ~643' - no cement. 100 pcf mud Ran ~ ~o,, . Tested liner to 800 psi for 15 ~-//~,~ tubing to 9620' minutes. Pulled tubing. Logged Schlumberger Cement Bond Log interval 6000' 9612'. Shot 4 - ~': ' ' - -f perforation holes at 9490 . ~ ~ pc f mud Ran Halco retainer on 2-7/8" tubing and 4~" drill pipe. Set tool at 9285'. Obtained breakdown at rate of 10 cu. ft. per minute at 2400 psi. Pu~aped 50 cu. ft. water ahead. Mixed 100 sacks Class G cement. Displaced with 500 cu. ft. mud, Closed tool and squeezed holes at9490' to 3900 psi. Bled off 8 cu. ft.-cement. Found top of cement at 9271'. ~,. ,-~- ..... 96 pcf mud April 17, ,1~78 Cleaned out hard cement 9271' to 9610'. Indication shoe broke do~ and no cement squeezed thru holes at 9490'. Circulated clean. Shot 4 - ~" perforation holes per foot interval 9lt88' - 9489'. 96 pcf mud Aoril 18. 1078 Set Halco retainer at 9285'. Established breakdown at 15 cu. ft./~inute mt 4800 psi. Pumped in 50 cu. ft. water, 100 sacks Class G cement mixed with .075~ CFR2 and .010~ retarder~ followed by 10 cu. ft. water. Mixed and displaced through Swaco choke with 500 psi back pressure. Displaced with 500 cu. ft. mud. Closed tool. Squeezed with 230 cu. ft. mud. Pressure rose from 4400 psi to 5200 psi. Bled off 9 cu. ft. mud. Reversed out mud. · No cement. Top of cement at 9441'. Cleaned out cement to 9543', Circulated clean to 9610'. April 19, ]-9,7,8 Logged Schlumberger Cement Bond Log interval 8563' - 9609'. Perforated 4 - ~'~ shot holes per foot interval 9518' - 9528'. DST #1 Interval 9518' 9528' April 19~ 1978 Set packer at 9450' with a 5/8" choke at tool. No cushion. Opened tool at 7:10 p.m. Opened tool on a ~" surface choke for a 3 hour initial flow. Light steady blow of air for 3 hours. Shut well in at tool for 8 hours and 50 minutes. Reopened tool on a ~" surface choke for 1 hour 30 minutes. Light stea~ blow of air for balance of test. Pulled tester and recovered 475' rise of 92 pcf drilling mud in 2-7/8" tubing. Rat hole volume equivalent to 442' rise in 2-7/8" tubing. Charts O.K. except for partial plugging during and flow period. 92 pcf mud April. 20~ 1978 Set bridge plug at 9360'. Perforated with 4 - ~" shot holes per foot interval 9230' - 9260'. 92 pcf mud 21, 1978 DST //2 Interval 9230' - 9260' April 21~ 1978 Set packer at 9170'; 26' of 2-7/8" tail to 9196' x 5/8" choke at tool. Opened tool on a ~" s~rface choke at 5:05 a.m. 4-21-78 for a 4 hour 10 minute initial flow on a !~" surface choke. Light steady blow with gas to surface in ~0 minutes at less than estimate 30 mcf/D rate for balance of initial flow. Shut well in at tool for 7 hour 15 minutes. Reopened tool on ~" surface choke for 1 hour 5 minutes and well continued to flow gas at less than 30 mcf/D rate for balance of test. Pulled tester and recovered 855' rise of ~as cut mud in 2-7/8" tubing. Rat hole vol~ume equivalent to 530' rise in 2-7/8:; tubing. Charts indicated plugging during flow periods. Circulated and conditioned mud to 9~o0' 92 pcf mud A~rit 22, 1978 Conditioned mud and dropped to 84 pcf. DST #2 RERLq~ Interval 9230' - 9260' ~PKi.! 22, !~78 Set packer at 9167'; tail to 9193'; 5/8" choke at tool; used 850' of water cushion. Opened tool at 8:10 p.m. 4-22-78 on a ~'~ choke for a 2 hour 5 minute initial flow. Light stea~y blow decreasing to a faint blow in 15 minutes, increasing to a light steady blow in 1 hour 30 minutes, declining to a faint blow for balance of initial flow. Gas to surface in 1 hour 15 minutes. Shut well in at tool for four hours. Reopened well on a ~" surface choke and well flowed gas at + 20 mcf/D for balance of test. Pulled tester and recovered 1030' rise in 4~" drill pipe and ~-i/o tl~i~g. Top $50' Water cushion, bottom 180' drilling fluid. Samples 1030' 515' and 0' above tool all tested 1360 PPM sodiUm chloride. Drilling fluid tested 1360 PPM sodium chloride. Charts 0.Ii. 84 pcf mud _April 23~ 1978 Ran open end tubing on 4~" drill pipe to 9360'. Equalized 80 sacks Class G cement. Worked cement. Top of cement at 9000'. Pulled up to 8663' and equalized 80 sacks Class G cement. Pulled out and laid down ~" tubing and 4-3/8" drill collar. Ran in and found top of cement at 8403'. Cleaned out cement 8403' to 8443'. 80 pcf mud Aoril 24 Worked stuck drill pipe. Valve on kill line open. Closed valve and attempted to move drill fluid. Split 9-5/8" casing 379' to 400' at 2100 psi. 4~" drill ?ioe free to top of 6" collars at 8345'. Backed off drill pipe leaving fish in hole (bit, bit sub, 3 - 6" drill collars and 2 X-overs). Ran in to 8345'. Circulated and conditioned mud. 80 pcf mud ?~,,~.~ .... April 25~ 1978' Cut 9-5/8" casing at 420'. Pulled casing, slips and packs offs. 80 pcf mud ~rril 26~ ~_L!~ Recovered 397.75' of 9-5/8" casing. Cut casing at 463'. Recovered 43.50' casing with collar. April 27, 1978 Ran in 491', 9-5/8~' casing equip't with 9-5/8" x 11'~" bowl adaptor on end. Latched onto 9-5/8" at 463' .Tested to 90,000# and 3000 psi. Landed casing head on casing. Installed tubing and tested pack off to 3000 psi. Installed Class IV B.O.P.E. and tested to 3000 psi. Conditioned mud. 80 pc f mud April 28~ 1978 Perforated 4 - ~" shot holes per foot interval 8160' - 8180'. DST#3 Interval 8160' - 8180' April 28, 1978 Set packer at 8020'; tail to 8046' x 3/4" choke at tool. No cushion. Opened tool at 2:06 p.m. 4-28-7~ on a ~'~ surface choke for a 3 hour 2 minute initial flow period which included a 15 minute sfc. Shut in after 1 hour 44 minutes. Light stea~y blow of air ~.~th Gas to surface after open 1 hour 9 minutes at 100 mcf/D rate increasing to estimate 132 mcf/D rate after open 1 hour 44 minutes. Shut in at surface for 15 minutes. Reopened tool on ~" surface choke and flowed Gas at 220-250 mcf/D for balance of initial flow. Shut well in at tool for a 6 hour shut-in. Reopened tool on ~" surface choke. Flowed Gas for 52 minutes then shut in at surface for 1 hour 15 minutes. Reopened well on ~" bean and flowed Gas at 726 to 756 mcf/D rate for balance of $ hour 22 minute second flow period. Shut in at tool for 12 hour final shut-in. Reverse circulated out 970' rise of Gas cut mud in 4~'~ drill pipe. Rat hole volume equivalent to 269' rise in 4~'~ drill pipe. Pulled tester. Charts 0.I~. 80 ~cf mud A~il ~9~ 1978 Set Schlumberger drill retainer at 7950'. Perforated 4 ~-~" shot holes per foot interval 7795' - 7833'. April 30,~ 1978 DST #4 Interval 7795' - 7833' April 30~ 1978 Set packer at 7738'; tail to 7764' x 3/4" choke at tool. No cushion, Opened tool at 9:02 a.m. 4-30-78 on a ~" surface choke. Light blow declining to dead after open 30 minutes. Shut in at tool for 1 hour 13 minutes. Unseated and reset packer at 7708'. Opened tool on ~" bean. Light blo~ declining to dead after open 30 minutes and dead for balance of 3 hour 3 minutes second f}ow period. Pulled tester and recovered 450' rise of drilling mud in 4~" drill pipe. Rat hole volume equivalent to 444' rise in 4~'' drill pipe. Charts O.K. Set Schl~]~erger EZ drill plug at 7045'. Perforated 4 - ~" shot holes per foot interval 6860' - 6876'. 80 pcf mud DST //5 Interval 6860' - 687~,' .MaM.!~ 197~8 Set packer at 6800'; tail to 6824' x B/4" choke at tool. No cushion. Opened tool at 5:10 a.m. 5-1-78 on a 1/2" surface choke. Light steady blow of air with Gas to surface in seven minutes at estimate 2141 mcf/D increasing to 5700 mcf/D after open 1 hour 5 minutes. Reduced surface choke to 3/~" and well flowed at estimated rates o~7500 to 9467 mcf/D with mud s~facing with Gas after open 1 hour 30 minute test. ~.Reduced surface bean to ~" after open 2 hour 5 minutes. Flowed GAS at estimated ~ .~ to · ~cf/D for balance of 4 hour 50 minute flow period. Shut in at tool for 4 ho~s 30 minute shut i~. Reopened tool on ~'~" choke for 1 hour 10 minutes. Flowed GAS with small heads of mud at an average rate of .5209 mcf/D. Shut well in at s~face for 2 hours. Reopened well on 3/8" surface choke for 3 hour 12 minutes and well flowed GAS ~ith mist of mud at an average rate .of 4562 mcf/D. Shut well in at surface for 3 hour 8 minute shut-in. Reopened at surface on a ~" chok. e and well flowed GAS at an average ~ 9o mcf/D for 3 hour 20 minute flow period. Shut well in at tool for 6 hour 55 minute final shut-in. Reverse circulated out 854' rise of Gas cut san~ mud. S~ples 854', 427' above and at tool all tested lB60 PPM sodiz~ chloride, 18~ sand. Drilling fluid tested 1360 PPM sodi~ chloride, ~ of 1~ sand. Rat hole vol~e is equivalent to 392~ rise in 4~TM drill pipe. Charts O.K. Ma~ 2,: 197=~ Set Schltu.~berger EZ drill at 6835' Perforated interval6740' 6758' with 4 ~' shot holes per foot. DST #SA Interval 6740' - 6758' May 2, 1978 Set packer at 6~78'; tail-to 6704'; 3/4" choke at tool. No cushion. Opened tool at 11:03 p.m. 5-2-78 on a ~" surface choke.- Initial flow period 6 hours. Light steady blow of air with GAS to surface in 12 minutes. Well flowed GAS with heads of mud and mud sprays with surface pressures stabalizing at ]_605 to 1625 psi during last 28 minutes of flow perisd. Estimate5 Gas rate during last 28 minutes was 10,610 mcf/D rate. Shut well in at tool for 5 hours 2 minutes for initial shut-in. 80 pcf mud *Rates of 2141 to 9~7 mcf/D during initial flow in error as ~uch as 50~! due to miscalibration of meter. Meter recalibrated for subsequent flow periods. ~s__J__~ ~ 1978_ DST ~'SA (continUed) Interval 67}~0' - 67~.8' May,,.3~ 1978 Opened tool at 10:05 a.m. 5-3-78 on a ~" s~rface choke for 2 hours 0 minutes. Surface pressure stabalized during last 1 hour 5 minutes of 1 hour 10 minute period. Well flo~.~ed GAS with spray of mud at 345S mcf/D rate. Change surface choke to 3/8" and flowed well for 2 hours 5 minutes including one 5 minute and one 28 minute surface shut-in periods during the initial 45 minutes of period to repair surface leaks. Surface pressure stabalized during last 50 minutes of period at 1990 psi and well flowed GAS with. mist of mud at 676~! mcf/D rate. Change surface choke to 1/2" and f!o~.~ed well for 1 hour 49 minutes. Surface pressure stabalized at 1470 psi during last 1 hour 5 minutes of period and. well flowed GAS with spray of mud at .9763 mcf/D rate. Shut well in at tool for final shut-in of 6 hours. Reverse circulated well and pulled tester. Charts O.K. (State given notice of test. Declined to witness. ) ~ ~ TM ~'"~'~ 79 pcf mud May 4,. 19~ -Msy 5, 1978 Set Schl~uberger EZ drill retai~er at 6730'. Perforated interw~ls 6680' - 6685' and 6695' - 6705' with 4 ~': shot holes per foot. DST #6 Interval 6680' - 6685' and 6695' - 670~' May 4. 107~ - T.~v q. lo?a Set packer at 6615'; tail to 6641'~ 3/4" choke at tool. No cushion. Opened tool at 6:20 p.m. 5-4-78 on a a surface choke. GAS to surface in 15 minutes. Flowed GAS with surface pressure increasing from 5 psi to 122 psi after open 2 hours 55 minutes. Shut well in at surface for 15 minutes then reopened on ~ surface choke for 2 hours 50 minutes and well flowed GAS at estimated average rate of 841 mcf/D rate. Shut well in at tool for 6 hours 10 minute initial shut-in. Opened tool on ~" surface choke for 4 hours~ and well flowed GAS at estimated rates of 1225-1286 mcf/D rates. Shut well in at s~face for 1 hour. Reopened at surface for 1 hour 55 minutes with surface pressure stabalizing during last 20 minutes at 99 psi. Well flowed GAS with spray of mud at 1307 mcf/D during stabalized period,. Changed to a ~'~ surface choke and flowed well for 2 hours 8 minutes with surface pressure stabalizing at 216 psi.. Well flowed GAS at :!~Sg ~cf/D during stabalized period. Shut well in at tool for final 6 hour shut-in. Reverse circulated out 210' of drilling fluid in 4~-~'' drill pipe, no free water. Charts indicated minor plugging 8uring initial flow. Set Schl~nberger EZ drill plug at 6670'. Perforated interval 6636' - 6644' with 4 - ~" shot holes per foot. _~ST #7 Interval 66B6' - 6644' May 6, 1978 set packer at 6580'; tail to 660~.~'; 3/4" choke at tool. h~o cushio~. Opened tool at 10:15 a.m. 5-6-78 on a-~2" surface choke for 5 hours initial flow period. Medium steady blow with GAS to surface in ].5 minutes. Flowed GAS with minor ~mounts of mud at rates of lh75 to 2044 mcf/D rates with 325 surface pressure. Shut in at tool 9 hours 45 minutes for initial shut-in. Reopened tool for four hours and we]_l flowed GAS as follows: 1/2" surface choke, 365 psi surface pressure, 22[~0 -2338 mcf/D rate 3/8" surface choke, 635 psi surface pressure~ 2089 mcf/D rate. Shut in well at tool for an 8 hour final shut-in. Reverse circulated well. Pulled tester. Charts O.K. ~, i~78 Set Schlumberger EZ drill retainer at 6620'. Perforated interva~ 6544' - 6554' with 4' ~" shot holes per foot. DST #8 Interval 6544" - 6554' May 7~ 1978 Set packer at 6488'; tail to 6514'; 3/4': choke at tool. Opened tool at 10:00 p.m. 5-7-78 on a l~" surface choke for a $ hour initial flow period. Medium blow decreasing to wes~ blow at end of flow period. GAS to surface at less 'than 30 mcf/D rate in 55 minutes. Shut in at tool for 7 hours 5 rminute initial shut-in. Reopened tool on a !~" surface choke for 1 hour 55 minutes with a weak blow of GAS throughout period. Pulled tester and recovered 90' of 79 pcf mud. Rat hole volu3'~e is equiva, lent to 324' rise in 41~" drill pipe. Charts O.tf. 80 pcf mud May 8, 1778 Perforated interval 6010' 6020' with 4 - ~" shot holes per foot. DS.T #~. Interval 6010' - 6020' May 8~ 1978 Set packer at 5955'; tail to 5981'; 3/4" choke at tool. No cushion. Opened tool at 9:50 p.m., 5-8-78 on ~" surface choke for a h hour initial flow period. Medimm blow with GAS to surface in 5 minutes. Flowed GAS with minor amounts of mud and blow declining to a faint blow at end of flow period. Shut in at tool for a 7 hour 50 minute initial shut-in. Reopened tool on a ~" surface choke for a 2 hour 20 minute flow period with a light blow declinging to a very weak blow of GAS at end of flow period. Pulled tester and recovered 415' rise in 4~" drill pipe of sandy 85-90 pcf drilling fluid. Charts O.K. Circulated and conditioned Gas cut mud to 60~5'. Perforated 4 - ~" shot holes per foot interval 60yo' - 6090'. 80 pcf mud May 10, 1978 DST #10 Intervals 6010' 6020' and 6070' 6090' .May. ]!.0~ 19[o Set packer at 5955'; tail to 5981'; 3/4" choke at tool. cushion. Opened tool at 5:24 a.m. 5-10-78. Open 3 hours on a ~" surface choke. Medium blow of air declining to faint blow of air in 31 ~inutes, then faint blow of air for balance of flow period. Shut in at tool for 6 hours. ,Reopened at tool on a lZ" surface bean for 2 hours. Faint blow of air throughout 2nd flow period. Pulled tester and recovered 975' rise of 75 to 100 pcf drilling mud in [~" drill pipe. h~o free water. Charts indicated plugging. Ran in hole and found sand at 6123'. 80 pcf mUd Cleaned out ssmd from 6123' - 6170'. Circulated and conditioned mud. Logged Schlumberger ,Cement Bond-Variable Density Log interval 3700' - 6123'. DST #10 Retest Interval 6010 '-6020' and 6070' - 6090' May 11, 197[{ Set packer at 5955'~ tail to 5951'~ 3/4" choke at tool. Used 600' of mud cushion. Opened tool at 12:15 p.m., 5-11-78. Ope~ 2 hours on a ~" surface choke. Light blow of air declining to a faint blow of air after 11 minutes and faint blow of air for balance of test. Pulled tester and recovered 1247' rise of drilling mud weighing 75-~2 Def. No free water. Charts indicated plugging. Tools badly plugged with fine sand. Set Iialco EZ drill bridge plug at 5960'. Ran open end drill pipe to 5960'. Equalized 100 sacks Class G cement. Pulled 4 stands, reversed out, pulled 4 more stands. 80 pcf mud SVBm? m ~W~' ~' ! 17'77!4 - .>TATE OF ALASKA :, OIL AND GAS CONSERVATION , j~ 50-z83-zoos5_ ~ · WELL COMPLETION OR RECOMPLETION REPORT AND LOg, ] ~-5879o b. TYPE OF COMPLETION: NEW lld II~I ~,II. r~ ~.^N .... -~ ~:I.L [_--J w~:l.l. ~ DaY [_--! Other ~:~ ~ ~.*CK gESVR. Other Chevron U. S.A. 'rna. P.O. Box 7-839, Anchorage, Alaska 99510 4, I.O(%.'I'I,}N uJ' ~ EI.L (Report location clrarl~l and itt accordance with atl~ ~tate requirements)* At nurrnce 773' souther1y and 495' westerly at right angles from xt ,,-,p proa. ,nt~¢~ ~¢,~e~$~t corner of Sec. ~¢'k/:*v ;~ ~'~::~ ....... Same as Surface *' ' At total deptl~ ':,::.cf~ .._)~-~.~ ' Same as Surface ;~ ?:'' ~ [~;'- '~:- ~'; '~ ~-' ...... 2-1~-78' ~-8-78 }LUO s,Ck! 5 14--78 ' J 25.37' gr. / J gO%V ~L~NY* ROTARY TOOLE ~650'~D ~50' TVD / 5680' ~ 5680'T~J 0-~650 ~. PII(M)UCI)~C] IN~Y2}{V;~LdSJ, OF T}IIS CO~IP~TION~TOP. BO'~O~I. NAX'iZ (~TD AND 8~60-8~80' ND an8 ~D 6680-66~5' ~ ~nd ~ 6870-6876' MD an~ TVD 6695-6705~ ND ~n~ ~D 67~0-675~' MD and TVD 6636-6644,. MD an~ ~ 24. 'FS'I'E i.~i,i'~(_";'i~l(' AND O'l'tI~t LOGS DIL, SONIC, DENSITY, ~'J. pNETER, ~ICROLOG, A~,, CF~qENT BOND LOGS - ~i_ CASING }{ECOHD ;.II.port ail strings set in 7. 1F 1NDI~N, ~'1'£E~2: Ott TIilLIE NAaME 8. UNiT,F.-MIL%I O1~ 1.,I~5.~i NAME Stump Lake 9, XVELL NO. 41-33 10, FiELD ~%-\'g POOL. Olii. \V1LDC~%T Stump Lake Field 11. SEC., T., t{,. 3I., (i3OIml'O~I HOI~E Sec. 33, T. 14 N. R. 8W. S.M. 't2, PEI~%IiT NO. 76- 86 I{T, GR, 5Tc,-JlV. ELEV CASINGttEAD ! INTER%'A!.S DRILLED BY I ' -- CABLE TOOI.S 23.%VAS DIRECTIONAL ! ~ SU~IV]EY MADE t 1510 C/~SU40 SIZE WEIGIIT. LTl t"'F J[ Gt%4. DEDJ;PTI! SET (~i !tOLE S~E I C:L_~iL.~il.~ x'.m'-~:~ ~ :~..~., 30" 46 ' . Drivan JN~e 20" 94 .._ H40 d24' 26" [ 540 aka. "G" ~t. .None ~ , 13 ~/~" , 72,, w~a 9q]9' ]7" ~ ~OqO ~k~ "~" nm~_ ]None , . .. 9 5/8" 43.5& 47 P-il0 8667' 12 1/4~"'~/: anoe w/~15aDV at 3~22/ iNone} $!Z~] 'fOP (?.ID, I;O'["l'O?.I IAID; { S~C'I{S CEME%T* 7 ..... a563' 970a' i 3q5 .. [ ~8~ P}J~')ii~'ilONS OPEN '1'~ p:R~ISN tintcrval, si .... lid ,, ....... ~,, · ~ ~ , , ~ , ..... PRODUCTION -- ~ -- J SusD~ded FNOW. TUBING CASING PRESSURE CALCU~T~ OiI~BBL. GA~-%I~ .... ' ' ~ -- ~2. lAST OF ACID, S~:C'l'. b ii,YE i CI:~, C~.IENT SQUL2Z~, ETC. .. 9490 100 sks. "G" ~t. 9490, 9488-9489 100 sks. ',G" cmt. } ' ,, ,]. .t ,,, DIL, SONICt DENSITY, DIPMETER, MICROLOG & ~EMENT BOND LOGS " 3.~ 7"1 h.r,.by "i.,;r, if y//' h:~e ~~.f"rem"l"g and~.a t tach,.~J,ir,,rm a t i,,n}~ Is comP:ere 'a ndArea cur re~'tEngineer as 'dete~L i,a-d from .i , i i .,1.1 i. I , Ills [ I , m 11 i il .... ~(See Instructions and Spaces ~or Additional Data on Reverse Side) COMJ°LETI ON REPORT Original Well ___Redrill CHEVRON U.S.A. INC. AREA: Beluga River, Alaska LAND OFFICE: Anch0~,g6' ~ ~J PROPERTY: Sttump Lake LEASE NO: ADL-58790 WELL NO: Stump Lake /,'!41-33 API NO: 50-283-20055 LOCATION AT SU!RFACE: 775' South and 495' West from NE corner of Section 33, T.14N., R.SW., SM LOCATION AT DEPTH: ELEVATION: 25.37' GR Straight Hole DATE: 5-17-78 BY: ~ _ -G. Matiu~. Z Area Engineer DRILLED BY: Brinkerhoff Rig #58 (contract) DATE CObRZ~NCED DRILLING: February 10, 1978 DATE COMPLETED: May 14, 1978 DATE OF INITIAL PRODUCTION: Suspended Producer SU~.~t~RY TOTAL DEPOt: 11,650' EFFECTIVE DEPTH: 9610' CASING: 30" Conductor at 77'. 20" cemente~ at 424.40' 7" Liner cemented at 9700' (1137') with top at 8563' 9-5/8" Casing cemented at 8667' 13-3/8" Casing cemented at 2512' PLUGS:Bridge Plug 5960' Bridge Plug 6620' Bridge Plug 6670' Bridge Plug 6730' Bridge Plug 68~5' Bridge Plug 7045' Bridge Plug 7950' Bridge Plug 8443' · Bridge Plug 9360' Cement Plug 9610' LEFT IN HOLE: Cone. 3 ea. 8" drill Collars, one stab, one cross-over, one 12%" bit. Bit, bit sub, 3 - 6" drill collars, 2 X-over subs. CASING DETAIL 1 joint 20", 94#, Buttress, H-40, Rg.3, T&C Baker Stab-in shoe 9 joints 20", 94//, Buttress, ~-40, Rg.3, T&C Cemented at 19.40 ' 3.20 401. [~0 ' 424.40 ' Baker Shoe 1 joint 7", 29#, Buttress, P-110, Rg. 3, T&C Float Collar 27 joints 7", 29#, Buttress, P-110, Rg.3, T&C Liner Hanger Top 8563', Bottom 9700' 1.75' 36.64' 1.60' 1094.51 ' 2.50' 1137.00 ' Baker Shoe 1 joint 9-5/8':, 47f, Buttress, P-il0, Rg.3, T&C Baker Float Collar 30 joints 9-5/8", 47#, Buttress, P-110, Rg. 3, T&C X-over, Buttress Pin to 8Rd. 23 Joints 9-5/8", 47#, Buttress, P-110, Rg. 3, T&C 1.80' 42.93' 1242.24' 5.95' 945.26' (includes cross-over) 83 Joints 9-5/$", 43.5#, Buttress, P-il0, Rg. 3 T&C 3403.2~' (at 3024') DV collar 1.72' 62 Joints 9-5/8", 43.5#, Buttress, P-il0, Rg. 3 T&C 2527.74' Tri-State Bowl Adapter 4.97' 12 Joints 9-5/8", 43.5#, Buttress, P-110, Rg. 3 T&C 489.57' Cemented at 8667.00' 65 Joints 13-3/8", 72#, Buttress, N-80, Rg. 3, T&C Casing Cemented at 2512' PERFORATIONS: 6010' - 6020' 6070' - 6090' 6544' - 6554' 6636' - 6644' 6680' - 6685' 6695' - 6705' 67~0' - 6758' 6860' - 6876' 7833' - 7795' 8160' - 8180' 9230' - 9260' 9488' - 9489' 9490' ~518' - 9528' LOGS: Schlumberger Dual Induction-SFL with Linear Correlation Dual Induction Laterolog Borehole Compensated Sonic Long Spaced Borehole Compensated Sonic Compensated Neutron-Formation Density Compensated Formation Density High Resolution Dipmeter Proximity Microlog Cement Bond Cement Bond-Vari~ole Density 424' - 2530' 25].3' - 8659' 8659' - 11,654' 424' - 2530' 2513' - 8659' 8659' - 11,654' ~24' - 2530' 8659' - 11,659' 2513' - 8660' 8658' - 11,658' 2513' - 8664' 8659' - 11,661' 2513' - 8664' 8659' - 11,661' 2513' - 8664' 8658' - 11,659' 2513' - 8664' 8659' - 1].,658' 6000' - 9612' 8563' - 9609' 3700' - 6123' 2" R~m 1 2" I-h~n 2 2" Run 3 5'~ Run 1 2': Run 2 5" R~m 3 2" ~-~ 5" Run 1 o,, , ~,, ~ ~ 2" & 5'~ Run 3 2" & 5" Run 2 2" & 5" Run 2 5'~ Run 1 5" Run 3 5" Run 2 5" Run 3 5TM Run 1 5'~ Run 2 5" Run 1 5" Run 2 5" Run 1 5" Run 2 5" Run 2 February 8~ 1978 Rigged up. Drove 30" conductor to 46'. February 9~ 19.78 70" rotating head Drove 30" conductor to 77' and cut off. Welded on .~ and flow line. Set rotary table. February 10, 1978 Spud in at 7"00 a.m. Drilled 17~?~ hole to 431' . Circulated hole clean. 431' (431') 71 pcf mud February 1!, 1978 Opened 26" hole 23' to 429'.-Circulated hole clean. 72 pcf mud Februar~ ~978 Ran 426 75' 20" · , , 94#, H-40 Buttress casing with stab-in shoe at ~!2~'. Ran 4~" drill pipe and stabbed into shoe at 422!. Circulated. Po~ped 450 cu. ft. Class'G cement mixed with 2.4~ Gel. Circulated. P~ped 400 cu. ft. 34 cu. ft. mud. Circulated. Ran 100' drill pipe in annulus. Cemented 20'~ x 30" annulus with 240 sacks Class G cement mixed with 3~ Calci~ Chloride· Cut off 20'~ and 30" casing. Installed 20': head. 69 pcf mud Februar~ 13, 197~8 Nippled up Class II-B B.0.P.E. and tested to 900 psi. Installed for 5000 psi service. Cleaned out cement in shoe 420' - 424'. Drilled 17!~'' hole. 431' - 696' (265') 69 pcf mud February 14 - i~ 1978 Drilled 17~'' hole. 696' - 2166' (1470') 71 pcf mud February 16, 1~78 Drilled 17~j'' hole to 2342'. Cone left in. hole. Unable to sidetrack cone. Ran in with Tri-State 15~j'' junk basket. 2166' - 2343' (177') 71 pcf mud .February 17~ 1978 Drilled with junk basket. No recovery. Milled fish with 14" junk · mill 2346' - 2356'. Re~ned 2290' - 2356'. No recovery. Fish left in hole, S.T. 2343' - 2356' (13') 71 pcf mud ?.ebr~uarY 18, Drilled 17~" hole to 2541'. Circulated for logs. Logged Schlumberger Dual Induction, Borehole Compensated Sonic and Dual Induction with Linear Correlation interval 424' - 2530'. .~ 2356' - 2541' (185') 71 pcf mud '~ February. 19, 1978 1 8", , Ran 2516' of 3-3/ 72# N-80 Buttress casing to 2512'. Cemented with 1600 sacks cement mixed with 2.4~ Gel, followed by 400 sacks Class G cement. No cement returns. Good mud returns. February 2.0, 1978 Located cement in annulus at 40'. Cemented annulus to surface with 50 sacks Class G cement. Cut off 20" casing. Installed 13-3/8", 5000# Cameron head. Tested to 5000 psi. ~'ebruary 21~ 197~ Installed Class IV B.O.P.E. per D-17 Spec. Februar)~ 22, 1~o78 Tested blind rams and pipe ra~m to 5000 psi, all valves to 5000 psi, Hydril bag to 3000 psi, Kelly and cocks to 5000 psi and13-3/8" casing to 3000 psi. February 23~ 1978 Drilled out stab-in collar at 2472'. Cleaned out cement to shoe at 2512'. Drilled out shoe. Tested B.O.P.E. to 5000 psi per D-17 Spec. Drilled 1~" hole. 2541' - 3486' (945') 71 pcf mud February 24, 1978 Drilled 12~" hole to 3990'. Wash out in 8" drill collar. Drill pipe stuck at 3990' Worked pipe. Pin broke on 8" drill collar. Left 96' fish in hole (~ ea. 8" drill collars, one stab, one cross-over and 127," bit). Top of fish at 3894 · /~. 3486' - 3990' (504') 71 pcf mud ~ Februar:f 25, 1978 Ran in hole with Tri-State 10-5/8" overshot with 7-7/8" grappl~~, ~umper. sub and jars. Unable to jar fish loose. Mixed 80 sacks Black Magic oil base, 3 barrels water, 50 barrels diesel and 125 sacks bar to 71 pcf. Discovered pill around stuck drill collars. Jarred fish and moved pill 1/2 barrel/10 minutes. Jars quit working. Released from fish. February 26, 1978 Laid down fishing tools. Pumped in 250 sacks Class G cment mixed with 2%f Calci~u'~ Chloride. Displaced with 282 cu. ft. mud. Worked over cement. Top of cement at 3584'. Cleaned out cement to 3616'. Plug held at 2500f/ wt. 278' of plug above fish; sidetracked fish 3894' - 3991'. 71 pcf mud Februa~ 27~ 1978 Drilled off plug at 3616' with Dyna-Drill. I)yna-Drilled ahead to 3689'. Drilled with locked assembly to 404~3' (53' below bottom of fish). 3616' - 404 3' (427') 71 pcf mud February 28, 19][8_ Drilled 12~" hole. Surveyed 4043' - 5256'. 4043' - 5256' (1213') 77 pcf mud March 1, 1978 Drilled 12!~'' hole to 6136'. Reamed 6076' - 6136' 5256' - 6151' (895') · 76 pcf mud March 2 - 4, 1~78 Drilled 12~¼TM hole. 6151' - 6905' 77-78 pcf mud March 5.., 197fi Reamed 6875' - 6905'. Drilled 12~" hole. 6905' - 7428' (523') 79 pcf mud March 6 - 11~ 1978 Drilled 12!~;'' hole. 7428' - 8555' (1!27') 80-86-93 pcf mud ~.jp, rch 12, 1978 12~" · · Drilled .~ hole. to 8669' Circulated Made wiper trip. Circulated hole clean. 8555' - 8669' (114') 93 pcf mud March ~13,. 1978 Logged Schlumberger Dual Induction Laterolog and Dual Induction Laterolog with Linear Correlation interval 2513' - 8659', Long Spaced. Sonic and Borehole Compensated Sonic interval 2513' - 8660', Compensated Neutron-Formation Density, Formation Density and High Resolution Dipmeter interval 25[[3' - 8664'.. Maroh lk_ 1072 Logged Schlumberger Proximity Microlog interval 2513' - 8664'. Shot 90 sidewall sa~4oles. Recovered 58; left 32 in hole. Mar____qh 15, ~!97~ Circulated and conditioned mud. Rigged up to run 9-5/8" casing. 93 pcf mud ?a~Kch 16, 1978 Ran 9-5/8" casing to 8667'. Float collar at 8621'. DV collar at 3024'. Cemented through shoe with 815 sacks Class G cement mixed with 2.17~ Ge].. Displaced with 664 barrels mud. Bumped plug with 1800 psi. Opened DV collar. Cemented through DV collar with 330 sacks Class G cement mixed with 2..1~ Gel. Displaced with 230 barrels mud. Btunped plug with ].600 psi. Closed DV collar. ~arch [,!l~..,1978 Landed 9-5/8" casing at 8667'. Tested seals to 5000 psi. Installed B.O.P.~:. March Installed choke and kill line and tested per D-17 Spec. Tested top and bottom kelly cocks, pipe and blind rs~ns to 5000 psi. Tested }l¥dril to 2500 psi. Retrieved bridge plug. Cleaned out DV 3024'. Cleaned out to top of baffle at 8671'. Cleaned out cement to 8634'. Tested casing to 1800 psi. Circulated and conditioned mud. 93 pcf mud ~ ' March 19, 1978 Cleaned out through shoe at 8667'. Pressured to 500 psi. Leake'd~o.f-f .............. ~ test equal to 110 pcf mud. Drilled in 8~" hole. 8669' - 8679' (10') 94 pcf mud March 20..- April 4~ ...]_978, Drilled 8~" hole. 8679' - 11,232' (2553') 9~.-97 pcf mud April 5, 1978 Drilled 8~" hole to ].1,361'. Twisted off pin on Kelly. 11,232' - 11,361' (129') 99.5 pcf mud April 6, 1978 Recovered fish. Circulated. Laid down three crooked joints ~" drill pipe. Drilled 8~" hole. 11,361' - 11,379' (18') 99.5 pcf mud Ap?il 7~ 1918 Drilled 8~" hole. 11,379' - 11,520' (141') 104 pcf mud April 8, 1978' Drilled 8!~'' hole. Circulated and conditioned, mud for logs. 11,520' - 11,650' (130') 104 pcf mud April 9, 1978 Logged Schlumberger Dual Induction Laterolog with Linear Correlation and Dual Induction Laterolog interval 8659' - 11,654', Borehole Compensated Sonic interval 8659' - 11,659', Long Spaced Borehole Compensated Sonic interval 8658' - 11,658', Compensated ~eutron-Formation Density and Compensated Formation Density interval 8659' - 11,661'. Circulated and conditioned mud. 101 pcf mud April 10, 1978 Logged Schlumberger Long Spaced Borehole Compensated Sonic interv~2 8658' - 11,658', High Resolution Diameter_ interval 8658' - 11,659' and Proximity Microtog interval 8659' - 11,658'. 103 pcf mud Shot 37 sidewall ss~ples. Circulated and conditioned mud. 104 pcf mud Ran 1137' of 7" liner. Landed liner at 9700' with top at 8563'. Float collar at 9620'. Cemented 7" liner with 335 sacks Class G cement mixed .075~ CFR~. Dffsnl~.o~ wit~ log ~wwol~ ~ T.~ ~.m ~ - K'~ ~n collars and heavy wall drill pipe. 105 pcf mud April 13, 1978 'Ran in hole with 9-5/8" casing scraper. Stringers of cement from 7724' to 8100'. Firm cement beyond. Cleaned out cement to 8474'. 104.1 pcf mud April !!~., 1978 Cleaned out cement 8474' to top of liner at 8563'. Circulated and conditioned mud Closed pipe rea~s Tested at 1000 psi for ..~0 minutes. Cleaned out inside of liner from 8563' to ~.603'. Ran to 8643' - no cement. 100 t~cf mud 2 7/8" . Tested liner to 800 psi for 15 Ran ~- tubing to 9620' minutes. Pulled tubing. Logged Sch!ur, berger Cement Bond Log interval 6000' - 9612'. Shot 4 - ~'? perforation holes at 9490'. 90° Pc f mud _April 16~ t97_8 Ran Halco retainer on 2-7/8" tubing and 4~" drill pipe. Set tool at 9285'. Obtained breakdown at rate of 10 cu. ft. per minute at 2400 psi. Pu~nped 50 cu. ft. water ahead. Mixed 100 sacks Class G cement. Displaced with 500 cu. ft. mud. Closed tool and squeezed holes at9490' to 3?00 psi.~ Bled off 8 cu. ft. cement. Found top of cement at 9271'. 96 pcf mud Apri.1 17~ 1978 Cleaned out hard cement 9271' to 9610'. Indication shoe broke do~m and no cement squeezed thru holes at 9490'. Circulated clean. Shot 4 - ~" perforation holes per foot interval 9~188' - 9489'. 96 pcf mud April 18. lg78 Set Halco retainer at 9285'. Established breakdown at 15 cu. ft./minute at 4800 psi. Pumped in 50 cu. ft. water, 100 sacks Class G cement mixed with .075~ CFR2 and .010~ retarder, followed by 10 cu. ft. water. Mixed and displaced through Swaco choke with 500 psi back pressvu~e. Displaced with 500 cu. ft. mud. Closed tool. Squeezed with 230 cu. ft. mud. Pressure rose from 4400 psi to 5200 psi. Bled off 9 cu. ft. mud. Reversed out mud. 'No cement. Top of cement at 9441'. Cleaned out cement to 9543'. Circulated clean to 96t0'. April ~9, 1978 Logged Schlumberger Cement Bond Log interval ~563' - 9609'. Perforated 4 - ~" shot holes per foot interval 9518' - 9528'. DST #1 Interval 9518' - 9528' April 19:.. 1978 Set packer at 9450' with a 5/8" choke at tool. No cushion. Opened tool at 7:10 p.m. Opened tool on a ~" surface choke for a 3 hour initial flow. Light steady blow of air for 3 hours. Shut well in at tool for 8 hours and 50 minutes. Reopened tool on a ~" surface choke for 1 hour 30 minutes. Light steady blow of air for balance of test. Pulled tester and recovered 475' rise of 92 pcf drilling mud in 2-7/8" tubing. Rat hole volume equivalent to 442' rise in 2-7/8" tubing. Charts O.K. except for partial plugging during 2nd ~low period. 92 pcf mud April 20~ 1978 Set bridge plug at 9360'. Perforated with 4 - ~-~" shot holes per foot interval 9230' - 9260'. 92 pcf mud April 21,. 1978 DST #2 Interval 9230' - 9260' April 21~.1978 Set packer at 9170'; 26' of 2-7/8" tail to 9196' x 5/8" choke at tool. Opened tool on a ~" surface choke at 5:05 a.m. 4-21-75 for a 4 hour 10 minute initial flow on a ~'~ surface choke. Light steady blow with gas to surface in 40 minutes at less than estimate 30 mcf/D rate for balance of initial flow. Shut well in at tool for 7 hour 15 minutes. Reopened tool on ~'~ surface choke for 1 hour 5 minutes and well continued to flow gas at less than 30 mcf/D rate. for balance of test. Pulled tester and recovered 855' rise of ~as cut mud in 2-7/8" tubing. Rat hole vol~ne equivalent to 530' rise in 2-7/8" tubing. Charts indicated plugging during flow periods. Circulated and conditioned mud to 9360'. 92 pcf mud April 22, Conditioned mud and dropped to 84 pcf. DST #2 RERL%~ Interval /o230' - 9260' Ap. ri,1, 22:19~8 Set packer at 9167'; tail to 9193'; 5/8" choke at tool; used 850' of water cushion. Opened tool at 8:10 p.m. 4-22-78 on a ~" choke for a 2 hour 5 minute initial flow'. Light stea~¥ blow decreasing to a faint blow in 15 minutes, increasing to a light steady blow' in 1 hour 30 minutes, declining to a faint blow for balance of initial flow. Gas to surface in 1 hour 15 minutes. Shut well in at tool for four hours. Reopened well on a ~" surface choke and well flowed gas at + 20 mcf/D for balance of test. Pulled tester and recovered 1030' rise in 4~" drill pipe and 2-7/8" tubing. Top 850' l'~ater cushion, bottom 180' drilling fluid. Samples 1030' , 515' and 0' above tool all tested x 13~0 PPM sodium chloride. Drilling fluid tested 1360 PPM soditm~ chloride. Charts O.i[. 8~ pcf mud A~Pril 23, 1978 Ran open end tubing on 4~" drill pipe to 9360'. Equalized 80 sacks Class G cement. Worked cement. Top of cement at 9000'. Pulled up to 8663' and equalized 80 sacks Class G cement. Pulled out and laid down ~" tubing and 4-3/8" drill collar. Ran in and found top of cement at 8403'. Cleaned out cement $403' to 8443'. 80 pcf mud . A~pri! 2.4., 1978 Worked stuck drill pipe. Valve on kill line open. Closed valve and attempted to move drill fluid. Split 9-5/8" casing 379' to ~00' at 2100 psi. 4~" drill pi~e free to top of 6" collars at 8345'. Backed. off drill pipe leaving fish in hole (bit, bit sub, 3 - 6" drill collars and 2 X-overs). Ran in to 8345'. Circulated and conditioned mud. 80 pcf mud , April _2_5, 1978 Cut 9-5/8" casing at 420'. Pulled casing, slips and packs offs. 80 pcf mud Recovered 397.75' of 9-5/8" casing. Cut casing at 463'. Recovered 43.50' casing with collar. April 27, 1978 Ran in 491', 9-5/8" casing equip't with 9-5/8" x 11~'' bowl adaptor on end. Latched onto 9-5/8" at 463'.Tested to 90,000# and 3000 psi. Landed casing head on casing. Installed tubing and tested pack off to 3000 psi. Installed Class IV B.O.P.E. and tested to 3000 psi. Conditioned mud. 80 pcf mud April Perforated 4 - ~" shot holes per foot interval 8160' - 8t80'. DST #3 Interval 8160' - 8180' April 28, 1978 Set packer at 8020'; tail to 8046' x 3/4" choke at tool. No cushion. Opened tool at 2:06 p.m. 4-28-78 on a ~" surface choke for a 3 hour 2 minute initial flow period which included a 15 minute sfc. Shut in after 1 hour h4 minutes. Light steady blow of air %~th Gas to surface after open 1 hour 9 minutes at 100 mcf/D rate increasing to estimate 132 mcf/D rate ?~. after open 1 hour 44 minutes. Shut in at surface for 15 ~ minutes. Reopened tool on ~" surface choke and flowed Gas at 220-2~0 mcf/D for balance of initial flow. Shut well in at tool for a 6 hour shut-in. Reopened tool on ~" surface choke. Flowed Gas for 52 minutes then shut in at surface for 1 hour '15 minutes. Reopened well on ~" bean and flowed Gas at 726 to 756 mcf/D rate for balance of 8 hour 22 minute second flow period. Shut in at tool for 12 hour final shut-in. Reverse circulated out 970' rise of Gas cut mud in 4~" drill pipe. Rat hole volu~ae equivalent to 269' rise in 4~'~ drill pipe. Pulled tester. Charts O.K. 80 pcf mud ~pril 29, 1~78 Set Schlumberger drill retainer at 7950'. Perforated 4 ~" shot holes per foot interval 7795' - 7833'. n~ril 30~ 17~8 DST #4 Interval 7795' - 7833' April 30~ 1978 Set packer at 7738'; tail to 7764' x 3/~" choke at tool. No cushion. Opened tool at 9:02 a.m. 1~-30-78 on a ~" surface choke. Light blow declining to dead after open 30 minutes. Shut in at tool for 1 hour 13 minutes. Unseated and reset packer at ~708'. Opened tool on ~" bean. Light blow declining to dead after open 30 minutes and dead for balance of 3 hour 3 minutes second flow period. Pulled tester and recovered 450' rise of drilling mud in 4~" drill pipe. Rat hole volume equivalent to 444' rise in 4~'' drill pipe. Charts O.K. Set Schlumberger EZ drill plug at 7045'. Perforated 4 - ~" shot holes per foot interval 6860' - 6876'. 80 pcf mud DST #~ Interval 6860' - 6g, 76' May 1~ ].978 Set ~acker at 6C, 00'; tail to 6524' x 3/4" choke at tool. No cushion. Opened tool at 5:].0 a.m. 5-1-7~~ on a 1/2" surface choke. Light steady blow of air with Gas to surface in seven minutes at estimate 2141 mcf/D increasing to ~700 mcf/D after open t hour 5 minutes. !~educed surface choke to 3/~" well flowed at estimated rates of~7500 to 9467 mcf/D with mud' surfacing ~dth Gas after ope~ 1 hour 30 minute test. Re~uced surface bean to ~,'~ after o?en 2 hour 5 mJ. nutes. Flo~.re~] GAS at estimated ~.,~ to 9467 ~'~cf/D for balance of 1~ hour 50 ~ninute flo~-z period. Shut in at tool f.o.r 4 hours 30 m~.nu'te ~-;hut i~. Reopened tool on ,~ choke for 1 i~our I0 minutes owed with s~a!l heads of mud at an average rate of 5209 n~cJ'/]p. Shut well in at surface for 2 hours. Reopened well on 3/P",~ surface choke for 3 hour 12 minutes and well flowed GAS with mist of mud at an average rate of 4562mcf/D. Shut welt in at .... ~ hour 8 mi,)ute shut-in. Reo:pened at surface on a ~" cho~.ie and well ~loved GAS at ~ avera6e ~09~ mcf/D for 3 hour 20 minute flow period. Shut well in at tool for 6 hour 55 mi:-~ute fine,1 shut-in. Reverse circulated ot~.t 854' rise of Gas cut san~V mud ~m~o 85h' 427' above and at tool all tested sodium ciilori~e, lox, san~. I)i'i!lin~ fluid tested 1Z60 sodium ci)!ozi~e~ ~ o~ 1%~ saiwa. ~at hole vol~rne is equ~wi]ent 3oo~ ~ rise in 4!>" C~ill ~,ip~. C~larts O.K. o_rll: at 653P Perforated interval 671!0' ochl~u.nuerger ]]Z . with 4 i-"2TM shot holes pcr foot. ,'/ · 10 $ DST }A Interval 67l.~0' - 6758' !'-.~%y 2: .~,7. Set packer at 6675'; tail 'to 6704'; 3/4" chol-~e at tool. ~{o cushion. Opened tool at 11'03 p.}~. 5-2-78 on a $~" surface choke. I?~itial flow period 6 hours. Light steady blow of aJ.r ~th GAS to surface iri 12 ~iinutes. Well floi,~ed GAS wit]i heads of mud and mud sprays with surface pressures stabalizing at ]~05 to ].625 psi during last 28 mint~tes of flow perfi. 0d. Estimate~] ~-~' 10 ~10 mcr/I) rate Shut we]] Jn o~' rate durin~ last 28 minutes ~,=~ ~ · tool for 5 hours 2 minutes for initial shut-iD. ~,'l~ates of ~141 to 9~d7 ~c~/a r~urinc J ni-tia], flow in error as much as to miscatibration of meter. Meter recalibrated for subsequent flow perliods. DST #5A (continued) InterVal 6720' - 67~8' May 3, 1978 Opened tool at 10:05 a.m. 5-3-78 on a ~" surface choke for 2 hours 0 minutes. Surface pressure stabalized during last 1 hour 5 minutes of 1 hour 10 minute period. Well flowed GAS with sprsy of mud at 3459 mcf/D rate. Change surface choke to 3/8" and flowed well for 2 hours 5 minutes including one 5 minute and one 28 minute surface shut-in periods during the initial 45 minutes of period to repair surface leaks. Surface pressure stabalized during last 50 minutes of period at 1990 psi and well flowed GAS with mist of mud at 67(i~ mcf/D rate. Change surface choke to 1/2" and flowed well for 1 hour 49 minutes. Surface pressure stabalized at 1470 psi during last 1 hour 5 minutes of period and well flowed GAS with spray of mud at .9763 mcf/D rate. Shut well in at tool for final shut-in of 6 hours. Reverse circulated well and pulled tester. Charts O.K. (State given notice of test. Declined to witness.) ? .......... 79 pcf mud Ms~v ~4~ t~8 -May 5, 1978 Set Schlur:~berger EZ drill retainer at 6730'. Perforated intervals 6680' - 6685' and 6695' - 6705' with 4 ~" shot holes per foot. DST #6 Interval 6680' - 6685' and 6695' - 6705' Ms~ 4. 1~78 - ~ q. ~o?a Set packer at 6615'; tail to 6641'; 3/4" choke at tool. No cushion. Opened tool at 6:20 p.m. 5-4-78 on a ~" surface choke. GAS to surface in 15 minutes. Flowed GAS with surface pressure increasing from 5 psi to 122 psi after open 2 hours 55 minutes. Shut well in at surface for 15 minutes then reopened on ~" surface choke for 2 hours 50 minutes and well flowed GAS at estimated average rate of 841 mcf/D rate. Shut well in at tool for 6 hours 10 minute initial shut-in. Opened tool on ~" surface choke for' 4 hours-and well flowed GAS at estimated rates of 1225-1286 mcf/D rates. Shut well in at s~face for 1 hour. Reopened at surface for 1 hour 55 minutes with surface pressure stabalizing during last 20 minutes at 99 psi. Well flowed GAS with spray of mud at 1307 mcf/D during stabalized period. ~a~ged to a ~" surface choke ~d flowed well for 2 hours 8 minutes with surface pressure stabalizing at 216 psi.. Well flowed GAS at ~8~ mcf/D during stabalized period. Shut well in at tool for final 6 hoor shut-in. Reverse circulated out 210' of drilling fluid in 4~" drill pipe, no free water. Charts indicated minor plugging during initial flow. Set Schlumberger EZ drill plug at 6670'. Perforated interval 6~36' - 66~4' with 4 - ~" shot holes per foot. DST #7 Interval 66B6' - 6644' ...May 6.,. 1~78 Set packer at 6580'; tail to 6606'; 3/4" choke at tool. No cushion. Opened tool at 10:15 a.m. 5-6-78 on a ~" surface choke for 5 hours initial flow period. Medium steady blow with GAS to surface in 15 minutes. Flowed GAS with minor ~o~mts of mud at rates of 1475 to 2044 mcf/D rates with 325 surface pressure. Shut in at tool 9 hours 45 minutes for initial shut-in. ]~eopened tool for four hours and well flowed GAS as follows: 1/2" surface choke, 365 psi surface pressure, 22~0 -2338 mcf/D rate 3/8~ surface choke, 635 psi surface pressure, 2089 mcf/D rate. Shut in well at tool for an 8 hour final shut-in. Reverse circulated well. Pulled tester. Charts O.K. ?1ay 7, 19~ Set Schlvumberger EZ drill retainer at 6620'. Perforated interval?~ ' 6544' - 6554' with 4~- ~'~ shot holes per foot. DST #8 Interval 6544~' - 6554' May 7, 19~° Set packer at 6488'~ tail to 6514'; 3/4TM choke at tool. Opened tool at 10:00 p.m. 5-7-78 on a !~" surface choke for a 3 hour initial flow period. Medi~un blow decreasing to weak blow at end of flow period. GAS to surface at less than 30 mcf/D rate in 55 minutes. Shut in at tool for 7 hours 5 minute initial shut-in. Reopened tool on a ~" surface choke for 1 hour 55 ~inutes with a weak blow of GAS throughout period. Pulled tester and recovered 90' of 79 pcf mud. Rat hole volu~_e is equivalent to 324' rise in 4~'~ drill pipe. Charts O.K. 80 pcf mud ~ay 8, 1978 Perforated interval 6010' - 6020' with 4 - ~'~ shot holes per foot. DST #9 Interval 6010' - 6020' May 8~ 19,7.8 Set Packer at 5955'; tail to 5981'; 3/4" choke at tool. ~o cushion. Opened too]. at 9'50 p.m., 5-8-78 on ~'~" surface choke for a 1~ hour initial flow period. Medium blow with GAS to surface in 5 minutes. Flowed GAS with minor amounts of mud and blow declining to a faint blow at end of flow period. Shut in at tool for a 7 hour 50 minute initial shut-in. Reopened tool on a ~" surface choke for a 2 hour 20 minute flow period with a light blow declinging to a very weak blow of GAS at end of flow period. Pulled tester and recovered 415' rise in 4~" drill pipe of sandy 85-90 pcf drilling fluid. Charts O.K. Circulated and conditioned Gas cut mud to 6085' Perforated 4 ~" shot holes per foot interval 6070' - 6090'. 80 pcf mud M8¥ lO, i975 DST #10 Intervals 6010' - 6020' and 6070' - 6090' Ma~ 1~ 1978 Set packer at 5955'; tail to 5981'; 3/4" choke at tool. cushion. ~ Opened tool at 5:24 a.m. 5-10-78. Open 3 hours on a ~" surface choke. Medium blow of air declining to faint blow' of air in 31 minutes, then faint blow of air for balance of flow period. Shut in at tool for 6 hours. ~Reopened at tool on a ~" surface bean for 2 hours. Faint blow of air throughout 2nd flow period. Pulled tester and recovered ~75' rise of 75 to 100 pcf drilling mud in 4~" drill pipe. No free water. Charts indicated plugging. Ran in hole and fom~d sand at 6123'. 80 pe'f mud May ii i~ Cleaned out sand from 6123' - 6170'. Circulated and conditioned mud. Logged Schlumberger ~Cement Bond-Variable Density Log interval 3700' - 6123'. DST #10 Retest Interval 6010 '-6020' and 6070' - 6090' Ma.y 11, 197~0~ Set packer at 5955'; tail to 5951'; 3/4" choke at tool. Used 600' of mud cusi~ion. Opened tool at 12:1~ p.m., 5-11-7~. Open 2 hours on a ~'~ surface choke. Light blow of air declining to a faint blow of air after 11 minutes and faint blow of air for balance of test. Pulled tester and recovered 1247' rise of drilling mud weighing 75-~2 pcf. No free water. Charts indicated. plugging. Tools badly plugged with fine sand. Set tlalco EZ drill bridge plug at 5960'. Ran open end (]rill pipe to 5960'. Equalized 100 sacks Class G cement. Pulled 4 stands, reversed out, pulled 4 more stands. 80 pcf mud May 12, 1978 Located top of cement at 5680'. Laid down drill pipe. Filled 200' 13-3/8" x 9-5/8" annulus with diesel Filled 200' 9-5/8" · , casing with diesel. Removed B.O.P.E. and installed C~ueron 10", 5000J~ flange on top of tubing head. 80 pcf mud !~ay .1~ 197~ Rigging down. Rigging down. Rig released at 6:00 p.m. S. S. SHIPPY F~rm .~;0-403 REV, 1-10-73 Submit "Intentions" In Triplicate & "Subsequent Reports" in Duplicate 6010 ~qPIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use thls form for proposals to clrlil or to cleepen Use "APPLICATION FOR PERMIT--" for such proposals.) i 5. APl NUMERICAL CODE 50-283-20055 6. LEASE DESIGNATION AND SERIAL NO, ADL-58790 7. ,F ,ND,AN, ALLO~EE oR TR,BE NAME O'L i'-'i GAs F~ WELLI I WELL ~L-.~I~ OTHER NAMEOF OPERATOR 8. UNIT, FARMOR LEASE NAME C~VRON USA INC ST~ ~ 3, ADDRESS OF OPERATOR P.O. Box 7-839r Anchoraqe, Alaska 4. LOCATION OF WELL At surface 99510 773' southerly and 495' westerly at right angles from the northeast corner of Sec. 33 T14N R8W SM 13, ELEVATIONS (Show whether DF, RT, GR, et~) _ 2,5.37~ GR. 9. WELL NO. 41-33 FIELD AND POOL, OR WILDCAT STUMP LAKE FIELD 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T.14N. R. 8W. S.M. 12. PERM IT NO. 76-86 14. Check Appropriate Box To Indicate. Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* ' (Other) SUSPEND (NOTE: Report results of mult,ple aor~l~ett~n,~n Completion or Recompletion Report and Log form.) DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent elates, including estimated date of lo Set200 bridgelinear plugfeet ofat 5.960'cement.(50' above top perforations 6010-6020' ) and cap ~C ~ tV E ~ 2. Cap 9 5/8" x 13 3/8" annulus with 15 barrels of diesel oil. 1 e Cap 9 5/8" casing with 15 barrels of diesel oil. D~..~i$i0~ Ct bfl~jl-i0,.,.,. Install 10" 5000 psi blind flange on 10" tubing head with outlets below to 9 5/8" casing and 9 5/8 x 13 3/8" casing annulus. Se Install 5000 psi gauges on 9 ='~" ~ ..... , , ~/o x ~ 3/8" -~,nulus ~,~t~e+~ res~ectivelv and suspend well. NOTE: Per conversation between Mr. John Miller (Division of Oil and Gas) and Mr. G. Matiuk (Chevron USA Inc) 5-10-78, the Division of Oil and Gas has waived the right to witness location and hardness of cement plug and has extended verbal authorization to suspend this producer as outlined above. 16. I hereby certify that the foregoin~q~l~true ancl correci?'"'\ --~/' /~'/-~/../-'~-~ITLE A~A ENGI~ER - ~S~ SIGNED G. ~'I'IU~- _/$- - / (TBiI space for State office u~) / CONDITIONS OF~PROVAL, IF ANY: ~ ~ITLE _ r . See Imtruction$ On Reverse Side DATE 5-11-78 Approved Copy Return3d STUMP LAKE 41- 33 (DST SUMMATION) DST NO 1 2 ,2RR 3 4 5 6 7 8 9 10 10RR INTERVAL FROM TO 9518 9528 9230 9260 9230 9260 8160 8180 7795 7833 6870 6876 . . 6680 6705 6636 6644 6544 6554 6010 6020 6010 6070 6010 6070 GAS RATE MAX. ACTUALLY ~ASURED 0 MCF/D Less than 30 MCF/D Less than 30 MCF/D 750 MCF/D 0 MCF/D 5209 MCF/D 9763 MCF/D 1388 MCF/D 2338 MCF/D 0 MCF/D 0 MCF/D 0 MCF/D 0 MCF/D GAS RATE OPEN FLOW POTENTIAA 0 MCF/D 0 MCF/D 0 MCF/D 750 MCF/D Est 0 MCF/D 6300 MCF/D 20500 MCF/D 1300 MCF/D Est 3000 MCF/D Est 0 MCF/D 0 MCF/D 0 MCF/D 0 MCF/D TOTAL 19448 MCF/D 31850 MCF/D DGR:gu Form No. 10-404 iSUBMIT iN DUPLICATE REV. 3-1-70 STATE OF ALASKA · OIL AND GAS CONSERVATION COMMITTE.E:.~,:' -' ~:-~.. ,:'i'.~. MONTHLY REPORT OF AND WORKOVER OPERATIONS WELL WELL OTIIER EXPLORATORY 2. NAME OF OPERATOR CHEVRON U. S. A.. INC. 3. ADDRESSOFOPERATOR P.O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL 775' South and 495' West from the Northeast corner of Section 33, T14N, R8W, S.M. 5. APl NUMERICAL CODE 50-283-20055 6. LEASE DESIGNATION AND SERIAL NO. ? r r,.,: '. ADL-58790 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME STUMP LAKE UNIT 9. WELL NO. ; [~!\/ ~ 41-33 10. FIELD AND POOL, OR WILDCA'~' ! - 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 33, T14N, 12. PERMIT NO. 76-86 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS F1SHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. April 1-11th Drilling ahead in 8~ hole from 10,490' to 11,650'. circ & condition mud for logs. Run Schlumberger log. April 12-18th Condition mud to run liner. Run and cmt 1137' of 7", 29 #/ft, P-110 Buttress thread liner at 9700' w/ top at 8563'. Cmt'd liner w/ 335 Sx. Class "G" cmt. Good circ throughout job. WOC. Clean out cmt stringers from 7724' to 8563'. Tested 9 5/8" csq to 1000 psi. Cleaned out cmt from 8563' to float collar at 9620'. Pressure tested liner to 800 psi for 15 minutes - OK. Ran Schlumberger CBL through 7" liner. Shot four 1/2" holes at 9490'. Squeezed holes at 9490' w/100 Sx. Class "G" cmt w/ up to 3900 psi. C/O cmt to 9610' indicating shoe job broke down. Ran Schlumberger & shot four 1/2" holes at 9488 1/2'. Squeeze holes at 9488 1/2' w/ 100 Sx. Class "G" cmt until a pressure of 5200 psi was reached. WOC. Found top cmt at 9441'. c/O cmt to 9610'. April 19-22nd Shot four holes/~t 9518' to 9528'. Ran DST #1 w/pkr, at 9450' & tail to 9476'. Set bridge plug at 9360'. Perforated four holes/Ft 9230' to 9260. DST #2 w/pkr at 9170' & tail to 9196'. Re-ran DST #2 w/ pkr at 9165' & tail to 9191'. April 23-24th Run open-end tbg to 9360'. Equlized 80 Sx. Class "G" cmt. WOC. Found top cmt at 9000'. Pulled up to 8663'. Equalized 80 Sx. Class "G" cmt across liner lap. WOC. Found top cmt at 8403'. C/O to 8443'. Stuck drill pipe. Backed off drill pipe at 8345', leaving in hole a bit, bit sub, 90' of 6" drill collars. Abandon 7" liner and 9 5/8 csq. Verbal approval H.H. Hamilton 14. I hereby certify thatPt~n$~trb'e and correef? .,:':>'7 OPERATIONS SIGNED /'...--¢. ~ ~-~-'~~---~" TITLE SUPERINTENDENT DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. 4/20/78 prior to abandonment. April 25-27th Attempted to pressure test 9 5/8" csg. No pressure above 2100 psi. Located split in casing at 379' to 400'±. Cut and recovered 9 5/8" csg to 463'. Dressed top of csg. Ran in w/ 9 5/8 csg bowl adapter, hooked on to 9 5/8" csg. Pulled 90,000# and tested to 3000 psi. Landed csg. Installed BOP~ & tested to 3000 psi. C/O to 8340'. April 28-30th Perforated four holes/Ft 8160' to 8180'. DST #3 w/pkr at 8020' & ~,~,~ ~ ~? tail to 8046'. Set bridge plug at 7950'. Perforated four holes/Ft ~ 7833'-7795'. DST #4 w/pkr at 7738'. Set bridge plug at 7045'. ~i~,~i~i~i~'~'~"~'~~ .... Perforated four holes/Ft 6860'-6876'. DST #5 w/pkr at 6800'. Testing. C-O-N-F-I-D-E-N-T- I-A-L Stump Lake 41-33 File April 27, 1978 Russel A. Douglass Petroleum Engineer Received a call from A1 Johnson, Chevron at 8:00 AM. He informed me they had to replace some 9 5/8" casing on their Stump Lake Unit 41-33 because of splitting. He wanted to know if we were to witness testing of the BOPE when they were nippled up again. He referred me to Bill Sower in Anchorage for further details. I talked with Bill Sower around 9:15 AM. Apparently the 9 5/8" casing had Split for some reason near the surface. It was cut at 463' then dressed and patched back to surface and cemented. They tested the patch to 3000 PSI and it held. The BOPE had to be nippled do%~ for the replacement opera- tion and were being nippled up for completion of the well. I waived witnessing the retesting of the BOPE. Form 10-403 REV. 1-10-73 Subml t *'1 ntentions" In Triplicate & '*Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such Proposals.) OW~%LF"-] GAS r-~ Exploratory WELLL.J OTHER NAME OF OPERATOR Chevron U.S.A. Inc. 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchoraqe~ Alaska 99510 4. LOCATION OF WELL At surface 775' South and 495' West from the Northeast corner of Section 33, T14N, RSW, S.M. !3. ELEVATIONS (Show whether DF, RT, GR, etc.) Ground 30' , KB-50' 14. Check Appropriate Box To Indicate Nature of Notice, Re 5, APl NUMERICAL CODE 50-283-20055 6. LEASE DESIGNATION AND SERIAL NO. ADL-58790 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME , St%~%p Lake Unit ,, 9. WELL NO. 41-33 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 33, T14N, RSW, S.M. 12. PERMIT NO. 76-86 ~ort, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR AClDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OH ~;UIVI~'L.C.I c.~ur'r-r~, .................. ,,.,,~., t...~....y .... . -..' .... ~ .... ,,~^-* .~o*~,,~. =nr~ nlvn n~.rtinent dates, including estimated date of starting any proposed worK. Per verbal approval Mr. H. H. Hamilton, April 20', 1978. Casing Detail: 9 5/8" csg. cemented at 8667'. 1137' 7" liner cemented at 9700' with top at 8563'. - Perforated 9518'-9528' - Production test Wireline set E-Z Drill bridge plug at 9360'. Perforated 9230' to 9260' - Production test. Ran open-end tbg. to 9360'. Equalized 80 Sx. Class "G" cement. WOC, 2 hours. Found top of cement at 9000'. wocRan open-endfound tbg. to 8663'. Equalized 80 Sx. Class "G" cemen~ top of cement at 8403'. C/O cement to 8443'. ,, ECE!\/ED Plug and abandoned the hole below 8443'. CONF ENT A APR 27 Division o( 0il and Gas L;~)n~,H'w~[i:m 16. I hereby certify that the foregoln"g I~,,~rue and correct _/~ SIGNED -'' /-~'~ - '- ..... TITLE SUPERINTENDENT C. F. 'K/IRKVOLD ~ -- - DATE, (This space for State office use) CONDITIONS O~/AI;P~'VAL, ![ ANY: . . TITLE . /' See Instructions On Reverse Side Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATBO'F ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTItER Exploratory 2. NAME OF OPERATOR Chevron U.S.A. Inc. 3. ADDRESS OF OPERATOR P. O. Box 7-839: Anchorage~ Alaska 99510 4. LOCATION OF WELL 775' South and 495' West from the Northeast Corner of Section 33, T14N. R8W, S.M. 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL N~ . ADL-58790 7. IF INDIAN'ALOTTEE OR TRIBE NAME~ - 8. UNIT FARM OR LEASE NAME Stump Lake Unit 9.WELL NO. 41-33 10.FIELD AND POOL. OR WILl)CAT wi 1 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 33, T14N, R8W, S.M. 12. PERMIT NO. 76-86 ',. 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Circ ;" and; condition Drilled ahead in 12 1/4" hole from 5256' to 8669'. mud and hole, prep. to log. March 1-12 March 13-18 Ran Schlumberger logs. Ran and cmt'd 9 5/8", 47#/ft., P-110 and 43.5#/ft., N-80 Buttress and 8 rd. csg. at 8667'. Cemented through shoe with 815 Sx. Class G cement, mixed with 2.1% gel, by weight of water. Full circ. throughout shoe job. Opened DV collar at 3024' and cemented through DV collar with 330 Sx. Class G cement, mixed with 2.1% gel, by weight of water. Displced, bumped plug and closed collar. Good circ. through- out DY collar job. Landed 9 5/8" cs~with slips, packing and secondary seals. Tested seals to 5000 psi. Installed BOPE. Tested to 5000 psi. Hydrill to 2500 psi. Witnessed and approved by DOG. March 18-19 Drilled out DV collar, c/o cement and mud to top of float collar at 8621'. Drilled out cement to 8634'. Tested csg. to 1800 psi. Drilled out shoe. March 19 - Drilled ahead in 8 1/2" hole from 8669' to 10,490'. RECEIVE , ;,:'., I ,t9t8 £ivLsi~n cf 0il & Gas CONFIDENTIAL 14. I hereby cert,fy th)q. the.~~ja-~%~nd corrj~ ;? fi) AREA OPERATIONS SIGNED. .s~ TITLE SUPERINTENDENT DATE ~//Of , t~' NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. 3~o Harold R. Hawkins Witness BOP test, Chevron Stump Lake 41-3~ Sec. 33, T14N, RSW, S~M. Permit ~. 76-86 Sa ~.turday., March 18,.1978 -.I left Anchorage by twin piper charte~ by ~ fron ~ ~-~s~ce at 8:00 AM to Beluga River. ~ of trip to witness BOP test at S~ Lake 41-33. I arrived at Beluga airstrip at 10:10 AM and at St%rap Lake at 11:00 AM. BOP tests started at 12:30 PM and f/nished at 4:30 PM. The test plug was a Baker cup type casing retr/mvable. Test/n~ was done with mud and wa~_r. With the blind rams closed, the manifold w~s also t~ted to 5000 psi. There w~re 7 valves, 7 flan~, and swaco superchoke that t~ced satisfactory. T~re were also t~o manually opera%sd chokes cn manifold OK. With the b~ rams still closed, the inside am~ outside Ydll val~s were tested to 5000 psi CK. The check valve ~ the kill 1/ne also tested to 5000 psi OK. Next the upper pipe rams and inside ~hok~ were tested to 5000 psi. The ~tside choke was tested next to 5000 psi. The ~ pipe rams %~re t~sted to 5000 psi. The annular preventer was tested next to 2500 psi. The ~ and lo~r k~lly w~re tested ~arately to 5000 clean and free of de~ris. The well sign was up with all data OK. The ni~ bac~ system had fi~ bottles with 2000, 1800, 2000, 1500, 2000 psi OK. The master controls read 1500 psi. Although there was c~ly 1500 psi c~ master hooked- up in unison te close BOPs and still ham 1200 psi in reserve with power shut off, ir~ting closing unit and BOP seals and control lines w~re control wc~ked satisfactory. The supervisor for Chevrun was Ben Smith. The cc~tract rig w~s Brinkerhoff 58. In. ~~. I wl~sed the tests of th~ BOPs and closing unit c~ Stump Lake ~. 41-33 for Chevron. Tests ~ satisfac~. Attachmsnt Al'ic~'i~a Oil 'and C~s conservation committee Field InSpectiOn~...Report Drlg. Permit' No'.~Z~_~~ " Well/Platfm Sec~3T/~.R~,~_M Operator ~-~/~/ V~./~'~ Represented by~$~2'~_ Name & Number~T~,~o SatisfactorY Yes No Item (~ () ((~)() () -UO () () () () () () () () () () () () () Type Inspection (~ Location,General 1. Well Sign 2. General Housekeeping 3. Reserve Pit-(~)open( }filled 4. Rig ( ) Safet~v Valve Te~'ts 5. Surface-No. Wells' 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , ,-~ , .]8. Hrs. obser , , , '9. BS&W , , , 10. Gr. Bbls. ( ) Final Abandonment Satis ~actory Ty~oe Inspection Yes No Item (~) BOPE Tests (A~ ( ) 15. ~-:~-~ing set (~() ( ) 16 T-~-~t f'luid-( )wtr.-:--~ )mud ( ) oil (xl () (k)() (~)() ~-:~ (~)() 0<)() 17' Master Hyd. Control Sys.-~_~_~_psig 18. N? btls.2~,(s~,~,~-~p~i~q~o 19. R~mote Contr° 20. Drilling ~sp.o.ol-~ "outlets 21. Kill Line-(~~) Check valve (,~') (~.~) 22. Choke Flowline ( ) HCR valve ~ ( ) 23. Choke Manifold No valvs~flgs~ ~;~ ~ ~hokes-(~Remgte(~)P~s. (~'Ad,i ' (~ ' ' 25. rest Plug-( )~,;ellhd(~cse( )none ~(~)?' (). 26. Annular Preven~er~mpsi~ .( ) 27. Blind Rams~sig ( ) ( ) 11. P&A Marker (9() ( ) 28. Pipe Ramsa~-~.m psi§ ( ) ( ) 12. Water well-( )capped( )plugged (.~). :~( ) 29. Kelly & Ke.lly~-cockg~mmm psig ( ) ( ) 13. Clean-up (9<) i{~i) ....... 30:~ Lowe.r~ Ke'l-l~ ~alves~-~~ psig ( ) ( ) 14. Pad leveled ,~ ~ ~) ( ) 31. Safety Floor valve~BV (~Dart Total inspection Dbservation time ~ ~/days Total number leaks and/or equip, failures~~ Remarks ~ ~~~y~ ~~ ~z~~ ~~~E~ ~ ~~~~' , . . . ~, , PROPOSAL FOR DRILLING OPERATIONS DRILLING PROGRAM Field: Stump Lake P..rg. perty, and Well: Stump Lake 41-33 Location: Surface - 773 ft. southerly at right angles from the northe~-ly bound~z7 of Section 33, and 495 feet westerly mt right angles from the easterly boundary, Section 33, T.14N, R.g~., SB & M. Bottom Hole - Same as above. Elevation: Estimated ground level 30'. Estimated KB 50'. Blowout Prevention Considerations: RECEIVED i. Potential Problems: a. Gas: ~he proposed well is an exploratory well in an area of.'known.'gas fields. Gas sands can be penetrated during the course of drilling this well to a total depth. Gas entries into the mud column can cause serious problems. Care must be exercised at all times to prevent gas entries by either swabbing the well or hydraulicing the formation on trips. Rapid penetration causes an increase in mud · weight and thereby increases the risk of lost circulation and subsequent kicks. Penetration rates will be restricted. Ceal beds can cause serious prOblems. They contain some gas, slough readily, and drill rapidly. If thick beds are encountered,~red~ce the penetration rate and/or circulate bottoms up. Be Lost Circulation and Water Entries: There was no lost circulation or water entries reported to 12,000' ~ertical depth in any of the nearby Ivan River wells. C. Precautions: Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at all times by every member of the crew. The hole must be kept full at all times. D. Special Problems: Considerable hole problems were experienced while drilling Ivan River 23-12. The 10 3/4", 7" casing, and 5" liner were stuck while running in the hole. Similar problems also occurred at Ivan River 14-31 where the 7" casing was stuck while running in the hole. APPROVED PROPOSAL FOR DRILLING OPERATIONS DRILLING PROGRAM (STUMP LAKE 41-33) -2- 2. Estimated Depths and Formation Pressures Interval TVD __ Approximate Reservoir Pressure, PSI Gradient PSI/Ft. Base Sterling 5200' 2445 ' .47 IR 44-1 Sand 8275' 4300 .52 Top "D" Sand 9750' ..6045 .62 * Total Depth 11650' 7225 .62 * · Based on salt water test on Ivan River 44-1. !~ ~; 3. Maxmimum Antic.i. pate.d Surface Pressure: :... 5100 psi based on assumed "D" gas zone. If "D" cont~in~ 'oil, pressure 'will be less If gas is present below "n" pressure will be greater. 4. Blowout Prevention E~uiPment: A. On 20" casing: Class IIB, consisting of Hydril. MSP 2000 bag and CSO rams, and Shaffer rotating preventer· B. On 13 3/8" casing: Class IV,'consiSt!ng.of'Hydril bag, two sets of pipe rams, blind rams~ :' C~ On 9-5/8" casing:'ClassIV~consisting of Hydril bag, two sets of pipe rams, blind rams. De Installation and testing of this equipment is'outlined in Operating Instructions D-17. PROGRAM i. install 30" conductor to 80' or as deep as practical. Install Shaffer rotating preventer on 30" conductor. 2. DrilllT½" hole to 425'. Open hole from 17½" to 26". Maintain drilling fluid per attached program. 3. Cement 20", 94#, H-40 (buttress or welded) at 425' with sufficient volume of gel treated Class "G" cement to reach the surface. Treat the last 400 sacks of cement with 3% calcium chloride. Theorectical volume plus 33% excess, is 850 cubic feet. If cement returns are not received at the surface, do a top job. ~ ...... ~ ..... APPROVED A.Use a Baker Duplex (stab-in) cement shoe. B. Baker lock bottom 3 joints. C. Centralize the 20" casing over the entire length. C. N. S?gnc, r PROPOSAL FOR DRILLING OPERATIONS DRILLING PROGRAM (STUMP LAKE 41-33) -3- 4. Install Class IIB, 20" - 2000 psi BOPE on the 20" casing per the attached diagram. Fabricate blow and kill lines for 5000 psi service. A Class IV, 13 5/8" 5000 psi BOPE will be installed later on the 13 3/8" casing. A. Test BOPE per Operating Instructions D-17. Bt Burst of 20", 94#/ft., H-40 casing is 1530 psi without a safety factor. Do not exceed 900 psi surface pressure on test. 5. Drill out cement and shoe of 20" casing. Drill ahead in 17 1/2" hole to 2500'. Install mud loggers before drilling out sh~e.~..of'~ 20"' casing. Log '-' to total depth. . ~ · Note: ' .. '~ Maintain mud properties per the attached program. ~evere-hole problems ~ developed While directionally drilling well IR 23-12. The section drilled from the surface to 6000' is essentially gravel. 6. At 2500' condition hole for logs. Obtain one-half gallon mud sam prior to running logs. 7. Run .logs per attached formation evaluation program. ole APPROVED C. N. Sognar 8. Run 2500' of 13 3/8" OD, 72#/ft., N-80, buttress casing and cement to the surface as follows (have stage collar on location in case lost circulation occurs or hole conditions dictate its use): A. Use float shoe and Duplex (stab-in) collar one joint off bottom. B. Lock Bottom three joints of 13 3/8" casing. C. Centralize casing above shoe. -D. Run drill pipe and stab into Duplex collar. Cement through the Duplex collar with sufficient Class "G" cement premixed with 2.4% gel, by weight of water to reach the surface. Follow the gel cement with 200 sacks of neat. Basis: Yield Class "G" = 1.15 ft? /sack Yield Class "G" + 2.4% gel by weight of water = 1.86 ft. 3/sack. E. If cement returns are not received at the surface, do a top job. PROPOSAL FOR DRILLING ~PERATIONS DRILLING PROGP~M (STUMP LAKE 41-33) 9. Cut off 13 3/8" casing 36" below the top of th~ cellar to allow the top ~ flange of the tubing head to be above ground level after completion. 10. Install 13 5/8" - 5000 psi x 13 3/8" SOW casing head. Test welded lap to 5000 psi. Install Class IV 13 5/8" - 5000 psi BOPE as per the attached drawing. Test BOPE~ kill line, blow line, and manifolding to 5000 psi as directed by "Operating Instructions D-l?". Clean out 13 3/8" casing to within 10' of the shoe. Pressure test the 13 3/8" casing to not over 4500 psi. . 13. Drill ahead in 12 1/4" hole to dull bit nea~- recast&red depth of 8500'. A. Maintain mud properties per the attached program. Limit penetration as required. B. Be Prepared to run conventional core barrel as directed anytime after shoe of 13 3/8" casing has been drilled out. 14. Run logs per attached formation evaluation program. 15. Cement 9-5/8" casir~ a+ 8500' .~ ~ as follows: A. Use stage collar at 3000' float shoe and Float collar B. Cement through shoe to be as high as 5000'. Cement through stage collar to be as high as 2000'. D. Use Class "G" cement with 2.1~ gel by weight of waker on both stages; followed by 200 sacks of Class "G" cement through float shoe only. · 16. Install Class tV 13-5/8" - 5000 psi BOPE as per the attached drawing. Test BOPE, kill line~ blow line, and manifolding as directed by "Operating InStructions D-17." Clean out 9-5/8" casing to vrithin 10' of.the shoe. Pressure test the 9-5/8" casing to not over 4500 psi. 18. Drill ahead in 8-1/2" hole to 11~650', measured depth. 19. Run logs per attached formation evaluation program. 20. Depending on results, a supplementary program will be issued to run 7" liner, test, complete, abandon, or deepen. APPROVED W. A. BROMME~IEK DRILLING FLUID PROGRAM STUMP LAKE 41- 33 STUMP LAKE FIELD Basic S~tem Lightly treated Lignosulfonate mud. O~timumP~gperties To 13 3/8" Csg. Point Value Range 13 3/8" Csg. Pt. to 8500' 8500' to TD Weight, pcf Viscosity, sec/qt., API Fluid loss, cc, API Plastic Viscosity, CPS Yield Point, lb./100 ft.2 Gel, lb./100 ft.2-10 min. pH Solids Content, % volume Diesel Oil, % 73-76 76-81w 40-200 40-45 - Less than 10 - 15-25 - 8-15 - 10 Max. - 8.5-10.0 - 10-16 - 4-7 Remarks: Chemically disperse mud with lignosulfonate. 81-93 40-45 4-8 10-15 5-10 10 Max. 8.5-10.0 8-10 4-7 Maintain adequate supply of .lost circulation m~terial and barite at the location. 'Run desander and desilter to keep solids at a minimum while drilling. Increase viscosity while drilling surface hole as required to control gravel. Limit dry jobs to 20 sacks of barite or as directed by Drill- ing Foreman. Gels must not be progressive. Mud weights as much as 97 pcf to !10 pcf have been required while drilling through the Middle Ground Shoals "D" Sands (approximate depth 9,750 feet in subject well) in this general area. Have appropriate amount of weighting material on location. APPROVED C. N. Segnar PROPOSAL FOR WELL uPERATI0~$ pRO-316-A (TO Bi: USED AS A G0-111) CASING REQUIREIVIENTS AND PRODUCING EQUIPMENT WELL/LOCATION NO. Stump Lake 41-33 · FIELD ' Exploratory TOTAL DEPTH 11650 METHOD OF PRODUCTION ESTIMATED O/W/G / _ //1000(~QUIP. FOR STEAM CASING Conductor Surface ,,. DATE - £7./1b/76 ESTIMATED SPUD DATE MAX. ESTIMATED SURF. PRESSURE _ IN J. PRODUCER Gross Footage APl Size Weight Grade Threads Coupling Computer Design For' ~ - 3U"----- ~L'~-n~-pipe~ drive shoe. This Well 425' 20" 94# H-40 Buttress or plain end. Standard Design For Field Requires duplex shoe (stab-in) 10 each 20" x 26" cen. tralizers Well No. 2500' 13 3/8" 72~ N-80 Buttress Max. Drift Angle . Requires float shoe, duplex collar (stab-in) 15 each 13 '3/8" X 17 1/2" centralizers. Water String: Design based on mud density lbs./cu, ft. and above max. surf. pressure ,' 6800' 9 5/8" 43.59 N-80 Butt : . ~!O' 9-5/8" ~' P-110 ~tt ," ~- U~' - 78" ..... .~_~~ ~_~ P-ilO ~ ~ _ P-~O Liner NOTE: -- Hanger None None Perforated ', CAS! NG _.TIZED CASING SPOOL ~3! eqUipment to be buttress. 7" float" shoe and float collar. .One 7" x 9-5/8"~ 47~, Burns plain liner hanger grooved for cementing. 15 each 7" x 8-1/2" centralizers. to. ', Mesh, Rows, SI ots, Centers, HEAD:__ 5000 PSI CWP. Bottom Conn. 13 3/8 SOW Top Conn. 13 5/8 5000 PSI 2 ", Fittings _ 1 - 5000 PSI valve w/blind flange .w/b~zll_plug PSI 0 0 MC - MUC 2 _ outlets TUBING HEAD TUBING Feet APl Size ~ _ ~/n/ 2000' 2 3/8" 4.7 ~/ 11600' 2 7/8" 6.4~ Total Tubing Catcher Packer with XMAS TREE " Tubing Beans Header Stuffing Box PUMP: RODS: Grade , PUMPING UNIT. APl Size Engine 5000 PSi CWP. Bottom Conn. _13 5/8" - 5000 PSI Top Conn.'_ 10" 5000 2 2 " Flanged outlets Type Suspension 9 5/8" secondary pack-off Use Cameron Triple Tree purchased for F~lls Creek. Plug one out£ef. Grad e Th re ads Ty p e~ R e ma r ks N-BO 8RD EUE N-80 'BRD EUE type. Csg. Size _ Type with Wt. Install at "stroke at _ (Cross-overs, etc.) APPROVED Arm #, ' Of Wt. Arm , Other Fittings PSI CWP. _Type Motor HP ._ __ Type " PSI CWP. Dwg. No. _Type. Polished Rod _' of "; Max. Stroke "Set at Remarks "X Type at ' of "Stroke and Type ' Long SPM Area Supervisor ~P F l,'l~/~!,n,! J~ _~. . .' ' - ---- ,I Approved by Drlg. Supt. Sr. Drlg. Engineer_ PRO-31G-A (CD-1-75: Printed In U.S.A. GAS WELt. OPEN FLOW POTENTIAL TEST REPORT t ~te~ervol~ I Test Date Fl'~iStump Lake DST #5A 6740'-6758' 5-2-78 · Ope~tor Chevron U. S A. Inc t Lea" Stump Lake · ' ' ' ' 41-33 ('ouaty i Location I Completloa piti { .rotll ~p~ ] T/l:,a¥ l, ru.du,:lnf . lntt. Lt ?r~ai Sec 33, T 14 N, RSW . plu~6835 6740- 106 'F -- 'F 9-5./~" 47~ _ ' ~ 6~! 8667 . ] {~arat~) J ~nt~ {h) . ~,,~ Mcr ~r ~Ut. Liquid (apl) Pipeline ConnectionNO~ I T~e;~..~.&Taps ~ultlple CompleLJon (Dual or Triple) -- ~ T~pe production from each zone I -- GAS WITH MIST 'OF DRILI,/N~ WL[.]ID .... OBSERWED ~ow Data Time SURFACE ~ , STATIC PEN :DIFf. PEN ' -- · '('1 PRES~ Casln~ Flowin~ No. of Flow ~CHOKE SIZE (Orl~ce)! . READING'. READING'-" AT 6696 PSi ._. Press. Temp. Hours Size pslg' °F 1. ' 2 hrs. 1/4" 2'.50~ 6.62 ~7.5 ': -~ 2'978 -37 Z " ~hrS 5 min '. 3/8"' ....... 3.5'0'0' '' 8.5 .... 5.55 ' ' '~58~ ....... -'~2 . - . . , , ..... ~ ....... , ......... ,. , .,~ · . . . , FLO%V CALCULATIONS Coefn' STATIC Flow Temp.. 'Gravity Compress. ~.~ ~69~664. ! 49.6S Cc~aff~a~ant.~. ~a]~]ae~a ~o~,~,-a~ .e~ ~=~ ~ ~ 34_5.9 . i:' 143,456 47.175. Natur..~l Gas A~a_' "l~]]~n T.qSa],,''~a~,~a ~ ]~ aa~t 676a Z~ . . Calculat. ed by floW. !:hru offic~ ~.q!~aeion ~Q.-- .,C P ........ 9763 ... 4.' .... because of,,,,yolume o~ mud .bei'nq, ,pr,~d,,uce.,d A Q./~-~T J' , ..... , .... ' - PRESSURE CALCULATION[ · ,' (2) · - ·(3) cai. w ,t . e c ,e pf'2 ps2 ~pf2 P - ~ P t x"106 'x 106 ."','.- e i~]- 1) '~r&~'~ur'~' ~eaSured wi~h a ~ttom. ~ote 8 868 -- 2.-144 -. ~ ....... Pressure r~ corder.. ~t 6696 6.687 4.137 .... , .,,., ~ [2) Pf = flowing pressare at ~696' 5.212 ~" 5.612 .~ 4. ~3~"PS -="st~ti(' P'r~ssuf'e"a~ 6(9~, ..... . ' ....... , , . .... .. , ,. , ~,., .,, , ,, . ,, Absolute I%tential .. n · - ..' -. ., .: .20,.5.00 :. ...... AICF/D · ... area engineer CICRTIFICATE: I. the undersigned. ~tate that l'axn tho Of the ~ Chevron U. S. A. Inc. pared under my aupervtsion and direction the best o/ my knowled~e~ * Q = Rate of Flow MCF/D C = Chok~ Coefficient G = Gas'Gravity of .565 T = ~bS~lute Gas Temperatur9 " . .~.. Upstream of. chokexEst±mated 60°F + 460 = 520 . ~' · ~= Ups~ream'Sfc. Press, +,14.~5 Psi - · · · (company), and that X am authorized by said company to make this report: and that this report was pre- and that the facts stated there/~ are true, correct and co.n%~let~ to .. " Gu Well Open Flow Potential Test Report . . . · , ii i i i il il Il Ill I I U , STU~VIP LAKE ~1- 55 DST ~SA ~0000000 ........... ..... . . I00000 ....................................................... I000 .' ;: -: !.- ~ v .... I0000 -' '~ I00000 Q - MCF/ O STUMP LAKE 41-33 INITIAL SHUT-IN AT 6696' DST~SA ............ AT 44 42 STUMP LAKE 41-33 ...... 44 FINAL SHUT-IN AT 6696' DST GAS WELL OPEN FLOW POTENTIAL TEST REPORT' [-] *n.u.' ['1 ~eld I Reue~oir ' . -stump.. Lake i ! .... ~ST #5 6870-687~ Op~t~ ] Lcas~ Chevron U.S.A. Inc. S~ump Lake i Test Dato 5/1Z,7~ " i %VeU No. 41-33 Ke'nai Sec 33,T14N, R8W ~1ug7045 ' - wame.d j CSt. SIn 1%Vt/Ft. i LD. I Se:@ 68"76' -- 'F 9-5/8" 47~ 8.681" 8667' 4-1/2P 3. 826 ~,~ a~r~ ~r ~. · ~ ceo 102 *F !'._P--x _[_. ' ?,m~,,,, D.P- SIZEt .. -Wt/FC ·I '4 1/2" · 16.6# Pipeline Connection ~ I (~pArztor) I Len[~ (L) t Liquid (Apl) ooz~ ! , 565 I .... ' ~0~ .... ""- '~' -- ~' '- .' ..... - " . M~tlple Completion (Dual or Triple) J Type production from each zone , , GAS WZTH MIS~ 0F DRILLING FLUID OBSERVED ~ow Da~ Time sURFAC~" ' ~ STATIC PE~ , 'DIFF Pt~N~'('i) PRES~S Casing Flowing of Flow '~HO~ SIZE (Orifice)* ~ADING .~ING ' AT 67871 Pres& Temp. Hou~ Size ' ,, 'PSI ..... .. ' .................... . ~460 . Packer 1Om~n 1/P" q Pqm R_q -~-25 ' ' :]~24 ._ Pa~ker in .. 12m~n 2Ya" ~-~5~ 9..1.S , a.l.O ' 2b~ 1'/4"" " 2. 500.. 6.05 7,3~ . 2450 '" ~kar ~20 . FLO%V CALCULATIONS · A~ic ..... Co,ffl' ST Flow Temp. Gravity Compres~ · . ! (24 Hr.) DIFF .... - Coefficien:zs ·were calculated accordin~ to 5209 .1;.,. 11 9,5,32. 4 3.6.V ..5 ....... ~.[' .. 121,5.9,8 37. 515 "Bu. lletin' PS..5'6...1"' ..publisli, e'd by 'fhe Cal:.foknia .. '. 4_562 .~. ...... 69,6..64 44.467,.~ - . Nat. ur.al ,'G. ai~' nssoc, ia.t.io, n. and ..have been . , ,3..098 , 4. . , ....... ,a. djusted t.? · 14..65 pr,ess~,~.re,, base. . ,, "' [,. · ' - PRESSURE CALCULATIONS P' : ' (2 ')' . '( 3 ' ' ' C~d. w : :: ,-6Pi2 P w (psis), . l~,t ~ Pe Q (P c Q)' ipsc Q)'~ X 1-e--. Pi?' 6'; P w P t X' 10.. ~- x 10 · ' _ c 1.- -- _ ,, · T- -- ., ~7,- ....... ] _ 753 ..... 10. 218 ....... · ...... ,, -- -- 3.748 8.224 .... ,,. , .,,, ..... , .......... , ,, , , ,, .. , ~, -- --, , -- ,. -- , ..... 6.,003 .5.,9~9 . -- ,,,,-- .. , , , ~, ,.~ . , .,, , , ,, . , , ,., , , . ,,, Absolute Potential .. , [ n ' "' ' 6300' :..- ........ MCF/D ' .0.96 ! .... area engine.er CERTIFICATE: ~ the undersigned, state that I am. th~, - : (company), and that I am authorized by said company to make this report; and that this report was pre- - .- . p~r~d under my supervision and directiaQ and that the /acta stated there~ are true, correct and coIllplete to . ~ (1) PressUres measured w~th a Bottom b - ' ' 7 ..... Hole.Pressure recorder at 6787' (2) Pf = Flowing ~ressure at 6786 (3~) PS'.= Static P~essure at 6787' . · · · · · J 'chevrOn U'S.A. Inc. ~ ~e .t Well Open Flow Potential Test Report i LITH. i TEXTURE OIL SHOWS I StYLI ~Y "X..4 ,x' -:',/,X× c,,X X' ' r_.,'r X x' !,,I. .4 x,~ X ¢ X . X. .... ~,,:,.,- sY X[:~ c XX' }x'c ix/ XX @" " ", """ ..... ' .. it' .I Xl~ .... Iz-e,, :; "' . ..... i c,'f X ~ d ~, ~;~ ~ x'X ~ Ix ~' ~" " , ' , ..... · ~ ,,. : - ~.~ . : ... ~. , i ,, l,, , , ~ , , . ~,,..; . ~ , ..... ....... - , ~ · , , ,,,7 , . , , ' "' - Z ' 0 W~.~H 0~L C C~o. .~ ~41-33 SIDEWALL SAMPLE D[SCRIPTIONS m ~ ~,..o,[-s.~,.,.~ ~ -_AKE, ALAS[A ~SCRIBCO ~YMAXWELL ~ ~NRAO ~ ~ MODCRATCLY SLIGHT O..~,~ D~.~ 5-14-78 ~. 5w5_ TaKen by Bob Conrad o~ CITCO v/ $W5 ~or COFRC analysis / ~,~.i~ / ,XX~N TEXTURE / / =_A_._K~._~_.4_I__-__3.~ ............ i'lL:....,: .., SIDEWALL' SAMPLE DESCRIPTIONS. S~EET 2. o~ 3 OIL SHOWS o. C~EVRON USA ~,,,$TUMP LAKE Loc.STUMP LAI/-E,~ ALASKA [ ........................... .[ ~Rare " " .... ~' ~ Carbonaceou~ mat'l In sample , , ~ breaks dp , ....................................... ~ Pebbly .............. ~ Carbonaceou, partings ~ /~ IN P~NT ~ SLI~MTLY O~ ~IG. J ~ vi., N No OIL ,SHOWS :o. CtAF. VRON USA, w~ STUMP LAKE ~41-33 L,c. STUMp LAKE) ALASKA ,X LAKE ~4 I- 3:3 LAKE ~ ALA.GK.A SIDEWALL SAMPLE DESCRIPTIONS ~,~o ~ tvtAXWELL ¢ CONRAD · ~. Coaly ..... Jr- ............ ~~_ ...... ~) Carbonaceous part,rig5 f ...... . ~ ~ Co~v,, a~b~,~ .......... ~ boai~ ~ebr~s ..... , ............ ............. ~ -- . .... , , : .......... ? ~ Abundant c~ly d~br~s :: ~' ~ .j'~' Common " " ~ Coal ~ In,,,~ragm~n,t~ ........ .~ ..................... ~ ...... ~ ,, , ,, , ~ ...... ~ ~ ; .............. , , ,,iii ,,, ,, , = ~ el = : ~. X FEATg~[ OCCURS A ABUNDANT CC, STUMP LAKE DST ~5 tO0000 I00000 Q - MCF/D STUMP LAKE 41-:3:3 VARIABLE RATE TEST $-1-78 INITIAL SHUT-IN AT 6787' DST 35 27 ............. : ~ ~7 26 ...... ' : ........................ ~ .............. LL ......................................... j .............................. /26 i I 0 I00 .T + AT 29 T -I. AT AT - O STUMP LAKE 41- VARIABLE RATE TEST $-1-78 FINAL SHUT. IN AT 6787' DST ~-~rch 13, 1978 ~evron U. S. A., Inc. P. O.:Box 7-839 Anchorage, Alaska 99510 Attention: C. F. ~~old referenced anr~d~nt is hereby aF~roved subject to our a[%oroval let- ters of Nov~ 15, 1976 -and Dec~ 21, 1977 and t]~ follc~ring stipu- lations: le 5~e ~area arour~l and below ~]e fuel stQrage facilities shall ]~ve a dike surrounding it with imperm~le m~ranes or fuel .storage facilities shall be of double v,~ll construction. 2~ The tanks shall b~. ~ptied in~ediately following %~11 c~a- pletion and the site topsoiled and vegetated with indigenous coastal, grasses at abandonmant. Sincerely, Ethel ti. Nelson I~%nd Manaq~m~n%t Officer F2~/mad STATE Oi LASKA REV. ~- 1-70 SUBMIT IN DUPLICAT~- OIL AND GAS CONSERVATION COMMII-i'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS AP1 NU.~IER~CAL CODE 50-283-20055 6 LEASE DESIGNATION AND SERIAL NO ADL-58790 1. ~ IF INDIA~, AbOT/EE OR TR1BE NAME OZL [] 0,, [] OrBE~ Exploratory WELL WELL -- ~. N~E OF OP~TOR 8. L~IT,F~ OH LEASE NAME Chevron U.S.A. Inc. St~ Lake Unit 3. ~DDRESS OF OPhiR 9 WE~ NO P. O. Box 7~839, Anchorage, AK 995~0 4~-33 4. IX)CATION OF WELL 775' South and 495' West from the Northeast corner..of Secti( 33, T 14 N, R 8 W, S.M. ~. 10. FIFJ~D END POOL. OR WILDCAT n Wildcat 11. SEC., T., R., M.. (BO"FTOM HOI_.,E Section 33, T 14 N, R 8 W,~,M. 12. PER.MIT NO. 13.REPORT TOTAL DI~TH AT END OF MONTH, CI-{A.NGF_,S IN HOLE SIZE, CASING AND CIK'..%dENTING JOBS INCLUDING DEPTH SET A~H~D vaLUaTES USED. PF-.P~ORATIONS. TF~STS AN'D RESULTS. FISHING JOBS. SUNK IN HOLE A.ND SIDE-Tlq. ACKED HOLE A3~D A3qY O/~IEt{ SIGNIFICANT ~G~ ~ HO~ ~DITIONS. Feb. 8 - 10 ~gging up B.D. Company 58 rig. Drive rat & mouse hole. Drive 30" conductor to 77' D.F. Install 30" rotating BOP. Feb 10 Spud 7:00 AM. Feb. 10 - 11 Drill 17 1/2" hole to 431'. Open 17 1/2" hole to 26" to 431'. Feb. 12 - 13 Cement 20", 94#/ft., H-40. Buttress csg. at 424'. Mix and pump 850 cu. ft. Class "G" cmt. mixed w/2.4% Gel, by wt. of water. Good circ. No returns. Ran 100' pipe in 30" ~ 20" annulus. Cmt'd annulus w/240 Sx. Class "G" cmt. Cut off 30" x 20". Installed 20" csg. head. Nipple up 20" - 2,000 psi. Class II B BOPE. Test to 900 psi. Feb. 13 - 18 Drilled 17 1/2" hole 431'-2541'. Prep to run 13 3/8" csg. Feb. 19 - 22 Feb. 23 - 28 Cmt. 13 3/8,, '72#/ft. N-80. Buttress csg. at 2512'. Mixed & pumped 1600 Sx. Class "G" mixed w/2.4% Gel, by wt. of water, followed by 400 Sx. Class "G". Good cir. throughout, no cmt. returns WOC. Cmt'd annulus w/50 Sx. Class "G" cmt. Cut off 13 3/8" csg. Installed 13 3/8" - 5000 psi. head. Tested head to 5000 psi. Installed Class. IV BOPE. Tested complete system to 5000 psi. Hydril GK to 3000 psi. Tested csg to 3000 psi. Witnessed by DOG. Drilled 12 1/4" hole from 2512' to 5256'. RECEIVED CONFIDENTIAL. MAR ' 9 i978 D!vision o~ Oil ,an(i Gas (;onserwtion Anchorag~ hereby certify that the/~,or~e~o~, true ~d ~ ,.~c~ /2' .~? .~ / ~A OPE~TIONS ,. , C.~ F.c.y~e~..QLD , , / ,, 3U~EniNTENDENT , , , , NOTE --Report on thit f~ ts ~e~utrtd for ~ colendor ~th% fegord~ss of Ibm mtotus of operations, end mu~t ~ filed 'In duplicate with oil an4 gas conservotbn commlffee by the 15~ of the tucc~ding ~n~, ~le~ otherwise direcfed. ~EP~ OF NA~ ~ESOt~CES Di-zisic~ of Oil ~ Gas Cc~x~zva~ Officer March 3, 1978;. Plan of Opera--S -'~m~mx~n~ ~' Chmvrcm-St~p Lake Unit No. 41-33 LO 78-25 (76-107), A~L 58790 cm February 16, 1978 and ~ its ~proval with no aklitic~al ? stipulate. DEP~ OF NATURAL RESOURCES Division of Oil and Gas fkxzeervatio~ O. K. Gilbreth, Jr/~~ March 1, 1978. ~ Stump Lake Unit 41-33 ~y, Fe~ 22, _1978- I received a call frc~ Ben Smith, Che~, ~ ~"at 7 :o0 ~,'-~ inf~ ~ that they woum ~e ready to ~ts w~re finalized. He called back at 7:30 AM and confirmad a .~_ight leaving from Troy Air Service at 10:00 AM. I departed Anchorage at 10:30 AM and arrived at the Beluga airstrip at 11:00 AM. I rod~ to the rig camp with Ieonard Dunham, Brinkerhoff tool- pusher, and ~ crew m~rs. At the camp I met with Ben Smith, th~ with diesel. The stank o0~si~ of a bottum set of pipe r~s, drilling spool with kill ~ choke lines, blir~ rams, pipe rams and Hydril. For the first test the blind ram~ ~e closed, the chec~ valve in plac~ on the kill !ine and the choke 1/ne open to a closed superchoke a~ valve to the blo~~ lin~. After pumping for awhile they decided they ~ pump~ belc~ the plug. While changin~ the position of the pump ~ I ~ the accumulator rocm with Leonard. T~mre ~ five 1600 PSI pres~. choke manifold to 5000 PSI, the blind rams and the upper pipe rams to 5000 PSI, the wing val~s (4) on both the kill and choke lines, and the check valve. ~he Hydril would not hold pressure and it was deci_de~_l to ~hanc3e out the bag and call in a Hall~ hand for the remainder of the test. We st~ testing at 9:30 PM_. ~y~. F~ - I was ca!l_ed back to the rig (Brinkerhoff 5~--~{'"-470~-~ ~--had-repla~ ~ Hydril bag, removed the test plug, ~ 3000 PSI due %o ~ limitations and the m3drill to 3000 PSI. We ~ mo%~ to ~ floor ~ tested ~ up~r and lower kelly valves to 5000 PSI. i obser%1~ ~ type ~ ~ type floor val~es and the absenoe of a %~ sign during ~he ~. i o0mpleted a "field i~pection report" ar~t ga~a two cop~ to Ben Smith. He s~d he would send a cor~y to Bill ~. I z~~ed he call n~ when the well sign was up. O. K. Gilbret/%, Jr. Stump Lake L~it 41-33 March !, 1975 ~: I wi~ ~x~f~l ~ of t~ b~ pr~nti~ equipment c~ B~~hoff rig 58. This rig is drilling the Stump. I~%ke Unit 41-33 ~i1 f~r Chevron. I retu~n~, to Anchorage at 3:30 PM. Attac~z~nt ^li~<a Oil and Gas Conservation Commi~t:~e Permit NO.7~__~_-~ Field Inspection Report ~~latfm SecX~T ~R~,~ M Operator~~V~o~ .... Represented by~ ~t ~ _ Number~m L~w~ ~~ ~1-~ Satisfactory T~vlzpe Inspection Yes .N.~ Item (~)q~ Location,General 1. Well Sign ( ) 2. General Housekeeping ( ) 3. Reserve Pit-(:~q)open( )filled IX) ( ) 4. Rig ( ) Safety Valve Tests ( ) ( ) 5. Surface-No. Wells ( ) ( ) 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , () () ( ) ( ) ~' 8. Hrs. obser () () 9. BS&W Satisfactory T_y~pe Inspection Yes No Item ~() BOPE Tests O~ ( ) 15.~/~_ "Ca~i'n.q Set @~/2- ~ ( ) 16. les~ fluid-( )wtr.-----~ )mud ~ oil (-~<) ( ) 17. Master Hyd. Control Sys.-./.~ psig (:~ ( ) 18. N2 btls.Zl~ ,Zm~-. ,~,~l,~psig (~><J ( ) 19. Remote Controls ( ) 20. Drilling spool-__~__"outlets ( ) 21 Kill Line-(~) Cheak valve (~)4) ( ) 22. Choke Flowline ( ) HCR valve ( ) 23. Choke Manifold No. va~vs_'7 flgs[ 0 ( ) 24 'Chokes-(I)Remote( )Pos.(~.~dj (~q) ( ) 25. Test Plum-OOWellhd( )csg( )none ' ,' ~o, s i Q ( } ( ) 1U. Gr. Bbls. , , , (,XO ( ) 26. Annular Preventer~ ( ) Final Abandonment (9<) ( ) ~2~7~ B, lind Rams~~si6 ~ ' ( ) ( ) l l. P~/~-~T~--~- ~) ( ) ~2~.'~pi~e~-'-~,~s~--~~siq~ ~,~ ( ) ( ) 12. Water well-( )capped( )plugged ~ ( ) (~]2~"'. 'Kelly & Ke~oCk~opsig ( ) ( ) 13. Clean-up ' (~ ( ) '~6; ~ower Kelly ~alve ~~si~ ( ) ( ) 14. Pad leveled ~~ (~ ( ) ~l./Safety Floor valve~BV ~)Dart Total inspection observation time ~ (hr~days Total numb6~teaks and/or equip, failures~ Remarks. ~~ ~_~--~~ ~. ~~ .... ~ ~:~_.~ cc' '~"' NOtify in days or when read.y~ Inspected by~ STATE of ALASKA TO.. FF~ Barber, SCDO Bruce Barrett, F & G Kyle Cherry D~C O.K. Gilbreth, O & G ~: Pete Nelson Land Manag~mentU Officer DATE: FILE NO: 2/21/78 LO 78-25 (76-107) TELEPHONE NO: SUBJECT: Chevron - Stump T..-3ke Unit Amendment Enclosed is the proposed amendment for the above referenced lease operations. Please review and send your ~ts to me as soon as possible. Thank YOu. Chevru~ C. F. Kirkvold Chevron U.SA. Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 Area Operations Superintendent Production Department State Oil and Gas Lease ADL-58790 Amendment - Plan of Operation-for Drilling Stump Lake Unit, Alaska Division of Lands Department of Natural Resources State of Alaska 323 East Fourth Avenue Anchorage, Alaska 99501 Attn: Mr. J. P. Green, Director Minerals and Energy Management Gentlemen: Please refer to the above subject and our Plan of Operation as amended November 17, 1977, and approved December 21, 1977. We have sucessfully completed construction of the winter road, bridge and drilling location. Drilling commenced during the week of February 5th. We propose to amend our Plan of Operation in the interest of economy and with the possibility of a winter road closure anytime after March 15, 1978. We must anticipate continuing drilling after road closure and prepare to support the operation by helicopter. In the interest of economy and in support of the drilling operation, we propose to establish 30,000 gallons of fuel storeage at the drilling lo- cation. This storeage will consist of two 15,000 gallon bladder tanks. A diked area of sufficient volume to contain the contents of the two full tanks was added to the drill site during construction. We have, on hand, a pit liner for the diked area to assure that no fuel leakage will escape the impounded area. The actual amount of fuel to be stored at the location will depend on estimated drilling days remaining as the time of road clo- sure approaches. The storeage will be established just prior to the elimination of road use. Paragraph 6B of our Plan of Operation refers to fuel storeage adjacent to the Beluga airstrip. We had anticipated hard tankage in that diked area but it did not materialize. The available 1,000 barrel tanks are some dis- tance from the airstrip and to save trucking expense of aircraft delivered fuel to these tanks, we propose establishing 40,000 gallons of fuel store- age in the diked area adjacent to the airstrip. This storeage will be two 20,000 gallon bladder tanks. We have ordered and will shortly receive a pit liner for use in the diked enclosure to assure containment of any tank leakage. R CEIVED FEB 2 2 ' 978 And:horn.]ne Mr. J. P. Green, Director Minerals and Energy Management -2- February 16, 1978 Your early consideration and approval of ~this amendment to our Plan of Operation is requested. · Very truly yours, EPW:dmw cc: Land and Water Management South Central District Attn: Ed Barber State Fish and Game Habitat Protection Attn: Bruce Barrett Form N'o. P--4 R.EV. ~- 1-70 STATE OF /-,,.LASKA SUBMIT IN 'DUPL1CAT~- OIL AND GAS CONSERVATION COMMI'Fi'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 0,L [] GAe [] Or,Z, Exploratory WELL WEL'L ~. NA2dE OF OPEPLATOR Chevron U.S.A. Ina. 3ADDRESSOFOPE~RATOR P. O. Box 7-839, Anchorage, Alaska 99510 ~.LOCA~ON OF W~ 775' south and 495' west from the northeast corner of Section 33, T14N, R8W, S.M. AP1 NUMERICAL CODE 50-283-20055 6 LEASE DES:GNA'i'ION A>,'D SEHIAL NO ADL-58790 ~ IF INDIA)4', ALOTTEE OR TRIBE NAME 8. L.~IT FA/iAI O11 LEASE NAME Stump Lake Unit 9 WELL NO 41-33 10. FIELD A_ND POOL. OR WILDCAT Wildcat 11. SEC., T., H, .5I.. ~OTq'OM HOI~E Section 33, T14N, R8W, S.M. 1~. PERA4IT NO. 76-86 13. REPORT TOTAL DF~TT{ AT END OF MONTH, CHANGES IN HOLE SIZE. CASING AND CE~LENTING JOES INCLUDING DEPTH SET AND VOLI~YES USED, PER~'ORATIONS, q-F~STS ;~%qD HE_CULTS. FISHING JOBS. JU/~K IN HOLE A-ND SIDE-TRACKED HOLE A~D ANY O'i/-{ER SIGNIFICANT CIiA~GF~S IN HOI.~ CONDITIONS. Spud Date - February 10, 1978 at 7 AM. Monthly Report to follow. Confidential NOTE ~Report on,is form i~ required for each calendar ~t~ regordtese of the status of operations, and must ~ filed Iff duplicate wif~ t~e . eil~nd gal coneervot[on commi~ee by the I~ of the succ~ding monlh, unle~ othermlle directed. Chevron Chevron U.S.A. Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 C. F, Kirkvold Area Operations Superintendent Production Department October 28, 1977 Permit to Drill Stump Lake Unit Well ~41-33 Permit 976-86 Mr. O. K. Giibreth, Director Division of Oil and Gas Conservation Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Gilbreth: Enclosed is a Sundry Notice Form 10-403 showning a change in the location of subject well. Please advise if any further information is needed. JET:dmw Very t~uly yours, C. F. Kirkv~ld / Form 10-403 Submit "Intentions" In Triplicate REV. [-10-73 & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form fei' proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OIL I--i GAs I--1 WELL L__J WELL g_J NAME OF OPERATOR Chevron U.S.A. ADDRESS OF OPERATOR OTHER Exploratory Inc. P. O. Box 7-839, Anchorage~ Alaska 4. LOCATION OF WELL At su trace See Below 99510 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Ground 30', ¥~-50' 14. Check Appropriate Box To Indicate Nature of Notice, Re 5, APl NUMERICAL CODE 50-283'-200_55 6. LEASE DESIGNATION AND SERIAL NO. ADL-58790 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Stump Lake Unit 9, WELL NO, 41-33 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 33, T14N, R8W, S.M. 12. PERMIT NO. 76-86 ~ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE pLANs (Other)_ SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEN'[* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, Permitted Location: 660' South and 660' West from the Northeast Corner of Section 33, T14N, RSW, S.M. New Location: 775' South and 495' West from the Northeast Corner of Section 33, T14N, RSW, S. M. ].6. I hereby certify t~a~ the f°reg°lng Is true ala(Lc0rrect (This space for State office/~). See Instructions On Reverse Side 24)01B STATE of ALASKA DEPARTHE[",iT OF i,[AI'URAL RESOU[~.CES ulvision~: of ,',~it aha' Gas Cansarv[]lcion TO.' I-- Pedro ~nton Leas ing Hanager [:Division of J4inerals and Energy Hanageme~t ,~-~ FROM: L C. Smith -~"~ '~ / Acting Di rector ,/ (} DATE ; January ~" 1:~77 SUBJECT: LO 76-107 (Paaend. 77-11) Socal -- S tur.%~ Lakc/I van .[:Live r ADL 5'~ Vie have no objections to the amended plan of operations and no additional stil-:ulations as a result of changes made. ~2~01B ST AT. of ALASKA DEP~ OF NATURAL RESCXIRCES Division of ~inerals and Energy Management TO: ~ Hoyle Hamilton - O&G Bruce Barrett - DF&G Kyle Cherry - D~C . Larry Dutton - SCDO ~/~ DATE : January 19, 1977 .. FROM: Pete Nelson ~ / SUBJECT: LO 76-107 (Amend. 77-11) Land Manage~_nt Officer III SoCal - Stump Lake/Ivan ADL 58790 Attached for your review and cc~ment is a copy of an amended plan of op~r~i6n~-'-~ on the referenced lease operation for SoCal. Your timely response is appreciated. RECEIVED P.O. Box 7-839, Anchorage, AK 995]0 - Phone (907) 279-9666 6. F. Kirkvold Area Supervisor Producing Department January 12, ].977 Amended Plan of Operation LO 76-1~7 ADL-58790 Stump Lake/Ivan River Area Division of Lands Department of Natural Resources State of Alaska 323 East Fourth Avenue Anchorage, Alaska 99501 Attention: Mr. Pedro Denton, Chief Minerals Section Gentlemen: A "Permit to Drill or Deepen" for subjec~ well~j~as approved by the State of Alaska Conservation Committee and issued ~--'S~andard Oil Company of California, now Chevron U.S.A. Inc., on December 6, 1976. The Plan of Operation for the surface operations required to drill subject well was approved by your office November 15, 1976. Inasmuch as this winter season has not yet allowed the needed frost penetration to provide support for the construction of a winter access road to the location, and inasmuch as it is our desire to commence drilling operations on this well this winter, we submit to you for your early consideration an amendment to the Plan of Operation providing for the construction of an all-weather access road as shown on the attached map. Time remaining and existing temperatures will not allow a winter operation. Basic construction timeframes for a winter operation include approximately 14 days for construction of the bridge across the Ivan River and 21 additional days to place the location fill. Before these can be accomplished 0°F. or below temperatures are required for at least a week for sufficient frost penetration to provide needed support to move bridge ramp fill material and transport bridge building equipment and material to the Ivan River. Temperatures below 0°F. are required for at least a week after completion of the bridge to support the hauling equipment during location construction and at least 2 more weeks of temperatures below freezing are needed to move the location fill. For the foregoing reasons, we do not believe that the current winter season will permit the drilling of this well as a winter operation. However, the construction of an all-weather road will provide for a continuous operation to most efficiently use available equipment and manpower as well as evaluate State Lease ADL-58790, which is due to expire on November 30, 1977. If you should need further information, we would be happy to meet with you at an early date to discuss our proposed operations in the Stump Lake area. Very truly yours, JET:nh Attachment PLAN OF OPERATION STUMP LAKE PROSPECT IVAN RIVER AREA, ALASKA 3~ 1. Well Site and Settinq The proposed location for the Stump Lake well is approximately 660' -south and 660' west of the NE Corner of Section 33, T. 14 N., R. 8 W., SB&M. The site is in the grass-covered ~ad flat area southwest of the southern end of Stump Lake. Tides greater than 33.0' cover the location. A location approximately 350' long and 170' wide will be constructed of gravel obtained from a source in Sec%ion 27, T. 14 N., R. 9 W. This pad will be built to a height of 5' above ground elevation. This height will provide sufficient freeboard above future high tides in the event the well becomes a permanent producer, A drilling waste pit approximately 100' x 170' will be constructed adjacent to the drilling pad. 2. Location Access Access to the location area will be by way of the all-weather road system to !van River Well 44-1 location. A gravel fill road will be constructed from a point just east of the Lewis River Bridge to the proposed location. (See attached Area Mapl. The route southwest of the Ivan River will serve proposed development wells in the Ivan River Unit. The Ivan Ri'¥er must be crossed. Stream bank width is 100'; therefore, a five bent, steel pile supported, steel beam bridge will be constructed. The bridge deck will be 8' above the ground surface. This will provide for 3' of freeboard at the river bank for~.the pile caps and 5' of structural bridge members. Existing Roads and Airstrip Ail roads in this area from the Superior Landing to the south to the !¥~n .River 44-1 well %o the north were built in the 1962-65 eza by Standard 0il Company of California as operator for the Beluga River Unit as well as during the course of other exploratory activity. The Beluga River. Airstrip was constructed during the 1962-63 original field development. It will also be used in support of our proposed drilling'operations at Stump Lake. ION LAKE PROSPECT RIVER AREA, ALASKA -2- r. 4. Water Supply A new water'source well will be drilled at the locaticc~ to su~ort our drilling operations. 5. Drilling Rig We plan-to negotiate with Brinkerhoff Drilling Company fc~ the u~e of their Rig #58 which is presently drilling Beluga River well 22!-2Z. We anticipate moving to Stump Lake after comm!eticn of ~-- construction of the new site and road. 6. Access to Site and Method of Supply %'he site is remote and is not connected to the Anchorace area by road. The only access is by one or more of the following: a~ BARGING TO THE SUPERIOR LANDING (STATE RESERVED During most of the year, barging is possible from ~te Kenai or Anchorage area to the Superior Landing and thence by truck no t!~e Uropo~:ed wellsite. Use-of this landing will definitely be re<uired ~) drill the p~oposed well. Most all of the materials and su~p!ics required to drill this well will have to be barged to the Superior Lan~ing. We .request continued permission to use the Supericr Landing. We estimate operations will continue intermittently ~- the quarter of 1977. B. AIR TRANSPORT TO BELUGA AIRSTRIP The BelUga Airstrip can handle Hercules-t~_~e airp!.a_-_~s, and we intend using this method to move freight an~ ~ .... ~ems a~ can be justified economically, in addition to barging. SinCe the rig uses diesel fuel, we will prcbably b~__--.~e or f].y in the fuel. Sufficient hard tankage is available to el~naEe consideration of "bladder" tanks. 5%~o 1,000 barrel tanks are available for fuel stOr~c'£ on ~e BRU 2Z4-4 location. An approximately 20,000 gallon fuel dm~ %-!!i be es%ablis!~ed at the Beluga Airstrip at the same location as exlsm£ng facilities · o~ '-~ ~_/.ked area which installed in 1962. These tanks are mn=~alz=u in a .will contain any fuel spillage or leakage. . . . . 7. Personnel Support A camp capable of housing and feeding approximately 40 m,~.m is installed in an area adjacent to the cities Service road tc their ~t Lewis River PLAN OF OPERATION STUMP LAKE PROSPECT !VAN RIVER AREA, ALASKA -3- location and will be our base of operations. Personnel will be flown in and out on a scheduled basis of approximately 10 days working and 5 days off. Food and other supplies will be flown in on an "as needed" basis. Sanitation facilities for the camp, consisting of a septic tank and leach pit, have been constructed with the approval of the Anchorage Office of the Department of Environmental Conservation. An approved .water well is in use at the existing camp. In addition to the camp, a house trailer has been installed for Standard Oil Company supervisory personnel adjacent to the Beluga Airstrip. 8. Miscellaneous Related Drilling Items. ae The waste pit will be located, constructed, and diked as necessary to prevent the possibility of any seepage to the surrounding terrain or drainages. Upon completion of drilling activities, the waste pit will be filled, leveled, fertilized, and reseeded with natural grasses. Be Sanitary facilities at the rig location will be chemical toilets These toilets will be emptied periodically and the material hauled and dumped into the camp septic tank. Ce The location will be graded so that any fuel or machinery oil leakage -will he.conducted to the waste pit. The 'location will be about 200' west-of the nearest lakes and ponds. Our drilling operation should not disturb the area, other than the construction of the drill pad fill. 9. Future Construction Stump Lake is being drJ.!!ed as an exploratory well. If co~uercial production is discovered, surface handling facilities will be required. At such time as this construction is required, proper permit application will be made. 10~ General Comments a~ Solid wastes such as mud sacks, kitchen waste, etc., will be hauled to the central waste pit near the airstrip and buried. Other hard waste such as drilling bits, etc., will be disposed of in the location waste pit when it is closed and covered after drilling is finished. B. Testing Any required testing will be accomplished using approved industry techniques. No hydrocarbon fluid will be disposed of on the ground surface. Gas flow testing will be to atmosphere through approved flare equipment. Attachment: Beluga River-Ivan River-Stump Lake Area Map. T.I 3NT. R 8W "' -- - PROPOSAL FOR DRILLING OPERATIONS - '----~' ...................... - ' _. DRILLING PROGRAM .... ~: .......... : ........... Field: Stump Lake .... - Property and Well: Stump Lake 41-33 .......... . --. Location: Surface_~_Approximately 660'. South .and 660,--West of the NE Corner ..................... - -of Section 33~ T. 14 Bottom ~ole - Same as above. Elevation: Estimated ground level 30'. Estimated KB 50'. " Blowout Prevention Considerations: 1. Potential Problems: A. Gas: .- . . ..- The proposed well is an exploratory well in an area of known gas- fields. Gas sands can be penetrated during the course of drilliqg .. .... this well to a total depth. Gas entries into the mud column can cause serious problems. Care must be exercised at all times to .... ._ · prevent gas entries by either swabbing the well or hydraulicing the formation on trips. Rapid penetration cause~ an increase in mud weight, and thereby increases the risk of lost'circulation and subsequent kicks. Penetration rates will be restricted. Coal beds can cause serious problems. They contain some.gas, slough readily, and drill rapidly. If thick beds are encountered, reduce the ......... . penetration rate and/or circulate bottoms up. · . BJ ..... Lost Circulation and Water Entries: ................... . . . · . · There was no lost circulation or water entries reported to 12,000' vertical depth in any of the nearby Ivan River wells. C. Precautions: Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at all times by every member, of the crew. The._ho!e must be k~pt full at all times. D. S~cial Problems: Considerable hole problems were experienced while drilling Ivan River 23-12. The 10 3/4", 7" casing, and 5" liner were stuck while running in the hole. Similar problems also occurred at Ivan River 14-31 where the 7" casing was stuck while running in the hole. Basi.c. System DRILLING FLUID PROGRAM STUMP LAKE 41-33 STUMP LAKE FIELD Lightly treated Lignosulfonate mud. O~timum Properties Value Ranqe To 13 3/8" C.sg. Point 13 3/8" csg. Pt. to 7000' Weight, pcf Viscosity, sec/qt., API Fluid loss, cc, API Plastic Viscosity, CPS Yield Point, lb./100 ft.2 Gel, lb./100 ft.2-10 min. pH Solids Content, % volume Diesel Oil, % 73-76 40-200 76-81 40-45 Less than 10 15-25 8-15 10 Max. 8.5-10.0 10-16. 4-7 Remarks: Chemically disperse mud with li~%osulfonate. Maintain adequate supply of lost circulation material and barite at the location. · · 'Run desander and desilter to keep solids at a minimum while drilling. Increase viscosity while drillin~ surface hole as required to control gravel. Li~it dry jobs to 20 sacks of barite or.as directed by Drill- ing Foreman. Gels must not be progressive. 7000 ' to TD 81-93 40-45 4-8 10-15 5-10 10 Max. 8.5-10.0 8-10 4-7 PROPOSAL FOR WE: OPERATIONS PRO'316-A (TO [ USED AS A G0-111) CASING REQUIREraE TS AND PRODUCING EQUIPMENT WELL/LOCATION NO. FI E L D Exploratory TOTAL DEPTH 11650 ESTIMATED O/W/G ,, / CASING Gross Fo0ta~l,e Conductor- 90 ' 425 ' Stump Lake 41-33 DATE ESTIMATED SPUD DATE METHOD OF PRODUCTION MAX. ESTIMATED SURF. /1000~QUIP. FOR STEAM INJ. APl Size Weight Grade Threads Coupling ~ 1L~pipe~ drive Shoe. 20" 94~ H-40 Buttress or plain end. Surface Requires-duplex shoe (stab-in) 10 each 20" x 26" centralizers 2500 ' 13 3/8" -72# N-80 Buttress Requires float shoe, duplex collar (stab-in) 15 each 13 3/8" X Water String: Design based on mud density lbs./cu.'ft, and above ma'x. surf. pressure 2100 ' 9 5/8" 43.5~ N-80 Butt 3500 ' 6050 ' ,z/15/76 PRESSURE PSI PRODUCER Computer Design For: This Well D Standard Design For Field r'] Well No. I-] Max. Drift Angle _ ° 17 1/2" centralizers. 7" 29% N-80 7" 29# P-110 8RD LT & C~Available in Alaska Buttress Cementing Accessories Liner None Hanger None Perforated ', CASING } HEAD: UNITIZED CASING SPOOL Float shoe, float collar, two stage collars, 40 each 7" x 12 1/4" centralizers. NOTE: All equipment except one stage collar to be buttress. One stage collar to be 8RD LT&C. One 7" x 9 5/8" crossover. to . ', Mesh, Rows, SI ors, , _. 5000 PSI CWP. Bottom Conn. 13 3/8 SOW Top Conn... 13 5/8 5000 PSI 2" Fittings 1 - .5000 PSI valve w/blind flanqe w/b~tll_plug Centers· MC MUC 2 outlets TUBING HEAD TUBING 5000 'PSI CWP. Bottom Conn. 13 5/8" - 5000 PSI Top Conn. 10" 5000 2 2 ", Flanged outlets Type Suspension 9 5/8" secondary pack-off '.,~ Use Cameron Triple Tree purchased for Falls Creek. Plug one outlet. Feet AP! Size Weight Grade Threads Type Remarks . (Cross-overs, etc.) 2000 ' 2 3/8" 4.7 N-80 8RD EUE 11600' 2 7/8" 6.4~ N-80 8RD EUE= ' · Total Tubing Catcher, Packer with XMAS TREE " . Tubing Beans Header Stuffing Box PUMP: RODS: Grade__ PUMPING UNIT. APl Size Engine " type. Csg. Size " Wt. Install at . : ,,,, , , ' "x " Type ~vith "stro e at # wt. Other Fittings , Arm ~ X PS! CWP. Type Motor Type Arm PSI CWP. Dwg. No. Type Type. Polished Rod "x ' Long ' Type at .... of .... of " · Max. Stroke "Set at "Stroke and SPM HP Remarks Prepared By ~/.y~. Area Supervisor Approved by Drlg, Supt. Sr. Drlg. Engineer PrIo-31(~-,% (CrJ-1.751 Pfhtt~,d m U.S.A. .o "(2) 4. VALVES a ~000 p~i o ... . HYDRIL BAO . · · -. o. ]~LOW Lib VALVES OUTLETS "% FLANa£S" 5000 p~ ~NIFO~ , . BULL PLUG · BU~ PLUG ' ~ooo/) · , · · I · CLASS ~ 13s'' ' ~ -..5oocP'~ KILL LINE ,. 4" VALVES OUTLETS ~ FLANGE ~ooo/! ~ANZFO~O - :s'ooo// ' CASI?,)G · · · HYDRIL :BAG ' ~.[.~-' 5;0oo# 500-0~ bn ~. CA~,IMG CL ASS. ]TLr. 13 ~''~ -- 20"- 2000// .. · ,. . ~~-"~ .. .'.. · '- ' ' .~ooo,~ . -. ~;: .':-' . .' ._., .,:- - .-" ';'.' -~ I. I y'c.,,,~.~.~o, ~. !. 1-. ,,-r-~-~ _ -. · · ' P~P~ '~1:'I' t' /TYP~ [I I P - ' ' '; --' -' "1 - : "~' "' ":' -~[ .-'-:. ~i~,,"-'~ooo,' '. :,-. -- .._ . ,~ ~ '; . ·., :, ; ~~ -, . ... · ~o~. '.. BLeD ' ' ' ' I '] : '~"~'"1' I I~/-¢ ~-',l. m~LLZ~o sPoo~ '~~ I ' - h" VA~S, OUT,TS A ' ' ~ ' ! ~ ' ~ '.. F~NG~S 5000~ MANIFOLD - ~-" ~ ~,, · ~=~. ' ' ': · ~ - ~,. . ~,,, ' ~-----~ ~.,,5 ~. , . . . · . · ' ~[;~'- -: .~--~ ~% ' . - I r. , '~" ' '"1 -. . ~ ~ ' '." -" : .'. :- · '.- ' . i ~ ' · ' ' t II ~ ' C ' " f~[ ' ' ' ..... ~ a LM~DIH~ SPOOL ~~ .... .. .. ~ ~ ' ' ~ .' ~ ~ k% .-g~ PROPOSAL FOR DRILLING OPERATIONS DRILLING PROGRAM (STUMP LAKE 41-33~ -2- 2. Estimated Depths and Formation Pressures Approximate Reservoir ~ressure, PSI Interval TVD Gradient PSI/Ft. . , ,, Base Sterling 5200' '2445 .47' 'IR 44-1 Sand 8275' _.. 4300 .52 Top "D" Sand 9750' 6045' .62 * Total Depth 11650' 7225 .62 * *Based on salt water test on Ivan River 44-1. 3. Maxmimum Anticipated Surface Pressure: 5100 psi based on assumed "D" gas zone. If "D" contains oil, pressure will be less. If gas is present below "D" pressure will be greater. 4. Blowout Prevention Equipment: ae On 20"-casing: Class IIB, consisting of Hydrill MSP 2000 bag and CSO ramS, and Shaffer rotating preventer. S. Ce On 13 3/8" casing: Class IV, consisting of Hydrill bag, two sets of pipe rams, blind rams. · On 7" casing: Class IV, consisting of Hydril bag, two sets of pipe rams, blind rams. D. Installation and testing of this equipment is outlined in Operating Instructions D-17.. PROGRAM 1. Install 30" conductor to 80' or as deep as practical. Install Shaffer rotating preventer on 30" conductor. 2. Drill 1-5" hole to 425'. Open hole from 15" to 26". Maintain drilling fluid per attached program. 3. Cement 20", 94~, H-40 (buttress or welded) at 425' with sufficient volume of gel treated Class "G" cement to reach the surface. Treat the last 400 sacks of cement with 3% calcium chloride. Theorectical volume plus 33% excess, is 850 cubic feet. If cement returns are not received~:. :~ :.~at the surface, do a top job. i~":'7~i ~: ii A. Use a Baker Duplex (stab-in) cement shoe. i: ~:' ~ .~ :~ B. Baker lock bottom 3 joints. ' C. Centralize the 20" casing over the entire length. ,.', '"', ~ ~' i~ ? ~-.. : " .~'~ · PROPOSAL FOR DRILLING OPERATIONS DRILLING PROGRAM (STUMP LAKE 41-33) · -3- 4. Install Class IIB, 20" - 2000 psi BOPE on the 20" casing per the attached diagraml-'Fabricate blow and kill lines for 5000 psi service. A Class IV, 13 5/8" 5000 psi BOPE wil'l be installed later on the 13 3/8" casing. A.' 'Test BOPE per Operating Instructions D-17. Burst of 20", 94#/ft., H-40 'casing is 1530 psi without a safety factor. Do not exceed 900 psi surface pressure on test. · . 5. Drill out cement and shoe of 20" casing. Drill.ahead in 17 1/2" hole to 2500'. Install mud loggers before drilling out shoe of 20" casing. Log to total depth. Note: ' ' Maintain mud properties per the attached program. Severe hole problems developed while directionally drilling well IR 23-12. The section drilled from the surface to 6000' is essentially gravel. 6. At 2500' condition hole for logs. Obtain one-half gallon mud sample prior to running logs. 7. Run and tape the following Schlumberger logs: a. Dual Induction Laterolog. Use 2" linear and 5" logarithmic scales. BHC Sonic with SP and Caliper. 8-10-10-12 Sonic. 8. Run 2500' of 13 3/8" OD, 72#/ft., N-80, buttress casing and cement to the surface as follows (have stage collar on location in case lost circulation Occurs or hole conditions dictate i~s use): A. Use float shoe and Duplex (stab-in) collar one joint off bottom. B. Lock Bottom three joints of 13 3/8" casing. C. Centralize casing above shoe, U. Run drill pipe and stab into Duplex collar. Cement through the Duplex collar with sufficient Class "G" cement premixed with 2.4% gel, by weight of water to reach the surface. Follow the gel cement with 200 sacks of neat. Basis: Yield Class "G" = 1.15 ft? /sack Yield Class "G" + 2.4% gel by weight 'of water = 1.86 £t.3/sack. If cement returns are not received at the surface, do a..~op.~job~ PROPOSAL FOR DRILLING OPERATIONS DRILLING PROGRAM (STUMP LAKE 41-33) -4- 9. Cut off 1'3 3/8" casing 36" below the top of the cellar to allow the top flange 'of the tubing head to be above ground level after completion. 10. Install 13 5~8" - 5000 psi x 13 3/8"SOW casing head. Test welded lap to 5000 psi. 11. Install Class IV 13 5/8" - 5000 psi BOPE as per the attached drawing. Test BOPE, kill line, blow line, and manifolding to 5000 psi as directed by "Operating Instructions D-17". 12. Clean out 13 3/8" casing, to within 10' of the shoe. Pressure test the 13 3/8" casing to not over 4500 psi. 13. Drill ahead in 12 1/4" hole to a measured depth of 11650'. Ao . Maintain mud properties per the attached program. Limit penetration as required. Be prepared to run conventioanl core barrel as directed anytime after shoe of 13 3/8" casing has been drilled out. ' C. Be prepared to run correlation log at 8500' M.D. 14. At 11650' condition hole for logs. Take a one-half gallon sample of mud -prior to pulling for logs. Run and tape the following Schlumberger logs: ae Dual Induction Laterolog. Use linear 2" and 5" logarithmic scale. BH~ Sonic with SP .and caliper and 8-10-10-12 Sonic. Co Compensated Neutron and Density Logs with Gamma Ray. Record simultaneously on 5"/100' scale. Four Ar~ High Resolution Dipmeter. Fo Proximity Log. Have two soft formation sample guns on location. Go Ail logs are to be'recorded from effective depth to the shoe of the 13 3/8" casing. 15. Depending on results, a supplementary programwill be issued to run 7" casing, test, ~omplete, abandon, or deepen. W. A. BROM~LSIEK Conserva t i on December 8, 1976 Stump Lake Unit No. 41-33 Sbn~rd Oil Company of California State Permit ILo. 7646 G. ~tl,uk Area Engineer Standard Oil Company of California P. O. ~x Panchorage, Alaska 99510 l~ar Sir: EnClOsed is the approved application for permit to drill the above referenced well at a location in Section 33, Township 14N, Range 8~, Well samples, con chips and a mud log are required. A directional survey is not required. ~tany rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subj~t to AS t6.50.870 and the regulations promulgated thereunder {Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Depart- men t of Fi sh .and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations promulgated thereunder {Title 18, Alaska Administrative Code, Chapter 70) and by the Federal ,~ater Pollution Control Act, as a~nded. Prior to commencing o~rations you may be contacted by a representative of the ~par~t of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifyin~q this office within 48 hours after the well is spudded. We would also like to be notifi~ so tP~t a representative of the Division may be present to witness ~sttng of blowout preventer equipment before surface casin~ shoe is drilled. December 8, 1976 %n the event ot' suspension or abandonaent please gtve thts offtce adequate advance notification so ~t we may have a wttness present. Thos, R. :~rsha11, £xecutlve ~tary A1as~ 0~1 a~ Gas C~nservatiOn ~lttee Enclosu~ CC: Oepar~nt of Fish and ~, Habitat Sectton w/o eric1. Oepar~nt of Envlro~mental ConservatiOn w/o encl. Oepar~t of Labor, ~rvtsor, Labor Law Compliance O~v!slon wlo eric1. Chevron Standard 0il Company of California, Western Operations, Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 C. F. Kirkvold Area Supervisor Producing Department November 29, 1976 CONFIDENTIAL Permit to Drill Exploratory Well Stump Lake Unit #41-33 Well State of Alaska Lease ADL-58790 · Stump Lake Area, Alaska Mr. O. K. Gilbreth, Director Division of Minerals & Energy Management Department of Natural Resources Division of Lands 323 East Fourth Avenue Anchorage, Alaska 99501 Dear Mr. Gilbreth: Standard Oil Company of California proposes to drill the subject well in a location as shown on the attached plat. For your consideration and approval we submit, in triplicate, State of Alaska Oil and Gas Conservation Committee form "Permit to Drill or Deepen", and our check in the amount of $100.00. We have filed the Plan of Operation with the State of Alaska, Division of Lands, which was approved November 15, 1976. We plan to commence drilling operations in January, 1977. If further data is required, please advise. Very t r u 1%.y/~. y.o~u~. ,. ? C. F. Kirkvold JET:nh Attachment !~ I0- 401 ~%r. I--I--?1 la. TYPB 01~ WORK SUBMIT IN ~IPL (Other instrue, ttons ~r~. side) STATE OF ALASKA OIL AND GAS CONSERVATION ,COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL [] DEEPEN b. ~Plg OJ' WILL NAME OF At,.~h~, ~~t~y 660' So~h ~d 660' W~t of ~e N~~t Co~.'of S~ion 33, T. 14 N., R. 8 W., S~ as ~e. S~e~ l~tion ~11 S~~ at a ~t~ date, At prolmsed prod. zone DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OI,'FtCE* ~ 35 miles west of Anchorage 14. BOND INFORMATION: "nrPZ Statewide s.~.t~, .,,.,or ~o, 6223435 D,STANCE FROM .PRO, OSCO' 660' to ADL-58789 LOCATION TO NEAREST PROPERTY OR LEASE L.IN~. FT. (Al~o to nearest drig. unit. if. any) ~8. DISTANCE FROM PROPOSED LOCATION' TO NEAREST WELL DRILLING. COMPLETI!iD. OR APPLIED FOR, FT. z~1.6500' frca'a Ivan Rivor 44-! 21. F. LEVATIONS (Show whether DF, RT. CR, etc.~ AP1 No. 50-283-20055 6. LEASE DISIGNATION ~ S~tlAL NO. 3I~L-58790 L IF IhrDIAN..,~I.~ 08 TRI.~E NJ~li~ 8. UNIT FARM OR LEASE NA~M[E Stump Lake Unit $. W~LI, NO. 41-33 ~0. FIELD AND POOL. OR WILDCAT Wildcat ti. SEC.. T., R.. M.. fBOT~OM HOLE OI~TF_,CTIVE } ~ec. 33, T. 1411'I.,R. 8 W.,SB&~'! t 16. ,NO~ OF ACRES IN LF~ASE. ' 19. PROPOSED DEPTH , ' -z6s0' (k-our~ 30' KB-50'" 23. PROPOSED CASING AND CEMEHTING PROGRAM ~, $100,000 17.NO. ACRES ASSIGNED TO THiS WELL 640 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK 'WILL START' SIZE OF HOLE SIZE OF CASING , WEIGHTpER FOOT GRAII~ SE'TTI~C, DEPTH quofltit¥ o~ ceme.t 26" 20" 94~ It-40' ' 425' " {60 sacks ..... , _ '17 1/2- 13 3/8" 72~ N~80 2500' 1210 sac~--."" ~ .. .. , , , , , , ~ , . , , , , ,, , , , , , We propose drilling this well as per the attached program. Please treat this well as confidential. ~ ABOV~ SPAC'E ~DI~!~'RIBE lmltOPOS~ PROGRAM: If ~ml ~ to d~n give ~w p~u~lve ~ne..l~~t ~ ~ a~[ or ~n ~to~. give ~e~? ~ on ~suff~ ~ ~a m~d ~d ~ue '~t~! de~. GI~ b~u~ D~veuter program. ~. ~. I he.by ~f/~hat the Fore~ is ~e ~ Co~e~ . . , , /t- t , ' (Th~ spa~ tot S~te of~ u~) Area Engineer CONDITIONS OF APPROVAL, IF ANY: [SAMPLE~ AND CORE CHIPS REI~ MIlD LOC I ~ I~L~U~~: Dm2:C'nONAL su~v~-y Rm~ 'A.~.Z. ~c~ ~ ~ ~ NO 76~6 .~ In'on, On ReverN Side 50-283-20055 December 6, 1976 December 6, 1976 PROPOS~FOR DRILLING OPERATIONS DRILLING PROGRAM Field: Stump Lake -. _- Property and Well: .Stump Lake 41-53 . Location: Surfaco_m_Approximately 660~ South.~d 660!--West of the ~ ~orner ................... - ~f Section 33'~ T. 14-' N: ~ R. 8 W;%- SBaM:'- Bottom Hole - Same as above. Elevation: Estimated ground level 30'. Estimated KB 50'. Blowout Prevention Considerations: 1. Potential Problems: A. Gas: .: - _._ The proposed well is an exploratory well in an area of known gas fields. Gas sands can be penetrated during the course of drilling this-well to a total depth. Gas entries into the mud column can cause serious problems. Care must be exercised at all times to --prevent gas entries by either swabbing the well or hydraulicing the formation on trips. Rapid penetration cause~.an increase in mud weight and thereby increases the risk of lostbcirculation and subsequent kicks. Penetration rates will be restricted. Coal beds can cause serious problems. They contain some.gas, slough readily, and drill rapidly. If thick beds are encountered, reduce the penetration rate and/or circulate bottoms up. B~ ..... Lost Circulation and Water Entries: _ . , · There was no lost circulation or water entries reported to 12,000' vertical depth in any of the nearby Ivan River wells. C. Precautions: Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at all times by every member, of the crew. The_._hole.~ust be k.~Pt full at all times D. ~p~cial Problems: Considerable hole problems were experienced while drilling Ivan River 23-12. The-10 3/4", 7" casing, and 5" liner were stuck while running in the hole. Similar problems also occurred at Ivan River 14-31 where the 7" casing was'stuck while running in the hole. · · · . · DRILLING FLUID PROGRAM STUMP LAKE 41-33 STUMP LAKE FIELD Basic System Lightly treated Lignosulfonate mud. Optimum P.r. oper~ies.' To 13 3/8" Cs Point Value Range 13 3/8" Csg. Pt. to 7000' 7000' to TD Weight, pcf Viscosity, sec/qt., API Fluid loss, cc, API Plastic Viscosity, CPS Yield Point, ~./100 ft.2 Gel, lb./100 ft.2-t0 min. pH Solids Content, % volume Diesel Oil, % 73-76 40-200 ~ . 76-81 40-45 Less than 10 15-25-' 8-15 10 Max. 8.5-10.0 10-16 4-7 81-93 40-45 4-8 10-15 5-10 10 Max. 8.5-10.0 8-10 4-7 Remarks: Chemically disperse mud with li~%osulfonate. Maintain adequate supply of lost circulation material and barite at the location. 'Run desander and desilter to keep solids at a minimum while drilling. · Increase viscosity while drillin~ surface hole as required to control gravel. L~it dry jobs to 20 sacks of barite or.as directed by Drill- ing Foreman. Gels must not be progressive. PROPOSAl FOR.WE[ 3PERATiONS PRD-316-A (TO E JSED AS A GO411) CASING REQUIREMENTS AND PRODUCING EQUIPMENT WELL/LOCATION NO. Stomp Lake 41-33 DATE FIELD'. Exploratory ESTIMATED SPUD DATE 12/15/76 TOTAL DEPTH 11650 METHOD OF PRODUCTION MAX. ESTIMATED SURF. PRESSURE ESTIMATED O/W/G /. '. /IO00.(~QUIP. FOR STEAM INJ. PRODUCER CASING ,,, Conductor' Surface Water String: Gross Footage APt Size Weight Grade Threads Coupling Computer Design For' 90 ' ' 3U"~' ~pipe w~---i-Eh drive shoe. This Well 425' 20" 94% H-40 Buttress or plain end. Standard Design For Field Requires' duplex shoe (stab-in) 10 each 20" x 26" centralizers Well No. 2500' 13 3/8" 72~ N-80 Buttress Max. Drift Angle Requires float s-~-~'~', duplex collar (stab-in) 15 each 13 3/8" X 17 1/2" centralizers. Design based on mud density lbs./cu.'ft, and above max. surf. pressure 2100' 9 5/8" 43.5% N-80 Butt 3500 '_ 7" 29% N-80 8RD LT* & C3Available in Alaska 6050 ' 7"- 29% P-ll0 Buttress PSI E] E] Cementing Accessories Liner None Hanger None Float shoe, float collar, two stage collars, 40 each 7" x 12 1/4" centralizers. NOTE: All equipment except one stage collar to be buttress. One stage collar to be 8RD LT&C. One 7" x 9 5/8" crossover, ..... - Perforated ', MC to ', '- Mesh, Rows, SlOts, Centers, MUC CASING } HEAD: UNITIZED CASl NG SPOOL 5000 PSI CWP. Bottom Conn. 13 3/8 SOW Top Conn.' 13 5/8 5000 PSI 2 ", Fittings 1 - 5000 PSI' valve .w/blind flanqe w/bu3~]~_plug 2 ,, , outlets TUBING HEAD TUBING 5000 -PSI CWP. Bottom Conn..13 5/8" - 5000 PSI 2 2 ", Flanged outlets Top Conn. 10" 5000 Type Suspension 9 5/8" .secondary pack-off Use Cameron Triple Tree purchased for"~alls Creek. Plug one out.Let.. Feet AP i Si ze Weight Grade Th reads TYpe Re ma rks ,,, ..... 'i:,,.':.' r(Cross-overs; ~c.):-7" 2000' 2 3/8" 4.7 N-80 8RD El/Si': ~. :,., ,~ .; ' ..... ~ , : 11600 ' 2 7/8" 6.4% N-80 8RD EUE! ~ . ~ . Total Tubing Catcher Packer with XMAS TREE __ Tubing Beans Header Stuffing Box PUMP: RODS: Grade__ PUMPING UNIT. APl Size Engine X Arm #, ,· · Of type. Csg. Size " Wt. Install at ': ';q? i,' ' " Type {Nith __" stroke at ' # wt. Other Fittings Arm Type Motor PSI CWP. /l~yO~'./l~'~/ USe Camornn q'ripl~ Tree Type ~" PSi CWP. Dwg. No. Type. Polished Rod "x Type at ' of "; ' of Max. Stroke "Set at "Stroke and HP Remarks Type 'Long SPIVi Prepared By Area Supervisor Approved by Drig. Supt. Sr. Orig. Engineer PRO-:111,~-,% (CL)-1-75} Pf httod .t U.'C.A. et, · ° HXDRIL BAG · --'..' ' ' ......... 13i]" - 5000// · · ' ' CM~ERON o .o · 5000 psi ' z:::[liJ:q 0 Fit ', t.:f 0 ';-::,',. ~ ~/ . ,, ; · --.~,j: ...-. · . . · .~ ~IPE BLIND BL~ LIS E .~~-~. VALVES OOTLETS '-'~ FLANGES"-'13["-~00~ ~O00 ps~ ~NIFO~ .... '. ' · . BULL PLUG · BULL PLUG · · · i 5ooc¢ CL'AS S ~w · o. TYPE "U" ' · & · f~ (2) ~,r' ~j_,, %~,1, · . . & OUTLETS .-?.. .. 5000 psi -~i" z ~o0~ .. '- ..~UB~ ", i ~'. ' .~,~RQN TYPE,,U,,- ,. · . . . .- · KILL LINE VALVES OUTLETS a FLANGE 5ooo// ~mNIFOnD · . - '5ooo~! '. 20 - 20OO~ ° i LAKE" o ~, · · . : .* - :.. · ".., ~ ~. * · . ~.~ - .'% ~ e ~ ee ~ . e- - . ..,- .. .HYDRIL ,BAO' . . 3,3-~,' ' ' ,~ooo#- · · . · PITCHER 'N · , · DRILLING SPOOL WITH h" VALet, S, OUTLETS & 'F~N~S 5000# MANIFOLD ~ ' ),.,, ' h,, ' r- ---- ,-" ? T-:: '":;'('bT:':,: .~ . . ~, ~.., ;_~,~,. ' .'' ' . ': . ,.-. roLL PLUG~J~ J o,'J 1'3,a CLASS. IIr. - 5000 PROPOSAL FOR DRILLING OPERATIONS DRILLING PROGRAM (STUMP LAKE 41-33) -2- 2. Estimated Depths and'Formation Pressures Interval TVD .. Approximate Reservoir ~ressure, PSI Gradient PSI/Ft. Base Sterling 5200' 2445 .47 IR44-1 Sand 8275' ..~ 4300 .52 Top "D" Sand ~750' 6045 .62 * Total Depth 11650' 7225 .62 * *Based on salt water test on Ivan River 44-1. 3. MaxmimumAnticipated Surface Pressure: 5100 psi based on assumed "D" gas zone. If "D" contains oil, pressure · will be less. If gas is present below "D" pressure will be greater. . o 4. Blowout Prevention Equipment: ae On 20" casing: Class IIB, consisting of Hydrill MSP 2000 bag and CSO rams, and Shaffer rotating preventer. Be On 13 3/8" casing: Class IV, consisting of Hydrill bag, two sets of pipe rams, blind rams. Ce On 7" casing: Class IV, consisting of Hydril bag, two sets of pipe rams, blind rams. De Installation and testing of this equipment is outlined in Operating Instructions D-17. PROGRAM 1. Install 30" conductor to 80' or as deep as practical. Install Shaffer rotating preventer on 30" conductor. 2. Drill 1.5" hole to 425'. Open hole from 15" to 26". Maintain drilling fluid per attached program. 3. Cement '20", 94#, H-40 (buttress or welded) at 425' with sufficient volume of gel treated Class "G" cement to reach the surface. Treat the last 400 sacks of cement with 3% calcium chloride. Theorectical volume plus 33% excess, is 850 cubic feet. If cement returns are not received 'at ~ the surface, do a top job. A, Use a Baker Duplex (stab-in) cement shoe. Baker lock bottom 3 joints. Centralize the 20" casing over the entire length. ~ROPOSAL FOR DRILLING OPERATIONS DRILLING PROGRAM (STUMP LAKE 41-33) 4. Install Class IIB, 20" - 2000 psi BOPE on the 20" casing per' the attached diagramS" 'Fabricate blow and kill lines for 5000 psi service. A Class IV, 13 5/8" 5000 psi BOPE wil-1 be installed later on the 13 3/8" casing. A.' Test BOPE per Operating Instructions D-17. B. Burst ~f 20", 94#/ft., H-40 'casing is 1530 psi without a safety factor. Do not exceed 900 psi surface pressure on ~st. · ....... ~ ·. 5. DrilI out cement and shoe of 20" casing. Drill ahead in 17 1/2" hole to 2500'. Install mud loggers before drilling out shoe of 20" casing. Log to total depth. Note: Maintain mud properties per the attached program. Severe hole problems developed while directionally drilling well IR 23-12. The section drilled from the surface to 6000' is essentially gravel. 6. At 2500' condition hole for logs. Obtain one-half gallon mgd sample prior to running logs. Run and tape the following Schlumberger logs: A. Dual Induction Laterolog. Use 2" linear and 5" logarithmic scales. B. BHC Sonic with SP and Caliper. C.' 8-10-10-12 Sonic. 8. Run 2500' of 13 3/8" OD, 72#/ft., N-80, buttress casing and cement to the surface as follows .(have stage collar on location in case lost circulation occurs or hole conditions dictate i~s use): A. Use float shoe and Duplex (stab-in) collar one joint off bottom. B. Lock Bottom three joints of 13 3/8" casing. C. Centralize casing above shoe. D. Run drill pipe and stab into Duplex collar. Cement through the ~uplex collar with sufficient Class "G" cement premixed with 2.4%. gel, by weight of water to reach the surface. Follow the gel cement with 200 sacks of neat. E. Basis: Yield Class "G" = 1.15 ft? /sack Yield Class "G" + 2.4% gel by weight of water = 1.86 ft.3/$ack. · If cement returns are not received at the surface, do a top job. PROPOSAL FOR DRILLING OPERATIONS DRILLING PROGRAM (STUMP LAKE 41-33) --4-- 9. Cut off 15.3/8" casing 36" below the top of the cellar to allow the ~op flange'of the tubing head to be above ground level after completion. 10o Install 13 5/8" - 5000 psi x 13 3/8" SOW casing head. Test welded lap to 5000 psi. 11. Install Class IV 13 5/8" - 5000 psi BOPE as per the attached drawing. Test BOPE, kill line, blow line, and manifolding to 5000 psi as directed by "Operating Instructions D-17". 12o Clean out 13 3/8" casing to within 10' of the shoe. Pressure test the 13 3/8" casing to not over 4500 psi. ~' 13. Drill ahead in 12 1/4" hole to a measured depth of 11650'. ao Be Maintain mud properties per the attached program. Limit penetration as required. Be prepared to run conventioanl core barrel as directed anytime after shoe of 13 3/8" casing has been drilled out. ' C. Be prepared to run correlation Iog at 8500' M.D. 14. At 11650' condition hole for logs. Take a one-half gallon sample of mud prior to pulling for logs. Run and tape the following Schlumberger logs: A. Dual Induction Laterolog. Use linear 2" and 5" logarithmic scale. B. BH~ Sonic with SP and caliper and 8-10-10-12 Sonic. Compensated Neutron and Density Logs with Gamma Ray. Record simultaneously on 5"/100' scale. D. Four Ar~High Resolution Dipmeter. E. Proximity Log. F. Have two soft formation sample guns on location. Ail logs are to be'recorded from effective depth to the shoe of th~ 13 3/8" casing. 15. Depending on results, a supplementary programwill be issued to run 7" casing, test, domplete, abandon, or deepen. W. A. BROM~LSIEK Nov~ !5~ 1976 Stm~ard O~CI C ~.cmpa~f of California, Western Operations, Inc. P. O. Box 7-839 Anchorage~ Alaska 99510 Attn: Co F. Kirkm~Id Re: LO 76-107 Stt'~ i~ke/Ivan Piver ADL 58790 ,\ The operations outlined Un .yo'&r letter of Octoh~ar 19, 1976, are hereOy appzoved subject to 'the fo!lovztng stipulations: 1. The reJerv~, pit shall be ad~uate!y s~ted to prevenh any s..~epage to the surrc~~g terrain and d~ainages. o Winter a~ shall }>e ~o~'~toact~ amff main~ain,e,'.d irt a co.~'~.:!!it.:Lon so 'tJ~at the ~otm~] is suffici~xt!y frozen ;-~u~.d protected by snow and ice 'to prevent any .disturbances, 3. The use of ground con'tact vekicles .~ ~zl-~is cr~eration shall !m~ subj~ ~ te~m~a~ion '~~ 72 hours of no~fica~on ~ny t~[~ after F~cln 15, 1977. If rig re~val a~d cle~ o~a'~op~ c~- ~t ~ ~piet~ ~y' ~~n~qion, r~tifica~i~n of ~n accelo't~!e p!~ for c~ple~on of o~rations sb~ll ~ filer{ wJ_~ ~J'~e D.~~r. 4. The well pad and pit shall be adecfuate!y covared wi-~ gravel~ soi!, arJ then seeded ~ t2ae satisfaction of the Division of I~mds. 5. The I~,~n P~iver bridge and crossing sb~ll be cleaned up and re-- moved to ~he satisfaction of the Division of Lar~/s provided ~that this is rot a deveiopm~t 6. Cor~st~z~on of the.~.~'~.~?~ road s~.-~J" .~." coxa~ence only after tlqe approval of the DistrJ~t Office, Division ..... ~; ,,.?... Lands. tO pZO~{: ~qe v~je-t~tive oove~ .of:. ~e SUsi~ Flats, the a~i~], ~:~ ' sb~ll ~ res~i~ f~ ~u~L~ wJn~ ~ad ~ns~t~on ~r~' ' off r~d ~~~s. ~ '~ " C6[~ ~ ~£orpf/a Sta~tard Oil ~~Tf of ". Il?. ' Page 2 15, ~.,78 8. An ~m..~!e 1Ln~ sb2~li tm us~ on the j~mide snlrface of ~he dik~ .~s ~ ~ any spi!l~ fuel ~,ril~ ]~/~ 9. _~r, %~ ~n~ se~,}~ge ~i'hy s~rzl~-ds of tho Dep~rtment of ~l~vi2~,ent~ Con~akion saal! not h:~ ' I0. ~! o~atL~ ~s sb~it ~ maim~Le~ ~l u~n c~ple~on of op~atio~ !~ ~ a.~ition setisfa~y to the =' ~ t .... a'oo].'kc~nt's sa~2 stock ~e o~' a coast-~! ~ie~ L~Lge~t~ ~ gP~ Ccok Z~e't. T~'~ (3~ such ~asses (1) ~ ..... ~tis sp. (2) ~:cc.~e~a sp. ~:d (3) ~ ~ , . P~3aro D~nton · Chief, t~in~a.!s Section 02-001B .STATE of ALASKA DAli: : "" FROM: Ch i ef ?e'Lre! e:.,.r ~ Eng i n,.:er SUBJECT: ~'r:r',,) r'ilt,':::t, l. nFtC ','.:Ii F']3P, Of ~i: ,. , ,.., .. . revie,,yed. T~',o o~]erator will install ,~. , .;~,~.. l~arrel the ,,roll locatio~ and on ,',~,~ rue st~i~p v '-' , both in diked areas. The eFeratcr shr)i,l]rl ,~pu,-u.:.;:~[~le i~si~]e surface tm *' , be contai~ed. C. F. Kirkvold Area Supervisor Producing Department Standard 0ii Company of California, Western Operations, Inc. ?:. .... ~-:,--. .......... :,....:,.:~% ......... P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9668 --· October 19, 1976 '" Division of Lands Department of Natural Resources State of Alaska 323 East Fourth Avenue Anchorage, Alaska 99501 Attention: Mr. Pedro Denton Gentlemen: State Oil and Ga~ Lease ADL-58790 Plan of Operation for Drilling Stump Lake ProspeCt Ivan River Area, Alaska Standard Oil Company of California plans to conduct drilling operations north of the Ivan River Unit Area. The well is proposed on behalf of itself and cities Service Oil Company. In order to carry out and provide logistical support for the proposed operations, it is necessary for us to obtain your approval of our Plan of Operations. Accordingly, we are enclosing our Plan of Operation for this project.. The items covered by the plan should answer any questions regarding surface operations. If you have need for further clarifi- cation, please detail these, and we will attempt to provide answers. Construction equipment is available in the Beluga River Area, and we plan to commence winter road construction as soo~ as ground and snow conditions permit. Your early consideration and approval of the attached plan is requested. EPW:nh Attachment Very truly yours, C. F. Kirkvold STAT~ o~ ALAS~ Ed Barber - ~ Bruce Barrett - ADF&G K¥1e Cherry - DEC H~yle Hamilton - O&G FROM: -. Pedro Denton su~3~cT: ~ 76-107 c:e~, ~~s section scc~ - sc-ar~ .o~e~o~. ~o~ ~~ ~e~e Ss ~~~. PLAN OF OPERATION STUMP LAKE PROSPECT IVAN RIVER AREA, ALASKA 1. Well Site and Setting The proposed location for the Stump Lake well is approximately 660' south and 660' west of the NE Corner of Section 33, T. 14 N., R. 8 W., SB&M. The si~e is in the grass-covered mud flat area southwest of the southern end of St~mp Lake. Tides greater than 33.0' cover the t location. The highest tide during the drilling operation will be 32,7'. A location approximately 350' long and 170' wide will be constructed of gravel obtained from a source .in Section 27, T. 14 N., R. 9 W. This pad will be built to a height of 5' above ground elevation. This height will provide sufficient freeboard above future high tides in the event the well becOmes a permanent producer. A drilling waste pit approximately 100' x 170' will be constructed adjacent to the drilling pad. 2. Location Access · Access to the location area will be by way of the all-weather road system to the Ivan River Well 44-1 location. A winter road will be constructed from there across the mudflats. (See attached area map). The Ivan River must be crossed, and construction of an ice bridge is considered impractical because of tidal fluctuation and stream velocity with changing tides. Therefore, a.bridge crossing is proposed. Stream bank width is 100', and a five bent, steel pile supported, steel be~mbridge will be constructed. Bolted construction will be used to accommodate easy removal in the event a commercial discovery is not made. The bridge deck will be 8' above the ground surface. This will provide 3' of freeboard at the river bank for the pile caps and include 5' of structural bridge members. A gravel ramp will be required on each side ~of the river to provide access from the ground level winter road to the bridge deck. 3. Existing Roads and Airstrip Ail roads in this area from the Superior Landing to the south to the Ivan River 44-1 well to the north were built in the 1962-65 era by Standard Oil Company of California as operator for the Beluga River Unit as well as during the course of other exploratory activity. The Beluga River Airstrip was constructed during the 1962-63 original field development. It will also be used in support~ drilling operations at Stump Lake. PLAN OF OPERATION STUM~ LAKE PROSPECT IVAN RIVER AREA, ALASKA -2- 4. Water supply ~. ~ ? A new water source well will be drilled at the locati~n ~' E~pS~f~b~r~ drilling operations. 5. Dril%ing Rig. We plan to negotiate with Brinkerhoff Drilling Company for the use of their Rig #58 which is presently drilling Beluga River Well 221-23. We anticipate moving to the Stump Lake location during the first half of January '1977 and move out before breakup road closure. 6. Access to Site and Method of Supply The site is remote and is not connected to the Anchorage area by road. The only access is by one or more of the following: A. BARGING TO THE SUPERIOR LANDING (STATE RESERVED AREA ADL-45327) During most of the year, barging is possible from the Kenai or A~chorage area to the Superior Landing and thence by truck to the proposed wellsite. Use of this landing will definitely be required to drill the proposed well. Most all of the materials and supplies required to drill this well will have to be barged to the Superior Landing. We request continued permission to use the Superior Landingl We estimate operations will continue intermittently to the second quarter of 1977. B. AIR TRANSPORT TO BELUGA AIRSTRIP The Beluga Airstrip can handle Hercules-type airplanes, and we intend using this method to move freight and other items as 'can be justified economically, in addition to barging. Since the rig uses diesel fuel, we will probably barge-or fly in the fuel. Sufficient hard tankage is available to eliminate consideration of "bladder" tanks. Two 1,000 barrel tanks are available for fuel storage on the BRU 244-4 location. An approximately 20,000 gallon fuel dump. will be established at the Beluga Airstrip at the same location as existing facilities installed in 1962. These tanks are installed in a diked area which will contain any fuel spillage or leakage. .7. Pe rs_0nne! Support A camp capable of housing and feeding approximately 40 men is installed in an area adjacent to the cities Service road to their East Lewis River PLAN OF' OPERATION STUMP LAKE PROSPECT IVAN RIVER AREA, ALASKA -3- location~d will be our base of operations. Personnel willbe flown in and out on a scheduled basis of approximately 10 days working and 5 days off. Food and other supplies will be flown in on an "as needed" basis. Sanitation facilities for the camp, consisting of a septic tank and leach pit, have been constructed with the approval of the Anchorage Office of the Department of Environmen~a! Conservation. An approved water well is in use at the existing camp. In addition to the camp, a house trailer has been installed for Standard Oil Company supervisory personnel adjacent to the Beluga Airstrip. 8. Miscellaneous Related Drilling Items The waste pit will be located, constructed, and diked as necessary to prevent the possibility of any seepage to the surrounding terrain or drainages. Upon completion of drilling activities, the waste pit will be filled, leveled, fertilized, and reseeded with natura~ grasses. B~ Ce Sanitary facilities at the rig location will be chemical toilets These toilets will be emptied periodically and the material hauled and dumped into the camp septic tank. The location will be graded so that any fuel or machinery oil leakage will be conducted to the waste pit. De The location will be about 200' west of the nearest lakes and ponds. Our drilling operation should not disturb the area, other than the construction of the drill pad fill. 9. Future Construction , Stump Lake is being drilled as an exploratory Well. If commercial production is discovered, a permanent all-weather road will be required and the Ivan River bridge will remain as a permanent installation. A permanent road route will not follow the winter road.trace indicated on the attached area map. It will be on higher ground northwest of Lewis River slough which is less affected by tidal action. Facilities for handling production will also be required. At such time as the above items are required, proper permit applications will be made. 10. Abandoned Dry Hole Should commercial production not be found, the following surface restoration is planned: A..~.~~ iThe drillsite waste pit will be backfilled before abandoning .the site. Topsoil will be spotted on the location and, if po§sible, it will be spread over the location and waste pit area. PLAN OF OPERATION STUMP LAKE PROSPECT IVAN RIVER IAREA, ALASKA Ce De Topsoil as in item B. will be located on the nor~eas~ ramp~.~t0' ~ :' -' ~ the Ivan River bridge. The bridge will be removed and the piles cut off at the mud line. Ee Topsoil as in Item B. will be located on the southwest ramp to the- Ivan River Bridge. If, because of freezing, it is not possible to spread the topsoil in B., C. and E., above, this will be accomplished in the spring with crews transported by helicopter. Ge Topsoil-covered location area and bridge .ramps will be fertilized and seeded with natural grasses in the spring. 11. General Comments ae Solid wastes such as mud sacks, kitchen waste, etc., will be hauled to the central waste pit near the airstrip and buried. Other hard waste such as drilling bits, etc., will be disposed of in the location waste pit when it is closed and covered after drilling is finished. Bo Testing Any required testing will be accomplished using app'roved industry techniques. No hydrocarbon fluid will be disposed of on the ground surface. Gas flow testing, wiLl be to atmosphere through approved ° flare equipment. Attachment: Beluga River-Ivan River-Stump Lake Area Map. ~HECK LIST FOR NEW WELL PERMITS Company ~)Od~O Yes No Remarks 1. Is the permit fee attached ..................... /~A~ _ Lease & Well No. ~DL/Lf2~vl/~ L~/q~ ~ d~'~/-~s 2. Is well to be located in a defined pool ............. 3. Is a registered survey plat attached ................ 4. Is well located proper distance from property line ....... X./~.~ 5. Is well located pFoper distance from other wells ........ 6. Is sufficient undedicated acreage available in this pool ...... ~.c 7. Is well to be deviated ..................... · 8. Is operator the only affected party ............. A~J~ 9. Can permit be a',~oroved~ before ten-day wait ............. ~aF__ 10. Does operator have a bond in force ............... /Z~o~ Il. Is a conservation order needed ........... ........ -- 12. Is administrative approval needed ................ 13. Is conductor string provided .................... ~/~.f 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and i~ntermediate or production strings 16. Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ........... ~ 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating - Test to~oo~ psig . 20. Has DMEM approved Plan of Operation ............... Additional Requirements' Approval Recommended' Geology: , f Engineering' ':- .! TRM ~ JAL .~}:>' ~,... HHH ~ JCM HWK ~.,~--.~ LCS/~.~'" RAD Revised 11/17/76
