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180-106
STATE OF ALASKA ALA—,.A OIL AND GAS CONSERVATION COM1...0SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned L Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ Li WAG ❑ WDSPL❑ No. of Completions: _1 Service 0 - Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp.,Susp.,or 12. Permit to Drill Number: Hilcorp Alaska,LLC Ctkbatn . 9/9/2014 - - 180-106/314-119 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive.Suite 1400,Anchorage.AK 99503 8/2/1981 50-133-20232-01 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 1879'FSL,498'FEL,Sec.5,T7N,R9W.SM 8/31/1981 Soldotna Creek Unit(SCU)42A-05 Top of Productive Horizon: 8. KB(ft above MSL): 185' 15. Field/Pool(s): GL(ft above MSL): 167' ` Swanson River-Hemlock Oil- Total Depth: 9. Plug Back Depth(MD+TVD): Tyonek Undef Gas-Tyonek Gas 1432'FNL,26 FEL,Sec.5,T7N, R9W,SM Surface Storage 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth (MD+TVD): 16. Property Designation: Surface: x- 341,868 y- 2,457.903 ' Zone- 4 11,180'MD/10,797'TVD FEDA028997 TPI: x- y- Zone- 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 341,940 y- 2.459,839 Zone- 4 N/A N/A 18. Directional Survey: Yes ❑ No El 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071) 22.Re-drill/Lateral Top Window MC/TVD: N/A N/A 23. CASING. LINER AND CEMENTING RECORD WT. PER SEI I ING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 18" Surf 74' Surf 74' Driven 10-3/4" 40.5# K-55 Surf 3.385' Surf 3,384' 15" 1575 sx Class C 7" 23# N-80 Surf 10,410' Surf 10,075' 9-7/8" 29# P-110 9-7/8" 5" 18# N-80 10,191' 10.993' 9,871' 10,600' 6" 75 c.f. 24.Open to production or injection? Yes H No 0 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 10,078' 10.080'(w/cmt pkr @ 7,265') 2-7/8" 10,807' 4,,r`"""' 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. RE C E I V E L. Was hydraulic fracturing used during completion'? Yes❑ No ❑ + — DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED wI..... . OCT 0 6 2014 AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Not Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A Test Period — Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate --► 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑I . Sidewall Cores Acquired? Yes ❑ No E • If Yes to either question,list formations and intervals cored(MD+TVD 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. SCANNED APR 2 4 2015 ABC MS OCT - 7 201 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? ❑ Yes ❑� .No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base Formation at total depth: 31. List of Attachments: Well Operations Summary;Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email: sporholaCc�hilcorp.corn Printed Name: Stan Porhola Title: Operations Engineer Signature: Phone: 907-777-8412 Date: r/d 4 3 4 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 b: 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 ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: 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 30: 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 10/2012 Hilcorp Alaska, LLC EG I tl eD Post Office Box 244027 REG Anchorage,AK 99524-4027 0 cT 0 6 2.0\4 3800 Centerpoint Drive 1 Suite 1400 Anchorage,AK 99503 AOGv'�+,C Phone: 907/777-8412 October 3, 2014 Fax: 907/777-8301 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage,Alaska 99501 Re: Swanson River Field SCU 42A-05 (PTD 180-106) Plug& Abandonment Dear Commissioner: This letter is to inform you of the completion of plug & abandonment operations on well SCU 42A-05 (PTD 180-106). Included are photos of the completed abandonment. Please do not hesitate to contact me should you have any questions or need additional information. Sincerely, HILCORP ALASKA, LLC Stan Porhola Operations Engineer stp 10-407 Form Operations Summary Abandoned Well Schematic Excavated Well Cellar Photo Cut& Cemented Casing Strings Photo Marker Plate Photo Backfilled Well Cellar Photo cc: Chad Helgeson Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 42A-05 50-133-20232-01 180-106 3/12/14 9/9/14 Daily Operations: 03/12/2014-Wednesday Hold JSA. MIRU Moncla 405 WO rig. Lay containment, start winterization. Shift change, hold JSA. Discuss tonight's job tasks. Bleed off well pressure, set BPV. ND prod tree, inspect hanger pins, find threads in hanger- no good. NU BOP and Hydrill. NU Koomey. Function test, shell test has leak on kill line, replace ring. Begin BOPE test, test all valves for 10 mins. 03/13/2014-Thursday Shift change, hold JSA. Repair test pump, continue testing BOPE 250 psi low-,.3,000 psi high. All valves tested for 10 minutes and charted, witnessed by BLM rep Justin Miller. Test Koomey. Load casing with fluid -5 bbls. Pressure up to 1,500 psi and chart for 30 mins-test good. MIRU priority E-Line. RIH with jet cutter and make cut at 4,000' MD. POOH, RD eline, PU Knight tubing spear 3.125" ID with 1-3.25" sub stop, 1 bumper sub, 2 6' extensions, 1 XO, and 1 lift sub. RIH, set spear. Work to set grapple, backout hold down pins, work pipe to 20K over string weight, pipe came free. POOH, LD fishing tools. Remove tubing hanger, install 3-1/2" buttress collar and prepare to circulate 9.5 ppg drilling mud. Circulate 154 bbls 9.5 ppg drilling mud, pulled mud straight from vac truck to keep from diluting mud with returns. Hauled clean returns away. POOH. S/B 108 jts of 3-1/2" tubing, 64 jts of buttress,44 jts of 8rd, 3,395' of pipe in derrick. LD 1 jt 3-1/2" buttress, 17 jts 3-1/2" 8rd, 1 6' sub, 1 gas lift mandrel, and 1 7' cut, 3-1/2" 8rd tubing. Total of 3,998'. Moncla rig down 1.5 hours to replace fuel filters. MIRU Priority E-Line. RIH with CIBP and set at 3,440' WLM. POOH. RD E-Line. Prep to run tubing in hole. 03/14/2014- Friday Hold JSA. Discuss today's tasks and bears coming out of hibernation. Instructed crew under no circumstances to feed animals. RIH with 110 jts 3-1/2" tubing to tag CIBP at 3,440'. Set down 10K on CIBP. Prep to circulate and test. Circulate well bottoms-up, test plug to 2,500 psi for 30 minutes and chart-test ok. MIRU SLB cementers- pump_8 bbl 15_.6 pig class G. cement plug, displace with 5 bbls f/w and 23.8 bbls 9.6 ppg drilling mud, leaving 1 bbl cement in tubing. RD cementers. POOH, LD 7 jts 200' 3-1/2" tubing. Reverse circulate. Tubing clean. POOH. LD 101 jts 3-1/2" tubing. MIRU Pollard slickline. RIH with Cavins plug and set at 150'. RDMO slickline. MIRU Priority E-Line. RIH with casing punch and perforate casing at 145'. RDMO E-Line. RIH, tubing hanger, set lock pins, tie pump line into surface casing valve, pump down 7" casing out, 10- 3/4" surface casing, pump 30 bbls 9.5 mud to break circulation then circulate an additional 5 bbls. MIRU SLB cementers-test lines to 2,000 psi. _Pump 20 bbl 15.6 ppg cement plug down 7" and back to surface in 10-3/4". Good cement returns to surface. Wash clean all cementer equipment and pump lines. RD work floor on rig. Clean pump, flow lines and manifold. Haul away contaminated mud and excess cement. RD rig floor. ND BOP and hydrill. NU tree. RD workover rig and continue to prepare to move. 08/08/2014- Friday Clean cellar. Expedite and set up casing saw. 08/27/2014-Wednesday Excavation and removal of well cellar. Haul off cement and cellar material. 08/28/2014-Thursday Make cut on casing strings. Finish cut across 18" conductor, 10-3/4" surface casing, and 7" production casing. Cement to surface on all strings except 7", void down to 10'. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 42A-05 50-133-20232-01 180-106 3/12/14 9/9/14 Daily Operations: 08/29/2014- Friday Fill 7" casing with 10' of cement to surface. Wait on cement. 08/30/2014-Saturday Cement in 7" hard and set. Weld on abandonment marker plate. Plan to backfill location next week. 09/02/2014-Tuesday Notify AOGCC and BLM of planned backfill of location. Witness waived by Jim Regg at AOGCC and Justin Miller at BLM. 09/04/2014-Thursday Backfill location. Short 20 yards. Will complete backfill in next few days. 09/09/2014-Tuesday Complete backfill of location. GPS coordinate 60°43' 27" N, 150° 53' 9" W (NAD 83). Finalized plug and abandonment. • • II Soldotna Creek Unit FINAL ABANDONMENT Well: SCU42A-05 Final Abandonment PTD: 180-106 Hilcorit Alaska,LLC API: 50-133-20232-01 RKB =18.5' r,a„ ;-;_ � Casing & Tubing 2 ze Type Wt Grade ID Top Btm Hole Cmt Cmt Top ti" 18" Conduct Surf 74' Yes Surf. 9.5 ppg 10-%" Surf Csg 40.5 K-55 10.05" Surf 3,386' 15" 1875 sx Surf ' f�. �� �� '�'� 7" 29 6.184" Surf 73' Prod 3 N-80 2100' 4. 9.5 ppg 7„ Csg 23 6.366" 73 3613' 460 sx CBL 4 — DV Collar 3613 3616 97/s" — r _ Tbg Punches 7" 23 6.366" 3616 4361' t e73!5' 7' Prod Csg 29 N-80 6.184" 4361' 8053' 1200 sx 8120' •6000• CBL 7" 29 P-110 6.184" 8053' 10,410' II-Tbg Punches 7"Window.Cut on 9/81 10,410' 10,457' @ 6993'-6999' 5" Liner 18 N-80 4.276" 10,191' 10,994' 6" 75 sx 10_5d0 ;1 1, [ "' " ,366• Tubing 3-1/2" 9.2 N-80 2.992 Surface 993' _ 3-1/2" 9.3 J-55 2.992 993' 10,078' 71.6 bbls 7265 - - =77-3 s" 2 7/8" 6.5 N-80 2.441 10,078' 10,807' Nb°;°J 6000' Jewelry ,.... ) * Item Top ID OD Description 18.5' Tubing Hanger, 7 X 3 1/2 Shaffer with a 3"type H BPV c - I 5750 Cmt Retainer w/Poppet Valve ' II 6993'- Tbg punch holes(23 shots,.21"diameter holes) = 6999' / Clot Ret 1 140' - _ - CasingPunch holes(5'of holes) i/ .4 6:4 ° 9,990' / = rt 2 150' - 5.687" Cavins Bridge Plug(cement to surface;20 bbl @ 15.6 i/ I ppg) 6 - 3 3,440' - 5.687" Bridge Plug(capped w/200'of cement;8 bbl @ 15.6 ppg) / til .s BP!o}10,065' 4 3,500' 2.992" 3.500" Tubing Cut _I 7 5807' 2.313 Owens Tbg Patch @ 5807'to 5818' 8 5969' 2.313 Owens Tbg Patch @ 5969'to 5980' - 6000' 2.313 Owens Tbg Patch @ 6000'to 6011' 9,990' -- FasDrill Retainer 5 10,004 GLM,Camco,MM62,3-1/2"x 1-1/2" 6 10,044' 2.813 Profile Nipple,"X",2.813" 10,065' -- FasDrill BP 7 10,078 BOT LSA w/10'of seals 8 10,080' 3.25 Packer,7""DB"w/10'SBE,3.25"ID 9 10,774' 2.205 Nipple,`XN',2.205 I.D. 1=19 PERFORATION HISTORY Interval Accum. Zone Top Btm Amt spf Comments 77-3 7,977' 7,987' 10' 6 Isolated Sqz 8,014' 8,015' 1' 4 Apr-72 Sqz 10,420' 10,421' 1' 4 Oct-81 H1 10,875' 10,902' 27' 8 isolated H2 10,917' 10,926' 9' 8 isolated H3 10,958' 10,968' 10' 4 isolated H4 10,978' 10,992' 14' 4 isolated i I I TD= 11,108' PBTD=10,993' Max Deviation=29° SCU 42A-05 Final Abandonment 9-09-14 Updated by STP 9/10/14 , , w - • I.y • ' , . 4 't , . .s. .• .4_40^.^:',, ..- .‘• . :.„.• .. • . . , . . . . „ .., . . . .), . . ...• ‘c' •Is , . • • . • - , ' , , 11 , . ' • •27'4'. , '' 4, . • ' 1 5 4 •il ' 4 j. . • ' . ' -4,‘,'' '• • •.ti i) • • , 401 ' '' • , ' 1- ' L. '. ' * .. r% ,4*$ 11,4i 1,1 ii.• ''' 4,1 I • -.,,,, $ , . ,, k .• 51, •it ,1••4114:. • ..'' " • .7 1. % ''. Is• ' , I 'I 1 , ' 'R`li ' ' . ' 's ; - .''- • ' '' • ,: oper' 6 • ' I i : - 4' '' .' * 4 g'kt , 2''' •• , • 1 ) '1 '. . ...., • F--. . . ' . .",./ i ' .:' . •, ' -C ZI. ' 4, ' ',is '.• . / .r. ','' ' ' -, , wz:. . . , ..r.r ., •r•-, ...- \ „ „. O • 06 - , . 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YAii" 14 ts, ti qty ,... iE a t f as r '", ,.,711, .4,,. 0 • ' ' i 'l q. • •. .. • • • . • • • ilLad ill • . . • • • • • - • . • - • •, _ • I J ItIII • • I I lake Imag ect Well History File Cover e X HVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. /' ~(~ ~- / Q ~ Well History File Identifier Organizing ~o,,~) RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: BY: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BEVERLY ROBIN VINCENT ~) MARIA WINDY [] [] OVERSIZED (Scannable) [] Maps: ,~ Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds Other /si ~ Project Proofing BY.. ~'~ ROBIN VINCENT SHERYL MARIA WINDY Scanning Preparation ~L x 30 = '/~-~? ROBIN VINCENT SHERYL MARIA WINDY BY: Production Scanning Stage l BY: Stage 2 BY; (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS ~)UE TO QUALITY, GRAY$CALE OR COLOR IMAGES) PAGE COUNT FROM SCANNED FILE: -/Y7 / PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO ReScanned ~individual page [special at~el~tic~nJ .~cat~ning ctJmpte~ed) RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; Isl General Notes or Comments about this file: Quality Checked (do.e) 12110/02Rev3NOTScanned.wpd Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 07, 2011 2:04 PM To: McMains, Stephen E (DOA) \ P k � Cc: Davies, Stephen F (DOA) cc) Subject: 77 -3 Gas Storage at Swanson River -Pool Code 772805 Steve, Further to the work begun earlier regarding the appropriate pool classification of Tyonek gas associated with the 64 -5 and 77 -3 storage projects, the 64 -5 [772803] and 77 -3 [772805] are distinct Tyonek sand intervals so the volume accounting needs to be separate. The matter is a little further complicated since there also is an undefined Tyonek pool code at Swanson [772500]. So far as I am aware, the only wells remaining to be reconciled are 42A -05 (180 -106) and 42B -05 (182 -199). Both wells were originally Hemlock oil producers and the Hemlock was plugged with the wells being completed in the 77 -3 sand. 42B -05 was converted to GSTOR 11/7/05. First storage injection is reported in 12/05. First gas production is reported 11/05. All gas volumes are reported to the 64 -5 pool, this should be changed to the 77 -3. _I 42A -05 is a little more complicated. There is no record of any gas having been injected for storage. The Hemlock was plugged and the well perforated in the 77 -3 in June 2004. It appears that all gas produced from then until the well was converted to GSTOR on 10/1/05 was credited to the undefined Tyonek Pool code [772500]. Fairly regular /continuous production is reported up through 11/05 (14 days). No production is reported in 12/05 and only 7 days in 01/06. Again, all Tyonek gas from this well should be against the 77 -3 pool code [772805]. Please let me know if further information is needed. It is probably appropriate to put a copy of this message in each well file. Tom Maunder, PE n �.` Sr. Petroleum Engineer VCS V C d �� d C- C\ t\ C,S s . \ S 0 -4-19 ts 'p \IN rA 3/7/2011 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Page 1 of 2 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] t Sent: Monday, January 10, 2011 2:26 PM v 1 To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: FW: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Almost correct Tom. X & Y are the active wells in the 77 -3 gas storage sand and 42A -05 & 42B -05 were completed in the same sand, but have since both been suspended. Both A & B are being as monitoring wells in case the gas gets out of the 77 -3, but neither has open perfs in that sand today. It is true that there are a number of other wells we are using to monitor the storage reservoir that penetrate, but were never completed in the 77 -3 sand. do believe the split of the gas storage pool code for the 64 -5 & 77 -3 sands will be forthcoming from production accounting. They truly are separate accumulations, but both Tyonek sands. Let me know if you need more info. i Larry *416 Ytrok From: aunder, Thomas E (DOA) [mailto:tom.maunder laska.gov] Sent: Monday, January 10, 2011 1:55 PM To: Greenstein, Larry P; Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: RE: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Larry, et al, have been working with McMains sorting out the Swanson River storage gas. The two Swanson storage projects employ Tyonek reservoirs (64 -5 and 77 -3), but they are separate accumulations. From a reporting sense, all the volumes had been being reported under one pool code. I think that has been changed or is in the process of being changed. The question I have regards 77 -3 storage. As I understand, 42 -05X and 42 -05Y are the active injection /production wells. 42 -B -05 and 42A -05 are completed in the 77 -3 sand, but are not being actively employed. There are a number of wells that penetrate the sand enroute to the Hemlock, but none are completed in the 77 -3 sand. Do l have that correct? Thanks in advance, Tom Maunder, PE AOGCC From: Greenstein, Larry P [mailto :Greensteinlp @chevron.com] Sent: Monday, January 10, 2011 9:29 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Jim & Tom, Here is December's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Storage reservoir. 3/11/2011 2010 December's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Page 2 of 2 Both X & Y are in heavy usage now that the winter is in full swing, but the warmth at the end of December did allow a little injection to occur. While performing the MIT on 5X last month the operators noted that leaving the annulus with 0 pressure readings didn't offer much to monitor. They put a few hundred psi on both the 5X & 5Y well 7" annulus to better monitor pressure changes. Both annuli are now showing some ups and downs related to temperature swings based on injection vs production at different rates. Neither annulus appears to be tracking or communicating with the tubing pressures, they are just much more responsive now that there is some pressure on them to observe. The pressure responses from both wells were within expectations with no indications of any loss of integrity. Bottom line, the pressures for all the monitored wells remain within their expected ranges. Larry «Master Well List TIO Report 2011 01 01.xis» Vz- 44kkg. tx■ot:kk,.* 3/11/2011 • oF77,7 I%%,tss,, THE, S'K'ATE ; •,-,Tid. f, _ . _. mai J v./s _� 333 Wev 1 Sevenih Avenue fP C OVHZ.NOR SEAAi PARNELL Anchorage, Alaska 99501-3572m 9501 3572 Main: 907.27° 433 O . L.AS 5' -cy: 907.276.75/,2 SCANNED MAY° 2 02014 Stan Porhola Operations Engineer O Hilcorp Alaska, LLC U 1 3800 Centerpoint Drive, Suite 1400 V Anchorage, AK 99503 Re: Swanson River/Hemlock Oil-Tyonek Undefined Gas-Tyonek Gas Storage Pool, Soldotna Creek Unit(SCU) 42A-05 Sundry Number: 314-119 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ":726) Vec-- Cathy P. 'oerster Chair DATED this 5 day of March, 2014. Encl. • I RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FB 2 8 2014 APPLICATION FOR SUNDRY APPROVALS s a( 6kci- 20 AAC 25.280 APge9provYrogram 1.Type of Request: Abandon Q • Plug for Redril ❑ Perforate New Pod ElRepair Well❑ ❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing Time Extension❑ Operations Shutdowl❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development ❑ 180-106• 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic 111 Service 2 - • 6.API Number. Anchorage,Alaska 99503 50-133-20232-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)42A-05 • Will planned perforations require a spacing exception? Yes ❑ ❑No 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997 Swanson River/Hembck Oil-Tyonek Undef Gas-Tyonek Gas Storage Pod 11. PRESENT WELL CONDITION SUMMARY Total Dept/D(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 8--• /'"' .f l 7,265 7,177 5,750 N/A Casing ;;•? 1-Length /ham Size MD 1VD Burst Collapse Structural Conductor 74' 18" 74' 74' Surface 3,386' 10-3/4" 3,386' 3,385 3,130 psi 1,580 psi Intermediate 10,457' 7" 10,457' 10,119' 6,340 psi 3,830 psi Production 803' 5" 10,994' 10,601' 10,140 psi 10,490 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2"x 2-7/8" N-80/J-55;N-80 993110,078';10,807' Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): 7"DB Baker Packer;N/A 10,080'MD/9,76T ND;N/A 12.Attachments: Description Summary of Proposal 0 X13.Well Class after prop.sed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic El Development n Service n • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑✓ • Commission Representative: GSTOR ❑ SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sDorhola( hiIcorD.corrl Printed Name Stan P0 ola Title Operations Engineer Signature _.x. / / Mk Phone 907-777-8412 Date 2-72-g;/(/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number q Plug Integrity V BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: i, Pi2.6f e u .0 C c...4.In c C a s j, L 44+-d AP i (.....).e. ` , / RE3Dm§tem u 9 2014 Spacing Exception Required? Yes ❑ No © Subsequent Form Required: /o—Li O 7 ' i i l/ APPROVED BY Approved by: �j 1� ," ^ /�COMMISSIONER THE COMMISSION Date: 3 -s---/t '1.11 �.f 1- Submit Form and For O 403(Revised 10/2012) Ap E�I� I�`r77NailieL12 months from the date of approval. Attachments in Duplicate " Well Prognosis Well: SCU 42A-05 Hilcorp Alaska,LLC Date:2/28/2014 Well Name: SCU 42A-05 API Number: 50-133-20232-01 Current Status: Suspended Well Leg: N/A Estimated Start Date: March 12th, 2014 Rig: Moncla 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 180-106 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405(0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: Reservoir isolated with cement plug Max. Allowable Surface Pressure: 50 psi (casing pressure); 40 psi (tubing pressure) Brief Well Summary This well was drilled and completed as an oil well in Hemlock H-1 thru H-5 in 1972 as SCU 42-05.This well was sidetracked in 1981 and completed in the Hemlock as SCU 42A-05.This well was plugged back in 2004 to recomplete in the Tyonek 77-3 sand.This zone was productive for gas.This well was converted to gas storage in the Tyonek 77-3 sand in October 2005. Pressure on the annulus and in offset well completed in the Tyonek 77-3 sand at SCU 42B-05 led to plugging back the 77-3 sand in this well in August 2006.The Tyonek 77-3 has been used as a gas storage zone since 2006 by well SCU 42-05X and 2007 by well SCU 42-05Y.SCU 42A-05 has remained in a suspended status to evaluate the plugback and isolation of gas stored in the Tyonek 77-3. The purpose of this work/sundry is to plug and abandon the well. Notes Regarding Wellbore Condition • Last tag at 5,456' RKB on 8/08/2006 w/a 2.25" GR. • Annulus and tubing freeze protected with 200 gallons of diesel. Eline Procedure: 1. MIRU Eline, PT lubricator to 3,000 psi Hi 250 Low. 2. RU 3.50"jet cutter, RIH and cut tubing at 4,000'. a. Have backup cutters on location if tubing does not part. 3. RD Eline. WO Rig Procedure: 4. MIRU Moncla#405 WO Rig. 5. NU BOPE.Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/1,500 psi High (hold each valve and test for 10-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance to witness. b. Notify BLM 48 hrs in advance of BOP test. c. BPV in hanger profile. T FIT /SOD PS 6. Bleed any pressure off casing. Pull BPV. C11-4.(1/1° 7. MU 3.5" landing joint, back out lockdown pins and pull tubing hanger free. 8. Displace well over to 9.5 ppg drilling mud. 9. SOOH and rack back 3-1/2"tubing. 10. MU 7" 23#CIBP and RIH on 3-1/2"tubing out of derrick. y Well Prognosis Well: SCU 42A-05 Hilcorp Alaska,LLC Date:2/28/2014 11. RIH and set CIBP at+/-3,440' MD in the 7" 23#casing. 12. Tag bridge plug w/10k down. PU 5'above CIBP.Circulate well w/9.5 ppg drilling mud. 13. Test casing to 2,500 psi for 30 min and chart./30 14. RU cementers. Mix and pump 8 bbl of 15.6 ppg Class G cement. 15. PU 200'. Reverse circulate clean. 16. POOH and lay down 3-1/2'tubing. 17. RU slickline. 18. MU 7" 23# Bridge Plug and RIH and set at+/-150' MD. 19. POOH. RD slickline. 20. RU E-line. 21. RIH w/6'casing punch.Tag bridge plug. PU 5'above Bridge Plug. 22. Punch casing from+/- 139'- 145' MD. 1 23. POOH. RD E-line. 24. Install tubing hanger. 25. Circulate 9.5 ppg drilling mud down 7"casing and up the 7"x10-3/4"annulus. 26. RU cementers. Mix and pump 20 bbl of 15.8 ppg Type I cement.Circulate cement to surface. 27. Clean and clear rig floor. Flush all surface lines and clean pits. 28. ND BOPE. NU dry hole tree. 29. RD Moncla#405 WO Rig. -fa l Post-Rig Abandonment Procedure: r-- it1 eTl / G -- -'p S Gc.r--^ 30. Excavate cellar,cut off casing 3' below natural GL. — U e"r4- 31. Set marker plate,collect GPS coordinates. ?hob, dou- C. L.,32. Backfill cellar, close out location. Attachments: ..Th 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic Soldotna Creek Unit ACTUAL SCHEMATIC Well: SCU 42A-05 Completion Ran:4/26/89 PTD: 180-106 Hilcorlt Alaska,LLC API: 50-133-20232-01 RKB =18.5' Casing & Tubing, Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 5 4:,. 18" Conduct Surf 74' Yes Surf. 1 1 V 10-%" Surf Cs' 40.5 K-55 10.05" Surf 3,386' 15" 1875 sx Surf 1(�A 7" Prod 29 6.184" Surf 73' la 2100' 7„ Csg 23 N-80 6.366" 73 3613' 460 sx CBL i ` DV Collar 3613 3616 9%" t 7" 23 6.366" 3616 4361' 1• Tbg Punches N-80 *5615', 812 ' °" 5973' 7 Prod Csg 29 6.184" 4361' 8053' 1200 sx CBL 7" 29 P-110 6.184" 8053' 10,410' 99 vdt II-Tbg Punches 7'+Window.Cut on 9/81 10410' 10457' v Pi s! g 6991'-6999' vF 5" Liner 18 N-80 4.276" 10,191' 10,994' 6" 75 sx 10,5540' rs PF: ' . , TOC Q 7265' Tubing _ 3-1/2" 9.2 N-80 2.992 Surface 993' ® k Top B 7971' I A 3-1/2" 9.3 J-55 2.992 993' 10,078'7._ ' -:- _77-3 seed 2 7/8" 6.5 N-80 2.441 10,078' 10,807' i ee N Jewelry ,1 Item Top ID OD Description _ 18.5' Tubing Hanger, 7 X 3 1/2 Shaffer with a 3"type H BPV • Cmt a°1 I 5750 Cmt Retainer /Poppet Valve �. I N 9,990'• w H 'I!� II 6993'- Tbg punch holes(23 shots,.21"diameter holes) 2 6999' 1 2,104' GLM,Camco,KBUG,3-1/2"x 1"(No valve in pocket) - -arra 10,065' _ 5807' 2.313 Owens Tbg Patch @SHOT to 5818' I l 5969' 2.313 Owens Tbg Patch @ 5969'to 5980' 5 6000' 2.313 Owens Tbg Patch @ 6000'to 6011' 9,990' FasDrill Retainer 2 10,004 GLM,Camco,MM62,3-1/2"x 1-1/2" 3 10,044' 2.813 Profile Nipple,"X",2.813" 10,065' -- FasDrill BP 4 10,078 BOT LSA w/10'of seals 5 10,080' 3.25 Packer,7""DB"w/10'SBE,3.25"ID -► 6 10,774' 2.205 Nipple,`XN',2.205 I.D. 10.420 IA- 6 PERFORATION HISTORY Interval Accum. Zone Top Btm Amt spf Comments 77-3 7,977' 7,987' 10' 6 'Isolated Sqz 8,014' 8,015' 1' 4 Apr-72 Sqz 10,420' 10,421' . 1' 4 Oct-81 Hl 10,875' 10,902' . 27' 8 isolated H2 10,917' 10,926' ., 9' 8 isolated • H3 10,958' 10,968' 10' 4 isolated H4 10,978' 10,992' , 14' 4 isolated Last tag: 5,456' RKB 8/08/06 w/2.25"GR Pulled valve out of GLM @ 2,104' RKB. I TD= 11,108' PBTD= 10,993' Max Deviation=29° SCU 42A-05 Actual Schematic 8-08-06 Updated by STP 2/24/14 Soldotna Creek Unit PROPOSED SCHEMATIC Well: SCU 42A-05 Proposed Abandonment PTD: 180-106 Hilcorp Alaska,LLC API: 50-133-20232-01 RKB =18.5' Y■ "` 1 , 74' Casing & Tubing r 2 Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 18" Conduct Surf 74' Yes Surf. �+ 10'/a" Surf Csg 40.5 K-55 10.05" Surf 3,386' 15" 1875 sx Surf 71 . - s s t 7" Prod 29 6.184" Surf 73' 9.5 ppg 3 7„ Csg 23 N-80 6.366" 73 3613' 460 5'x 2100' ;"I L ' 4 DV Collar 3613 3616 9'/8" I 7" 23 6.366" 3616 4361' L'' Tin Punches N-80-r a;;"' 7" Prod Csg 29 6.184" 4361' 8053' 1200 sx 8120, St 6005' 7" 29 P-110 6.184" 8053' 10,410' X •; • 11-Tbg p.a.. 7"Window.Cut on 9/81 10,410' 10,457' 6993'-6999' 0..AV- 5" Liner 18 N-80 4.276" 10,191' 10,994' 6" 75 sx 10,540' CBL TOC @ 7265' Tubing ® i$ . ToP,,:,971, _3-1/2" 9.2 N-80 2.992 Surface 993' g I z 3-1/2" 9.3 J-55 2.992 993' 10,078' 71.6 bbls 7265' i p p - =77-3 Sand 2 7/8" 6.5 N-80 2.441 10,078' 10,807' - '• Btm Cal 9000' - Jewelry Item Top ID OD Description 18.5' Tubing Hanger, 7 X 3 1/2 Shaffer with a 3"type H BPV O. . ¢ +I1 5750 Cmt Retainer w/Poppet Valve F II 6993'- Tbg punch holes(23 shots,.21"diameter holes) - 6999' • Cmt Ret 1140' - - Casin Punch holes 5') '*9,990' - g 2 150' - 5.687" Bridge Plug(cement to surface) 5 3 3,440' - 5.687" Bridge Plug(capped w/100'of cement) h BP@ 10,065' 4 3,500' 2.992" 3.500" Tubing Cut 5807' 2.313 Owens Tbg Patch @ 5807'to 5818' I * --- *LIM 7 5969' 2.313 Owens Tbg Patch @ 5969'to 5980' :�j 8 6000' 2.313 Owens Tbg Patch @ 6000'to 6011' 9,990' -- FasDrill Retainer 1: I 10,004 GLM,Camco,MM62,3-1/2"x 1-1/2" 6 _ 10,044' 2.813 Profile Nipple,"X",2.813" 10,065' — FasDrill BP 7 10,078 BOT LSA w/10'of seals 8 10,080' 3.25 Packer,7""DB"w/10'SBE,3.25"ID 9 10,774' 2.205 Nipple,`XN',2.205 I.D. Sqz holes.. @ 10,420 9 PERFORATION HISTORY Interval Accum. Zone Top Btm Amt spf Comments s77-3 7,977' 7,987' 10' 6 Isolated Sqz 8,014' 8,015' 1' 4 Apr-72 Sqz 10,420' 10,421' 1' 4 Oct-81 5 HI 10,875' 10,902' 27' 8 isolated H2 10,917' 10,926' 9' 8 isolated H3 10,958' 10,968' 10' 4 isolated H4 10,978' 10,992' 14' 4 isolated I II Last tag: 5,456' RKB 8/08/06 w/2.25"GR Pulled valve out of GLM @ 2,104' RKB. I TD= 11,108' PBTD= 10,993' Max Deviation=29° SCU 42A-05 Proposed Schematic 2-28-14 Updated by STP 2/28/14 . H Swanson River 2014 Moncla Rig 405 iii��.p 1u..t..IAA. Knight Oil Tools BOP r 1 O (tt an in fittt 2.57' Shaffer 71/16 ill_ST fillitt 1U 1LIJIUJ LIT 0 / — -\ \ 2 3/8-31/ variable 1I CAMERON V .11 3.68' H H N tiI :, Its 7 41 I illi Blind 7 1/16 5000 I \ H H M t iiilll.ilol 1i lil 2 1/16 10M Kill Valves \ 2 1/16 10M Choke Valves Manual and HCR Manual and HCR _ rori. I sir iii ill i I i 474111I — ev6,•_i �� 1.56' `�,,'JI �� 71/16 5000• s'.iii.tii.ii. SI '- \ �/ Pr6 1601000 "Regg, James B (DOA) From: Larry Greenstein [Ireenstein @hilcorp.com] Sent: Monday, May 07, 2012 11:23 AM k �' ((7/ To: Regg, James B (DOA) 1� Cc: Christopher Walgenbach Subject: RE: SRF MIT's for SCU 42A -05 and SCU 42B -05 Hi Jim, Chris sent me your e -mail requesting some info on the MIT for these two wells. You and I talked about these wells on ,- Friday, as special cases for MITs not related to any UIC issues. The BLM wanted these wells classified as 'Monitoring Wells' (MW) for the containment of the 77 -3 gas storage. The don't have a status called 'Suspended', as the state does, and wanted a status more befitting to their actual usage in the field. One of the requirements they put on this MW status is the need for a MIT every two years with the initial one this spring. This is the only reason we are performing MITs on these wells and we will continue to report them with the monthly 77 -3 gas storage monitoring plots we send to you. If BLM wants to send an inspector, they can. As per our routine, we notify both agencies about any MIT efforts at SRF. Larry From: Christopher Walgenbach Sent: Friday, May 04, 2012 4:14 PM To: Larry Greenstein Subject: FW: MITs Here you go Larry. Hilcorp Alaska LLC Production Foreman kANNEDJUN g 2t11 Swanson River Happy Valley Westside Baker Dillon Red Pad Office 907 -283 -2541 Cell 907 -690 -1727 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, May 04, 2012 3:38 PM To: Christopher Walgenbach Subject: RE: MIT's SCU 42A -05; PTD 1801060; suspended 8/9/2006 SCU 42B -05; PTD 1821990; suspended 6/21/2006 AOGCC records show both wells are suspended; last activity was producing; neither well has ever injected. What is purpose of MITs? 1 • • Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: Christopher Walgenbach [ mailto:cwalgenbach @hilcorp.com] Sent: Friday, May 04, 2012 2:17 PM To: tzelenka @blm.gov; Regg, James B (DOA) Cc: Bruce Hershberger; Dale Ashe; Kevin Cassidy; Larry Greenstein Subject: MIT's Tom /Jim, We are ready to do the BLM required MIT's on both 42A -05 & 42B -05 wells at your convenience. Thanks, e zed Veteledad Hilcorp Alaska LLC Production Foreman Swanson River Happy Valley Westside Baker Dillon Red Pad Office 907 -283 -2541 Cell 907 - 690 -1727 2 c From: Greenstein, Larry P [mailto:Greensteinlp @chevron.com] Sent: Friday, March 11, 2011 11:06 AM b0 iQ To: Maunder, Thomas E (DOA) Subject: RE: 2011 February's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report You bet Tom. Because the operators don't always get their readings at the same time each day, we could be hitting different wellhead temperature conditions. Just doesn't look so normal to me either. Glad the pressures are all low and not trending up and up indicating something potentially bad is going on. Thanks 6\ wati otp OR, Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, March 11, 2011 8:02 AM To: Greenstein, Larry P Subject: RE: 2011 February's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Larry, Thanks for looking into this; it is unusual and you are correct that all the sunshine might have something to do with the changes. That at least might explain the cycles, although that is curious with only 1 reading a day. Tom From: Greenstein, Larry P [mailto:Greensteinlp @chevron.com] Sent: Thursday, March 10, 2011 3:56 PM To: Maunder, Thomas E (DOA) Subject: RE: 2011 February's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report You're right Tom. This `activity' does look out of character for this well. This is the time of year we sometimes see this on certain wells. The ambient temperature changes from night to day especially with the bright sun heating up parts of the tree during the day can swing the temps in tight wells. The operators have checked all the gauges and needle valves and all looks good. The pressures aren't scary at all, but the fact that they're moving around is unusual. We didn't see this last year on this well, but I don't remember 3 straight weeks of gorgeous sunshine with warm days and zero degree nights. Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, March 07, 2011 4:39 PM To: Greenstein, Larry P; Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: RE: 2011 February's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report • Larry, et al, What is the "chatter" in the recent pressure information for 42A -05? There have been changes through time, but I don't remember chatter like this. Thanks in advance. Tom Maunder, PE AOGCC From: Greenstein, Larry P [mailto:Greensteinlp @chevron.com] Sent: Monday, March 07, 2011 9:26 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Ayer, Phil M; Walsh, Chantal [Petrotechnical Resources of Alaska (PRA)] Subject: 2011 February's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Jim & Tom, Here is Februarys monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Storage reservoir. Both X & Y continue to be in demand during our cold weather. The wells are responding as needed with the rates and pressures meeting expectations. Most of the wells appear stable lately. Except for 32 -4 where we are still trying hard to keep the well flowing smoothly and 12A -4 where there were some surface freezing problems that had the pressures trapped for a while. Other than those wells unrelated issues, the monitoring wells show no indications of a loss of storage gas containment. Larry «Master Well List TIO Report 2011 03 01.xIs» ) Plot Pare & Rate vs Time - Well SCU 42A -0� 200 - 180 ••••••19 5/8" 160 Tubing —. — -- -- -- 140 120 m 3 u, 100 ai a` 80 60 40 20 rAilf ‘I ‘rlii 1 1 \ 0 . ,� n O O O O O M N N co N N N CO m O N N O O ,- ,- ,- O O Date .r "g TIO Report 02/28/11 ra 60 02/27/11 40 0 40 Data Sheet 02/26/11 40 0 17 02/25/11 40 0 30 02/24/11 ", 45 0 35 SCU 42A -05 02/23/11 45 0 40 02/22/11 '100 0 40 02/21/11 100 0 50 GAS LIFT 02/20/11 - 100 0 105 02/19/11 0 0 50 02/18/11 ' 42 0 70 Permit # 1801060 02/17/11 0 0 38 02/16/11 0 0 40 02/15/11 < 0 0 20 API # 50- 133 - 20232 -01 02/14/11 40 0 20 02/13/11 40 0 20 02/12/11 40 0 20 08/30/2010 to 03/01/2011 02/11/11 40 0 20 02/10/11 40 0 20 02/09/11 40 0 20 02/08/11 40 0 20 02/07/11 40 0 15 02/06/11 40 0 15 02/05/11 40 0 15 02/04/11 40 0 15 02/03/11 s 40 0 31 02/02/11 40 0 16 02/01/11 - , , 40 0 16 01/31/11 ` 40 0 18 01/30/11 40 0 18 01/29/11 40 0 18 01/28/11 - , 40 0 18 01/27/11 , 40 0 15 01/26/11 40 0 15 01/25/11 40 0 20 01/24/11 r 40 0 20 3/11/2011 8:12 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 03 01 (6).xls SCU 42A -05 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report l Date Inspected: 09/27/10 Inspector: Bob Noble Operator: Union Oil 1 Well Name: SCU 42A-05 Oper.Rep: Lee Elliott • I PTD No.: 1801060 Oper.Phone: 907-398-9992 Location Verified? Yes Oper.Email: If Verified,How? Other(specify in comments) SCANNED AUG 1 4 2015 Onshore/Offshore: Onshore Suspension Date: 08/09/06 Date AOGCC Notified: 09/22/10 I Sundry No.: 305-389 Type of Inspection: Initial - Wellbore Diagram Avail.? Yes - Well Pressures(psi): Tubing 0 Photos Taken? Yes - IA 0 OA 0 Condition of Wellhead: The location was verified with the use of a plot plan and a well sign.The wellhead was found to be in good condition with working gauges. There was a guard rail to protect the wellhead.The cellar was dry and free of any oil. Condition of Surrounding Surface The location was found to be in good condition without any signs of old oil. Location: I Follow Up Actions None Needed: Attachments: Photos(2) - REVIEWED BY: 1 Insp.Supry 3Cr-- Comm PLB 09/2010 2010-0927_Suspend_SCU_42A-05_bn.xlsx Suspended Well Inspection—SCU 42A-05 PTD 1801060 Photos by AOGCC Inspector B. Noble 9/27/2010 • L • �} 'SOLDOTNA CREEK UNIT WELL NO SCU 42A-5 r . 1.1 �,f ; •- Chevrn: f 'S . z,, Y 0.4$4 te.,...,,..$'0i;j4.:'-...:'''tre.0}. !AZ- ;,... ... .1„..,.....r:',,;,t,4,z,, . .,. . ; cis:' I 'y $ 's. ) c-Jt; ;F'. o s.#.` k ;ry.i " � °' .. ., i' t :� ; Y `I t. r; - a ! 1-' A ill'Ailiaiika 4Q-- _,. [/'ff r ' ' - ---......m.••, ' 'F! YY.,.. . , •r ' V.;;;;?-11;'4,4Y.:':. ' • ;'44 � f " A `M J i x` • .-` F y .'Pt:, .f p ••— \\ �` , „„\\\ , \mow.„ 2010-0927_Suspend_SCU_42A-05 photos.docx Page 1 of 1 2009 November's SRF Tyonek 7~ Sand Storage Well Monitoring Repo Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, December 04, 2009 12:02 PM To: 'Greenstein, Larry P' Subject: RE: 2009 November's SRF Tyonek 77-3 Sand Storage Well Monitoring Report Thanks Larry. I checked our files and database. Both wells are listed as suspended. I am going to be working more with injection now so I wanted to get up to speed. Tom From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Thursday, December 03, 2009 4:45 PM To: Maunder, Thomas E (DOA) Subject: RE: 2009 November's SRF Tyonek 77-3 Sand Storage Well Monitoring Report You're right, Tom. The X & Y wells are the actual gas storage wells we use for both injection and production from the 77-3 sand. Of all the other re orted wells, only 42 -5 and 42 5 were completed in the 77-3 sand, the rest just penetrate the 77- 3 sand. `{~,. ~p t,® ~ ,~Sa--1S~ Both 42A-5 and 42B-5 have had the 77-3 sand perfs cemented off and are just basically holes in the ground now. Their classification probably should be suspended, if I understand how you use that term for wells. We still monitor these holes in the ground in case some kind of pressure starts showing up. I've attached the schematics for both wells for you to look at. Hope this helps. Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, December 03, 2009 4:08 PM To: Greenstein, Larry P Subject: RE: 2009 November's SRF Tyonek 77-3 Sand Storage Well Monitoring Report Hey Larry, Just thinking about this project; for the 77-3 reservoir storage project, I know 42-05Y and 42-05X are used for storage and deliverability (production from storage). Are any of the other wells completed in the interval? I think 42-B5 was, but not now?? Thanks in advance. Tom From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Thursday, December 03, 2009 3:58 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Ayer, Phil M; Winslow, Paul M Subject: 2009 November's SRF Tyonek 77-3 Sand Storage Well Monitoring Report Hi Jim & Tom, 12/4/2009 2009 November's SRF Tyonek 7~ Sand Storage Well Monitoring Repo Page 2 of 2 Here is November's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77-3 Sand Storage reservoir. The first of this winter's storage production occurred in November and the pressures responded as anticipated. No anomalies noted. Since the 13 3/8" pressure had stabilized in 426-5, the field did a 100# bleed off to see if the casing would repressure or not. A small response was seen and we will continue to watch this pressure. The wells appear to have pressures for the month that don't show any indications of a response due to the gas storage operations. Bottom line, the pressures remain in expected ranges for all the wells being monitored. Larry «Master Well List TIO Report 2009 12 01.x1s» 12/4/2009 2009 August's SRF Tyonek 77 -3 Storage Well Monitoring Report • Page 1 of Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Tuesday, September 15, 2009 7:19 AM 10 ce, To: Maunder, Thomas E (DOA) Subject: RE: 2009 Augusts SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Sounds good Tom, I'll find a way to get this done...hopefully with the correct axis label, but if not, some kind of side note. Thanks o Larry VA _ From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 14, 2009 9:14 PM To: Greenstein, Larry P Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report If you can't, thats OK. The storage wells are the only ones where you all inject gas. You might just make a note in the "note field" where you give the specifics on the well. Tom MAR 1 0 2011 From: Greenstein, Larry P [mailto :Greensteinlp @chevron.com] Sent: Mon 9/14/2009 5:23 PM To: Winslow, Paul M; Maunder, Thomas E (DOA) Cc: Ayer, Phil M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Thanks Paul. Tom, I'll look into the program that spits out these plots to see if we can tweak it to be more accurate on the labeling. Larry Fro inslow, Paul M Sent: Mon.: September 14, 2009 4:15 PM To: Maunder, Tho E (DOA); Greenstein, Larry P Cc: Ayer, Phil M; Regg, • • - s B (DOA) Subject: RE: 2009 August's S' - • nek 77 -3 Sand Storage Well Monitoring R- • Tom, Prior to April 2009, we had only injected int. A - 45X, and ha. • • used from both 42 -05X and 42 -05Y. After installing a coalescer this year, we s . - • injecting into both 42 -05Y a 12-05X. From here on out, we will be injecting and producing fro• •oth wells. Paul 3/7/2011 Lvu7 Hugusl s 31s.r 1 yamm& / / -J JallU. 3lorage W CLL 1v1Vnuornig rceporL rage 1 01 G • • Maunder, Thomas E (DOA) From: Winslow, Paul M [PWinslow @chevron.com] Sent: Monday, September 14, 2009 4:15 PM To: Maunder, Thomas E (DOA); Greenstein, Larry P Cc: Ayer, Phil M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Tom, Prior to April 2009, we had only injected into 42 -05X, and had produced from both 42 -05X and 42 -05Y. After installing a coalescer this year, we started injecting into both 42 -05Y and 42 -05X. From here on out, we will be injecting and producing from both wells. Paul Paul Winslow Chevron North American Exploration & Production MidContinent / Alaska Business Unit 3800 Centerpoint Dr., Suite 100, Anchorage, AK 99503 Tel: 907 - 263 -7629 Cell: 907- 382 -3813 Fax 907- 263 -7828 pwinslow @chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 14, 2009 3:59 PM To: Greenstein, Larry P Cc: Ayer, Phil M; Winslow, Paul M; Regg, James B (DOA) Subject: RE: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Larry, et al, It will be interesting to see the pressure plot next month on 12A -04. On 5X and 5Y, there are a couple of items. One is listed as an injection well and the other a storage well_ Do both wells inject gas and then produce it back? In our data base they are both listed as "GSTOR ". Also, the volume on the right axis says BBLS. Should that be MCF? Thanks in advance. Tom Maunder, PE AOGCC From: Greenstein, Larry P [mailto:Greensteinlp @chevron.com] Sent: Monday, September 14, 2009 2:44 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Ayer, Phil M; Winslow, Paul M Subject: 2009 August's SRF Tyonek 77 -3 Sand Storage Well Monitoring Report Hi Jim & Tom, Here is August's monthly report for the wells requiring pressure monitoring near the SRF Tyonek 77 -3 Sand Storage reservoir. 9/14/2009 2009 August's SKI' "hyonek 77 -3 Sa Storage Well Monitonng Report Page 2 of 2 • We are still injecting into the wells, but the volumes are slowing down as the reservoir fills up. Both the 5X & 5Y wells are getting gas injected and the tubing pressures show the increases expected. The 12A -04 well WO has been completed and production has started. It is having some problems, but we are still trying to clean up the lost fluids and get production rates up, The rest of the wells appear to have pressures for the month that don't show any indications of a response due to the gas storage operations. Bottom line, the pressures remain in expected ranges for all the wells being monitored. Larry «Master Well List TIO Report 2009 09 01.xls» 9/14/2009 • Paul Winslow Chevron North America Chevron Paul Engineer Advisor Exploration and Production Continen Alaska SBU 3800 Center point Dr., Ste 100 Mi d t/ P ] Anchorage, AK 99503 Tel (907) 263 -7629 Email pwinslow @chevron.com February 23, 2009 1 13 2009 Mr. Dan Seamount, Chairman s: ��, }�, ; " i��.•L.a'a� `" Alaska Oil and Gas Conservation Commission l Y'4, 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Annual Material Balance Calculations of Production and Injection Volumes Swanson River Gas Storage Facility #3 (Tyonek 77 -3 sand Swanson River Field yam a- k \, SAC Dear Commissioner Seamount: i'OrNJ TX. flr Attached for your review is the annual material balance calculation of production and injection volumes for the Swanson River Gas Storage Facility #3 (SRGSF #3), as required per AOGCC Storage Injection Order #6 (SIO #6). SRGSF #3 applies to the Tyonek 77 -3 reservoir, which has had four wells completed in it1SC(1 42A -05 SC(1 42B -05. SCU 42 -05X. and SCU 42 -05Y), This material balance report covers the primary production period, as well as the gas storage operations that have taken place from October 1, 2005 to the present time. Attachment #1 is a table of gas production and injection volumes for the SCU 42A -05, SCU 42B -05, SCU 42 -05X, and SCU 42 -05Y wells, from the commencement of primary production (July 2004) up through February 22, 2008. Note that the January and February 2009 volumes are estimated from daily metered values. Historic reservoir pressure estimates have been obtained primarily through surface shut -in tubing pressure (SITP) readings which were then converted to bottomhole pressures. In addition to the SITP's, downhole pressure gauges have been run several times, to obtain static bottomhole pressures and /or to conduct pressure transient tests. These data points are tabulated in Attachment #2 and plotted versus the corresponding net cumulative production on the standard P/Z plot (Attachment #3). Viewing Attachment #3, it has previously been noted that the early injection cycle pressures deviate above the straight line path established from the primary depletion points. Previous Annual Performance Reports have also documented that the production volumes /pressures have deviated below the primary depletion path. The latest 2008 injection and 2008/2009 production cycles mimicked the previously established trends, indicating the continued reservoir confinement of the gas storage volumes. During the peak of the 2007/2008 winter production season (Nov. '07 — Feb. '08), a net total of 852 MMcf of gas was produced from the 77 -3 reservoir. From Mar. - Sep. '08, a net total of 889 MMcf of gas was injected back into storage, via the SCU 42 -05X wellbore. To date (2/23/09) a total of 1,322 MMcf of gas has been withdrawn from storage during the 2008/2009 winter season. Note that after the extended cold period which lasted until mid January, Chevron was MidContinent /Alaska SBU /Chevron North America Exploration and Production www.chevron.com i • Swanson River Gas Storage Facility #3 2008 Annual Performance Report Page 2 able to re- inject a small amount of gas for about a week in mid January (15 — 23 and again in mid February (13 — 20 This injection and offsetting production over the past two months, accounts for the final P/Z vs. cumulative production point seen on Attachment #3. If you have any questions regarding this annual performance report, please contact Paul Winslow at your earliest convenience. Sincerely, Paul M. Winslow Petroleum Engineer Advisor Cc: Dave Whitacre Attachments Union 00 Company of California / A Chevron Company http: / /www.chevron.com • • ATTACHMENT #1 SRGSF #3 - PRODUCTION AND INJECTION VOLUMES (TYONEK 77 -3 SAND) 42a -05 42b-05 • 42 -05X 42 -05Y • Tyonek 77 -3 Sand Totals Cum Depletion Inventory Monthly Monthly Monthly Monthly Monthly Monthly . Monthly Monthly , (Prod -Inj) (Primary- Depl Vol) Gas Gas Gas Gas Gas Gas Gas Gas Cum for POZ Total Gas Date Inj Prod Inj Prod Inj Prod 1 Inj Prod Plotting Inventory MCF MCF MCF MCF MCF MCF MCF MCF MCF MCF • Jun -04 0 0 2,377,000 , L, S Jul -04 0 55,040 . 55,040 2,321,960 Aug -04 0 194,185 249,225 2,127,775 Sep -04 0 173,352 422,577 1,954,423 Oct -04 0 151,770' 574,347 1,802,653 Nov -04 0 161,949 • 736,296 1,640,704 Dec -04 0 116,582 852,878 1,524,122 Jan -05 0 160,730 1,013,608 1,363,392 Feb -05 0 160,235 • 1,173,843 1,203,157 Mar -05 0 164,902; 1,338,745 1,038,255 Apr -05 0 156,158 1,494,903 882,097 May -05 0 172,327' 1,667,230 709,770 Jun -05 0 162,359; 1,829,589 547,411 Jul -05 0 157,953 1,987,542 389,458 Aug -05 0 114,531 2,102,073 274,927 Sep -05 0 71,034 2,173,107 203,893 Oct -05 0 113,342 0 2,286,449 90,551 Nov -05 0 53,196' 0 20,267 2,359,912 17,088 .O V1 \ i7 Dec -05 0 0 224,142 16,950' 2,152,720 224,280 1, Jan -06 0 31,872 22,827 433 2,162,198 214,802 Feb -06 0 17,334 172 0, 2,179,360 197,640 Mar -06 0 87,263 24,813 99,300 2,341,110 35,890 Apr -06 0 30,355 0 106,8631 2,478,328 101,328 May -06 0 0 311,189 8; 2,167,147 209,853 Jun -06 0 0 12,011 0' 2,155,136 221,864 Jul -06 0 863' 0 0 0 35,263 2,191,262 185,738 Aug -06 0 131 0 0 331,869 6,215 • 1,865,739 511,261 Sep -06 0 0 0 0 422,802 0 I 1,442,937 934,063 Oct -06 110,657 0 1,332,280 1,044,720 Nov -06 83,366 66,1961 1,315,110 1,061,890 Dec -06 200,905 12,889 ; 1,127,094 1,249,906 Jan -07 156,326 70,834 h 1,041,602 1,335,398 Feb -07 106,193 56,7481 992,157 1,384,843 Mar -07 54,252 88,933! 1,026,838 1,350,162 Apr -07 247,449 0 779,389 1,597,611 May -07 74,062 0 705,327 1,671,673 Jun -07 82,060 0' ; 623,267 1,753,733 Jul -07 39,731 103 583,639 1,793,361 Aug -07 139 0' 0 18,925 602,425 1,774,575 Sep 07 134,187 01 0 35,500E 503,738 1,873,262 Oct -07 1 41,803 641 0 0' 461,999 1,915,001 Nov -07 0 29,621 ; 0 0" 491,620 1,885,380 Dec -07 19,505 171,2471 0 35,047 678,409 1,698,591 Jan -08 3,691 227,468'. 0 228,082 1,130,268 1,246,732 Feb -08 117,547 120,442 0 180,632∎ 1,313,795 1,063,205 Mar -08 239,096 24,957 k 0 5,280 l 1,104,936 ' 1,272,064 Apr -08 , 223,992 12,168,` 0 5,25511 898,367 1,478,633 May -08 212,951 414 0 0� 685,830 1,691,170 Jun -08 1 117,095 01 0 0 568,735 1,808,265 Jul -08 75,423 0 0 0 �I 493,312 1,883,688 Aug -08 1 44,900 0! 0 011 448,412 1,928,588 Sep 08 24,393 4481 0 0 424,467 1,952,533 Oct -08 9,943 47,2081' 0 80,0681; 541,800 1,835,200 Nov -08 1,267 222,108 H 0 94,718 857,359 1,519,641 Dec -08 t 716 223,9131 0 312,3491. 1,392,905 984,095 Jan -09 90,992 127,887 I 0 182,125 1,611,925 765,075 Feb -09 69 655 76,719' 0 127,2441 1,746,233 630,767 January and February (thru 2/22) '09 volumes are estimated from daily metered figures 2/23/2009 O:\ NAU\ MCBU \Alaska\Depts%AssetDev\CIGas \Gas CFT\Openmind \Swanson\Soldotna Creek Unit North \SCU42A- 51Surveys \ Pressure \AOGCC • • ATTACHMENT #2 SRGSF #3 - P/Z VS. CUM PRODUCTION DATA (Tyonek 77 -3 Sand) Parameter Value Units Gas Gravity 0.563 Bench Datum 7811 ft (tvd) Datum Temp. 141 ° F Datum Temp. 601 ° R Initial Z Guess 0.88 - Gauge - Test Measured Datum Duration Test Depth Pressure at Pressure, Wellname Date Test Type (hrs) (MTD), ft MTD, psia Z Factor Psia Cum Gas, bcf P /Z, Psia Primary Production 42A -5 06/27/04 Surf PBU 1 0 '3994 0.9803 4774 0.0000 4870 42A -5 10/22/04 Surf PBU 1 0 3050 0.9110 3646 0.5354 4002 42A -5 12/21/04 BHP Static 1 7982 3194 0.8933 3194 0.8403 3576 42A -5 2/8/2005 BHP PBU 8 7982 2482(SITP) _ 0.8859 2926 1.0599 3303 42A -5 06/23/05 BHP PBU 8 _7811 1985 0.8835 1985 1.7931 2247 42A -5 07/11/05 SITP 2 0 1565 0.8859 1871 1.8881 2112 42A -5 08/25/05 SITP 3 0 1385 0.8923 1655 2.1024 1855 42A -5 09/13/05 SITP 3 0 1490 0.8883 1781 2.1051 2005 42A -5 10/25/05 BHP PBU 8 7811 1556 0.8959 1556 2.2666 1737 2005 Injection Cycle 142A &B -5 1 1/4/2006 1BHP Static f42 17811 11857 1 0.8803 1 2232 I 2.1423 1 2536 2006 Production Cycle 42A &B -5 3/10/2006 SITP 4 0 1895 0.8802 2236 2.1633 2540 42A &B -5 3/18/2006 BHP Static 1 7811 2026 0.8827 2026 2.2260 2295 • 42B -5 4/12/2006 BHP Static 42a- 120 0 1412 0.8911 1689 2.4038 1895 42B -5 5/4/2006 SITP 96 0 1280 0.8969 _1530 2.4783 1706 2006 -2007 Injection Cycle 42A &B -5 5/17/2006 SITP 48 0 1528 0.8871 1826 2.3799 2058 42A5 6/9/2006 Psuedo SITP 192 0 2010 0.8797 2403 2.1551 2732 42 -05X 8/3/2006 SITP/ BHP PBU 15 0 1875 0.8801 2256 2.1976 2563 42 -05X 8/24/2006 SITP /BHP PFO 12 0 2400 0.8851 2886 1.9949 3261 42 -05X 9/7/2006 SITP 24 0 2826 0.9004 3396 1.7610 3772 42 -05X 9/26/2006 SITP 24 0 3347 0.9290 4000 1.4678 4306 42 -05X 10/3/2006 SITP 53 0 3312 0.9267 3958 1.4422 4271 42 -05X 10/6/2006 SITP 11 0 3309 0.9265 3955 1.4390 4269 42 -05X 10/17/2006 SITP 107.5 0 3245 0.9234 3896 1.4127 4219 42 -05X 10/20/2006 BHP PFO 8 7794 3241 0.9216 3862 1.4015 4191 42 -05X 11/8/2006 SITP 31.5 0 3445 0.9358 4118 1.2840 4401 42 -05X 11/16/2006 SITP 44.5 0 3403 0.9328 4067 1.2497 4360 42 -05X 1/7/2007 SITP 89 0 3469 0.9374 4146 1.1109 4423 42 -05X 4/20/2007 SITP 20 0 3794 0.9626_ 4534 0.8318 4710 42 -05X 5/22/2007 SITP 8 0 3755 0.9583 4473 0.7523 4668 42 -05X 8/28/2007 SITP 12 0 3715 0.9561 _ 4440 0.5834 4644 42 -05X 11/26/2007 SITP 840 0 3815 0.9644 4560 0.4622 4728 2/23/2009 O:I NAUIMCBU1AIaska1DeptsWssetDevlCIGas1USERSIPMWIGas StoragelSwanson River\SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xls 42ABXY -5 POZ data • • ATTACHMENT #2 SRGSF #3 - P/Z VS. CUM PRODUCTION DATA (Tyonek 77 -3 Sand) Parameter Value Units Gas Gravity 0.563 Bench Datum 7811 ft (tvd) Datum Temp. 141 ° F Datum Temp. 601 ° R Initial Z Guess 0.88 Gauge - Test Measured Datum Duration Test Depth Pressure at Pressure, Weliname Date Test Type (hrs) (MTD), ft MTD, psia Z Factor Psia Cum Gas, bcf P /Z, Psia 2008 Production Cycle 42 -05X 12/14/2007 SITP 89.5 0 3647 0.9507. 4359 0.5166 4585 42 -05X 1/4/2008 SITP 31 0 3258 0.9231 3890 0.6896 4214 42 -05X 1/23/2008 SITP 7 0 2676 _ 0.8934 3199 0.9690 3581 42 -05X 2/8/2008 SITP 10 0 1990 0.8797 2379 1.2923 2704 42 -05Y 2/13/2008 SITP 27.3 0 1909 0.8800 2282 1.3859 2593 2008 Injection Cycle 42 -05Y 5/16/2008 SITP 24 0 3668 0.9476 4311 0.783 4549 42 -05Y 6/6/2008 SITP 216 0 3771 0.9552 4427 0.686 4635 42 -05Y 7/6/2008 SITP 96 0 3915 0.9663 4587 0.567 4747 42 -05Y 9/22/2008 SITP 96 0 3796 0.9571 4455 0.431 4655 42 -05Y 10/7/2008 SITP 96 0 3857 0.9618 4523 0.427 4703 2008 / 2009 Production Cycle 42 -05X & Y 11/13/2008 SITP 72 0 3214 0.9182 3796 0.660 4134 42 -05X & Y 11/30/2008 SITP 24 0 2847 0.8995 3372 0.853 3749 42 -05Y 12/8/2008 SITP 96 0 2719 0.8942 3222 0.941 3603 42 -05Y 1/14/2009 SITP 24 0 1518 0.8880 1792 1.654 2018 42 - 05X & Y 2/21/2009 SITP 48 0 1777 0.8816 2104 1.748 2386 2/23/2009 0: 1NAUIMCBU1AIaskalDepts \AssetDevlClGas1USERSIPMW1Gas StoragelSwanson River\SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xls 42ABXY -5 POZ data ATTACHMENT #3 SRGSF #3 - POZ vs Cum Gas Production Plot (Tyonek 77 - 3 Sand) 6000 Primary 41'05 -'06 lnj Cycle 5000 ♦'06 Prod Cycle •'06 -'07 In) Cycte ® 4 . ♦'07 -'08 Prod Cycle 4000 � .,- - -- •'08 Inj Cycle • '08 -'09 Prod Cycle N i L 33000 a �. • 2000 Si 1000 • 0 0 1 2 3 4 Cum Gas Produced, bcf 2 / 23 / 20090 NAU\ MCBU \Alaska\Depts\AssetDev \CIGas \USERS \PM\MGas Storage \Swanson River \SCU 42 -05 77 -3 Sd POZ 2- 17- 09.xls AOGCC (090223) ----- " ........., . STATE OF ALASKA /<;c:.... IJ C/o¿ SEP 0 6 2006 ALASKAW AND GAS CONSERVATION COMMIS. WELL COMPLETION OR RECOMPLETION REPORT ~tjil~ons. Ccnnmission 1 a. Well Status: OilU GasD Plugged U Abandoned U Suspended ~ WAGD 1 b. Well Class: I·U/coorage 20AAC 25.105 20AAC 25.110 Development 0 Exploratory D GINJD WINJD WDSPL D No. of Completions Other Service D Stratigraphic TestD 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Union Oil Company of California Aband.: 8/9/06 180-106 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 August 2, 1981 50-133-20232-01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1879' FSL, 498' FEL, See 5, T7N, R9W, SM August 31,1981 SCU 42A-05 Top of Productive Horizon: nla 8. KB Elevation (ft): 15. Field/Pool(s): 167' RKB Swanson River Field Total Depth: 9. Plug Back Depth(MD+ TVD): 77-3 Tyonek Sand 1432' FNL, 426' FEL, Sec. 5, T7N, R9W, SM 5456' I 5455' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 341,868 y- 2,457,903 Zone- 11180' 110797' TVD Swanson River Field TPI: nla (- y- Zone- 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 341,940 y- 2,459,839 Zone- NIA A-028996 18. Directional Survey: Yes ~ No D 19. Water Depth, if Offshore: 20. Thickness of Permafrost: NIA feet MSL 0 21. Logs Run: NIA 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD CEMENTING RECORD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE PULLED 18" --- Surf 74' Surf 74' Driven -- 10-3/4" 40.5# K-55 Surf 3385' Surf 3384' 15" 1575 sx Class C -- 7" 23# N-80 Surf 10410' Surf 10075' 9-7/8" -- -- 29# P-110 9-7/8" -- -- 5" 18# N-80 10191 ' 10993' 9871' 10600' 6" 75 c.f. -- 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) "None" 3-1/2" 10078' 10,080 (wI emt pkr at 7265') 2-7/8" 1 0807' ~(;ANNe[} BEP 13 20D5 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: IGaS-Oil Ratio: Test Period ..... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate -. 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". *Finished the first phase of well bore abandonment. Isolated perforations (suspending well) to enable the monitoring of pressures. Will complete full abandonment of wellbore sometime in the future. RBDMS 8FL S£P 0 7 1006 Form 10-407 Revised 12/2003 n R \ G \ N A L AFE 164782 CONTINUED ON REVERSE (:, NAME GEOLOGIC MARKER M TVD 29. ORMATION TESTS Include and briefly su e test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. NIA "None" 30. List of Attachments: Job Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler 263-7649 Printed Name: Timothv C. BrandenburQ ~ Signature: Title: Drilling Manager Phone: 907-276-7600 Date: Sundry Number or NIA if C.O. Exempt: 305-389 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 1a: 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 elevation in feet above mean low low water. 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: True vertical thickness. 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: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 AFE 164782 ....... _ ... ~ ~.. .. IiIIIIIIIIIIIII ~ Well SCU Drm& 1972 API# 50-133-20232-01 Last RKB =18.5' c ¡ s i n & Tub i no ~e TVDe Wt Grade m TODd Btm Hole Cmt Cmt TOD Conduct Sur 74' Yes Surf. Y" Surf CS¡¡ 40.5 K-55 10.05" Surf 3,386' 15" 1875 sx Surf 1 - 4 ~ T' Prod 29 6.184" Surf 73' ~ Csg N-80 460 sx 2100' 7" 23 6.366" 73 3613' CBL '~i:ì! DV Collar 3613 3616 9Y," " T' 23 6366" 3616 4361' r..¡ > fbg Punches N-80 8120' Q @ ~HIl5', 7" Prod Csg 29 6.184" 4361 ' 8053' 1200 SX 5973' CBL & 6005' 7" 29 P-II0 6.184" 8053' ~ rbg Punches 7" Window. Cut on 9/81 10,410' 10,457' 6993'-6999" 5" Liner 18 N-80 4.276" 10,191' 0, 6" 75 sx " Š OC 7265' Tubin!! ~ " 3-1/2" 9.2 N-80 2.992 Surface 993' (§) ~ up 7971' ] 3-1I2" 9.3 J-55 2.992 993' 10,078' 7265' 8 :t 10,807' c' 27/8" 6.5 N-80 2.441 10,078' 1m (âi 8000' ~ ,~ì ,I ewe I r y u 0 f-< Hem Top II) OD Description ¡¡ " ]8.5' Tubing Hanger, 2-7/8", Shaffer Cmt Ref j 5750 Cmt Retainer wi Ponnet Valve rµ} 9,990' !J 6993'- Thg I'nnch holes (23 shots, .21" diameter holes) 6999' 1 2,104' I I I GLM, Cameo, KBUG, 3-1/2" x]" I P@ 10,065' 5807' 2.313 Owens TI)¡! Patch (jiJ 5807' to 5818' 5969' 2.313 Owens Thl!: Patch (ii) 5969' to 5980' 5 6000' 2.313 Owens Thl!: Patch (ii) 6000' to 6011' 9,990' ---- F asD rill Retainer 2 10,004 2.813 Profile Nipple, "X", 2.813" 3 10,005' GLM, Cameo, MM62, 3-1/2" x ]-1/2" 10,065' ----- FasDrill BP 4 10,078 BOT LSA wi 10' of seals 5 10,080' 3,25 Packer, 7" "DB" wi 10' SBE, 3.25" ID 6 10,774' 2.205 Nipple, 'XN', 2.205 J.D. ho 10,420 PERFORATION HISTORY 6 Interval Accum. ~ Zone Top Btm Amt spf Com.ments :=: 77-3 7,977' 7,987' . 10' 6 ~~) f-- ' 8,014' ., 8,015"- I' 4 Apr-72 u Sqz 0 ~,.J~J ~IO,~~ ..10,421' . l' 4 Oct-81 f-< ~ ~ " HI i 10,875' 10,902' 27' 8 isolated H2 I 10,917' 10,926' 9' I 8 isolated i H3 10,958' 10,968' I~~ 4 isolated " -~' ~- H4 i 10,978' 10,992' 14' 4 isolated - - - - , - TD= 11,108' PBTD= 10,993' M ax Deviation = 29° SCU 42A-05 Final dwg 08-06 Revised 08-25-06 CRW e Name SCU 42A-5 Primary Job Type Abandon Well Jobs Primary Job Type Abandon Well Job Category Abandon Objective ~ ~~ i$; ijj,~ ~~' d\i'Sij!,'Z,"~~~ 0!iJ'Z .".~ ¡¡;;..' .,..~ .'.m,.''';1 ,,>( 0 f/Y~" ss&,¡'¥ik~,,"" S 00. ÄH&~N :fuF N ~'% ~~~~ i@ ~." x ~)' Daily Operations 81212006 05:00 - 8/3/2006 00:00 Operations Summary SIMOPOS, PTSM. Prep location. 8/3/2006 00:00 - 8/4/2006 00:00 Operations Summary SIMOPS and PTSM. SCU 42A-05 well pressures are Tbg 1885 psig, PIC 1845 psig, & SIC 0 psig. Bled PIC pressure down to 1600 psig. RU Slickline, and RIH wI 2.8" GR to 5810' RKB and tag top of Owens patch. POOH. RIH with 3-1/2" kick over tool. and 1-1/4" JOS and pull gas lift valve at 2110' RKB. LO slickline and RU pump truck. Pump lease water down tbg until getting returns from annulus. Establish killing well and fluid packing. Establish squeeze rates into 77-3 Zone perfs. Record pump rates and pressures. LD and secure equipment. 8/4/200600:00 - 8/5/2006 00:00 Operations Summary SIMOPS and PTSM. RIH with 2.2" GR to top of perfs at 7981' Fluid level at 4500'. Set dummy gas lift valve at 2104'. Confirm valve is holding. RD slickline and RU eline. PTSM and PU tubing punch (6' with 23 shots, .21 diameter holes) and RIH. Shoot tubing punch holes at 6993 to 6999' with 1000 psig on tbg. POOH. Establish circulation through tbg punch holes. PU HES 3-1/2" EZ Drill Squeeze Packer. PIH and tie into top of Owens patch at 5807'. Set retainer at 5750'. POOH RO Eline.Establish circ rate and squeeze pressure through retainer. LD equipment for night. 8/5/2006 00:00 - 8/6/2006 00:00 Operations Summary Hold SIMOPS and PTSM. Wait on cement lab to run analysis of cement blend. 8/7/2006 00:00 - 8/8/2006 00:00 Operations Summary SIMOPS and PTSM. DSM contacted AOGCC/BLM. Both agencies waived witnessing lower cement plug setting. Prep for cement job. Mix 66 bbls of 15.8# LXT blend cement Slurry (DO-53 Thixotrop at 3% BWOCDO-65 Dispersant at .2% BWOC, D-800 Retarder at .23 % BWOC, MO-45 Antiforam at .1 gallsack, D-600G gasblock at 1.3 gall sack and C-359 Biozan at .05% BWOC) Pump 62 bbls cement down tbg with returns up annulus. Launch foam ball. 14bbls to catch pressure. Bumped retainer with ball at 49.5 bbls of displacement. LD equipment and WOC. 8/8/200600:00 - 8/9/2006 00:00 Operations Summary WOC. SIMOPS and PTSM.Test cement plug on 77-3 sands with 300 psi low test of tbg and 3290 psi for high test. Pressure tested the PIC to 270/3175psi. PIH with slickline with 2.25" GR. Set down at 5434' and worked to 5456'. POOH. RIH with KOT and pull dummy gas lift at 2104 RKB. POOH. Pump diesel down annulus and equalize with tbg for freeze protection. RD slickline. Secure operations. RE: SCU 42A-05 - Extension of Expected wuction Period , fo - to& e Subject: RE: SCU 42A-05 - Extension of Expected Production Period From: "Ayer, Phil M" <pmayer@chevron.com> pate: Thu, 16 Mar 2006 10:41 :26 ~0900 '1"o:winton..i.auDel't@adinin.stat s CC: "Greenstein, Larry P" <G einlp@chevron.com>, "Whitacre, Dave S"<whitacred@chevron.com>, "Myers, Chris S" <myersc@chevron.com>, "Brandenburg, Tim C" <brandenburgt@chevron.com>, "Walsh, Chantal-Petrotechnical" <walshc@unocal.com>, "Greenstein, Larry P" <greensteinlp@unocal.com>, "Merle, Greg L" <merlegl@unocal.com>, "Darkwah, Samuel A" <darkwahs@unocal.com::>, "Tyler,SteveL" <tylersl@unocal.com> Winton, As per our recently completed conversation, this is to confirm that verbal approval was given by you to continue temporary production from Swanson River gas storage well SCU 42a-05. The well is classified, in the AOGCC data base, as being in service/gas storage status. As such, gas storage status retains both injection and production authorization. This is to confirm that no injection will occur in the well and that production will be on a temporary and intermittent basis not extending beyond April 2006. In addition, as we discussed, the currently approved 10-403 for abandonment stays intact. Emails,sent to you earlier, are attached for reference. Phil Ayer Union Oil Company of California Chevron North America Exploration and Production Company 909 West 9th Avenue, Anchorage, AK 99501 email: pmavertéQchevron.com 907-263-7620 (work) 907-250-2711 (mobile) 907-263-7847 (fax) -----Original Message----- From: Ayer, Phil M Sent: Wednesday, January 25,200612:34 PM To: 'winton aubert~admin.state.ak.us' Cc: Greenstein, Larry P; Whitacre, Dave S; Myers, Chris S; Brandenburg, Tim C; 'Walsh, Chantal-Petrotechnical'; 'Greenstein, Larry P'; 'Merle, Greg L'; 'Darkwah, Samuel A'; Tyler, Steve L Subject: SCU 42A-05 - Extension of Expected Production Period Winton, As per our recently completed conversation, this is to confirm that verbal approval was given by you to produce Swanson River gas storaqe well SCU 42a-05 on a temporary basis. The well is classified, in the AOGCC data base, as being in service/gas storage status. As such, gas storage status retains both injection and production authorization. This is to confirm that no injection will occur in the well and that 1 of 3 3/16/2006 10:45 AM RE: SCU 42N05 - Extension of Expected wuction Period e production will be on a temporary and intermittent basis not extending beyond March 2006. In addition, as we discussed, the currently approved 10-403 for abandonment stays intact. Chris Myer's email, sent to you earlier this morning, is attached for reference. Thank you. Phil Ayer Union Oil Company of California Chevron North America Exploration and Production Company 909 West 9th Avenue, Anchorage, AK 99501 email: pmavertéQchevron.com 907-263-7620 (work) 907-250-2711 (mobile) 907-263-7847 (fax) -----Original Message----- From: Myers, Chris S Sent: Wednesday, January 25, 2006 11 :30 AM To: 'winton auberttéQadmin.state.ak.us' Cc: Greenstein, Larry P; Ayer, Phil M; Whitacre, Dave S Subject: 42A-05 change of status Winton, As per your request here is a summery of our phone conversation. In regards to well 42B-05; the well is shut-in and our diagnostics regarding the pressure on the 5 1/2 by 7 5/8 annulus are ongoing and will continue for the short term. In regards to well 42A-05; the well is currently shut-in waiting on a procedure for down hole isolation and abandonment. We are proposing a tempary change of status on the well back to a gas producer from storage zone 77-3. The reasons for this are mainly due to well 42B-05 issues. (We are unable to flow back this storage well pending the above mentioned diagnostics). Historically 42A-05 has been the initial blow down well for the 77-3 sand. The well has good outer an inner annulus integrity which we monitor on a daily basis. There is some minor communication from the tubing to the inner annulus (production casing). The current pressure on the tubing is approximately 1600#. This is under the 2000# limit on the production casing. Our intention over time will be to lower this as the well depletes, thereby lessening any risk to future well integrity. We ask for a quick decision on allowing us to flow this well due to some immediate need for gas from the local utility (Enstar). If there is anything else you need (beside the 403 form) please let me know. Thanks, Chris S. Myers Operations Superintendent Union Oil Company of California 20f3 3/16/2006 10:45 AM SCU 42A-05 - Extension of Expected Prr '")ction Period lfa -lO~ ) Subject:SCU .42A-05 - Extension of Expected Production Period From: "Ayer, Phil Mil <pmayer@unocal.com> Date: Wed, 25 Jan 2006 12:33:44 -0900 It): wint()r~aubêrt@)admin.$tatè..ak.u~ .. .. . . .... .... . ....... . ... ....... .. ............. .... ..< .. <. > ...... .. ..... .'. ..... ........... cc: .."Greenstein, Larryp" . <greensteinlp@unoçal.qC>.m~,'.',^,hit:apr~,pave $" ·<\Nhit~cred@unocal.com>, ".M. ...... y..·...e....... f...8.........'... ..C.... h... f. i.$.......... S. ...". <.. ....m.........y.....e........·.r..8.c. .·....@.·........u...n..... .o..·...c..·.·.a. ......1... C. .·...o.........m........ ......>. ... ...'....... ".8.......f. ·.a. ....n..· ..d...·.....en. b..·..u...·. .r....g..· ..,'.·..·.T.. ·..·..i..m.... ..... ..C...·..·.'..,'. ..·,..<.·..........b......r..a... n.· ...d... e. n..... b...U....f. 9. t.@... ... u....n.. .. 0... c.· ... 8....I.C.o.· ... m... . .. >. ,. ·.'.'W.·. ... ....a.·..lsh, Ghantal-Petrotechniçal"<walshc@unocatcom>,"Greenstein,LarryP"«greenste.inlp@unocal.com>, "Merle,GregL..'\<merlegl@unocal.com>,."[)arkwah,SamueIA".·<darkwªhs@unocaLcom:>, ."Tyler,.· Steve L" <tylersl@uoopal.cqrn:> Winton, As per our recently completed conversation, this is to confirm that verbal approval was given by you to produce Swanson River gas storage well SCU 42a-05 on a temporary basis. The well is classified, in the AOGCC data base, as being in service/gas storage status. As such, gas storage status retains both injection and production authorization. This is to confirm that no injection will occur in the well and that production will be on a temporary and intermittent basis not extending beyond March 2006. In addition, as we discussed, the currently approved 10-403 for abandonment stays intact. Chris Myer's email, sent to you earlier this morning, is attached for reference. Thank you. Phil Ayer Union Oil Company of California Chevron North America Exploration and Production Company 909 West 9th Avenue, Anchorage, AK 99501 email: pmaver@chevron.com 907 -263-7620 (work) 907-250,"2711 (mobile) 907 -263-784 7 (fax) $CANNEO .l1\~ t \) L\)Û\J -----Original Message----- From: Myers, Chris S Sent Wednesday, January 25,2006 11 :30 AM To: 'winton aubert@admin.state.ak.us' Cc: Greenstein, Larry P; Ayer, Phil M; Whitacre, Dave S . Subject 42A-05 change of status Winton, As, per your request here is a summery of our phone conversation. In' regards to well 428-05; the well is shut-in and our diagnostics regarding the pressure on the 5 1/2 by 7 5/8 annulus are ongoing and will continue for the short term. In regards to well 42A-05; the well is currently shut-in waiting on a procedure for down hole isolation and abandonment. We are proposing a tempary change of status on the well back to a gas producer from storage zone 77-3. The reasons for this are mainly due to well 428-05 1 of 2 1/25/2006 1 :25 PM SCU 42A-05 - Exte~sion of Expected Pre" ""ltion Period issues. (We are unable to flow back this storage well pending the above mentioned diagnostics). Historically 42A-05 has been the initial blow down well forthe 77-3 sand. The well has goòd outer an inner annulus integrity which we monitor on a daily basis. There is some minor communication from the tubing to the inner annulus (production casing). The current pressure on the tubing is approximately 1600#. This is under the 2000# limit on the production casing. Our intention over time will be to lower this as the well depletes, thereby lessening any risk to future well integrity. We ask for a quick decision on allowing us to flow this well due to some immediate need for gas from the local utility (Enstar). If there. is anything else you need (beside the 403 form) please let me know. ' , Thanks, Chris S. Myers Operations Superintendent Union Oil Company of California 909 West 9th Avenue; Anchorage, AK 99501 Tel 907 263 7654 Fax 907 263 7847 Mobile 907 398 9955re 20f2 ) 1/25/20061:25 PM 2A-05 change of status ) tto-/O& ) Subject: 42A-05 change of status From: "Myers, Chris S" <myersc@unocal.com> Dåte: Wed, 25 Jan 200611 :30:22 -0900 T o:.·,wi·nt9.n....aub~;rt@adrb.i·.n..statê...~.k.·u.s C.C:. .nGreenst~in,...L5lrry·.P"<greenstE}inlþ@unocal.com>,,·."Ayer,.·.·Phi.l. M"·.·.<prnayer@unocal.com>\.·."Whitacre, Dave.S" <whitacrE}d@unocaLcom> Winton, As per your. request here is a summery of our phone conversation. In regards to well 42B-05; the well is shut-in and our diagnostics regarding the pressure on the 5 1/2 by 7 5/8 annulus are ongoing and will continue for the short term. In regards to well 42A-05; the well is currently shut-in waiting on a procedure for down hole isolation and abandonment. We are proposing a tempary change of status on the well back to a gas producer from storage zone 77-3. The reasons for this are mainly due to well 42B-05 issues. (We are unable to flow back this storage well pending the above mentioned diagnostics). Historically 42A-05 has been the initial blow down well for the 77-3 sand. The well has good outer an inner annulus integrity which we monitor on a daily basis. There is some minor communication from the tubing to the inner annulus (production casing). The current pressure on the tubing is approximately 1600#. This is under the 2000# limit on the production casing. Our intention over time will be to lower this as the well depletes, thereby lessening any risk to future well integrity. We ask for a quick decision on allowing us to flow this well due to some immediate need for gas from the local utility (Enstar). If there is anything else you need (beside the 403 form) please let me know. Thanks, Chris S. Myers Operations Superintendent Union Oil Company of California 909 West 9th Avenue; Anchorage, AK 99501 Tel 907 263 7654 Fax 907 263 7847 Mobile 907 398 9955re 1 of 1 1/25/2006 1 :24 PM FW: 42A-05 and 428-05 Subject: FW: 42A-05 and 42B-05 From: "Greenstein, Larry P" <greensteinlp@unocal.com> Date: Tue, 27 Dee 2005 10:36:58 -0900 Tô:"MeMains, Stephen E -AOGCC" <steve_mcmains@admin.state.ak.us< I rfð 0 ~' !J b Steve, Here is the e-mail we talked about. ~ED DEe 2 8 ZUU5 The reclassifying of the produced gas from the Tyonek zone in these two wells occurred as of 10/1/0S. ~ Both wells are now storage wells. . ("~~ £- ~ ~ ;l~~4d '£;HctU0 q-f ~L ~ I - GAS '1ó GSTD ~( . 5Çv1;L,,~· ~ . )~ ~<'" as Hope this helps. Larry -----Original Message----- From: Ayer, Phil M [mailto:pmayer@unocal.com] Sent: Tuesday, December 13, 200S 11:13 AM To: Shehata, Danny Cc: Page, Donald Ai Greenstein, Larry Pi Tabler, Kevin A Subject: 42A-OS and 42B-OS As of 10/1/0S we have a gas storage agreement with the BLM ~n conduct gas storage operations in the Tyonek 77-3 sand which bot~42A-0~and 42B-OS are completed in. ....~ So as of this date the reservoir is a gas storage reservoir and: * all withdrawals are gas storage withdrawals (not subject to royalty until an additional 643 MMCF of native gas is withdrawn) * all injection is gas storage injection. * Both the gas storage injection and withdrawals are subject to fees that are outlined in the agreement. I will email you a copy of the gas storage agreement and XA (for paying the native gas royalty) that was emailed to Don Page and cc to others by Judy Stanek on 11/9/0S. Judy did ask in her email how monthly payments will be made and I presume Don has or is addressing this. 10f2 12/27/2005 3:39 PM FW: 42A-05 and 428-05 I believe gas production from 42a-OS ended on 11/30/0S (well will be left shut in and abandoned sometime in next 2 months). Production operations commenced on 42b-OS on 11/10/0S and injection commenced on 12/9/0S. Phil "'--.:~ Phil Ayer Union Oil Company of California Chevron North America Exploration and Production Company 909 West 9th Avenue, Anchorage, AK 99S01 email: P.~9.:Y.~E.~~~_b:e~£S2~_~~S2~ 907-263-7620 (work) 907-2S0-2711 (mobile) 907-263-7847 (fax) 20f2 12/27/2005 3:39 PM rifù C7~ lì~l\ ..;~.:;¡ [? ~\ i i /l!\ ! [ 16 I® :.~l iU t> lJ Lob ) (~ñ') ~I~~I::::J ! .iljl'.J; ;.U.:~ \~~\.,,' :1 ri~\ J .;l~ II \. 1.1J\ iLj~ ) / ¡ I j' / ¡ I FRANK H. MURKOWSKI. GOVERNOR AI,AS&A OIL A5D GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 \~()/\ O~ Re: Swanson River SCU 42A-05 Sundry Number: 305-389 ~NE!) DEC ~ 8 2005 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~ay of December, 2005 Encl. 1. Type of Request: ,. ~eelV~V STATE OF ALASKA tJ~ JVç¿>/n 5 Au k OIL AND GAS CONSERVATION COMJI.. _~ION L.>EC 1 9 200 APPLICATION FOR SUNDRY APPROVALS 0'\ & Gas Cons. commission 20 MC 25 280 Mas\(a , . . . I A &boraot' / Suspend U Operational shutdown U Perforate U Waiver u" Other U Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: 5. Permit to Drill Number: Abandon ~ Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: Development Stratigraphic o o / Exploratory 0 o Service 180-~t 0" 6. API Number: 50-133-20232-01 /' \(.l.líA- PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 18.5' RKB 8. Property Designation: Swanson River Production Facility 11. Total Depth MD (ft): 11,108' Casing Structural Conductor Surface Intermediate Production Liner 803' Length 9. Well Name and Number: SCU 42A-05 / 10. Field/Pools(s): Swanson River FieldlTyonek PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9,990' 9,683' 9,990' Size MD TVD Burst Collapse Total Depth TVD (ft): 10,701' 74' 3,386' 10,457' 18" 74' ( 74' 3,386' / 3,385' 3130 psi 10,410' ./ 10,075' 6,340 psi 10,994' / 10,601 ' 10,140 psi 1,580 psi 3,830 psi 1 0-3/4" 7" 5" Perforation Depth MD (ft): 7977' - 7987' -- Perforation Depth TVD (ft): 7811' -7821' Tubing Size: Tubing Grade: 10,490 psi Tubing MD (ft): / 993' 1 10,078' 1 10,807' Packers and SSSV Type: 7" "DB" with 10' SBE. 3.25" 10 3-1/2" - 2-7/8" <,/ 9.2#N-80, 9.3#J-55, 6.5# N-80 Packers and SSSV MD (ft): 10,080' / 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program D BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Timothy C. Brandenburg Title Drilling Manager Signature /'~ cA r§ Phone 907-276-7600 Date ~ ¿:/' COMMISSION USE ONLY Date: 13. Well Class after proposed work: Exploratory D Development 0 / 15. Well Status after proposed work: 1/1/2006 Oil D Gas D Plugged D WAG D GINJ D WINJ D / Service 0 Abandoned WDSPL /"' o D Steve Tyler 263-7649 12-/9-0:) Conditions of approval: Notify Commission so that a representative may witness Sundry Number~ 5 - :;Z;XO¡ Plug Integrity æ::( BOP Test D Mechanical Integrity Test D Location Clearance ~ Other A OC¡ cc.. r:"" '> p~". . to \1 e-.- ,. 4¡ I (1 W 4..r 0.."'- duff e.,-- u WI.. ev...:t ýJ! ~ c. . {.>.e"r 1-0 M- L '2.. S · I 2...(, j ) tU t WIA.Þ---t-€- well bot" (!.. fl~n; It 1 f roC£. tk vo( ,'s at pr.J1le RBDMS BFL DEe 2 2 2DD5 APPROVED BY COMMISSIONER THE COMMISSION Date /1./¡':Z,,"oŠ Form 10-403 Revised 07/2005 AFE 164782 Submit in Duplicate Phase 1 ) ) seD 42A-05 P&A Operation Summary AOGCC API# 50-133-20232-01 PTD# 180-106 /' 1. MIRV P~l . ~¢.u 1<. Establish injection rate & pressure into the 77-3 sand. MASP = 50Q/psi, monitor casing pressure. R[ set J:.-f2(~mt retainer w/ poppet valve above the tubing patches~Êstablish injection/circulation rates and pressures through retainer. The retainer will be set more than 500' above the perforation interval, not complying with the AOGCC Regulations lOAAC 25.ll2.(c).(1). (D), because of the tbg patches. Pump/circulate cement into thezone, the amount being greater than the ~ volume of the wellbore from 100 feet below the perforation interval to the retainer, as described in AOGCC Regulations 10AAC'7 '" 25.1l2.(c).(1). (D). .,.'" MIRV cementers. Mix 25 bbls (125 sx) of G neat. Pump/circulate cmt down tbg. Launch wiper ball. Displace cmt to retainer until wiper ball is bumped. WOC 24 hours. , Pressure test tbg to 2500 psi. / MIRU Eline. RI cut tbg at least 160' below the original ground level (AOGCC Regulations 10AAC 25.l12.(d)). RD Eline. Fill wellbore with lease water. Confirm cut by circulating well. Jug test wellbore. /' 2. 3. 4. 5. 6. 7. Phase 2/3 (Win wait on warm weather to continue) 8. RU Crane and Portable Work platform and BOPE. ND tree. POOH LD tbg. 9. MIRV slickline. RI set 7" Cavins BP above cut tbg, enabling enough space to place a minimum 150' of cement to surface (AOGCC Regulations 1~~þCf5.112.(d)). RD sliekline. NU dr~ hole tree. ~. . 10. MIRU Elme. RIH w/ tpg punch perf gun. Perforate above the bndge plug. EstablIsh cIrculatIon rates & pressures out 10-3/4" x 11. ~';xan~;s (250 sx) o';:~t. Pump/etreulate emt down 7" esg whIle takmg returns out 10-3/4" x 7" annulus tIll emt IS at surffc,~/ 12. SI 1 0-3/4" x 7" annulus. Continue pumping till cmt is at surface. Displace surface lines & tree valve(s). RD cementers 13. WOC 24 hrs. ND tree. Top-off cmt as needed. /// 14. Excavate /remove cellar. Dig down to exposed surface csg strings. Cut surface tubular off3' below original ground level. Weld abandonment plate. Record GPS surface location. Back-fill hole. T e Wt Cmt Cmt To Conduct Yes Surf SurfCs K-55 10.05" 3,386' 1875 sx Surf Prod N-80 6.184" 73' 2100' Csg 6.366" 73 3613' 460 SX CBL 3613 3616 23 N-80 6.366" 3616 4361 ' Prod Csg 29 6.UW 4361 ' 8053' 1200 sx 8120' CBL 1'-11 0 6.184" 8053' 10,410' Tog PUß<:he.~ 10,410' 10,457' @ 5815',5973' & 60íl5' 5" 4.276" 10,191' 10,994' 9.2 N-80 2.992 993' ~ 9.3 J-55 2.992 993' 10,078' :§: .. 6.5 N-80 2.441 10,078' 10,807' .. ~ Hem I II III +i- 5750 1 2,104' 5807' 5969' 6000' 9,990' 2 10,004 2.813 3 10,005' 10,065' 4 10,078 5 10,080' 3.25 6 10,774 ' 2.205 6 wi GLM, Cameo, KBUG, 3-li2" xl" Owens Tb Patch Cii! 5807' to 58J8' Owens Tb Patch Cii! 5969' to 5980' Owens Tb Patch Cii! 6000' to 60 II ' FasDrm Retainer Profile Nipple, "X", 2.813" GLM, Cameo, MM62, 3-1/2" x I-Ii2" FasDril! HI' BOT LSA wi 10' of seals Packer, T' "DB" wi 10' SBE, 3.25" ID Nipple, ')(N', 2.205 J.D. I ' I Comments TD= It,J08' PBTD= 10,993' M ax Deviation = 29° SCD 42A-05 Proposed dwg 12-05 Revised 12-15-05 CRW Size T e Wt Btm Hole Cmt Cmt To i8" Conductor Surf 74' Yes Surf Surf Cs 40.5 Surf 3,386' IS" 1875 sx Surf Prod Csg 29 Surf 73' 2100' 23 73 3613' 460 sx eBL 3613 3616 9-'1." 3616 4361' Prod Csg 4361' 8053' 1200 sx 8120' eBL i 8053' 10,410' l T~J\mchi);¡ 10,410' 10,457' ~ (if 5815',5973' &6005' = 5" 10,191' 10,994' ! Tubin 3-112" 9.2 N-80 2.992 18.5' 993' 3-112" 9.3 J-55 2.992 993' 10,078' 27/8" 6.5 N-80 2.441 10,078' 10,807' ¡¡ t.) 1D= 11,108' PBID= 10,993' Max De\iation =290 SCD 42A-05 Actual dwg 09-05 Item 2 3 4 5 6 10,078 10,080' 10,774' BOT LSA wi 10' of seals Packer, T' "DB" wi 10' SBE, 3.25" ID Nipple, 'XN', 2.2051.D. 3.25 2.205 I I í Comments Revised 10-03-05 DED ) ) Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: ·oudeand@uriocal.com f=< ! C j'2 :) 2' UNOCAL .,:, I,"', Debra Oudean Technologist Date: October 21, 2005 To: AOGCC Helen Warman 333 W. ¡th Ave. Ste#100 Anchorage, AK 99501 -SRU .P, E~MIT, .A.P: (':HUM: B,ER.. .LOG (NTERVM,. 'RUN 's.: . ',,' NOTES·' tr '. WELL. . ,.LOG TYPE SCALE· DATE' LOGGED':.' t' . LINE, ~IJ':' CD '. LAS,f)DS,: ". '",' .', ,",,' .', , " '..,', DUS. :i62-:ö1¡;- sõ133iõi61-0õ-Š-ÄÜ14A-33 l~~~~E~~~~~~frI 1I8-'-'-"lšlÑcH1õï¡4ï2õõ51i35ò-:jõ768-1-T'1~1"--1--'~-"¡;d~-.-.-.-¡ ;1ãõ:1·o6....·50-1-332õ23201...šclT42~õ5-·_·PÃëKER·sEmNG -ÄECO-RD·"·-""··""·--""·-5-IÑC~i' -"W27/2Ò05" 5i90~ö·47------·-·-1-·--I-"'1·-"'_·_-"·1···""·rT-~""-·-...·_..pd~--".._·"·_·l , WEATHERFORD INFLATABLE I J ) J.,...c--i RETRIEVABLE BRIDGE PLUG I ~ '.µ i 'Ú~O~1 06150'1 '332Õ:Ó201 [SCÜ-42A:-OS-- "/ruBIÑG"S-EÃ"LÄ'NT"õuMP-SAiLER'--' 15ïNÓ~ï [ ''ai2å/2005Ts7SÕ:S936 " '1- 1-' i-' 1- r -1" 1'-" -. ,..". ". ~~~~~J~~~~~~~I~~~~[~.~tJ~~~.~.~ SCANNED üC1 3 1 2005 Please acknowledge eceipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received By: ()JJ Date: ~)-()~~ r- I ~I\)~~' l& Ú' F:~ l~", '- Unocal Alaska Resourc( Unocal Corporation C__J 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (gO?) 276-7600 UNOCALe AUG 2: 4: 2005 August 24, 2005 Ms. Cathy Forester Mr. John Norman Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 i ~O-ID(P j.f:J..ft-05" APPLICATION FOR GAS STORAGE AREA INJECTION ORDER FOR TYONEK 77-3 SAND, SCU 42A-05, SWANSON RIVER FIELD ~ £. It '. 15 ç- I ~ 0 J 0 (, 42g~OÇ If? i'ii Dear Commissioners: Attached for your review are two copies of an Application for Area Injection Order for gas storage for the Tyonek 77-3 Sand at the Swanson River Field and specifically for Well SCU 42a- 05. The application is submitted by Union Oil Company of California (dba Unocal), as Operator. Upon your approval of this application and pending approval of a gas storage agreement with the Bureau of Land Management, Unocal plans to commence injection of gas into this well for storage as early as this fall. Please contact either Phil Ayer at 263-7620 or Samuel Atta-Darkwah at 263-7864 if you have any questions regardinQ this application. SJ]¡ l/1)-r Philip M. Ayer Petroleum Engineer PMA:dma Attachments cc: Phil Ayer, Unocal Jeff Smetanka, Unocal Kevin Tabler, Unocal Dave Whitacre, Unocal Robin West, USF&WS Claire Caldes, USF&WS SCU 42A-05 Well File Gas Storage File SCANNED NO\l 0 3 Z005 OUPL'CA7E , . ..-- APf'"'LICATION FOR AREA INJECTION ORDER TYONEK 77-3 SAND, SWANSON RIVER FIELD TABLE OF CONTENTS Section/Requlatorv Citation Subject Paqe A. 20 AAC 25.252(c)(1) Plat 3 B. 20 AAC 25.252(c)(2) Operators/Surface Owners 3 C. 20 AAC 25.252(c)(3) Affidavit 4 D. 20 AAC 25.252(c)(4) Description of Operation 5 E. 20 AAC 25.252(c)(4) Pool Information 5 F. 20 AAC 25.252(c)(4) Geologic & Prod. Information 6 G. 20 AAC 25.252(c)(5) Well Logs 7 H. 20 AAC 25.252(c)(6) Mechanical Integrity 7 I. 20 AAC 25.252(c)(6) Casing Information B J. 20 MC 25.252(c)(7) Injection Fluid 11 K. 20 AAC 25.252(c)(B) Injection Pressure 11 L. 20 MC 25.252(c)(9) Fracture Information 12 M. 20 AAC 25.252(c)(10) Formation Fluid 12 N. 20 MC 25.252(c)(11) Aquifer Exemption 12 O. 20 MC 25.252(c)(12) Wells Within Area 12 1 Number 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 ..~ APPLICATION FOR AREA INJECTION ORDER FOR GAS STORAGE TYONEK 77-3 SAND, SWANSON RIVER FIELD LIST OF ATTACHMENTS Description Cook Inlet Location Map SCD 42A-05 Location Map SCD 42A-05 Location Map (Expanded) Structure Map at Top Tyonek 77-3 Sand SCU 42A-05 Well Log Section at Tyonek 77-3 Sandstone SCU 42A-05 - Tyonek 77-3 - Production Data Material Balance Plot - P/Z vs Cumulative Gas for Tyonek 77-3 SCD 42A-05 Current Wellbore Schematic Sample Gas Analysis from Swanson River Field Leak Off Test for SRU 243B-4 Leak Off Test for SRU 223-28 Leak Off Test for SRU 213-10 Leak Off Test for KGSF # 7 Leak Off Test for SRU 241-16 SCU 42b-05 Schematic SCU 42-05 Schematic 2 -- SWANSON RIVER FIELD SWANSON RIVER GAS STORAGE FACILITY APPLICATION FOR AREA INJECTION ORDER TYONEK 77-3 SAND August 23,2005 Introduction In 2001 Unocal commenced operation of a gas storage pilot project within the boundaries of the Swanson River oil field. Unocal refers to this gas storage operation as the Kenai Gas Storage Facility. In order to expand the capacity of the Kenai Gas Storage Facility, Union Oil Company of California (dba Unocal), as operator of the Swanson River Field (SRF), requests an area injection order for injection of gas for gas storage purposes into the Tyonek 77-3 sand, which is present in SCU 42A-05. Well SCU 42A-05 will be used to store gas in the Tyonek 77-3 sand. Additional wells may be converted, redrilled, or drilled into this sand to increase the future deliverability of the storage facility. In addition, Unocal requests that the commission include a provision in the injection order providing for administrative approval of future modifications to operational constraints. SCU 42a-05 will be converted from gas producer status to gas storage service as soon as practically possible. Up to this time Unocal has referred to gas storage operations in the field as being part of the Kenai Gas Storage Facility and gas storage wells had been renamed as KGSF #. I n the future we will no longer refer to gas storage operations in the field as being part of the Kenai Gas Storage Facility but as part of the Swanson River Gas Storage Facility. In addition any future wells converted to gas storage will not have any name changes. Section A - Plat Attachment 1 is a regional map showing the location of the Swanson River Field relative to other fields in the Cook Inlet area. Attachments 2 and 3 are plats showing the location of the proposed injection well and the surrounding wells in sections 4 and 5. Section 8 - Operators/Surface Owners The surface owners and operators within a one-quarter mile radius are: . Unocal · U.S. Department of the Interior, U.S. Fish & Wildlife Service 3 <---- '~ . Section C - Affidavit Affidavit of Philip M. Ayer STATE OF ALASKA THIRD JUDICIAL DISTRICT I, Philip M. Ayer, declare and affirm as follows: 1. I am over 19 years of age. I am employed by Unocal as a Reservoir Engineer. I have personal knowledge of the matters set forth in this affidavit. 2. On (L..A I, /J -j- :l..^I ,2005, the surface owners/op;;~t~d in section B were provided a copy of this permit application. DA TE;l;) at Anchorage, Alaska this {~lV ~ ' 2005. o ~Jf'~ day of ~+ Philip M. Ayer Su~cribed and affi~ryed before me at Anchorage, Alaska on U'..I~~ ~ ï ,2005. ~~. ~\\\\\\\\UlIIIIIII/J// ~ ~ M. ~ ~, ~~~""'''''''..~<9. ~ ~ o~·· ....~ ~ ;§ Q ... ... é::o ~ ~ lNOTARY\~~ æ : : æ - ·PUBLT .;::: ~... .... .1C / Jf.¡§È ~ ~.". .... ~ ~ ~ AI l"1··......··....C;,~ ~ ~ OF ~\..T'~ W¡¡llllIIlm\\\\\~ Notary Public in and for the State of Alaska , / '7/ My commission expires: //; 5(07 4 --~ '~ Section D - Description of Operation Unocal proposes injecting gas into the Tyonek 77-3 sand for gas storage purposes. Initially, the SCU 42A-05 well will be used as the sole well for gas storage operations (both withdrawal and injection). Unocal may later decide to drill a new well, or red rill or recomplete another well to expand storage operations within this reservoir. The storage gas will normally be injected during the summer months and produced back in the winter months for sales. Section E - Pool Information The Tyonek 77-3 sand of the Tyonek Formation is the proposed zone of injection. This shallow gas reservoir is part of the Tyonek Participation Area (PA) [8910086520-C]. Gas from these reservoirs has typically been used on lease for fuel and for sales to Agrium/Enstar. The Tyonek PA (891 0086520-C) comprises the stratigraphic interval the top of which correlates to the measured depths defined in the following wells: Well SRU 212-10 SRU211-15 SRU 234-15 SRU 212-27 SCU 341-4 SCU 34-4 SCU 21-16 Measured Depth 5764 5640 5639 5322 5304 5123 5512 The base of the Tyonek PA is equivalent to the top of the Hemlock PA as defined in Unocal's October 2, 1995 letter to the AOGCC requesting expansion of the Hemlock Pool. The Hemlock Pool is defined in that letter in the following Soldotna Creek Unit wells: 41-4(10,085'-10880'MD), 43-4(10, 168'-10,920'MD), and 41A-8(10,116'-10,880'MD), therefore the base of the Tyonek PA's stratigraphic interval correlates to"the measured depths in the following wells: 5 --.-' Well SCU 41-4 SCU 43-4 SCU 41A-8 Measured Depth 10085 10168 10116 Section F - Geologic & Production Information The Swanson River Field structure is a broad north-south trending anticline cut by a number of east-west trending normal faults. Oil and/or gas is produced from four formations at Swanson River Field. The shallowest gas production is from the Sterling Formation. The Sterling Formation extends to a depth of approximately 3000 TVD feet and is comprised of thick sandstones, mudstones and coals deposited in a high-energy meandering to braided stream environment. Gas is also produced from the thinly bedded sands of the Beluga Formation that underlies the Sterling Formation. These discontinuous sands were deposited in a lower energy stream system, and they are interlayered with abundant mudstones and coals. The Beluga Formation is approximately 2000 feet thick at Swanson River Field. The Tyonek Formation is comprised of meander belt and braided stream sandstones interlayered with mudstones and thick coals. The Tyonek Formation is approximately 5000 feet thick at Swanson River Field. Gas is produced from several sands in the upper and middle part of the formation, while oil production comes from the lowermost 100 feet of the Tyonek (the Tyonek G Zone). -- ~ -~ _.~- Underlying the Tyonek is the main oil producing interval at Swanson River Field, the Hemlock Formation. The Hemlock Formation is 600 feet thick at Swanson River Field and is comprised of thick conglomeratic sandstones interlayered with thin mudstones and minor coal. The Tyonek 77-3 sand is interpreted as a meandering channel belt that is present in portions of Swanson River Field. It can be mapped with existing wells and stratigraphically is surrounded by associated floodplain deposits. This relatively low energy fluvial system creates stratigraphic traps in which gas is found. This sand is gas bearing in portions of sections 4 and 5. The 77-3 sand gas column is penetrated by wells SCU 42A-05, SCU 42-05, SCU 42B-05, SCU 41-05, SCU 12-04, SCU 323-04 and SCU 332-04. The sand shales out up dip to the east at well SCU 43-04. The 77-3 sand is faulted out along the "0" fault on the south side of the accumulation in wells SCU 33-05 and SCU 43-05 6 ~~f ~-" (Attachment 3). Down dip in well SCU 32-05 the 77-3 sand is interpreted as water bearing; however it may also be interpreted as non-payor stratigraphically pinching out. The 77-3 sand accumulation at SCU 42A-05 can be seen on the structure map (Attachment 4). The maximum area case for the 77-3 sand at SCU 42A-05 is shown in green. The 77-3 gas storage sand is interpreted to be a combination structure/stratigraphic trap in which the 77-3 sand is bounded to the north and south by sealing faults, an aquifer down dip to the west and a pinch out/shale out up dip to the east. The attached log section for SCU 42A-05 (Attachment 5) shows the 77-3 sand at depths of 7972 to 8001 feet measured depth (MD). The 77-3 sand is overlain by 91 feet of impermeable, siltstone, clayey siltstone and shale. It is underlain by 100's of feet of siltstone, claystone, coal and silty sandstone. The 77-3 sand perforations were added to the SCU 42A-05 well in June, 2004. The well was perforated from 7972' to 7982' OH MD log depth. The peak gas rate occurred on 7/30/04 at 6.2 MMCFD. The well has produced no water and a cumulative gas volume of 1.830 bcf through June of 2005 (Attachment 6). Material balance analysis of historical production and pressure data indicates an original gas in place of 3.18 bcf (Attachment 7). Using this figure for the original gas-in-place, the current recovery of 1.83 bcf (as of 7/1/05) corresponds to 57.5%> recovery. The SCU 42A-05 is still producing gas today from the 77-3 sand. Our current plans are to convert the well to gas storage service prior to complete depletion of the sand to avoid water and sand production problems which often occur in the late stages of depletion. Given the production history of the Tyonek 77-3 sand, it should be a good gas storage reservoir. Section G - Well Logs All open hole logs from wells in the Swanson River Unit are sent to the Commission as the logs are completed. Attachment 5 shows a log section for the proposed Tyonek 77-3 injection interval in well SCU 42A-05. Section H - Mechanicallntegritv The SCU 42A-05 well will be tested for mechanical integrity using the standard 30 minute annulus test as per 20 MC 25.412. To confirm continued mechanical integrity, Unocal will monitor daily the injection rates and pressures and notify the AOGCC the next working day if the rates and pressures indicate pressure communication or leakage in any casing, tubing, or packer. The rate and 7 ~ pressure data will also be reported to the Commission on a monthly basis. It is planned to repair a small tubing leak prior to converting the well to gas storage service. Section I - Casinçt Information Attachment 8 is the current and proposed wellbore schematic for the SCU 42A- 05 well. The casing in SCU 42A-05 was cemented in accordance with 20 Aee 25.252(b) and tested in accordance with 20 AAC 25.030(g) when completed. Summary: seu 42A-05 is completed with 7" casing cemented down to a KOP depth of 10410' MO, a 5" liner cemented from 10994' to 10191', and 3 %" tubing cemented in place. The TOe and bottom of cement in the 3 %" tbg X 7 "csg annulus is at 7265' and 1 0055' respectively. The TOC in the tubing is at 9990' MD (top cement retainer). Note that the proposed Tyonek 77-3 sand gas storage interval lies above the 5" liner. CBl and temperature survey data from SCU 42A-05 indicates the Tyonek 77-3 sand (7970' - 8000') has full zonal isolation. Production data from this zone is also supportive of a good cement bond and zonal isolation. The straight line P/Z curve on the Tyonek 77-3 sand is indicative of a volumetric acting reservoir with no behind the casing fluid migration. SCU 42A-05 (10410' MD KOP) is a 1981 redrill of SCU 42-5. Well SCU 42-5, which was completed in 1972, is sometimes referred to within Unocal as SCU 42-5 RD (as it is the cased sidetrack of the original SCU 42-5 open hole that was plugged). Official State records only recognize the SCU 42-5 name and do not differentiate between the original hole and the cased sidetrack. It is important to note that the casing information for SCU 42A-05 and SCU 42-5 are one and the same above the 10410' KOP. In addition the Tyonek 77-3 sand of interest is penetrated above this KOP; therefore the casing information in both wells below this KOP is referenced but, is not of primary importance. The detailed casing histories for SCU 42-5 and SCU 42A-05 are as follows: 8 '~ Detail,;, SCU 42-5 Casina History SCU 42-5 was spud on 1/9/72. A wellbore schematic is included as attachment 16. The 10 %" casing was set at 3385' and cemented with 1875 sacks of class G cement with good circulation and returns. The shoe was tested to 2500 psi surface pressure with 72 pcf mud without breaking down (equivalent to 1.24 psilft at 3385' MO, 3384' VO). A 9 7/8" hole was drilled to 10965' prior to losing circulation and sticking the drill pipe. The drill pipe was free pointed and recovered down to 5844'. The hole from 5674' to 10965' was abandoned by equalizing in a 350 cf 125 pcf class G cmt plug at 5818' (displaced by 20 cf wtr and 432 cf of 98 pcf mud). Cement was cleaned out from 5633'- 5674' and the well (referred to as SCU 42-5RO within Unocal, but State retains same SCU 42-5 name) was kicked off and successfully drilled to 10731'. The 7" casing was set at 10731' and cemented in two stages. The first stage was with 1200 sacks of 116 pcf class G neat cement around the shoe and had good circulation for 2/3rds of the displacement and lost circ with less then1 % displacement to go. The second stage was through a stage collar at 3613' with 440 sacks of class G cement and had good circulation throughout. Cement was drilled out from 10535' to 10721'. The casing and 7" shoe tested to 2500 psi surface pressure with 95 pcf mud without breaking down (equivalent to 0.925 psi/ft at 10535' MO, 10192' VD). A CBL was run in the 7" casing (with 2000 psig surface pressure) from 10718'- 7700' and 3700'- 1800' (TOC @ 8120' and 2100' respectively for each cement stage, good cement bond 10535'- 8120' and 3613' - 2100', uncemented pipe 8120' - 7700'). The uncemented portion of?" casing was perforated at 8014' just below the Tyonek 77-3 sand (7970'-8000'), broke down with 1000 psig pump pressure while pumping 98 pcf mud at 10 cflmin. rate, and cement&que~?eq wJth4QQ", sacks of class G'ce'ment. The top of cement plug and casing held a final 4500 psi surface pressure with 98 pcf mud without breaking down (equivalent to 1.25 psi/ft at 8014' MO, 7845' VO). Firm cement was cleaned out from 7913'-8017'. A CBL was run from 10698'- 6550' wI 2500 psig surface pressure (good cement bond 10698'- 8104' and 7700'-7200', patchy cement bond 8104'- 7700'). Within the patchy cement bond section, there is very good to adequate bond in seven intervals (7992'- 8016',7966'- 7978',7922'-7940',7892'- 7912',7830'-7854', 7770'-7774', and 7744'-7754'). Cement was cleaned out from 10721'- 10731' (to 7" csg shoe) and a 6" hole was drilled to 11170'. The 5" liner was hung at 11168', top 10497', and cemented with 80 sacks of 120 pcf class G cement around the shoe with good circulation. Cleaned out firm cement 10346'- 10497' (to liner top), cement stringers 10497'-11113', and hard cement 11113'-11123' (to cement wiper plug). A CBL was run 11095'-10494' 9 .,~ "- (good bond 11095'- 10696' which is 35' up in the 5" liner X 1" casing lap). The liner lap and 5" shoe was tested to 2500 psi surface pressure with 90 pcf mud without breaking down (equivalent to 0.857 psi/ft at 11123' MO, 10743' VO). Soon after perforating the Hemlock formation and running the tubing Ipacker completion, the tubing was pulled, and a tubing hole was found at 8012'. The 7" csg perforation hole at 8014' was isolated with a bridge plug and cement packer tool and cement squeezed with 300 sacks of class G cement. The cement plug and casing was tested to 5000 psi surface pressure with 98 pcf mud without breaking down (equivalent to 1.26 psi/ft at 8014' MO, 784S' VO). Firm cement was cleaned out from 7862'-8016' and the squeeze job perforation and casing tested to 5000 psi surface pressure with 98 pcf mud without breaking down (equivalent to 1.26 psi/ft at 8014' MD, 784S' VD). Prior to re-running the tubing packer completion, the 7" X 5" liner lap was isolated with DST tools and tested in an underbalance condition. There was no blow to surface during the test. An insignificant is' rise in the original underbalance fluid cushion level and no significant pressure changes in pressure charts was noted; all indicative of liner lap integrity. WSO OK. The tubing and packer completion were rerun and the well completed in the Hemlock formation. SCU 42A-05 Casing History In 1981, seu 42-5 was re-drilled from a 10410' KOP as SCU 42A-05 to gain a more favorable drainage point in the Hemlock formation. As mentioned earlier, seu 42A-OS and SCU 42-S's casing are one and the same above the 10410' KOP and the Tyonek 77-3 sand lies above this KOP. Although the SCU 42A-05 casing information below this kick off point is not of primary importance, it is included as a requirement of the injection order application. In preparation to drill SCU 42A-OS, seu 42-05 was killed with 86 pcf mud and all tubing but 38' was pulled and recovered leaving the the top tubing fish at-10994'. The 7" csg and S" liner was plugged back by equalizing in a cement plug at 11046' of 40 cf class G cement. Squeezed 12 cf cement away. Tag TOe 10852'. Equalize in plug at 10852' wI 56 cf G cement. Tag TOe 10490'. Test casing 3000 psi. Milled window in 7" from 10410'-10457'. Equalize in kick off plug at 10490' wI 65 cf G cement. Tag TOC 10315'. Kicked off seu 42A-OS well at 10416' and drilled 6" hole to 11180'. The 5" liner was hung at 10994', top 10191' and cemented with 75 cf class G cement around the shoe. The plug was bumped during displacement. Reversed out with no cmt returns. Tested liner lap to 3000 psi surface pressure with 76 pcf mud without breakdown (equivalent to 0.83 psi/ft @ 10191' MD, 9871' VD). Clean out cement to shoe. Test liner to 3000 psi surface pressure with 76 pcf mud without breakdown (equivalent to 0.81 psi/ft @ 10994' MD, 10601' VD). Ran CBL from 10976'-10181' (TOe 10540', good bond 10976'-10540'). 10 .~ ~ The 5" liner was perforated at 10420', 10' below the 7" casing shoe, and squeezed with 20 sacks class G cmt. Pull out of retainer and reversed out. Clean out cement stringer to 10425'. Perforated well in Hemlock and ran 3 ~" tbg completion with tbg tail at 10828' and packer at 10133'. In June of 2004, SCU 42A-05 was successfully recompleted in to the Tyonek 77- 3 sand by effectively cementing the tubing in place and creating a cement packer in the tubing casing annulus. The 3 %" tubing was cemented in place as follows: A tubing bridge plug was set at 10065',the tubing was perforated from 10055'- 10060' for circulation ports, a 3 ~" cmt retainer was set at 9990', circulation was established up the 3 %"X 7" annulus via coil tubing stabbed in to the retainer, and 78.1 bbls of cement was pumped and displaced to the retainer by lease water. The CT was released from the retainer and 47 bbls lease water was circulated out. A temp log was run from 9984'-6200' (7265' TOC in the 7" csg X 3 1/2" tbg annulus) Section J - In¡ection Fluid The type of fluid for proposed injection is gas. Produced natural gas from the Swanson River field and from other fields in the Cook Inlet will be injected and stored in the proposed storage interval during periods of high supply and redelivered during periods of high demand. The fluid composition for the proposed injection is dry natural gas with a specific gravity which ranges between 0.56 and 0.58. The properties of the Swanson River gas are shown in the gas sample included as Attachment 9. The estimated maximum amount of gas to be injected daily is 42 mmcfd. The injection g~~"shq,LJldJ)~ fullY,G()mpatible with the Tyonek 77-3 formation, ' since this zone previously contained dry methane gas and was produced without any signs of formation damage. Section K - Injection Pressure Existing compression will be used for gas injection and production operations. The estimated average injection pressure is 3500 psi. The maximum injection pressure will be 4400 psi. The compressor plant maximum output pressure limits the maximum injection pressure. Wellhead pressures will be maintained such that a gradient of 0.676 psi/ft at the target midperf reservoir depth of 7816' TVD is not exceeded. This corresponds to a wellhead pressure of 4400 psig at 0 mmcfd injection rate. Any injection rates at the maximum 4400 psig wellhead injection pressure will result in a downhole gradient at the target midperf depth less then 0.676 psi/ft due to the frictional pressure drops in the tubing. 11 .~/ ~ Section L - Fracture Information The proposed maximum injection pressures for the gas storage operation will not initiate fractures in the confining strata which might enable the injection or formation fluid to enter freshwater strata. A pressure control valve will be installed to protect the Tyonek 77-3 sand. The proposed maximum injection pressure for SCU 42A-05 in the 77-3 sand, as previously mentioned will not exceed a gradient of 0.676 psi/ft at the sandface. Leak off tests in wells SCU 2438-4, SRU 223-28, SRU 213-10, KGSF #7, SRU 241-16, all new wells drilled in the last eight years, show the fracture gradient at approximately 2000' to range from. 75 to 1.1 psi/ft (see attachments 10, ii, 12, 13, and 14). Original reservoir pressure in the 77-3 sand in SCU 42A-05 is estimated at 4774 psi based on initial shut-in tubing pressure measurements of 3979 psi. Using the reservoir true vertical depth of 7816', this equates to an original pressure gradient of 0.61 psi/ft. Section M - Formation Fluid No samples exist of produced water from the proposed injection interval. Section N - Aquifer Exemption The proposed gas injection will be at a depth of approximately 7811'-7821' TVD. As per 40 CFR 147.102(b) the aquifers in the Swanson River Field are exempted in accordance with 40 CFR 144.7(b) and 40 CFR 146.4. Section 0 - Wells Within Area Well SCU 428-05 is the only well within a quarter mile of the proposed SCU 42A- 05 gas storage well that penetrates the 77-3 sand. C8l data from this well indicates the Tyonek 77-3 sand (7859' to 7897') has full zonal isolation. A wellbore schematic is included in attachment 15. Casing history is as follows: The 10 %" casing was set at 3395' and cemented with 1250 sacks of class G cement. The shoe was tested to1500 psi surface pressure with 9.3 #/gal mud without breaking down (equivalent to 1.56 psi/ft at 3395'). A 9 7/8" hole was drilled to 7874' with some well flow from 7604'- 7874 prior to sticking the drill pipe. The drill pipe was freepointed and recovered down to 3497'. The hole from 7897' to 3444' was abandoned by laying in 350 cu ft class G cmt plug at 3500', 12 .~ pulling up to 3288' and braiden head squeezing the cement with 100 cf 11.9 ppg mud with a final surface pressure of 4500 psi (no apparent formation breakdown seen). Cement was cleaned out from 3397' to 3444' where the well was kicked off and successfully drilled to 10505'. The 7 5/8" casing was set at 10428' and cemented in two stages. The first stage was with 910 sacks of class G cement around the shoe and had good circulation throughout. The second stage was through a DV collar at 7508' with 1260 sacks sacks of class G cement and had good circulation with 50 sacks cmt returns (lost circ with only 5% displacement to go). Cement was drilled out from 10197' to 10415' and a CBL was run from 10075' to the surface (TOC 3374', good cement bond throughout however patchy intervals from 7576' to 7696' and 7852'- 7893'). Shoe was tested to 3000 psi surface pressure with 9.9 ppg mud without breaking down (equivalent to 0.803 psi/ft at 10415'). The well was then drilled to 10945'. The 5 %" liner was set from 1 0943' to 1 0229' and cemented with 125 cf of class G cement around the shoe. Pulled out of liner and reversed out cement contaminated mud and water. Ran CBL from 10911'- 10000' (no cement in liner lap, excellent cement in 7 5/8" casing to top of CBL logged interval at 10000'. Liner lap and 5 % 'shoe were tested to 5000 psi surface pressure with water without breaking down (equivalent to 0.891 psi/ft at1 0911 '). 13 L L I, U 1 T F A.ll ~7ELLs ( 1 ) )SCU_ 42A-05 ), Oil Water Gas Cum Cum Cum Rate Rate Rate Oil Water Gas Month (CD) (CD) (CD) Prod Prod Prod bbl/d bbl/d Mcf/d Mbbl MbbI fvJ.M c f -.-.-------- ------- ---------- ---------- ------- ------- ---------- 2004-Jul. 0 0 1775 0 0 55 2004-Aug 0 (] 6264 0 0 249 2004-Sep 0 0 5778 0 0 423 2004-0ct 0 0 4896 0 0 574 2004 -·Nov 0 0 5398 0 0 736 2004-Dec 0 0 3761 0 0 853 2005-Jan 0 0 5185 0 0 J.014 2005-Feb 0 0 5723 0 0 1174 2005-Mar 0 0 5319 0 0 1339 2005-Apr 0 0 5205 0 0 1495 2005-May 0 0 5559 0 0 1667 2005-Jun 0 0 5412 0 0 1830 Attachment 6 ~.__.._ ._.._.~" 0" ,___._..._ » ~ Q) C'") ::J 3 <D :J ,-t- -...J 5000 , '~ 4000 SCU 42A-05 -- poz vs Cum Gas Production for Tyonek 77-3 Sand 3000 .!:2 ~ (J) 0- N ã: 2000 1000 o o ~ 2 Cum Gas¡ bef 3 4 8/23/2005 3:39 PM O:\Gas CFT\Openmind\Swanson\Soldotna Creek Unit North\SCU42A-5\Surveys\Pressure\SCU 42A-05_POZ vs Cum_081705.xls 42A-5_POZ_Chrt ) 5({{A - ;2;: 3 - ~ () CUM $513,122 AFE# 126626 ACTUAL TIME 3.33 DAY AFE TIME 4.00 DAY ACCEPT RIG 8/4/97 16:00 8/7/97- DRILL FROM 2074' TO CASING POINT AT 2125'. POOH, TIGHT HOLE FROM 1331'-600'. RIH WITH CLEAN OUT ASSY. REAM THROUGH BRIDGE AT 642'-685' WASH DOWN FROM 685' TO 750'. REAM TIGHT SPOTS AT 1425'-1455',1600'-1640' AND 1877'-1925'. TAG BOTTOM AT 2125' WITH NO FILL. PUMP HI VIS SWEEP WITH NO SIGNIFICANT CUTTINGS RETURN. POOH WITH NO PROBLEMS. BEGIN RUNNING 7" SURFACE CASING. SWANSON RIVER #223-28 DAY 5-7 8/8-8/10/97 D.C. $63689 CUM $712145 AFE# 126626 ACTUAL TIME 6.33 DAY AFE TIME 7.00 DAY ACCEPT RIG 8/4/97 16:00 8/a/97-RAN 7" CASING TO 2125'. CEMENT CASING WITH LEAD CEMENT OF 400 SX (140 BBlS) CLASS G WITH 4% BENTONITE, 20/0 / GACl, AND .266°/0 CEllOFLAKES AT 12.9 PPG, AND TAil CEMENT OF 4 BBLS CLASS G WITH 2% CACl, .1GAUSK D-145, .75 GAUSK D- 300. PROBLEMS PUMPING TAIL SLURRY DUE TO LOSING PRIME. DISPLACE CEMENT AND BUMP PLUG. FULL CIRCULATION / THROUGHOUT JOB, CEMENT CONTAMINATED MUD TO SURFACE. ND DIVERTER AND RAN 1" TUBING TO 96', PUMPED TOP JOB WITH 74 SX CLASS G CEMENT. SET SLIPS, CUT CASING AND INSTALL TUBING SPOOL. NU BOPE. 8/9/97-PRESSURE TESTED BOPE TO 5000 PSI, WITNESSED BY LOU GRIMALDI-AOGCC. RIH WITH 6' BIT TEST 711 CASING TO 3000 PSI. DRILL FLOAT EQUIPMENT. 8/10/97-DRllL 10' OF NEW FORMATION TO 2135'. PERFORM LEAK- OFF TEST WITH 9.0 PPG MUD AT 2058' TVD. BROKE FORMATION AT 1300 PSI = 21.1 PPG EMW. DRILL 6' HOLE TO 3923'. Attachment 11 1 J' '", 1 1 I I. I ,I, 1 1 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION RECEIVED 04 WELL COMPLETION OR RECOMPLETION REPORT AND LQ~ n /\- 1 a. Well Status: OilO Gas0 Plugged 0 Abandoned U Suspended 0 WAGD 1b. Well Class: ... -v V ,( 20AAC 25.105 20AAC 25.110 Development [jlaska Ojf~'S"Î~o~c8 GINJO WINJO WDSPLO No. of Completions Other Service 0 Stratigrapl¡lc est' 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: -g' Union Oil Company of California Aband.: June 21,2004 8()"()106-O ~i/-~ð9r~ 3. Address: 6. Date Spudded: 13. API Number: ,. PO Box 196247, Anchorage, AK 99519 501332023201 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1879 S, 0498 E, Sec 05, T7N, 009W, SCU 42A-05 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 167' Total Depth: 9. Plug Back Depth(MD+ TVD): Swanson River Field 10,993/10,600 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 341,868 y- 2,457,903 11,180/10,765 Swanson River Unit TPI: x- 341,699 y- 2,458,634 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 341,914 y- 2,459,840 10,080' nla 18. Directional Survey: Yes ld No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost: nla feet MSL nla 21. Logs Run: Temperature survey 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 18" 0 74 0 74 yes, cmt at top 10-3/4" 40.5# K-55 0 3,386 0 3,385 15" 1,875 sx, cmt top @ surface 7" 23,29# N-80, P- 0 10,410 0 10,075 9-7/8" 1,660 sx, cmt top @ 2,100' BL and 8,120 100 CBL 5" 18# N-80 10,191 10,994 9,871 10,601 6" 75 sx @ 10,540 CBL 23. Perforations open to Production (MD + TVD ofTop and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE I DEPTH SET (MD) PACKER SET (MD) See Schematic Attached 3-1/2",2-7/8"; @ 10,078', 10,807'; 7" DB w/10' SBE, 3.25" I ID @ 10,080' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7,265 to 10,065 71.6 bbls 1 G-Neat 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): June 27,2004 Flowinç¡ Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: GaS-Oil Ratio: 6/27/2004 24 Test Period .... 6 MMCF/D 0 12/64 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 3,250 2000 24-Hour Rate ..... 6 MMCF/D 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". none ORIGINAL ~f' COmmissior Form 10-407 Revised 12/2003 CONTINUED ON REVERSE R8DMS SF L sa> 0 1 2GO~ 28.. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 77-3 sand 7,971' 7,807' Perf 7,977' to 7,987' MD. Flow Test 1 tested 6 MMCFID at 2,240 FTP, 2,360 SITP; 4.2 MMCFID at 1,520' w/hydrostats. ReCEIVED AUG 8 0 2004 Alaska Oil & Gas Cons Comm' . . I$Slon Anchorage 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler 263-7649 Printed Name: PhiliD J. Krueaer Title: Drilling Manger Signature: \...ß.-:.-it ," Phone: 276-7600 Date: 8/18/2004 / I ~ 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 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Altemating-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 elevation in feet above mean low low water. 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: True vertical thickness. 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: If no cores taken, indicate "none", Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ORIGINAL r-- STATE OF ALASKA .~ ALA~ . OIL AND GAS CONSERVATION COM \, jlON REPORT OF SUNDRY WELL OPERATIONS PO Box 196247, Anchorage, AK 99519 Operation Shutdown Plug Perforations D Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic D Perforate Waiver Stimulate D Time Extension D Re-enter Suspended Well 5. Permit to Drill mber: 1. Operations Abandon.; Suspend Performed: Alter Casing D Repair Well D Change Approved Program D Pull Tubing D 2. Operator Union Oil Company of California Name: Tubing: (size, grade, and measured depth) Exploratory D Service D 3. Address: 180-106 6. API Num r: 50-133-20 2-01 9. Well Name and Number: SCU 42A-05 10. Field/Pool(s): Swanson River FieldlTy 7. KB Elevation (ft): 167' KB 8. Property Designation: Soldotna Creek Unit 11. Present Well Condition Summary: Total Depth measured 11,180 true vertical 10,797' feet feet Effective Depth measured 10,993 true vertical 10,599 feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size 74' 18" 3,386' 10-3/4" 1 0,457' 7" 1 0,994' 5" MD TVD Burst Collapse 74' 3,385' 3,130 psi 1,580 psi 10,119' 6,340 psi 3,830 psi 10,601' 10,140 psi 10,490 psi Perforation depth: True Vertical depth: 3-1/2",3-1/2",2-7/8"; N-80, J-55, N-80; 993',10,078',10,807'; 7" DB w/10' SBE, 3.25" ID @ 10,080' 12. Stimulation or cement squeeze summa. Intervals treated (measured): SEE SCH , .. i.l '7\\04 Treatment descriptions including volumes u 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Well not producing prior to operations 4.1 MMCFPD 0 2,000 psi 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 at the foregoing is true and correct to the best of my knowledge. Oil-Bbl Tubing Pressure Prior to well op ation: Subsequent to eration: 14. Attachments: Copies of Logs and Surve Run Daily Report of Well 01'. ations n/a 3,673 psi Service D x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 304-209 Title Drilling Manager Phone 907-276-7600 Date 7/27/2004 nq'r;\~lAL ~~ ß!t¡~~ l_iJ J-; UNOCAL8 API# 50-133-20232-01 /""'.. /""'. Swanson River Field Soldotna Creek Unit Well SCU 42A-O5 Original Drill & Completed 1972 Re-drilled 7/81 Last Completed 04/24/89 RKB =18.5' ~ J: ... ! ... ~ e . 0 T" Po.," @583""'" iI ;¡; ,,: :s ... ~ emIR.. @8100' TD= 11,180' PBTD= 10,993' Max Deviation = 290 SCD 42A-05 Proposed dwg 5-04 Cas i n Size T e Wt Grade ID 18" Conductor 10-'1." SurfCs 40.5 K-55 10.05" 7" Prod Csg 29 N-80 6.184" 7" 23 6.366" OV Collar 7" N-80 6.366" Prod Csg 6.184" P-IIO 6.184" To 8tm Hole Cmt Cmt To Surf 74' Yes Surf Surf 3,386' 15" 1875 sx Surf Surf 73' 2100' 73 3613' 460 sx CBL 3613 3616 9-Y.' 3616 4361' 4361' 8053' 1200 sx 8120' CBL 8053' 10,410' 10,410' 10,457' 10,191' 10,994' 5" 4.276" Tobin 3-1/2" 3-1/2" 2 Yo" 18.5' 993' 10,078' 993' 10,078' 10,807' 9.2 9.3 6.5 N-80 J-55 N-80 2.992 2.992 2.441 Jewe ry Item TOD ID 00 DescriDtion 18.5' - Tubing Hanger, 2-7/8", Shaffer I 2,104' GLM, Cameo, KBUG, 3-1/2" x I" 2 10,005' GLM, Cameo, MM62, 3-1/2" x 1-1/2" 3 10,004 2.813 Profile Nipple, "X", 2.813" 4 10,078 BOT LSA wi 10' of seals 5 10,080' 3.25 Packer, 7" "DB" wi 10' SBE, 3.25" ID 6 10,774' 2.205 Nipple, 'XN', 2.205 to. PERFORATION HISTORY mIL) Interval AcCUIIL ZOne Top 8tm Amt spr -Comments 77-3 7,972' 7,982' 10' 6 Prooosed Sqz 8,014' 8,015' l' 4 Apr-72 Sqz 10,420' 10,421' I' 4 Oct-81 HI 10,875' 10,902' 27' 8 4/88 & 6/88 H2 10,917' 10,926' 9' 8 4/88 & 6/88 H3 10,958' 10,968' 10' 4 Nov-9O H4 10,978' 10,992' 14' 4 Oct-81 5/21/2004 SL T r-- ~ 6/8/04 No Operations. Slickline retrieved (3) pack-off isolation assemblies from well @ 5800', 5953' & 5990'. SDFN. 6/9/04 No Operations. Pollard in field. PJSM. Load 50 bbls on Hot Oil truck. MIRU Hot Oil truck. PT surface lines. Heat up oil to 150 deg. Pump same down tbg while working slineline conveyed brush in tbg. Worked brush to EOT. POOH. RD Hot oil truck. RIH w/ 2.86" Scratcher to 10078'. No joy going any deeper. POOH. RD. 6/15/04 No Operations. Safety meeting, rig up Pollard, pressure test lubricator to 2000 lbs and put PDS Caliper tool on. Run in hole with caliper down to 10,036' RKB and logged out at 50-55 [pm. Down load data from caliper tool. Rig down pollard and secure well 6/16/04 No Operations. Attend SIMOPS. No Operations. Safety meeting, rig up Schlumberger, pressure test 2500 lbs and MU Haliburton 2.70 Fast drill bridge plug. RIH with bridge plug and set plug at 10,065'. RIH with 1.56 perf gun, 5' long and perf tubing from 10,055' to 10,060 (21 perfs). RIH with haliburton cement retainer and set at 9990'. Rig down Schlurnberger and secure well 6/25/04 Rig up. Perform BOP test on Blind Rams (OK). Pick up Injector head and M/U 10' Hard line onto Baker connector. (Left Baker connector on coil to save time). Stab injector head on well PT Pipe Rams (OK). Unstable and make up HES Retainer Overshot with Centralizer. Hook up annulus lines to junk tank and spot cement equipment. Help Company man tie annulus and flow cross to production flow line. Get with production to line out and blow well down to tank setting. Well has 600# on production casing and tubing with no flow line to tank setting. Valve on pad to flow line is bad. Got field operator and isolated at setting and blew line down. Put valve on flow line at well pad and hook to annulus and tubing of well. Blew well to tank setting until pressure was low enough to blow to atmospheric tank. Four hours oflost time at coil spend rate because this was not done prior to rigging up coil. RIH checking weights pumping 0.3 BPM. Shut pumps down easing in hole and tag bottom 32.5' high. Circulate and try to get deeper with no luck. Talk to town about setting down high. Theorize that Retainer was set one joint high. Develop plan to analyze same. Pressure test well to 1000# (OK). Establish circulating rates setting down and also establish circulating rates hanging above retainer, All rates where down the coil and returns were switched from coil annulus to tubing 42A-05_AOGCC10-404Summary_AFE162558, last revised 7/7/2004, page 1 r-- ~ annulus both. (There is 200# to 400# deference in circulate pressures from off retainer to on retainer. NOTE: we are on the retainer it just set one tool joint higher than recorded. Mix cement chemicals while coil is circulating lease water up production annulus. Mix cement. Having problems blowing cement from one of the ABT's. Looks like the cement is going to be light. Call Evan Harness and discuss with Schlumberger our options. Schlumberger engineer said that both tanks should be in the 15.5# range if we want to pump. Time is up and he stated that he can not get any more dry products out of the one ABT. Started pumping cement. Pumping cement at 0.8 BPM. First tank of cement away recorded its weight at 15.67# per Bbls (36.7 Bbls total). Second tank of cement average 14.92# per barrel while pumping away (34.9 Bbls) Ask engineer to talk with his lab (they stated that it would be good cement) and I told them to analyzes and send report to us on 14.9# cement at a latter date. Total cement pumped 71.6 Bbls in place. Check floats(OK). Pull up above retainer circulate 47 Bbls lease water bottoms up. POOH start to rig down. 90% rigged down. Left hard line on annulus and surface tank to use on nitrogen job. Coil cost switch over to 212-27 again. 6/26/04 PJSM, Rig up Pollard, test lubricator to 2500 psi. RIH with 2.7 GR to 9994 RKB. POOH. RIH with temp tool and logged from 6200' to 9984' and back. Rig down, check gauges and secure well. Mobe in N2. Pumped down tubing with back-side open to 210Opsi. Put N2 cap on tubing. PJSM, RU Schlumberger, pressure test to 2500 psi. RIH with Owens tubing patch, logged on depth with PDS log and set patch from 6000' to 6011 '. Hole at 6005'. POOH. RIH with Owens tubing patch, logged on depth and set patch from 5969' to 5980'. Hole at 5973'. POOH. Took fluid level shot that showed fluid at 3123'. Check casing pressure and it was 620 psi. Discussed with Ken Lucas. Bled casing down and RIH with Owens tubing patch and set from 5807' to 5818'. Hole at 5815'. POOH. 6/27/04 Talk to town over fluid depth. Pressure test casing and bleed down casing. (OK) Appears as though there is a gas lift valve in the # 1 Mandrel. RIH with 10',2" 6 spfHC perf gun. Tied in with GR/CCL log 6-16-04 and perf 61 holes from 7977' to 7987'. POOH. Tubing had 706 psi and casing 0 when gun was fired. Rigged down and turned over to PTS. Flowed well. Rates increasing to 5.4 MM/D for clean up. TP varying. Shut in for pressure build up. Final TP 3940 psi. Wait on orders Look over well head with production. Some under rated fitting's in well head system that will need to be replaced. Second flow period for 3 hrs. Stablized rates of 6 MM/D and average TP 3550 psi. Dry gas - no water. Shut in for pressure build up. Rig down test equipment. Secure well. 7/1/04 42A-O5_AOGCC1D-404Summary-AFE162558, last revised 7/7/2004, page 2 ------ /"----. No operation for the time recorded. Lined up Weatherford, Schlumberger to run and set WRP Bridge Plug. MIRU Schlumberger EL equipment, Rigged up on well, pressure tested to 4,500-psi. Picked up 2.8" ring gauge. Opened well Tubing 4,000-psi, casing 1,220-psi. RIH to 2,240' wIno problems POOH. Picked up 2.79" WRP Bridge plug, RIH to 2,240' picked up got on depth and set BP @ 2,160' RKB. Pooh and rigged down Schlumberger and Weatherford. 7/2/04 Picked up 2.8" ring gauge. Opened well Tubing 4,000-psi, casing 1,220-psi. RIH to 2,240' wIno problems POOH Picked up 2.79" WRP Bridge plug, RIH to 2,240' picked up got on depth and set BP @ 2,160' RKB. Pooh and rigged down Schlumberger and Weatherford. Filled out report, lined up Pollard Slickline Held safety meeting with crew. Rigged up choke manifold, pressure tested to 4,500-psi, SL rigged down at 212-27 moved equipment to SCU 42A-5. Opened well w/4,000-psi on tubing casing 720-psi bled casing down to 150-psi gas/H20 mostly gas. Rigged up Slickline. Held Safety meeting. Bled down tubing from 4,000-psi to 1,300-psi casing from nO-psi to 200-psi, Shutdown bled off left tubing 180-psi over balanced to annulus. Picked up OM-l kickover tool & JDC. Latched valve @ 2,104' and pulled. Tubing fell to 1,1 OO-psi Casing went to 400-psi Pooh with valve. Rigged up Schlumberger N2 Unit to tubing. Pressure tested lines to 4,500-psi. Jetted 37-bbls. packer fluid around @ 500-scfm with 1,200-psi tubing pressure, 460-psi casing pressure, unloading back side fluid to mini frac tank. Final tubing pressure 900-psi, casing 440-psi. (Jetted with 25,500-scfN2, 334-scfN2 per barrel space Totaled 76-barrels circulated). Picked up Daniels KlO tool wldummy GL V to 2,104' and set. POOH. Displaced 38,000-scfN2 tubing 4,500-psi (l,437-scfN2 per barrel of space total displaced 26.44-bbls., casing 695-psi Held tight for I-hour. Casing slowly started increasing. Tubing down to 4,300-psi pressure back up to 4,475-psi. Installed pressure chart on casing. Secured well for the night. 1800 Hour Tubing 4,475-psi, Casing 760-psi. 0350 Tubing 4,425 psi, Casing 1,025-psi Pressure increased 265-psi in 10-hours, (26.5-psi per hour) Tubing pressure fell 50-psi in 10-hours. 42A-05_AOGCC10-404Summary_AFE162558, last revised 7/7/2004, page 3 API# 50-133-20232-01 CURRENT COMPLETION Swanson River Field Soldotna Creek Unit Well SCU 42A-O5 Original Drill & Completed 1972 Re-drilled 7/81 Last Completed 06/27/04 UNOCAL8 RKB =18.5' Cas i n & Size T e Wt Grade ID To Btm Hole Cmt Cmt To 18" Conductor Surf 74' Yes Surf. 10-0/." SurfCs 40.5 K-55 10.05" Surf 3,386' IS" 1875 sx Surf 7" Prod Csg 29 N-80 6.184" Surf 73' 2100' 7" 23 6.366" 73 3613' 460 sx CBL OV CoUar 3613 3616 9-y." 6.366" 3616 4361' Prod Csg N-80 6.184" 4361' 8053' 1200 sx 8120' CBL polIO 6.184" 8053' 10,410' T,," ..."'... 10,410' 10,457' @5815'."'73' "'..' 5" 4.276" 10,191' 10,994' Tobin "f'l 3-1/2" 9.2 N-80 2.992 18.5' 993' i.'::! 3-1/2" 9.3 J-55 2,992 993' 10078' ~a ..-. 27/8" 6.5 N-80 2.441 10,078' 10,807' ... :'¡I ;:~ J .. .. '" ewe ry Item Top ID 00 Description 18.5' - - Tubing Hanger, 2-7/8", Shaffer 1 2,104' GLM, Cameo, KBUG, 3-1/2" x I" 5807' 2.313 Owens Tbt! Patch (ÍÌ), 5807' to 5818' 5969' 2.313 Owens Tbt! Patch (ÍÌ), 5969' to 5980' 6000' 2.313 Owens Tbt! Patch (ÍÌ), 6000' to 6011' 9,990' - FasDrill Retainer 2 10,004 2.813 Profile Nipple, "X", 2.813" 3 10,005' GLM, Cameo, MM62, 3-1/2" x 1-1/2" to 065' -- FasDrill BP 4 10,078 BOT LSA wI 10' of seals 5 10,080' 3.25 Packer, 7" "DB" wI 10' SBE, 3.25" ID 6 10,774' 2.205 Nipple, 'XN', 2.205 J.D. 6 PERFORATION HISTORY Interval Accorn. Zone Top Btm Amt spf Comments 77-3 7,977' 7,987' 10' 6 6/27/2004 Sqz 8,014' 8,015' I' 4 Apr-72 Sqz 10,420' 10,421' l' 4 Oct-81 HI 10,875' 10,902' 27' 8 4/88 & 6/88 H2 10,917' 10,926' 9' 8 4/88 & 6/88 H3 10,958' 10,968' 10' 4 Nov-90 H4 10,978' 10,992' 14' 4 Oct-81 1D= 11,108' PB1D= 10,993' Max De"ation = 29° SCD 42A-05 Actual dwg 7-04 5/21/2004 SL T 6/8/04 No Operations. Slickline retrieved (3) pack-off isolation assemblies from well @ 5800', 5953' & 5990'. SDFN. 6/9/04 No Operations. Pollard in field. PJSM. Load 50 bbls on Hot Oil truck. MIRU Hot Oil truck. PT surface lines. Heat up oil to 150 deg. Pump same down tbg while working slineline conveyed brush in tbg. Worked brush to EOT. POOH. RD Hot oil truck. RIH w/ 2.86" Scratcher to 10078'. No joy going any deeper. POOH. RD. 6/15/04 No Operations. Safety meeting, rig up Pollard, pressure test lubricator to 2000 lbs and put PDS Caliper tool on. Run in hole with caliper down to 10,036' RKB and logged out at 50-55 fpm. Down load data from caliper tool. Rig down pollard and secure well 6/16/04 No Operations. Attend SIMOPS. No Operations. Safety meeting, rig up Schlumberger, pressure test 2500 lbs and MU Haliburton 2.70 Fast drill bridge plug. RIH with bridge plug and set plug at 10,065'. RIH with 1.56 perf gun, 5' long and perf tubing from 10,055' to 10,060 (21 perfs). RIH with haliburton cement retainer and set at 9990'. Rig down Schlumberger and secure well 6/25/04 Rig up. Perform BOP test on Blind Rams (OK). Pick up Injector head and MID 10' Hard line onto Baker connector. (Left Baker connector on coil to save time). Stab injector head on well PT Pipe Rams (OK). Unstable and make up HES Retainer Overshot with Centralizer. Hook up annulus lines to junk tank and spot cement equipment. Help Company man tie annulus and flow cross to production flow line. Get with production to line out and blow well down to tank setting. Well has 600# on production casing and tubing with no flow line to tank setting. Valve on pad to flow line is bad. Got field operator and isolated at setting and blew line down. Put valve on flow line at well pad and hook to annulus and tubing of well. Blew well to tank setting until pressure was low enough to blow to atmospheric tank. Four hours of lost time at coil spend rate because this was not done prior to rigging up coil. RIH checking weights pumping 0.3 BPM. Shut pumps down easing in hole and tag bottom 32.5' high. Circulate and try to get deeper with no luck. Talk to town about setting down high. Theorize that Retainer was set one joint high. Develop plan to analyze same. Pressure test well to 1000# (OK). Establish circulating rates setting down and also establish circulating rates hanging above retainer. All rates where down the coil and returns were switched from coil annulus to tubing annulus both. (There is 200# to 400# deference in circulate pressures from off retainer to on retainer. NOTE: we are on the retainer it just set one tool joint higher than recorded. 42A-05_AOGCC10-404SummarLAFE162558, last revised 8/20/2004, page 1 Mix cement chemicals while coil is circulating lease water up production annulus. Mix cement. Having problems blowing cement from one of the ABT's. Looks like the cement is going to be light. Call Evan Harness and discuss with Schlumberger our options. Schlumberger engineer said that both tanks should be in the 15.5# range if we want to pump. Time is up and he stated that he can not get any more dry products out of the one ABT. Started pumping cement. Pumping cement at 0.8 BPM. First tank of cement away recorded its weight at 15.67# per Bbls (36.7 Bbls total). Second tank of cement average 14.92# per barrel while pumping away (34.9 Bbls) Ask engineer to talk with his lab (they stated that it would be good cement) and I told them to analyzes and send report to us on 14.9# cement at a latter date. Total cement pumped 71.6 Bbls in place. Check floats(OK). Pull up above retainer circulate 47 Bbls lease water bottoms up. POOH start to rig down. 90% rigged down. Left hard line on annulus and surface tank to use on nitrogen job. Coil cost switch over to 212-27 again. 6/26/04 PJSM, Rig up Pollard, test lubricator to 2500 psi. RIH with 2.7 GR to 9994 RKB. POOH. RIH with temp tool and logged from 6200' to 9984' and back. Rig down, check gauges and secure well. Mobe in N2. Pumped down tubing with back-side open to 2100psi. Put N2 cap on tubing. PJSM, RV Schlumberger, pressure test to 2500 psi. RIH with Owens tubing patch, logged on depth with PDS log and set patch from 6000' to 6011'. Hole at 6005'. POOH. RIH with Owens tubing patch, logged on depth and set patch from 5969' to 5980'. Hole at 5973'. POOH. Took fluid level shot that showed fluid at 3123'. Check casing pressure and it was 620 psi. Discussed with Ken Lucas. Bled casing down and RIH with Owens tubing patch and set from 5807' to 5818'. Hole at 5815'. POOH. 6/27/04 Talk to town over fluid depth. Pressure test casing and bleed down casing. (OK) Appears as though there is a gas lift valve in the # 1 Mandrel. RIH with 10',2" 6 spfHC perf gun. Tied in with GR/CCL log 6-16-04 and perf 61 holes from 7977' to 7987'. POOH. Tubing had 706 psi and casing 0 when gun was fired. Rigged down and turned over to PTS. Flowed well. Rates increasing to 5.4 MM/D for clean up. TP varying. Shut in for pressure build up. Final TP 3940 psi. Wait on orders Look over well head with production. Some under rated fitting's in well head system that will need to be replaced. Second flow period for 3 hrs. Stablized rates of 6 MM/D and average TP 3550 psi. Dry as - no water. Shut in for pressure build up. Rig down test equipment. Secure well. 7/1/04 No operation for the time recorded. Lined up Weatherford, Schlumberger to run and set WRP Bridge Plug. MIRV Schlumberger EL equipment, Rigged up on well, pressure tested to 4,500-psi. Picked up 2.8" ring gauge. Opened well Tubing 4,000-psi, casing 1,220-psi. RIH to 2,240' wino problems POOH. Picked up 2.79" WRP Bridge plug, RIH to 2,240' picked up got on depth and set BP @ 2,160' RKB. Pooh and rigged down Schlumberger and Weatherford. 42A-05_AOGCC10-404SummarLAFE162558, last revised 8/20/2004, page 2 7/2/04 Picked up 2.8" ring gauge. Opened well Tubing 4,000-psi, casing 1,220-psi. RIH to 2,240' wIno problems POOH Picked up 2.79" WRP Bridge plug, RIH to 2,240' picked up got on depth and set BP @ 2,160' RKB. Pooh and rigged down Schlumberger and Weatherford. Filled out report, lined up Pollard Slickline Held safety meeting with crew. Rigged up choke manifold, pressure tested to 4,500-psi, SL rigged down at 212-27 moved equipment to SCU 42A-5. Opened well w/4,000-psi on tubing casing 720-psi bled casing down to 150-psi gas/l-I20 mostly gas. Rigged up Slickline. Held Safety meeting. Bled down tubing from 4,000-psi to 1,300-psi casing from 720-psi to 200-psi. Shutdown bled off left tubing 180-psi over balanced to annulus. Picked up OM-1 kickover tool & JDC. Latched valve @ 2,104' and pulled. Tubing fell to 1, 1 DO-psi Casing went to 400-psi Pooh with valve. Rigged up Schlumberger N2 Unit to tubing. Pressure tested lines to 4,500-psi. Jetted 37-bbls. packer fluid around @ 500-scfm with 1,200-psi tubing pressure, 460-psi casing pressure, unloading back side fluid to mini frac tanle Final tubing pressure 900-psi, casing 440-psi. (Jetted with 25,500-scfN2, 334-scfN2 per barrel space Totaled 76-barrels circulated). Picked up Daniels KlO tool w/dummy GL V to 2,104' and set. POOH. Displaced 38,000-scfN2 tubing 4,500-psi (l,437-scfN2 per barrel of space total displaced 26.44-bbls., casing 695-psi Held tight for I-hour. Casing slowly started increasing. Tubing down to 4,300-psi pressure back up to 4,475-psi. Installed pressure chart on casing. Secured well for the night. 1800 Hour Tubing 4,475-psi, Casing 760-psi. 0350 Tubing 4,425 psi, Casing 1,025-psi Pressure increased 265-psi in 10-hours, (26.5-psi per hour) Tubing pressure fell 50-psi in 10-hours. 42A-05_AOGCC10-404Summary-AFE162558, last revised 8/20/2004, page 3 "Information >Well >Directional Surveys >Full Survey Select Well: SCU 42A-05 - ~ ~ Report Name Well Date Created Position Log SCU 42A-05 8/17/2004 Well Name CURRENT STATUS API KB Surf X Surf Y (ft) (ft) (ft) InterpOlåte SCU 42A-05 OIL 501332023201 167 341,868 2,457,903 MD TVD SSTVD X Off Y Off X Y Inc Azimuth (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (deg) 0 0 167 0 0 341,868 2,457,903 0.0 0 378 377 -210 2 -1 341,870 2,457,902 0.8 123 902 901 -734 4 0 341,872 2,457,903 0,0 0 1,394 1,393 -1,226 5 0 341,873 2,457,903 0.3 45 1,898 1,897 -1,730 5 2 341,873 2,457,905 0.3 301 2,395 2,394 -2,227 3 1 341,871 2,457,904 0.3 140 2,899 2,898 -2,731 5 2 341,873 2,457,905 0.3 0 3,385 3,384 -3,217 3 2 341,871 2,457,905 0.5 210 4,283 4,282 -4,115 9 -5 341,877 2,457,898 1.3 74 4,719 4,718 -4,551 20 -2 341,888 2,457,901 1.7 69 5,232 5,231 -5,064 38 3 341,906 2,457,906 2.5 75 5,369 5,368 -5,201 43 4 341,911 2,457,907 2.5 80 5,674 5,673 -5,506 54 8 341,922 2,457,911 1.7 66 5,730 5,728 -5,561 54 9 341,922 2,457,912 1.3 270 5,765 5,763 -5,596 53 8 341,921 2,457,911 2.5 247 5,796 5,794 -5,627 51 8 341,919 2,457,911 3,5 260 5,901 5,899 -5,732 41 9 341,909 2,457,912 7.5 288 5,965 5,962 -5,795 32 12 341,900 2,457,915 9.3 289 6,028 6,024 -5,857 22 15 341,890 2,457,918 10.3 289 6,069 6,065 -5,898 16 18 341,884 2,457,921 10.0 298 6,117 6,112 -5,945 9 23 341,877 2,457,926 10.3 323 6,243 6,235 -6,068 -4 47 341,864 2,457,950 15.0 333 6,446 6,428 -6,261 -31 102 341,837 2,458,005 20.3 336 6,590 6,563 -6,396 -50 148 341,818 2,458,051 20.3 339 6,775 6,736 -6,569 -75 210 341,793 2,458,113 22.3 337 7,019 6,959 -6,792 -110 303 341,758 2,458,206 25.5 341 7,084 7,017 -6,850 -119 329 341,749 2,458,232 26.0 341 7,150 7,076 -6,909 -128 358 341,740 2,458,261 28.5 346 7,343 7,245 -7,078 -146 450 341,722 2,458,353 29.5 352 7,468 7,354 -7,187 -153 510 341,715 2,458,413 28.0 354 7,522 7,402 -7,235 -156 535 341,712 2,458,438 27.8 354 7,694 7,555 -7,388 -163 613 341,705 2,458,516 26.5 356 7,956 7,792 -7,625 -169 725 341,699 2,458,628 24.3 358 8,119 7,942 -7,775 -171 789 341,697 2,458,692 21.8 358 8,256 8,069 -7,902 -172 839 341,696 2,458,742 21.5 360 8,446 8,246 -8,079 -174 908 341,694 2,458,811 21.0 357 8,510 8,306 -8,139 -175 931 341,693 2,458,834 20.8 358 8,604 8,394 -8,227 -175 964 341,693 2,458,867 20.3 1 8,662 8,449 -8,282 -174 983 341,694 2,458,886 19.5 5 8,758 8,539 -8,372 -170 1,016 341,698 2,458,919 20.0 7 8,903 8,675 -8,508 -162 1,065 341,706 2,458,968 20.8 11 9,066 8,827 -8,660 -150 1,123 341,718 2,459,026 21.5 14 9,322 9,065 -8,898 -127 1,215 341,741 2,459,118 22.3 14 9/602 . 9/324 -9/157 -98 1/318 341/770 2/459/221 22,5 17 9/831 9/535 -9/368 -74 1/402 341J94 2/459/305 22.3 15 10/077 9J64 -9/597 -50 1/489 341/818 2/459/392 21.0 16 10/327 9/998 -9/831 -25 1/574 341/843 2/459/477 20.5 17 10/416 10/081 -9/914 -16 1/604 341/852 2/459/507 20.6 17 10/453 10)15 -9/948 -13 1/618 341,855 2/459/521 25.0 7 10J80 10/410 -10/243 7 1/759 341/875 2/459/662 26.5 10 10/993 10/600 -10/433 27 1/853 341/895 2/459/756 27.5 13 11/180 10/765 -10/598 46 1/937 341/914 2/459/840 27.5 13 11/230 10/810 -10/643 51 1/960 341/919 2/459/863 27.5 13 Contract: Contract Name of Work Describe the Scope of Work. What type of wells are going to be drilled. What services, equipment, and personnel are required for this? What geographical area is being covered? Are multiple business units affected? Is it going to be consistent or stop/start? What is the term of the projects? Other Business Units Contractor ~~ ~.~--~ Thailand 11/112099 Indonesia 1/112099 Gulf of Mexico 1/112099 .m Pure 1/112099 Alaska 1 / 112099 Exgiration Date ----- .J .J =--:1 Contract: ContractName CUrrent Market Conditions Describe the current market for the goods and services of this contract. Vendors Rank by ,$ I VendorName: 1 Describe the strengths and weaknesses of the vendor. Rank by $ I Vendor Name: 2 Describe the strengths and weaknesses of the vendor. Abandon U Alter casing 0 Change approved program 0 2 Operator Name Union Oil Company of California 3. Address' 1 Type of Request PO Box 196247, Anchorage. AK 99519 7 KB Elevation 1ft). 16:" KB 8 Property Designation. Soldotna Creek Unit 11 . Total Depth MD (ft). 11,180' Total Depth TVD (ft). 10.797' Length Casing Structural Conductor 74' 3.386' Surface Intermediate Production Liner 10.457' 10.994' Perforation Depth MD (ft). 7.97ì to 10.992' Packers and SSSV Type: . STATE OF ALASKA ALA~ . OIL AND GAS CONSERVATION COMM JION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool 0 4. Current Well Class: Suspend U Repair well 0 Pull Tubing D wc:¡Æ '( ¿~'I¿CC4 Perforate U Waiver U Annular Dispos U Stimulate D Time Extension D Other D Repair tubing integrity issue ./ 5. Permit to Drill Number Development Stratigraphic 0 0 Service Exploratory 0 ~ I ~O .- 0 ¿, lN61t- 0 6 API Number: 50-133-20232-01 ,,"" / 9. Well Name and Number' SCU 42A-05 / 10. Field/Pools(s): Swanson River Fieldl Tyonek. Hemlock PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10.993' 10.599' Size MD Plugs (measured): TVD 18" 10-3/4" 74' 3.386 74' 3.385' 7" 5" 1 0.457' 1 0.994' Tubing Size: 10,119' 1 0.601' Tubing Grade: Perforation Depth TVD (ft): 7.811 to 10.599 7" DB w/1 O' SBE. 3.25" ID 3-1/2"; 3-1/2"; 2-7/8" N-80: J-55; 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 Date: 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: 6/10/2004 Oil 0 Gas [;] WAG 0 GINJ 0 Commission Representative. 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Philip J. Krueger Title Drilling Manager Phone 907 -276-7600 Date COMMISSION USE ONLY Slgnalure ~I Fn-r Contact Junk (measured¡: Burst Collapse 3,130 psi 1 580 pSI 6.340 psi 3.830 pSI 10,140 psi 10.490 psi Tubing MD (ft). 993'.10.078',10.80T 10.080' [J Service 0 Plugged WINJ 0 0 WDSPL Abandoned u u Steve Tyler (907-263-7649) Conditions of approval: Notify Commission so that a representative may witness Plug Integrity U BOP Test 0 Other ./ . ¡fl\ ~.. f' 'I l\iB(M§¡ lt$\t f£- Sundry Number: Mechanical Integrity Test 0 Location Clearance ORIGINAL COMMISSIONER BY ORDER OF THE COMMISSION , . - II \\ 1~,sT~~WIONS ON REVERSE IA~~' w ,., ,j.~' ~ 7/27/2004 .3o'f- - 02- tl~ 0 I' . I , " .',i ¡ii',' Date: ~~yv Submit in Duplicate 1. Workover Summary: 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. Prep-Work- SI well. RU Eline. RIH set Baker IBP @ 7900'. Dump bail 20' of sand on top of I BP. Bleed well pressure down to 1500 psi. Prep-Work- MIRU hot oil truck. Lubricate tbg full wi 140° lease water RIH wi SCMT. Log from 7850' to 5700'. Prep-Work- .RIH perf 6' tbg punch gun, 5' above TOC. Establish circulation wi 140° lease water until returns are noted @ I surface. Mobe 1-3/4" Coil Unit and cement equipment to Location. Mobe/Spot Coil Unit & accessory equipment on liner. Berm in same. CT - NU 3-118" 5m x 4-1/6" 10m adapter flng, Pump-in Sub, Riser & BOP's. Rig up coil tubing unit. RU surface lines. CT - Thread 1-3/4" CT into injector head. Fill CT. Drift CT wi Hippo Turbo & 1.30" ball. MU CTC & test plate. Pull & pressure test CTC. Pressure test BOPE. .' CT - MU MHA & Cmt nozzle. Shell test BOPE. CT - RIH wi CT to -7200' or within 50' of top of tbg punch. Establish ./ circulation down CT while taking return up tbg x csg annuli. CT - Mix/pump' 127 bbls of cement (635 sx) down CT while taking return up tbg x tsg annuli to bring TOC in tbg x csg annuli to 2200'. Over displace CT by % bbl. WOC. CT - RI cleanout excess cmt and sand to IBP. PU to 1500'. RIH jetting tbg dry wi N2 to IBP. POOH. Secure well. RD Demobe CT. Pressure tbg to 3900 psi wI N2. WL - RU Slickline. PU MU IBP Retrieving tool. RIH latch & release IBP @ 7900'. POOH. RD Slickline. Secure operations UNOCAL8 ,.\ PI# 50-1.13-20232-01 RKB =18$' k~ b. '. ~ :,) ~~ ~ ;..., ~,. ~',4- Î~ ó ~ i !! rhR. Pun.:h,. ,iI ~RIC:' ~"",' &.".....~. 6 ~Çj ¡'.J ~ ,~ ': ,'-' cc. ..J 'oJ " l ~ ..:; ] ~~.. ~. .(, ~\) ~ ít :.~ ~, \~ J '~.,... ...... ......,~....... . '''''''. ...... "". ,., , I!"'~''''~ '''''''.' " ----: '-_:_5:-::~ J ill= 11,1 OS' PBll>= 10.993' !\Iu De\iarion = 29': SCU 42A-05 Actual d\\g 7-04 ClIRRENT CO~IPLETIONI C a s i n 9 Size Type Wt Grade ID IS" CünJucwr 10-,';' Surf Csg 40.5 K-55 10 05" 7" Prod (5g 29 N-80 6.184" T' 23 6.366" D\' Collar T 23 N-SO 6.366" 7" Prod C sg 29 6.184" T 29 P-IIO 6.\ 84" 7" \\'indo~, Cut on 9/81 5" I Liner I 18 N-SO I 4276" Tubing 3-1:2"' 9.2 N-SO 2.992 3-1.'2" 9.3 J-55 2.992 2 7 8" 6.5 N-SO 2.441 Item S" anson Rher Field Soldotna Creek Unit \\'ell SClI 42:\-05 Original Drill & Completed 1972 Re-drllled 7,'81 La~t Completed 06/27/04 & Tu b i n 9 Top Btm Hole Cmt Cmt Top Sur ' 7-r Yö Sur!'. Surf 3,386' 15" ] 875 5X Surf Surf 73' 2100' 73 3613' 460 SX CBL 3613 3616 \)' " 3616 4361' - ~ 4361' 8053' 1200 sx 8120' CBL 8053' 10.410' 10.410' 10.457' 10,191' I O,()94' 6" 18.5' 993' 10,078' 993' 10,078' 10,807' 2 3 Top 18.5' :!.Io-r !'S07' !'969 , 6000' 9,990' 10.00-1 10.005' IO,06!" 10.078 10.Of:,O' 10.77-1' Jewelry OD Description TuÞmg Hanger. ~-7 8". Shaffer GL~I. Cameo, KBUG, 3.) ~":< I" O\\en\ Tb~ Patch ,ii, !'807' to !'SIS' O\\en\ Tbg Patch ,å' !'969' to 59S0' O\\en\ Tb~ Patch ,~ 6000' to 60 II' Fa\Drill Retainer Profile Nipple, "X", ~.813" GL~1. Cameo. M~16~. 3-1 ~.. x I-I 2" Fa\Drill BP BOT LSA \\ ) 0' of seab Packer, 7" "DB" \\ 10' SBE. 3.~5" 10 Nipple. 'XN'. ~.~O5 I.D ID 2..~B 20.'13 2.-'B 2.813 4 5 6 325 ~.205 Zone 77-3 Sqz Sqz HI H2 H3 H~ PERFORATION HISTORY Inten'al Accum, Top 8tm Amt spf 7,977' 7,987' 10' 6 8,OI~' 8,015' I' 4 10,420' 10,42 I' I' 4 10,875' 10,902' 27' 8 10,917' 10,926' 9' 8 10,958' 10,968' 10' 4 10,978' 10,992' 14' 4 Comments 6/27/2004 Apr-72 OcI-81 4,88 & 6 '88 4,88 & 6 88 No\'-90 Oct -8 I 5/21 2004 SL T UNOCALe :\ PI# ~O-133-:!()232-01 RKB =185' 1,' ~t - 6 ~~ "I.! ~~: ~î ~ ....: ~~. 'Þ;" ~:; ':\ 'j.: '.~ ;, ~~ :';;.... ....J '~ ...:;~)~(~t1<..~ê'<..~Ô'<..~~~;'~ ~:sc--::. J J TO= 11,10S' PBTO= 10,993' !\Iall. Oe\ iation = ~9' sell ..r~A-05 Proposed d\\g 07-04 Sizl' IS" 10-) ;' .,.. I 5" Tubing 3-]'~" 3-1 ~.. ~ 7' 8" S\\ an son Rher Field Soldotna Creek llnit "'ell SClI 42:\-05 Original Drill & Complet~d 1972 Re-drilled 7,'81 La~t Completed 06/27/0..a PROPOSED CO!\1 PLETION Type C 0ndu':lùr Surf Csg Prod C sg Item Prod C ~g Hole Cmt Cmt Top Yes Sur!' 15" 1875 sx Surf 460 sx 2100' CBL Q-'," 1200 S:\ 8120' CBL 6" C a s i n 9 & T u b i n 9 Wt Grade ID Top Btm Surf '4' 405 K-55 10.05" Surf 3.386' 29 N-80 6.184" Surf ;3' T' 23 6.366" 73 3613' D\' Collar 3613 3616 7" 23 N-80 6.366" 3616 4361' T 29 6.184" 4361' 8053' T' 29 P-110 6 I 84" 8053' 10AIO' 7" \\ indo"', Cut on 9/81 10,410' I OA57' I IS N-SO I 4.276" 10,191' 10,994' N-80 2.992 IS.5' 993' J-55 2.992 993' 10,078' N-SO 2,441 lÜ,07S' 10,807' Liner 9.2 9.3 6.5 2 3 Top 18S :!,I04' SSOT S969' 6000' 9,990' 10.004 10.005' 1O,06S' 10.078 10.080' 10:17 -I' ID Jewelry OD Description Tubmg Hangt'r. :!-7 8". Shaner GLI\1. Cameo. KBUG. 3-1 ~":-. I . O\\en~ Tb~ Pluch ,ii SS07' to SSIS' O\\en\ Tbg Palch ,ü' S969' 10 S9!10' O\\en... Thg Palch ,ii, MOO' 106011' Fa\Orill Relaint'r Profile Nipplt'. "X". :!.813" GLI\I. Cameo, 1\111.162. 3-12'" '( I-I 2" Fa...Orill BP BOT LSA \\ 10' of seab Packt'r. T' "DB" \\ 10' SBE. 3.25" ID Nipple. 'XN'. 2.2051.0. 2..H.~ 2..l1.l UB :!.813 .¡ 5 6 3.25 ~.205 Zone 77-3 Sqz Sqz HI H2 H3 H'¡ PERFORATION HISTORY Inten-a1 Accum. Top 8tm Amt spf 7.977' 7.987' 10' 6 8,014' 8,015' \' 4 IOA20' IOA21' I' .¡ 10,875' 1O,90::!' 27' 8 10,917' 10,926' 9' 8 10,958' 10,968' 10' .¡ 10,978' 10.992' I'¡' .¡ Comments 6/27/200'¡ Apr-72 Oct-81 .¡ 88 & 6 88 .¡ 88 & 6 88 Nû\'-90 Oct-81 5 2 I 2004 SL T t ðc" - I 0 & Subject: Swanson River SCU 42A-5 annulus communication From: "Greenstein. Larry P" <greensteinlp@unocal.com> Date: Thu. 15 Jul 2004 13:46:04 -0800 To: "Winton Aubert @ AOGCC" <winton_aubert@admin.state.ak.us>, "Stan Porhola @ BLM" <Stan_Porhola@ak.blm.gov> CC: "Myers, Chris S" <myersc@unocal.com> As we discussed. the SRF shallow gas well 42A-5 has developed communication between the 3 1/2" tubing and the 7" casing. The well was shut-in upon this discovery. This well used to be a Hemlock gas-lifted oil well and was recently recompleted as a shallow gas well. The shut-in tubing pressure approached 4000#. During the initial testing of the newly perforated shallow gas zone. the annulus pressure was seen slowly rising up to 2000#. Bleeding down the annulus to 500# occurs as needed. The well has been shut-in while we worked up a safe plan and notified AOGCC & BLM. Our plan is to put this well into temporary production for testing the gas reservoir. The annulus will have a pressure transmitter installed so the plant control room can monitor the pressure. A PSV will be installed with a set pressure of 1900# as a back up to the bleed down by the operators and control room monitoring. The outer annuli are being monitored daily and have remained at a stable low pressure «100#). Permanent production facilities will be installed at a later date and will address these concerns as we learn more about the potential of this well. Thanks Larry ... Abandon ~ 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): 167' KB 1. Type of Request: 8. Property Designation: Soldotna Creek Unit 11. Total Depth MD (ft): 11,180' Casing Structural Total Depth TVD (ft): 10,797' Length Conductor Surface 74' 3,386' Intermediate Production ~ STATE OF ALASKA 1"""\ ALAL..A OIL AND GAS CONSERVATION COMM,....dION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 / Stratigraphic 0 I)?J '/71 ~ Suspend U Repairwell 0 Pull Tubing 0 Perforate U Waiver U Annular Dispos. U /imulate 0 Time Extension 0 Other 0 P&A Hemlock, Recomplete Tyonek 5. Permit to Drill Number: 1ß6A- ~ ~IÞ~""fp 6. API Number: 50-133-20232-01 /' Exploratory 0 Service 0 9. Well Name and Number: SCU 42A-05 / 10. Field/Pools(s): ~v' i~/V) rf Swanson River Field/ Tyonek, Hemlock PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10,993' 10,599' Size MD Plugs (measured): Junk (measured): Burst Collapse TVD 18" 74' 74' 10-3/4" 3,386 3,385' 1 ,580 psi 3,130 psi 10,457' 10,119' 1 0,994' 1 0,601' Tubing Size: Tubing Grade: 3-1/2"; 3-1/2"; 2-7/8" N-80; J-55; N-80 Packers and SSSV MD (ft): 6,340 psi 3,830 psi 10,140 psi 10,490 psi Tubing MD (ft): 993'; 10,078'; 10,807' Liner 10,457' 7" 10,994' 5" Perforation Depth TVD (ft): Perforation Depth MD (ft): 8,014 to 10,992' Packers and SSSV Type: 7" DB w/10' SBE, 3.25" ID 10,080' 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Philip J. Krueger Title Drilling Manager Sigoat"", r/ /r:-r Pho"" 90~~::::ON USE ONLY Oste 13. Well Class after proposed work: Exploratory 0 Development /" 15. Well Status after proposed ,rk: 6/10/2004 Oil 0 Gas 0 Plugged WAG 0 GINJ 0 WINJ Abandoned WDSPL 0 0 ,/ Service 0 0 0 0 Date: Contact Steve Tyler (907-263-7649) 6/1/2004 Conditions of approval: Notify Commission so that a representative may witness SUndry Number: Plug Integrity 0 BOP Test 0 Other: Approved by: Mechanical Integrity Test 0 304 - ;) oqL/ LocationClearance RECEIVED JUN 021004 A\aska Oi\ & Gas Cons. Commission Anchorage ~ Bf\. 1U~ 0 8 ?{\~4 BY ORDER OF : h~ COMMISSIONER THE COMMISSION Date: 6( ?. tJtf" INSTRUCTIONS ON REVERSE 0 RIG I N A L Submit in Duplicate ,~ r----.. SCU 42A-O5 Workover Summary . MIRV Slickline. Retrieve straddle pack-offs . Gauge tbg strings. Tag for fill. Brush tbg. . PUMV memory caliper survey tools. Log tbg from 8150' to surface. RD Slickline. ,,/ . MIRV Eli~ RIH set 3-1/2" Fas Drill Bridge Plug @ 10,070'. RIH punch 3-1/2" tbg @ 10,060'. RIH set 3-1/2" retainer @ 10,000'. RD Eline. /' . MIRV 1-3/4" CT unit and cementers. RIH wi polish stinger. Stab into retainer @ 10,000'. . Establish circu1 IOn r e & pressures down CT, out tbg x csg annulus. Circulate/p 73 Is of cement to bring TOC in tbg x csg annuli to 7200'. PV above retainer. U. POOH. RD CT and cement equipment. . MIRV slickline. RIH wi quick temp memory tool to 9000'. POOH. Review log results for depiction ofTOC. . WOC for 72 hrs. . MIRV Eline. RIH set Owens tbg patches to straddle tbg punch holes @ 5990' & ( / 5835'. Correlate patches to caliper survey. . Arm 10' x 2.5", 6spf, PowerJet HC gun. RIH perforate 77-3 sand @ 7972' - 7982'. /" / ~~ .c- ~-I«r . Turn well over to production UNOCAL APl# 50-133-20232...01 RKB =18.5' b. ~ ~ § ð is 5 T~gPutt<h" @ 5835& 59~ B'm@8OO0' N " @ u 0 ... 15 Sqz @ 10,420 ~ § U 0 ... ;ì u ] ] ..... TD= 11,180' PBTD;: 10,993' Max Deviation = 29° SCD 42A-05 Actual dwgl CURRENT COMPLETION Wt 5 Grade ID Size Type 18" Conductor 10-%" SurfCsg 40.5 K-55 7" Prod Csg ~ N-80 7" 23 DV Collar 10.05" 6.184" 6.366" 7" HH N-80 16.366" 7" Prod Csg 29 6.184" 7" 29 P-ll0 6.184" 7" Window. Cut on 9/81 5" I Liner I 18 I N-80 14.276" Swanson River Field Soldotna Creek Unit Well SCU 42A-O5 Original Drill & Completed Re-drilled 7/81 Last Completed 9 & Top Btm Hole Cmt Cmt Top Surf 74' Yes Surf. Surf 3,386' 15" 1875 sx Surf Surf 73' 2100' 73 3613' 460 sx CBL 3613 3616 9-;;'" 3616 4361' 4361' 8053' 1200 sx 8120' CBL 8053' 10,410' 10,410' 10,457' 10,191' 10,994' 6" 75 sx CBL Tubing 3-112" 9.2 N-80 2.992 18.5' 993' 3-112" 9.3 J-55 2.992 993' 10,078' 27;'" 6.5 N-80 2.441 10,078' 10,807' Top 18.5' 2,104' 10,005' 10,004 10,078 10,080' 10,774' Jewelry OD Description Tubing Hanger, 2-7/8", Shaffer GLM, Cameo, KBUG, 3-1/2" x I" GLM, Cameo, MM62, 3-112" x 1-1/2" Profile Nipple, "X", 2.813" BOT LSA wi 10' of seals Packer, 7" "DB" wI 10' SBE, 3.25" 1D Nipple, 'XN', 2.205 J.D. Item ID 1 2 3 4 5 6 2.813 3.25 2.205 Straddle Pack-oris installed: 5990' to 6008' 5953' to 5963' 5800' to 5807' Zone Sqz Sqz HI H2 H3 H4 PE~~~TIONJUSTORY f~~~ Top Btm Amt spf 8,014' 8,015' l' 4 10,420' 10,421' l' 4 10,875' 10,902' 27' 8 10,917' 10,926' 9' 8 10,958' 10,968' 10' 4 10,978' 10,992' 14' 4 Comments Apr-n Oct-81 4/88 & 6/88 4/88 & 6/88 Nov-90 Oct-81 5/21/2004 SLT UNOCAL API# 50-133-20232-01 b. ~ ~ @J u is Thg Pno,h" @5835&5990 ~ g @J u 0 ... ..¡ = u J J ] TD= 11,180' PBTD;: 10,993' Max Deviation = 290 SCU 42A-05 Proposed dwg#2 5-04 PROPOSED COMPLETION! Casin~ Grade ID Size Trpe 18" Conductor 10-%" SurfCsg 40.5 K-55 7" Prod Csg ~ N-80 7" 23 DV Collar ~ ProdCsg I;~ I T-j 29 7" Window. Cut on 9/81 Wt 10.05" 6.184" 6.366" N-80 16.366" 6.184" P-I10 6.184" 5" Tubing 3-1/2" 3-1/2" 118 1 N-80 I 4.276" Liner 9.2 9.3 6.5 N-80 J-55 N-80 2.992 2.992 2.441 21's" Swanson River Field Soldotna Creek Unit Well SCU 42A-O5 Original Drill & Completed 1972 Re-drilled 7/81 Last Completed 04/24/89 & T ubi n~g Top Htm Hole Surf 74' Surf 3,386' Surf 73' 73 3613' 3613 3616 3616 43.61' 4361' 8053' 8053' 10,410' 10,410' 10,457' 10,191' 10,994' 18,5' 993' 10,078' Cmt Cmt Top Yes Surf. 1875 sx Surf 460 sx 2100' CBL 1200 sx 8120' CBL 75 sx CBL 15" 9-;;'" 6" 993' 10,078' 10,807' J ewe I ry Item Top ID OD Description 18.5' Tubing Hanger, 2-7/8", Shaffer 1 2,104' GLM, Cameo, KBUG, 3-1/2" x 1" 2 10,005' GLM, Cameo, MM62, 3-112" x 1-1/2" 3 10,004 2.813 Profile Nipple, "X", 2.813" 4 10,078 BOT LSA wi 10' of seals 5 10,080' 3.25 Paeker, 7" "DB" wit 0' SBE, 3.25" 1D 6 10,774' 2.205 Nipple, 'XN', 2.205 I.D. Zone 77-3 Sqz Sqz HI H2 H3 H4 PERFORATION HISTORY (DlL) Interval Accum. Top Htm Amt spf 7,972' 7,982' 10' 6 8,014' 8,015' l' 4 10,420' 10,421' l' 4 10,875' 10,902' 27' 8 10,917' 10,926' 9' 8 10,958' 10,968' 10' 4 10,978' 10,992' 14' 4 Comments Proposed Apr-n Oct-81 4/88 & 6/88 4/88 & 6/88 Nov-90 Oct-81 5/21/2004 SL T WALTER J. HICKEL, GOVERNOR ALASKA OIL A~D GAS CONSERVATIO~ C~IMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 AUGUST 3, 1992 WATTY STRICKLAND ARCO ALASKA INC. P O BOX 1900360 ANCHORAGE, ALASKA 99510 DEAR MR. STRICKLAND, OUR FILES INDICATE THAT ARCO ALASKA INC. IS THE OPERATOR OF THE FOLLOWING WELLS MENTIONED IN THIS LETTER. WE ARE REVEIWING WELL FILES FOR MISSING 404 SUNDRY WELL OPERATION FORMS. SEVERAL 403 (SUNDRY APPROVALS) HAVE BEEN APPROVED FOR WORK ON THESE WELLS AND OUR FILES DO ~NOT REFLECT THAT THE WORK WAS ACCOMPLISHED. WOULD YOU PLEASE LOOK INTO THESE WELL SUNDRYS SO WE CAN CLOSE THEM OUT EITHER BY SUBMITTING THE APPROPRIATE 404 FORM WITH ATTACHMENTS FOR COMPLETED WORK OR A NOTE STATING THAT THE 403 APPROVAL NUMBER IS VOID. THE APPROVAL NUMBER IS ON THE SIGNED COPY OF THE 403 THAT AOGCC SENT BACK TO THE OPERATOR. WELLNAME PERMIT 403 APPROVAL # SOLDOTNA CK UNIT 21-4A SOLDOTNA CK UNIT 42A-5 SOLDOTNA CK UNIT 41A-9 SOLDOTNA CK UNIT 41B-9 PRUDHOE BAY UNIT DS14-11 KuPARUK RIV UNIT lB-2 PRUDHOE BAY UNIT DS13-12 80-0105 · 9-266 80'0106 8-739 80-0107 90-835 80-0108 9-982 80-0131 9-1016 80-0133 90-876 80-0142 9-969 PLEASE LET ME KNOW IF THERE IS ANY PROBLEM WITH SUBMITTING THE PROPER FORM IN A TIMELY MANNER. THIS IS GOING TO BE ANOTHER PROJECT JUST LIKE THE PLUG AND ABANDON WELLS. S INCERELY,- STEVE MCMAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST ARCO Alaska, Inc.[ ~" Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering February 11, 1991 ORIGI t Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is a subsequent report of operations for the perforating of SCU 42A-5. SCU 42A-5 was perforated in the H3 interval from 10,958' to 10,968' MD on November 17, 1990. The well is currently producing approximately 247 BOPD, 17,415 MCFPD and 65 BWPD. Sincerely, T. Wellman Regional Engineer TW:JKW:jll: 0015 Attachment cc: Mr. A. R. Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ( 0 ALASKA OIL AND 6AS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown~ Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1879' N and 498' W of SE corner, Sec. 5, T7N, R9W, SB&M At top of productive interval 1804' N and 17' E of Surface Location At effective depth Stimulate Alter casing ~ Repair well 5. Type of Well: Development ..~ Exploratory __ Stratigraphic __ Service At total depth 1969' N and 72' E of Surface Location 12. Present well condition summary Total Depth: measured 11180' feet true vertical 10797' feet Effective depth: measured true vertical Casing Length Structural Conductor Surface 74' Intermediate 3385' Production 1041 O' Liner 802' Perforation depth: measured 13. Plugging 14. Plugs (measured) 10993' feet Junk (measured) 10599' feet Perforate X Pull tubing Other 6. Datum elevation (DF or KB) 167' KB 7. Unit or Property name Soldotna Creek Unit III 8. Well number SCU 42A-5 9. Permit number/approval number 10. APl number 50-133-20232-01 1 1. Field/Pool Swanson River Field Size Cemented Measured depth True vertical depth 18" Driven 0-74' 0-74' 10-3/4" 1175 sx Class G 0-3385' 0-3385' 7" 1640 sx Class G 0-10410' 0-10076' 5" 75 C.F. Class G 10191'- 10933' 9870'- 10621' 10875'-10902'MD, I0916'-10926'MD, 10958'-10968'MD, 10988'-10992'MD truevertical 10509'-10512'TVD, 10530'-10534'TVD, I0568'-10576'TVD, 10594'-10598'TVD Tubing (size, grade, and measured depth) 3- 1/2", J-55, 10078' MD x 2-7/8", N-80, 10807' MD Packers and SSSV (type and measured depth) Baker FHL packer (7", 29~)., 10080' MD Stimulation or cement sqUeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure feet Prior to well operation N/A FEB 2 1991 Alaska Oil & Gas Cons. 6ommiss!m Anchora~a Representative Daily Average Production or Injection Dai;a Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 245 16951 70 640 Tubing Pressure 2850 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 247 17415 65 670 16. Status of well classification as: Oil X Gas Suspended ........ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /'~~~--~ Form 10-404 Rev 06/15/88 Title Cook Inlet Re,qional Engineer 2875 Date Z -t~- ~ t IT IN'DU lC ' ' N~0-18-"90 08:26 ID:SWANSON RIUER TEL N0:2651383 ~954 P03 ARCO Alaska, Inc. ~ WELt SERVICE REPORT ~1~i~ of AIl~ntlc Richfield C~pMy ' .'~. / · ~ * . , . ARCO Alaska, ,( Post OffiCe Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering November 15, 1990 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval to perforate the H3 interval in Well $CU 42A-5. We propose to perforate 10' of the H3 sand (10,958' - 10,968' MD) using 2 1/8" strip perforating guns @ 4 spf. With your approval, we would like to begin this work as soon as possible. If you have any questions please contact David Pursell at 263-4258. Sincerely, T. Wellman T~V:jkw:0004 Attachment cc: Mr./~ R. Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ~"~: ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPRovALs 1. Type of Request: Abandon _ Suspend B Alter casing __ Repair well Change approved program __ Operation Shutdown m Re-enter suspended well __ _ Plugging w Time extension _ Stimulate Pull tubing m Variance _ Perforate ~ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development .~. Exploratory _ Stratigraphic _ Service 1879' N and 498' W of SE corner, Sec. 5, T7N, R9W, SB&M At top of productive interval 1804' N and 17' E of Surface Location At effective depth At total depth 1969' N and 72' E of Surface Location 12. Present well condition summery Total Depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Structural Conductor Surface 74' 1 8" Driven .Intermediate 3,3 8 5' I 0 - 3 / 4" I, 5 7 5' Production 1 0,41 0' 7" .... Uner 8 02' 5" 75 C. F. Perforation depth: measured Current: 10,875-10,902' MD, 10,916-10,926' true vertical 6. Datum elevation (DF or KB) 167' KB 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 42A-5 9. Permit number 10. APl number S0-133-20232-01 11. Field/Pool Swanson River Field fee.t RECEIVED J NOV 2 ! 1990 Measured depth True ve~l~ti~ ' 0 - 74' 0 - 74' 0 - 3,385' 0 - 3,385' 0 - 10,410' 0 - 10,076' 10,191 - 10,993' 9,870 - 10,621' MD, 10,988-10,992' MD 13. Tubing (size, grade, and measured depth 0, ! 3 /2 J-55, 10,078' MD x 2-7/8", N-80, 10,807' MD Packers and SSSV (type and measured depth) Baker FHL packer (7", 29#), 10,080' MD Attachments Description summary of proposal _ Detailed operation program X 16. 17. Estimated date for commencing operation 15. Status of well classification as: November. 1990 oi~ X Gas If proposal was verbally approved Name of approver Date approved Service ~__ I hereby certify that the foregoing is true and correct to the best of my knowledge. Silitned Title Cook Inlet Regional Engr. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative mey witness Plug integrity ... BOP Test m Location clearance Mechanical Integrity Test B Subsequent form require 10- BOP sketch X Suspended . IApproval No. ,~' ,,., Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH Approvea Copy Re;ruffled Commissioner SUBMIT IN TRIPLICATE" Well SCU 42A-5 H3 Sand Perforation Procedure Objective Perforate H3 Sand in order to increase oil production. Current Status SCU 42A-5 is producing 250 BOPD, 90,000 GOR Minimum Restriction: XN Nipple at 10,774' MD (ID = 2.205") Pressures: FTP 2900 psi PC 650 psi SC 55 psi Procedure Prior to Perforating 1. RU slickline and tag ifil with 2.2" gauge ring. 2. Contact Anchorage office to verify sundry approval before proceeding. · perforating 1. MIRU E-Line Unit. Pressure test lubricator to 4000 psi. 2. SI well. RIH w/ perf gun/CCL. Tie-in to perf the following interval in 1 gun run: Interval Run No. [CNL 9-28-81) Footage (ft) Sand SPF Phasin~ 1. 10958-10968 10 H3 4 0° - NOTE: Gun orientation should be down (at bottom of the hole). 3. POOH. RD E-Line Unit. 4, Test well on days 1,3, 5 following re-perforation. Available Per]' Guns Company Halliburton Schlumberger Western Atlas Gun _Type Gun Size Dyna-Strip 2-1 /8" Enerjet Strip 2-1/8" Silver Jet 2-1/8" RECEIVED NOV 21 1..990 A,~a~ka Oil & Gas Cons. Anchora~ Well- scu 42A-5 Spud Date: 9/28/81 Original RKB: 18.5' Top of Hemlock:10850'UD Max, Hole Angle: Arco Alaska Inc.- Swanson Rive,. ield APl#: 133-20232-01 Well Type' Producer Completion Date: 10/5/81 Last Workover. 4/24/89 Hanger Type: Shaffer Hanger: 29° Angle @ Hemlock: 20° All Depths are RKB MD to Top of Equipment. J L Jewelry I 993' 2 2104' 3 10,005' 4 10,004' 5 10,078' 6 10,080' 7 10,774' 8 10,994' X-OVer 3-1/2" N-80 to 3 1/2" J-55 Camco 3-1/2" x 1" KBUG GLM Camco 3-1/2"xl 1/2" MM62 GLM Otis "X' Nipple I.D. 2.813 Baker Locator wtl0' Seals Baker 7" DB Packer W/10' SBE I.D. 3.250 Otis 2-7/8 "XN' Nipple I.D. 2.205 Fish (Dd# Collars) Minimum ID; 2.205" (a) 10.744' (Otis 2-7/8" 'XN' nia_l;lle) Casing and Tubing Description 4 18"¸ 10-3/4" 7" 3-1/2" 3-1/2" 2-7/8" line pipe 0 74' 40.5#/ff K-55 0 3385' 29 #/it N-80 0' 73' 23 #/ft N-80 73' 4361' 29#1ft N-80 4361' 8053' 29#/ft P-110 8053' 10,410' 18#/ft H-80 10,191' 10,994' .9.2#/ft N-80 0 993' 9.3#/ft J-55 993' 10,078' 6.5#/ft N-80 10,093' 10,807' Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing Tubing Perforation Data 10,402' 10,420' 10,875'- 10,902' H1 10,917'-10,926' H2 10,988'- 10,992' H4 PBTD = 10,993' TD = 11,108' FT SPF ~ Comments 1' 4 10/81 SQZ. 1' 4 10/81 SQZ. 27' 8 4&6/88 9' 8 4&6/88 4' 4 10/81 RECEIVED NOV 2 ].. 1990 A1as~ .O~l & Gas Cons. Co.m~issior~ /~chorage Well SCU 42A-5 By: JL8 11/28/89 E-Line BOPE's Grease Head/ Hydraulic Packoff ~-- Lubdcator Extension Manual Rams Swab Valve Double Maste~ Valves {~., c~; c ~tV ellhe ~hora~a ad ARCO Alaska, Inc(~ Post Office BoX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering June 18, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 42A-5 Dear Mr. Chatterton: Attached is a Report of Sundry Well Operations of the hydraulic fracture stimulation of the H1 & H2 intervals in Well SCU 42A-5. Following a data frac, we fracture stimulated the H1 and H2 sands with 265 Bbls of crosslinked gel and 20,200 lbs. of 16-20 mesh fracture proppant. If you have any questions please contact David Pursell at 263-4258. Sincerely, T. Wellman Regional Engineer TW:DAP:ch:0032 Attachment cc: S.W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company RECEIVED JUN 2 0 1990 Alaslm Oil & Gas Cons. Com~ts$ion ~nchorage ARCO Ala.i(a, Inc. is a Subsidiary of Atlantic Richfield Company A( ..,KA OIL AND STATE OF ALASKA GAS CONSERVATION COMI~ -qON REPOFrI' OF SUNDRY WELL OPEI:: TION$ 16 IN 1. Operations performed: Operation shutdown __ Stimulate X Plugging __ Perforate __ Pull tubing __ Alter casing __ Repair well __ Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510 5. Type of Well: Development .~X Exploratory __ Stratigraphic __ Service __ Other ~ 6. Datum elevation (DF or KB) 167' KB 7. Unit or Property name Soldotna Creek Unit feet 4. Location of well at surface 1879' N and 498' W of SE At top of productive interval 1804' N and 17' E of SL At effective depth At total depth 1969' N and 72' E of SL corner, Sec. , T7N, R9W, SB&M 8. Wellnumber SCU 42A-5 9. Permit number/approval number 8o / 'Z~ --,-~ '~ ~ 10. APl number 50-- 133-20232-01 11. Field/Pool Swanson River Field 12. Present well condition summary Total depth: measured true vertical feet feet Plugs(measured) Effective depth: measured true vertical feet feet J u nk (measured) Casing Length ~~r Surface 74 Intermediate 3,385 Production 10,410 Liner 802 Perforation depth: t~zuYe~g~a~X Tubing (size, grade, and measured depth) 3-1/2", N-80, 10,078' MD x Size Cemented 18" 10-3/4" 7" 5" Current 10,875-10,902' 10,916-10,926' 10,988-10,992' 2-7/8", N-80, Measured depth True vertical depth driven 0-74' 0-74' 1,575' 0-3,385' 0-3,385' --- 0-10,410' 0-10,076' 75 C.F. 10,191-10,993' 9,870-10,621' PackersandSSSV~ypeandmeasureddepth) Baker FHL packer (7", 29#) 10,080' MD MD MD MD 10,807' MD RECEIVED J UN 2 0 1990 13. Stimulation or cement squeeze summary Intervals treated (measured) 10,875-10,902' MD & 10,916-10,926' MD Treatment description including volumes used and final pressure 265 Bbls crosslinked gel and 20,200 lbs. of 16-20 proppant 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Alaska Oil & Gas Cons. Commission Anchorage Tubing Pressure Prior to well operation 225 10,000 25 580 Subsequent to operation 437 23,971 60 580 15. Attachments 116. Stat[is of well classification as: Copies of Logs and Surveys run __ ! Daily Report of Well Operations ~ . Oil __X Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 3200 2600 Signed /'~"'/~~~ Title Cook I n I et Reg i ona I Eng [ neer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE · I ARCO Alaska, Sub~idl~'y of Attentio Richfield Company ~4~ q"L~- <.s' WELL CONTRACTOR REMARKS WELL SERVICE REPORT DISTRICT-STATE PERATION AT REPORT TIME x~'z,~ "O Lsz. R ...... 15'3Z [,~ JUN 2 0 1990 ~-CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Alaska Oil & Gas Cons. Commission -. t"""., "'.,iv'''''''''.,,,..I ..0,.I'"'L~ ~~o~,-' _ MAY-11-' 90 07: 20 I 'qNSON R I UER TEL NO:~ · . · ,. '"" ........ < '"" WELL SERVICE REPORT ARCO Alaska, Inc. ~} ~ ' CONTRACTOR , - REMARKS [zt¢ t,A ~ lqtS'" I'-t'ZA \. O 50 so 50'70 t '4 %,.<' O ,~ ,,.to ~0 ,~' CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W#l#W' 1 Temp. ! Chill Factor 'I Visibility --1Wind Vel. , , ~736 P02 MAY-l~-'90 07:21 I(' 'ANSON RIUER TEL NO: 2.6 "' ARCO Alaska, Inc. ~l~l&cy 0f All&ntlc RlchflllCl Coml3~ny WELL CONTRACTOR REMARKS ;'-:~I~.D- [~l~t%1GT :'~T~TE IOpERATION AT R~'l~f :rIME WELL SERVICE REPORT ~o o,4 O4OO !~Z~ ~'~o ,~i~o ........ t?-~.-.O__ ~- CHECK THIS BLOCK IF SuMMARy CONTINUED ON BACK _wemmer I T. ml~ t Chill F,~. I ¥1,1bllity I~ v¢. _ MAY-il-'90 07:21 ?',lANSON RIUER TEL NO: 2 ~'~ ARCO Alaska, Inc. Sub~idi&~y of Atlantic Rl¢llfleld Company CONTRACTOR :~-.._.~.~..' DI S___....T.~.I.C_.T..T ."~'TAT F JOPt[I:IATION A~ ~"'~)l=l? TIIVlI= WELL SERVICE REPORT IDAY% ;OATE REMARKS JUN 2. 0 1990 Alaska Oil & Gas Cons. Commi.~siu~, Anchorage n CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK .W~_*~ I'r.,,.. I c.# ~'.~,'J ~,,b,,,ty j w~ va. ~ SCU 42A-5 Spud Date' 9/28/81 Original RKB' 18.5' Top of Hemlock:10875'MD Ma](. Hole Angle: Arco Alaska Inc. - Swanson Ri ,..' I=ield APl#: 133-20232-01 [ Well Type:Producer Comp[etlon Date: 10/5/81 Last Workover: 4/24/89 Hanger Type' Shaffer Hanger: 29° Angle @ Hemlock' 27° All Depths are RKB MD to Top of Equipment. J L Jewelry 1 993' 2 2104' 3 10,005' 4 10,044' 5 10.078' 6 10,080' 7 10,744' 8 10,994' X-Over 3-1/2" N-80 to 3 1/2' J-55 Carnoo 3-1/2' x 1" KBUG GLM Camcx) 3-1/2'xl 1/2" MM62 GLM Otis 'X' Nipple I.D. 2.813 Baker Locator w/10' Seals Baker 7' DB Packer WI 10' SBE I.D. 3.250 Otis 2-7/8 'XN' Nipple I.D. 2.205 Fish (Ddll Collars) Minimum ID: 2.205" ~ 10.744' (Offs 2.7/8" 'XN' nlDplet Casing and Tubing Oescrl_~tlon 4 5,6 18' 10-3~4' 7' 5-1/2' 3-1/2' 3-1/2' 2-7/8' line pipe 0 74' 40.5#/ft K-55 0 3385' 29 #fit N-80 0' 73' 23 #fit N-80 73' 4361' 29#/fi N-80 4361' 8053' 29#/ft P-110 8053' 10,410' 18#/ft H-80 10,191' 10,994' 9.2#/ft N-80 0 993' 9.3#/ft J-55 993' 10,078' 6.5# N-80 10,093" 10,807" Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing Tubing Perforation Data 10,402' 1' 4 10/81 10,420' 1' 4 10/81 10,886'-10,893' H1 7' 8 4&6/88 10,917'-10,920' H2 3' 8 4 &6/88 10,988'- 10,992' H4 4' 4 10/81 SQZ. SQZ. PBTD = 10742' TD = 10790' Anchorage ARCO Alaska, Iv Post Offi[. ~× t00360 Anchorage, Alaska 9951 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering April 27, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 42A-5 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to hydraulically fracture the HI & H2 intervals in Well SCU 42A-5. We propose to fracture the Hi and H2 sands with 235 Bbls of crosslinked gel and 20,200 lbs. of 16-20 mesh fracture proppant. Also, a data frac will be performed prior to pumping the frac. If you have any questions please contact David Pursell at 263-4258. Sincerely, T. Wellman TW:DAP:ch:0030 Attachment cc: S.W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company RECEIVED MAY 0 1990 Alaska Oil & Gas Cons', CommL~lol~ Anchora~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1879' N and 498' W of SE corner, Sec. 5, T7N, R9W, SB&M 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 6. Datum elevation (DF or KB) 167'KB 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 42A-5 feet At top of productive interval 1804' N and 17' E of SL At effective depth At total depth 1969' N and 72' E of SL 12. Present well condition summary Total Depth: measured true vertical feet Plugs (measured) feet 9. Permit number 10. APl number so-1 33-20232-01 11. Field/Pool Swanson River Field Effective depth: measured true Vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 74' 1 8" 3,385' 10-3/4" 10,410' 7" 802' 5" Current 10,875-10,902' MD 10,916-10,926' MD 10,988-10,992' MD Cemented Measured depth True vertical depth Driven 0 - 74' 0 - 74' 1,575' 0 - 3,385' 0 - 3,385' .... 0 - 10,410' 0 - 10,076' 75 C.F. 1 0,191 10,993' 9,870 - 10,621' Tubing (size, grade, and measured depth 3 1/2", N-80, 10,078' MD x 2-7/8", N-80 10,807' MD Packers and SSSV (type and measured depth) Baker FHL packer (7", 29#), 10,080' MD 13. Attachments RECEIVED Description summary of proposal MAY O 1..990 ~aska 0il & Gas Co'n~. Anchorage Detailed operation program X BOP sketch X 14. Estimated date for commencing operation Mav. 1990 Oil ~ Gas 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~ [,42~,j Title Cook Inlet Engineering Manager FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-~0~ Approved by the order of the Commission Form 10-403 Rev 5/03/89 15. Status of well classification as: _ Suspended IJAppr°val No.¢ ~ - C~,=~ Original ~;~n.'~d By David W. donnston Approved CoPY p, eturneCl ~ssioner Date ,,~ "~-"' ~ D SUBMIT IN TRIPLICATE Data Frac & I~'acture ~ ~ SCU 42A-5 SR 156 · Prior to Data Frac 1. Dump Sand over H4 Sand. · Data Frac 1. NU Tree Saver. RU E-Line and RIH w/ Pressure, Temperature, CCL. Monitor pressure throughout data frac. 2. Breakdown test @ 15 BPM w/ 50 bbls uncrosslinked gel, preceeded by 20 bbls xylene. 3. Pump-in/Shut-in Test w/ 15 bbls uncrosslinked gel @ 15 BPM. Repeat until consistent closure data is acquired. 4. Mini Frac at 15 BPM w/ 100 bbls crosslinked gel w/additives. 5. Analyze Data Frac. · Fracture Stimulation 1. Pump 214 bbls of crosslinked gel w/fluid loss additives and 20,200 # 16-20 Carboltte at 15 BPM. Flush w/91.5 bbls 40# linear gel. RECEIVED MAY o 1990 Alaska Oil & Gas Cons. Commission ~nchora~ Well- scu 42A-5 Spud Date' 9/28/81 Original RKB' 18.5' Top of Hemlock'10850'MO Max. Hole Angle: ,-,n=o Alaska Inc. - Swanson Rive,. ield APl#: 133-20232-01 Well Type:Producer Completion Date: 10/5/81 Last Workover: 4/24/89 Hanger Type: Shaffer Hanger' 29° Angle @ Hemlock: 20° All Depths are RKB MD to Top of Equipment. Jewelry I 993' 2 2104' 3 10,005' 4 10,004' 5 10,078' 6 10,080' 7 10,774' 8 10,994' X-Over 3-1/2" N-80 to 3 1/2" J-55 Camco 3-1/2" x 1" KBUG GLM Camco 3-1/2"xl 1/2" MM62 GLM Otis "X' Nipple I.D. 2.813 Baker Locator w/10' Seals Baker 7" DB Packer W/10' SBE I.D. 3.250 Otis 2-7/8 "XN" Nipple I.D. 2.205 Fish (Ddll Collars) Minimum ID: 2.205" ~ 10.744' (Offs 2-7/8" 'XN' ni.o.ole) 4 5,6 Casing and Tubing Size Weiqht ~ 18" 10-3/4" 7" 5-1/2" 3-1/2" 3-1/2" 2-7/8" line pipe 0 74' 40.5#/ft K-55 0 3385' 29 #fit N-80 0' 73' 23 #/ft N-80 73' 4361' 29#/ft N-80 4361' 8053' 29#/ft P-110 8053' 10,410' 18#/ft H-80 10,191' 10,994' 9.2#/ft N-80 0 993' 9.3#/ft J-55 993' 10,078' 6.5#/ft N-80 10,093' 10,807' Description Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing Tubing Perforation Data Interval ~ FT SPF Date 10,402' 1' 4 10/81 10,420' 1' 4 10/8'1 10,875'-10,902' H1 27' 8 4 &6/88 10,917'-10,926' H2 9' 8 4 &6/88 10,988'- 10,992' H4 4' 4 10/81 Comments sQz. SQZ. PBTD = 10,993' TD = 11,108' Well. scu 42A-5 By: JLB 11/28/89 E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead ARCO Alaska, Inc[~ Post Office~ ~ '~ ~ ~"~ ' ~ Anchorage, Alaska 99510-0360 · Telephone 907 275 ~,~, '~ '"~,: Cook ~nlet/New Engineering April 3, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 42A-5 Dear Mr. Chatterton: This is to notify you that ARCO Alaska, Inc. re-perforated the Hi & H2 intervals in Well SCU 42A-5. We re-perforated 36' of the Hi and H2 sands (10,875' - 10,902' MD and 10,917' - 10,926' MD) using a 2-1/8" strip perforating gun at 4 spf. Attached are Sundry Notices and Well Service Reports which document the operation. We received verbal approval on Friday, November 24, 1989 to perform this work, and subsequently received written approval. If you have any questions please contact David Pursell at 263-4258. Sincerely, T. Wellman Interim Manager TW:DAP:ch:0025 Attachment CC: S. W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company RECEIYEI) APR ! 0 1990 Alas~ Oil & Sas ~ns. 6~l~It ~cfiOra,ge ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA [' Al, (A OIL AND GAS CONSERVATION COMI~._.....,ION REPORT OF SUNDRY WELL OPERATiON ) t G N A L 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate ..Z. Pull tubing __ Alter casing 2. Name of Operator ARCO Alaska, Inc. Repair well ~ Pull tubing __ Other 3. Address P. O. Box 100360 Anchorage, AK 5. Type of Well: Development Exploratory Stratigraphic 99510 Service 4. Location of well at surface 879' N and 498' W of SE corner, T7N, R9W, SB&M At top of productive interval 1804' N and 17' E of SL At effective depth At total depth 1969' N and 72' E of SL 6. Datum elevation (DF or KB) 167' KB feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 42A-5 9. Permit number/approval number 10. APl number 50-- 133-20232-01 11. Field/Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Plugs (measured) Junk (measured) None Casing Length Surface 74' Intermediate 3,385 ' Production 1 O, 410 ' Liner 802 ' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size 18" 10-3/4" 7" 5" Cemented Driven 1,575' 75 C.F. Current 10,875-10,902' MD t0,916-10,926' MD 10,988-10,992' MD 13. Measureddepth 0-74' 0-3,385' 0-10,410' 10,191-10,993' Re~per.f~ 10,875-10,902' MD 10,917-10,926' MD 3-1/2", N-80, 10,078' MD x 2-7/8", N-80, PackersandSSSV~ypeandmeasureddepth) Baker FHL packer (7", 29#), 10,080' HD Stimul~ionorcementsqueezesummary 10,807' MD ~ueve~icaldepth 0-74' 0-3,385' 0-10,076' 9,870-10,621' Intervals treated (measured) Treatment description including volumes used and final pressure APR ! O 1990 Ala$ 0il & Gas Cons. Co mi OJ 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 300 14,000 30 700 3100 $ u bseq uent to operation 70.0 15,000 30 ' 15. Attachments ] 16. Status of well classification as: Copies of Logs and Surveys run -w-- ! Daily Re port of Well Operations ~ Oil __X Gas ~ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 700 3100 Service Signed % ~,u~ Form 10-404 Rev 06/15/88 Title Cook Inlet Engineerin~l Manager Date ¢-3-'~O SUBMIT IN DUPLICATE N0'.;-26-'89 05: ~4 . ,ARCO Alaska, ~<ll~lldllry Of &lllAfl¢ TEL NO: £6513S3 WELL SERVICE REPOR WELL -. ~Z:oo ..... ~ z~:,~ Z ~ .. Zu~,~To~. __ ~c~ ~~ ~wo. APR IO 1990 . _ Ill I I/. -_ ARCO Alaska, Inc.( Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures November 28, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 42A-5 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to re-perforate the H1 & H2 intervals in Well SCU 42A-5. We propose to re-perforate 36' of the H1 and H2 sands (10,875'- 10,902' MD and 10,917' - 10,926' MD) using a 2-1/8" strip perforating gun at 4 spf. We received verbal approval on Friday, November 24, 1989 to perform this work (re-perforating was performed the following day). If you have any questions please contact David Pursell at 263-4258. Sincerely, T. S. McCorkle TSM:DAP:ch:0024 Attachment cc: S.W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ^R3B--6279 A~ STATE OF ALASKA ~ OIL AND GAS C(]qSERVATION COMMISSION 0 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _~ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 879' N and 498' W of SE corner, T7N, R9W, SB&M At top of productive interval 1804' N and 17' E of SL At effective depth 5. Type of Well: Development Exploratory Stratigraphic Service At total depth 1969' N and 72' E of SL 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 7 4' Intermediate 3,3 8 5' Production 1 0,41 0' Liner 8 0 2' Perforation depth: Current 10,875-10,902' MD 10,916-10,926' MD 10,988-10,992' MD feet Plugs (measured) feet feet Junk (measured) feet Size Cemented I 8" Driven I 0-3/4" I ,575' ,, . . . _ . 5" 75C. F. Pro_Dosed Re-perfs 10,875-10,902' MD 10,917-10,926' MD 13. 6. Datum elevation (DF or KB) 167' 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 42A-5 9. Permit number 10. APl number 50-1 33-20232-01 11. Field/Pool feet NC~E Measured depth True vertical depth 0-74' 0-3,385' 0-10,410' 10,191-10,993' 0-74' 0-3,385' 0-10,076' 9,870-10,621' RECEIVED NOV 2 81989 Tubing (size, grade, and measured depth 3-1/2", N-80, 10,078' MD x 2-7/8", N-80, 10,807' MD :AI~ska0Jl&GasC0ns, Comm]ssl01t Packers and SSSV (type and measured depth) ~ ! '_~l~llCh0r~ '~ Baker FHL packer (.7"~ 29#), 10,080' MD. Attachments Description summary of proposal _ Detailed operation program X BOP sketch X 14. Estimated date for commencing operation .. November. 1989 16..1~ proposal was. verbally approved Name oT approver Date approved 15. Status of well classification as: Oil :X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si(:jned ~ IA/~~" F 'TS ~ ¢~,v ~C(C._ Title Cook Inlet Engineering Manager FOR COMMISSION USE ONLY Date !Conditions of approval: Plug integrity_ Mechanical Integrity Test Notify Commission so representative may witness IApproval No./3.,, ,~O .3~"/' / ~;~/' BOP Test ~ Location clearance ~. I Subsequent form require 10-~" ~9~o~e6 0o9~ LONNIE G. SMi~" ~ss,oner,~Date //~ 2~' ~? SUBMIT IN TRIPLICATE '~lApproved by the order of the Commission orm 10-403 Rev 5/03/89 Perforation Procedure SCU 42A-5 1. RU slickline and pressure test lubricator. 2. RIH with 2.2" gauge ring and tag fill. RD slickline. 3. RU E-line unit and pressure test lubricator. 4. Re-perforate the H2 sand from 10,917'-926' MD and the Hi sand from 10,875'- 10,902' MD. RD E-line. 5. Return well to production and test periodically. Well- scu 42A-5 , Spud Date-9/28/81 Original RI(B: 18.5' Top of Hemlock:10850'MD Max. Hole Angle: 1~ "co Alaska Inc. - Swanson Ri .-ield '-- ,.tPl#: 133-20232-01 Well Type:Producer Completion Date' 10/5/81 Last Workover-4/24/89 Hanger Type: Shaffer Hanger- 29° Angle @ Hemlock: 20° All Depths are RKB MD to Top of Equipment. Jewelry I 993' 2 2104' 3 10,005' 4 10,O04' 5 10,078' 6 10,080' 7 10,774' 8 10,994' X-Over 3-1/2" N-80 to 3 1/2" J-55 Camco 3-1/2" x 1" KBUG GLM Camco 3-1/2"xl 1/2" MM62 GLM Otis "X' Nipple I.D. 2.813 Baker Locator w/10' Seals Baker 7" DB Packer W/10' SBE I.D. 3.250 Otis 2-7/8 "XN" Nipple I.D. 2.205 Fish (Drill Collars) Minimum ID: 2.205" (~ 10.744' (_Otis 2-7/0" 'XN' nipple_) Casing and Tubing Size Weight Grade ToD Bottom Descri_otion 4 5,6 1 8" 10-3/4" 7" 5-1/2" 3-1/2" 3-1/2" 2-7/8" line pipe 0 74' 40.5#/ft K-55 0 3385' 29 #/ft N-80 0' 73' 23 #/ft N-80 73' 4361' 29#/ft N-80 4361' 8053' 29#/ft P-110 8053' 10,410' 18#/ft H-80 10,191' 10,994' 9.2#/ft N-80 0 993' 9.3#/ft J-55 993' 10,078' 6.5#/ft N-80 10,093' 10,807' Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing Tubing Perforation Data Interval Zone FT SPF Date 10,402' 1' 4 1 0/81 10,420' 1' 4 1 0/81 10,875'-10,902' H1 27' 8 4&6/88 10,917'-10,926' H2 9' 8 4&6/88 10,988'-10,992' H4 4' 4 1 0/81 Comments SQZ. SQZ. PBTD = 10,993' TD = 11,108' Well SCU 42^-5 By: JLB 11/28/89 E-Line BOPE's Grease' Head/ Hydraulic Packoff ~-. Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead ~ STATE OF ALASKA f a~. ,A OIL AND GAS CONSERVATION COMMI[ .)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging m Pull tubing __ Alter casing m Repair well m 2. Name of Operator ! 5. Type of Well: ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 9951 -0360 4. Location of well at surface 1879' FSL, 498' FEL, Sec.5, T7N, Rgw, SM At top of productive interval 1594' FNL, 481' FEL, Sec.5, T7N, R9W, SM At effective depth 1550' FNL, 471' FEL, Sec. 5, T7N, Rgw, SM At total depth 1432' FNL, 426' FEL, Sec.5, T7N, Rgw, SM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length Casing 59' 3370' Conductor Surface 10395' Production Perforate ~ Pull tubing ~ Other Development Exploratory Stratigraphic Service Workover 6. Datum elevation (DF or KB) RKB 167 ' 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 42A-5 9. Permit number/approval number Approval 9-014 10. APl number 50o 133-20232-01 feet Liner 802' 11. Field/Pool Swanson River - Hemlock 11180'MD feet Plugs(measured) None 10797,TV~eet 10993'MD ~ Junk(measured) None 10599'TV~e~ Size Cemented Measured depth True vertical depth I 8" Driven 74' MD 74 ' TVD 10-3/4" 1175 sx Class G 3385'MD 3385'TVD 7" 1640 sx Class G 10410'MD 10074'TVD 7" csg sqzd ~8014' w/400 sx Class G 5" 75 ft3 Class G 10191'-10993'MD 9871'-10598'T~ 13. Perforation depth: meaSured Top job w/20 sx C1 G 10893'-10896. 10916'-10920', 10988'-10992' true ver[ical 10509'-10512', 10530'-10534', 10594'-10598' Tubing (size, grade, and measured depth) 3½"/2-7/_8", N-80./J-55, tbg tail (~ 10807' Packers and SSSV Fype ano measured depth) SSSV: None, Baker 'DB' pkr ~ 10080' Stimulation or cement squeeze summary I nte~s treated (measured) Treatment description including volumes used and final pressure P ECEIVED Alaska Oil & 8as Cons. Comr~ission Anchorage 14. N/A Representative Daily Average Production or Injection Da!a OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run ~ I Daily Report of Well Operations.~Y,.~..:~ Oil X' Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed -. ~) Form 10-404 Rev 06/15/88 Service Area Drilling Engineer Title SWO1/3 * Workover Well History SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instmetlene: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the' form giving inclusive dates only. District ICounty, parish or borough I Field ~I~L,,~ ;~.[,A$~, i.~C., iLease o~n~ ............... I Title Auth. or W.O.~~m ~v~ I Stet gOO 42A .% Iwe. no. Operator Spudded or V~.~b~gun IDate Dste and dep~~'~'~'~ as of 8:00 a.m. 04/14/89 ( TD:11180 PB:10994 SUPV:DL 04/15/89 ( TD:11180 PB:10994 SUPV:DL 04/16/89 ( TD:11180 PB:10994 SUPV:DL 04/17/89 ( TD:11180 PB:10994 SUPV:DL TD:11180 PB:10994 04/19/89 ( TD:11180 PB:10994 SUPV:DL 04/20/89 ( TD:11180 PB:10994 SUPV:EEV Completerecordforeachdayreported R~ .... g RiG ~ Agi; $C-133-20232-01 ARCO W.l. Prio'~ ~t&t~if ~ W.O. RIG UP MW= 8.6 NaCl MOVE RIG FROM SCU 31-8 TO SCU 42-A5. RIG UP. DAILY=S14,946 CUM:$14,946 ETD:S14,946 EFC:$410,000 MONITOR WELL. MW: 8.7 NaCl FIN R/U. ACCEPT RIG AT 0900 4/14/89. R/U LINES AND CHOKE. PULL BPV. TAKE ON WATER @8.7PPG. CIRC WELL TO FLOW TANKS. MONITOR PRESSURE. SITP-0/SICP-100PSI CIRC 2 CIRCULATIONS STILL A SMALL AMOUNT OF GAS PRESSURES 170 AND 200PSI...S RAISE FLUID WT TO 9.2PPG AND MONITOR WELL. DAILY:S14,990 CUM:$29,936 ETD:S29,936 EFC:$410,000 N/U BOP MW: 9.3 NaCl KILL WELL WITH 9.3 PPG BRINE. MONITOR WELL FOR PRESSURE. WELL DEAD. SET BPV AND N/D TREE AND N/U BOP'S. DAILY:S16,690 CUM:$46,626 ETD:S46,626 EFC:$410,000 POOR L/D 3-1/2" TUBING MW: 9.3 NaC1 N/U BOP AND TEST SAME. CIRC OUT GAS/OIL THRU CHOKE. SPOT HEC PILL. P/U ON TUBING. TUBING FREE. POOH L/D 3-1/2" TUBING. DAILY:S17,390 CUM:$64,016 ETD:S64,016 EFc:$410,000 TIH W/ 3-1/2" DP MW: 9.3 Nat1 SERVICE RIG, FINISH TOOH, LD 3-1'/2" TBG, PKR, TBG WAS IN FAIR CONDITION, SEVERAL JTS GALLED WHILE BACKING OUT, PKRWAS SHEARED, RU TU RUN 3-1/2" DP, RACK, TALLY,AND TIH W/ BHA ON 3-1/2" DP. DAILY:S24,312 CUM:$88,328 ETD:SO EFC:$498,328 RIH WITH REP MW: 9.3 NaC1 P/U 3-1/2" DRILL PIPE AND RIH. WELL STARTED FLOWING. CIRC OUT GAS THRU CHOKE. FINISH RIH TO TOL AY 10,198 W/O RKB. CIRC WELL CLEAN. SLIP AND CUT DRILLE LINE.POOH WITH BIT.. P/U REP AND RIH. DAILY:S23,210 CUM:$111,538 ETD:S111,538 EFC:$410,000 GIH TO PULL RBP MW: 9.3 NaCl RIH W/ RBP. CIRC OUT GAS AT 10,123. TEST CASING TO 2500 PSI FOR 30 MIN. SET STROM PACKER BELOW TBG HEAD. N/D BOP AND · TUBING SPOOL. N/U NEW TUBING SPOOL. TEST SAME TO 3000 PSI. N/U BOP AND TEST SAME. puLL'sTORM PKR. RIH TO PULL RBP. DAILY:S21,204 CUM:$132,742 ETD:S132,742 EFC:$410,000 The above is correct · For form prel3aratj~n'd distributl~ see Procedures k~arJbal, Section 10, Drilling, Pages 86 "a'nd 87, IDate-- [Title Drilling Supt, AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company "~' Daily Well History--Interim Instna©tions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ali drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. ICounty or Parish COOK INLET/KENAI Lease or Unit SCO 42&--5 ]Stat~l~ SWANSON RIVER Date and depth as of 8:00 a.m. 04/21/89 ( TD:11180 PB:10994 SUPV:EEV 04/22/89 ( TD:11180 PB:10994 SUPV:EEV 04/23/89 ( TD:11180 PB:10994 SUPV:EEV 04/24/89 ( TD:l1180 PB:10994 SUPV:EEV 04/25/89 ( TD:11180 PB:10994 SUPV:EEV Complete record for each day while drilling or workover in progress ROLL'N RIG 5 POOH MW: 9.3 NaC1 RELEASED RBP. CBU. GAINED 6 BBLS. CONT TO CIRC OIL AND GAS W/ RETURNS. RAISE WT TO 9.4 PPG. CHECK F/ FLOW. SLIGHT FLow. CIRC OUT THROUGHT CHOKE. STILL CIRC OUT GAS AND OIL. MIXED AND PUMPED 50 BBL HEC PILL AND SQUEEZED 19 BBLS INTO FORMATION. RELEASED PRESS AND CBU. CBU 8 TIMES. RAISED BRINE WT TO 9.5 WHILE CIRC. OBSERVED WELL. APPEARS DEAD. POOH SLOWLY. DAILY:S17,840 CUM:$150,582 ETD:S150,582 EFC:$410,000 POOH MW: 9.3 NaCl POOH. L/D 4-3/4" DC AND RBP. P/U BIT AND BOOT BASKETS AND 3-1/8" DC. RIH. CBU @ PBTD-10,994 RKB. SPOT HEC PILL. POOH. DAILY:S24,695 CUM:$175,277 ETD:S175,277 EFC:$410,000 RIH WITH PACKER ON DRILL MW: 9.5 NaCl POOH WITH DRILL PIPE. CUT AND SLIP DRILL LINE. L/D 3-1/8" COLLARS. R/U AND RUN DRESSER VERTILOG. R/U AND RUN TAIL ASS'Y AND 7" X 3.25" BAKER 'DB' PKR W/ B-2 SETTING TOOL. RIH WITH PACKER ON DRILL PIPE. DAILY:S32,853 CUM:$208,130 ETD:S208,130 EFC:$410,000 RIH WITH COMPLETION STRING MW: 9.5 NaC1 RIH WITH PACKER ON DRILL PIPE. SET SAME AT 10075'. TEST ANNULUS TO 2500 PSI- OK. RELEASE SETTING TOOL FROM PACKER. CBU. POOH L/D DRILL PIPE. R/U AND RUN 3-1/2" COMPLETION STRING. DAILY:S78,863 CUM:$286,993 ETD:$286,993 EFC:$410,000 PREP TO RUN STORM PKR MW: 9.5 NaCl FIN IN HOLE W/ COMP STRING. SPACED OUT AND LANDED. TBG WOULD NOT TEST. ATTEMPT TBG AND CSG TEST AT 2200 PSI. TBG HGR JUMPED INTO LOCKDOWN SCREWS. SHEARED BALL F/ TBG. SET "PXN" PLUG IN PKR TAIL ASSY AT 10,775'. PULLED CHECK VALVE AND INSTALLED DUMMY VALVE. TEST TBG TO 2500 PSI. LD LANDING JT. ND BOP'S. INSPECT TBG HEAD. SEALS NO GOOD. NU BOP'S. SCREWED LANDING JT INTO HGR. PULLED HGR AND LAID OUT PUP JTS PREPARING F/ STORM PKR. (BAKER 'DB' PKR @ 10080, SSSV: NONE, & TT @ 10807') DAILY:S32,815 CUM:$319,808 ETD:S319,808 EFC:$410,000 well no. Th,,e,, a.~ve is correct Fo'r form prej~at~ion and"distributio~--.-.) see Procedures ~lanual Section 10, Drilling, Page"s-~6 and 87 AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Flail Repo~t" on the .first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District I State ' ~ I Well no. Field AliCe A.L~A~I'~%, J. Nt~. Auth. or W.O.,~IAN~ON KIV~K AOb447 ICounty or Parish Lease o r [~,~ Title fldJJa: A-G2&996 q~P~. O Operator Spudded or ~&llg~l~lun Date and dept~ as of 8:00 a.m. 04/26/89 ( 1: TD:11180 PB:10994' SUPV:EEV 05/16/89 ( 1 TD:11180 PB:10994 SUPV:DL 05/17/89 ( 1 TD:llla0 PB:10994 SUPV:DL Old TO Released rig Classifications (oil, gas, etc.) 50-~'$~-~52~t~umber of wells (active or inactive) on this, Icost center prier to plugging and I labandonment of this well if a W.O, Complete record for each day reported u~/J,q/O~ V:~vv t"&%~ KvhL' ~ KIG 5 ;OTE: RIG RELEASED MW: 9.5 NRC1 SET RTTS AND SSV 3' BELOW TBG HEAD. N/D BOP. ATTEMPT TO TA~ THREADS IN LOCK DONN SCREWS-W/O SUCCESS. N/D TBG HEAD AND N/U RECONDITIONED 11"5M x 7-1/16"5M TUBING SPOOL. TEST TO 3,000 PSI. PULL RTTS/SSV. SPACE OUT AND LAND TUBING. SET BPV. N/D BOP AND N/U TREE. ATTEMPT TO TEST ADAPTER FLANGE. WOULD NOT. TEST. SECURED WELL AND RELEASE RIG AT 0400 HR 4/26/89. DAILY:S40,709 CUM:$360,517 ETD:S360,517 EFC:$410,000 Jim Zernell recieved verbal approval by Lonnie Smith (AOGCC) & Aden Siedlitz (BLM) on 5/1/89, to delay final work until replacement wellhead equipment could be obtained. Detailed description of final work will follow. N/U BOP MW: 9.5 NaCl MOVE RIG FROM SCU 23B-3 TO 42A-5 TO CHANGE OUT TUBING SPOOL. RIG ACCEPTED AT 0300 5/16/89. N/D TREE. N/U BOP ' DAILY:$14,330 CUM:$374,847 ETD:$374,847 EFCt$410,000 RIG RELEASED MW: 9.5 NaCl N.U BOP AND TEST SAME. PULL HANGER AND SPACE OUT. SET ST~ PACKER. N/D BOP AND C/O TUBING HEAD. TEST TO 5000 PSI. N/U AND TEST BOP. PULL STORM PKR. M/U TUBING HANGER AND LAND SAME. TEST ANNULUS TO 2000 PSI. SET BPV. L/D SUB AND N/D BOP. SET TREE AND TEST TO 5000 PSI. MOVE RIG OFF DAILY:$~0,100 CUM:$404,947 ETD:S404, epthgFc:S410,000 IOate ~ind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abov..e is correct ~-/m/.~? Drilling Supt For form prell'ration and distribufi~, see Procedu Sl~l~l~anuai, Section 10, Drilling, Page~ 86 and 87. a: 'Number ali daily well history forms consecutively I Page no. ~as they are prepared for each well. I AR3B-459-3-C Dlvldon of AtlantlcRIehfleldComlN - A(b STATE OF ALASKA ALASK IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~, GAS ~ SUSPENDED ,~1 ABANDONED ~ SERVICE [] ,,, 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. N/A 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 133-20232-01 4. Location of well at surface 9. Unit or Lease Name 1879' FSL, 498' FEL, Sec. 5, T7N, RgW, SM Soldotna Cr,eek Unit At Top Producing Interval 10. Well Number 1594' FNL, 481' FEL, Sec 5, T7N, R9W, SM SCU 42A-5 At Total Depth 11. Field and Pool 1432' FNL, 426' FEL, Sec. 5, T7N, Rgw, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Swanson Ri vet, Fi el d 167 ' RKBI A-028996 Hemlock 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set [ 21. Thickness of Permafrost 11180'MD/10797'TVD 10993'ND/10599'TVD YES J~ NO []! None feet MDI N/A . .. 22. Type Electric or Other Logs Run CBL/VDL/Wavefor,rn, CNL, TOTK~ Single-Shot Svy 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE~wT.PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1R" ...... S~,rf 74 ' --- Driven None 1(3-~//~" /~0_~# K-_~5 .~urf _~.~8_~' . 15" 1175 sx Class G None 7" 9q_O/?"4.d~ N-RI3/P-11{3 .~,,~,f 10b, 1t3' q-7/R" 1R/~O .~x Clm.~.~ ~ - Rn?r w/400 sx 5" 18.O# 'N-80 10191' 10993' G" 75 ft3 Class G - Top jgb w/20 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 10807 ' 10080 10893 ' -10896'MD/10509' -10512 ' TVD ' . ...... 10916' .10920 ' MD/10530 ' -10534 ' TVD ..... 10988 ' -10992 ' MD/10594 ' -10598 ' TVD 26. ACID, F RACTUR E, CEMENT SOU E EZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED , NA , , , , 27. N/A PRODUCTION TEST Date First Production Method of Operation {Flowing, gas lift, etc.} Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MGF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED =~ OIL-BBL GAS-MGF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE '28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. None RECEIVED JUN071989 *Note= Workover' performed O4/26/89. A/as/(a Oil & Gas Cons. WCl/9 Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ 29. 30. GEOLOGIC MARKEF~s FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A · . . .. . . · . · 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge -. ........... Signed .... INSTRUCTIONS General: This form is designed for submitting a complete and correct wei! completion report.,a.nd ,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 (QF, 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..2.7:. Method· of Operation' Flowing, Gas Lift., ROd Pump, Hydraulic Pump, Submersible, Water In- jection, Gas InjeCtion, Shut-in, Other-explain. ' ....... ~' ~'''" A L~,.,KA OIL ANDsTATE OF ALASKA coM M ~",.,.ON GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate m Pull tubing ~__ Variance __ Perforate ~ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1879' FSL, 498' FEL, Sec. 5, T7N, R9W, SM At top of productive interval 1594' FNL, 481' FEL, Sec. 5, T7N, Rgw, SM At effective depth 1550' FNL, 471' FEL, Sec. 5, T7N, Rgw, SM At total depth 1432' FNL, 426' FEL, Sec. 5, T7N, Rgw, SM 12. Present well condition summary Total depth: measured true vertical 11180 'MD 10797 ' TVD feet feet 5. Type of Well: Development Exploratory Stratigraphic Service Plugs(measured) None 6. Datum elevation (DF or KB) RKB 167' 7. Unit or Property name Soldotna Creek Unit 8. Well number 4?A-':i 9. Permit number 10. APl number 50-- 133-2023 2-01 11. Field/Pool Hemlock 10993 'MD Effective depth: measured true vertical 10599 'TVD feet feet Junk (measured) No ne Casing Length Structural 59' Conductor 3370' Surface 10395 ' Intermediate 802 ' Production Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 18" Dr i ven 74 'MD 74 'TVD 10-3/4" 1175 sx 3385 'MD 3385 'TVD 7" 890 sx 10410'MD 10074 'TVD 5" 75 sx 10993 'MD 10598 'TVD 10893 ' -10896 ' , 10916 ' -10920 ' , 10988 ' -10992 ' true vertical 10509'-10512', 10530'-10534', 10594'-10598' Tubing (size, grade, and measured depth) 3-1/2" N-80 to 10828' Packers and SSSV (type and measured depth) FHL ~ 10,133' RE£E VED ,0il & Gas Cons..Commission 13. Attachments Description summary of proposal ~' Detailed operations program __ BOP sketch 14.FebruaryEStimated cJate.~f.r ~commencing/, -,~ operation I 16. If proposal was verbally approved I Oil __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best.of my knowledge. p Area Drilling Engineer Signed ,, ~ ~C_~,,.~Z/ Title / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~d~ ~' 15. Status of well classification as: Gas Suspended __ Date IApproval No, /~ .-~i-.~ OR!SINAI. SIGNED BY Approved by order of the Commissioner LONN!F C SMITH Form 10-403 Rev 06/15/88 046/5A4 .Approved Copy Returned f'"/~'"~:)/~' Commissioner Date SUBMIT IN TRIPLICATE feet SRU 42A-5 GENERAL PROCEDURE PRE-RIG ARRIVAL 1. Ensure the well is still dead and full of 9.1 ppg brine. If necessary, circ well through GLM one jt above packer, pumping kill pills as neccessary. 2. Chase threads in BPV profile. RIG OPERATIONS 10. 1. MIRU Roll'n 5. Establish circulation to ensure well is dead. ND tree. NU BOPS & test same. ' ' 2. Release Baker FHL packer(if not already released). Circulate BU. POH LD tbg. 3. Make a 6" bit and scraper run to TOL @ 10191'. Circ'bottoms up and POH. 4. GIH with a retr. BP. Set same at 10125' and test csg. PU a storm pkr, set same 1' below tbg spool. Rel from pkr. 5. Change out tbg spool. NU and test BOPS. Retr. pkr and BP. 6. Make a 4-1/8" mill and scraper run and clean out fill to TD @ 10994'. Circ hole clean. 7. POH and LDDP. 8. RU WL. Run casing inspection log in 7" only. Perf 5" with 3-3/8" casing guns. RD WL. 9. Run a new 3-1/2"completion with 2-7/8" tailpipe below the packer. Set the packer in the 7" @ +/-10100' and run enough tailpipe to put the tbg tail +/-75' above the top perf in the 5" liner. Release Rig. Displace the well to lease crude after the rig is moved off. .Oil & ~as Cons. ,ell ,i 4S uTS --- $057.25' -- CAMCO MAHONE~. 39Z" in0 --? ~l ,~S 3~/~'' $ 2 e H-IG In0 H-SO Id '-- S4el.40' -,, CAMCO MAN0#E~ 31/Z'' eNO eS -- SlTt.tS' -- CAMCO MANONE~ 31/Z" IN014 I UTS $~/~' E E E · -- SI4Z.II' -- CAMCO Z PUP UTS 3¥Z"e.Z# N-lO SA0 3iZl CLMC0 MANONEL ~t/~' tie M-lO OTIS 'S' NIPPLE P01 --,0,4S? OC' W~NOOW 23 JTS SEAL ~QK. 3~/~"eZl N-I0 t~0 W/ P-~s0 SCU 42A-5 CASING & TUBING DETAI SEC. 5, TTN. R9W. $.M. ANNULAR PREVENTER 7 PIPE RAILS 6 1. zo~/"/" SURFACE CASING 2. I I" CASING HEAD / / "-5 000 PSI FLANGE '~ II "- 5'.000 PSI X'/'/J'~ 5000 PSI TUB lNG HEAD 4.'1%c - 5000 PSI X 11" - 5000 PSI CROSS-OVER SPOOL. 5. 11" - 5000 PSI BLIND RAHS 6, I 1" - 5000 PSI PIPE RAMS 7. 11"- 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1, CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRE~,~URE I~ 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADO REPORT. THE ACC,,EPTABLE LOWER LIMIT' IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRE~URE. BOP ST ACK, TEST 1, FILL BOP STACK AND MANIFOLD WITH BRINE. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN 50REW$ IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PS! AND HOLD FOR 10 MINUTES. BLEED TO ZERO 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAHS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRES,SURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSt WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. DM MARCH 9, 1987 . ARCO Al~ka, Inc. ( Post Office Box 100350 Anchorage, Alaska 99510-0360 Telephone 907 275 1215 Cook Inlet/New Ventures Engineering September 19, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Sundry Notice for SCU 42A-5 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to acidize, re-perforate and add perforations in Well SCU 42A-5. We propose to first stimulate the current H1 and H2 intervals with half strength mud acid. Subsequently, we propose to add perfs in the H1 (10,875'-10,886' and 10,893'-10,902'), H2 (10,922'-10,926'), H3 (10,948'-10,970') and H4 (10,978'-10,988') with 2-1/8" hollow carrier perforating guns at 4 SPF. In addition, we may re-perforate the current H1 (10,886'-10,883' MD) and H2 (10,917-10,920' MD) perforations with 2-1/8" hollow carder guns at 4 SPF. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Carol Baker at 263-4643. Sincerely, T. S. McCorkle Cook Inlet Engineering Manager TSM:CMB:cmk:0002 Attachment CC: Mr. J. Coltart Chevron Mr. D. Jones Marathon Mr. G. Graham UNOCAL ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon F'I Suspend [] Operation Shutdown [] Re.enter suspended well [] Alter casing [] Time extension E] Change approe~l program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Ala.qka Inc. 3. Address Post Office Box 100360 Anchorage, AK 99510 4. LocatiOn of well at surface 879' N and 498' W of SE comer of Sec. 5, T7N, R9W, SB&M At top of productive interval 1804' N and 17' E of SL At effective depth At total depth 1969' N a~d 72' E of SL 11. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured feet true vertical feet Junk (measured) Casing Length Size Cemented Structural Conductor Surface 7 4' 18" Driven Intermediate 3,3~ 10-3/4" 1,57~ Production 10,410' 7" - ........ 321' 5" 75 C. F. Liner Perforation depth: Current Proposed Add Perfs 10,886' - 10,893' MD 10,875' - 10,886' MD 10,917- 10,920' MD 10,893' - 10,902' MD 10,988' - 10,922' MD 10,922' - 10,92¢ MD Tubing (size, grade and measured depth) 3-1/2", N-80, 10, 828' MD 5. Datum elevation (DF or KB) 167' KB 6. Unit or Property name Soldered Creek Unit feet 7. Well number SCU 42A-5 8. Permit number 9. APl number 50-- ] 33-20232-0 ]' 10. Pool Measured depth True Yertica[depth :0- 74' 0 -074' 0-3,385 0-3,385 0- 10,410' 0- 10,076' ya,/..~:t:; 10,731' qef9- 10,397' 10,948'- 10,970' 10,978'- 10,988' Proposed Reperfs: 10,886' - 10,893' MD 10,917' - 10,920' MD Packers and SSSV (type and measured depth) Baker FHL Packer (7", 29#), 10,133; MD 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation September, 1988 14. if proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed'~,. [~~~,~..~ ~,~ 'T~ ~,.~.~ Title Cook Inlet Eng~eefing Manager Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. 4~ 7~q [] Plug integrity [] BOP Test [] Location clearance ~ - 3~i~,)AI SIGNED BY Approved by 4~O,NNIE C. SMITH Form 10-403 Rev 124-85 ~,pproved Copy Returned _ Commissioner by order of Y~")I the commission Date f'~a97 ~ Submit in triplicate SCU 42A-5 STIMULATION/ADD PERF PROCEDURE OBJECTIVE: To selectively stimulate the recently added HI and H2 perforations, successively trying treatments (xylene and mud acid) until a production increase is realized. Subsequent to the stimulations, additional HI, H2, H3 and H4 intervals will be perforated. Completion: Minimum Restriction: PBTD: Tie-in Log: Current Wellhead Pres: Tubular Capacities: 3-1/2" Tbg. to 10,745' ELM 2.875" ID Otis "S" Nipple @ 10,074' ELM 10,989' ELM (6/11/88) CBL (9/28/81) ,i~...:~. ..... FTP = 3,100 psi; PC = 500 psi; SC = 130 psi 3-1/2" tbg = .00870 Bbl/ft; 3-1/2" x 7" annulus = .0252 Bbl/ft; 5" liner = .0177 Bbl/ft NOTE: Top of fish is located at 10,994' MD. CTU Mud Acid Stimulation 1. Flush clean pump track, lines, mixers and CTU. (NOTE: If CTU has not been recently used may need to be pickled with acid to clean it UP). . Titrate acid on location to ensure proper acid concentration, as per attached procedure. (Procedure should be witnessed by an ARCO company representative). In addition, assure that emulsion/sludge testing has been satisfactorily performed (step #2). 3. MIRU stimulation company and CTU. Pressure test lines and CTU to 4,000 psi. 4. Roll all acid compartments before pumping starts. 5. RIH with CTU to 10' above PBTD circulating with dead produced crude as needed to liquid-pack annulus. . While circulating (keeping the fluid return rate equal to the CTU pump rate), pump 4 Bbls of 2% NH4C1 water weighted with 9,5 ppg NaC1 salt. It is important to use only high quality NaC1 salt (low calcium content) when weighting up the 2% NH4C1 water.* (This weighted water will keep acid from settling in the rat hole). Displace with 2% NH4C1 water* to balance at hole bottom). 7. Pull CTU uphole to 10,905' MD. Let weighted water settle for 20 minutes. 8. SI the CTU/Tbg. annulus. 9. Pump the following fluids. (Do not exceed a .68 Bbl/ft frac gradien0: A. 20 Bbls of 2%NH4C1 water* B. 400 gals. of 7-1/2% HC1 with additives* C. 800 gals. of 6% HC1 - 1-1/2% HF with additives* D. 1,000 gal. of 2% NH4C1 water* with 10% mutual solvent and 1% clay stabilizer. E. Displace coiled tubing with dead produced crude (16 Bbls). NOTE: Friction reducer is to be added to all fluids pumped. All fluids except displacement crude should be filtered to 2 microns. ACID ADDITIVES Dowell- Additive Ouantitv Schlumberger Halliburton Corrosion Inhibitor 0.2% Iron sequestering agent 100g/1000 gal Erythorbates (iron stabilizer) 20g/1000 gal (max) Surfactant ** Anti. sludge agent/non-emulsifier ** A250 HAI-75 L-41 Ferchek A, Fe2 L-58 Ferchek F-75N LoSurf 300,251 or 259 W-35 AS-5 ** To be determined by lab testing (step #2). 10. POOH while producing well using gas from 42B-5 for gas lift gas. Continue producing well after CTU has been pulled. 11. (Note that acid may not be completely spent when it is produced to the surface. Soda ash should be used to neutralize any unspent acid). 12. After all load has been produced and well is flowing on its own, well may be taken off gas lift. (Load volume is approximately 180 Bbls). 13. Once all the stimulation fluids have cleaned-up, obtain a production test on SCU 42A-5 while drawing down well approximately 600 psi. Perforations 14. MIRU slickline unit. Pressure test lubricator to 4,000 psi. 15. RIH with a 2-3/8" gauge ting to top of fill. 16. If fill is above 10,989' MD, clean out to PBTD (10,994' MI)) using a bailer. 17. RDMO slickline unit. 18. SI well. MIRU conductor line unit. Pressure test lubricator to 4,000 psi. 19. RIH with perf gun/CCL. Tie in to perf' interval: Perforation Intervals (CBL is on depth with CNL) t~BL (9/28/81) Footage Sand SPF - 10,875-10,886' 10,886-10,893'* 10,893-10,902' 10,917-10,920'* 10,922-10,926' 10,948-10,970' 10,978-10,988' 11' MD H1 4 (7' MD)* H1 4 * Only shoot if 9' MD H1 4 well did not (3' MD)* H2 4 respond to xylene 4' MD H2 4 or mud acid sfim- 22' MD H3 4 ulations. (Consult 10' MD H4 4 with Carol Baker). TOTAL 5 6' MD (66' if all intervals are perfed). Recommended Guns Hole Hole Company.. Type Gun. Size Phasing Depth Diameter Schlumberger Domed Scallop 2-1/8" 0° 7.92" 0.34" Arias Jumbo Jet 2-1/8" 0° 6.40" 0.344" NOTE: Gun orientation should be down (at hole bottom). 20. Open tubing to flow (as possible) and fire shots. 21. Allow well to flow 15 minutes (as possible). SI. POOH. Check gun to conf'mu that all shots have fired. 22. Repeat steps g47 - 49 as needed to perf all intervals. 23. RDMO. Test well. eeeo L tm dTI, tP~ d~ ~/I · o*ltOJ, el' -- I pup afl $'/1' E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension L Manual Rams Swab Valve Double Maste~ Valves Wellhead ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering July 6, 1988 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Report of Sundry Well Operations: SCU 42A-5 Dear Mr. Chatterton: Attached is a Report on Well SCU 42A-5 regarding the m-perforation of the H3 and H4 intervals of the Hemlock formation. If you have any questions, please contact me at 263-4304. Sincerely, Tom Wellman Interim Manager TW:WJO:ch:0014 Attachment Mr. F. Hallmark Mr. W. Kirchner Mr. S. Lambert Wellffle SCU 42A-5 WI Chevron U.S.A., Inc. Marathon Oil Company UNOCAL Corporation RECEIVED JtJ L 1 1 1988 Alaska 0ii & Gas Cons. Commission ,, Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASI~ )IL AND GAS CONSERVATION COMI~~' ;ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate I:[] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. 167' KB Feet 3. Address 6. UnitorProperty name Post Office Box 100360 Anchorage, AK 99510 Soldotna Creek Unit 4. Location 1,879 ' At top of 1,804' N & 17' W of SL of well at surface N & 498' W of SE corner of Sec. 5, T7N, R9W, SB&M productive interval At total depth 1,969' N & 72' E of SL 11. Present well condition summary Total depth: measured true vertical 7. Well number SCU 42A-5 8. Approval number _/ 9. APl number 50-- 133-20232-01 10. Pool Swanson River - Hem Iocl feet Plugs (measured) feet Effective depth: measured feet true vertical feet Junk (measured) Casing Length Size Cemented Surface 74 ' 18" Dr i van Intermediate 3,385' 10-3/4" 1575 SX Production 10,410 ' 7" --- Liner 321' 5" 75 C.F. Perforation depth: Measured depth ~ueVerticaldepth 0-74' 0-74' 0-3,385' 0-3,385' 0-10,410' 0-10,076' 10,191-10,731' 9,871-10,397' 12. Tubing(size, grade and measured depth) 3-1/2", N-80, 10,754' MD Packers and SSSV(type and measured depth) Baker FHL (7", 29#), 10,133' MD Stimulation or cement squeeze summary Intervals treated (measured) -- Treatment description including volumes used and final pressure JtlL 1 t 1988 A,,~.,...ka 0ti .& Gas Cons. Commission ,, =Anchorage 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 250 Subsequent to operation 300 14. Attachments Daily Report of Well Operations 17,394 107 410 21,000 115 440 Copies of Logs and Surveys Run [] 3,000 3,00O 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ /~"/~.~ ~-----~ Title Cook Inlet Interim Manager Form 10-404 Rev. 12-1-85 Date Submit in Duplicate..._.._ ~ DAILY REPORT OF WELL OPERATIONS SCU 42A-5 Re-Perforate H3/H4 Sands 6/10/88 6/10/88 MIRU slickline unit. Pressure test lubricator. RIH with 2.60 gauge ring and tagged fill @ +10,964' (WLM). POOH. RD wireline and secured well. MIRU Dresser Arias E-line unit. RIH with CCL and perforating guns. Correlate depth with CBL. Select fire interval 10,916' to 10,920' (WLM), 4 SPF with 2-1/8" HSC guns. Select fire second interval 10,893' to 10,896' (WLM), 4 SPF with 2-1/8" HSC gun. POOH. All shots fired. RD Dresser Arias and secure well. RECEIVED J tlL 1 1 1988 Alaska Oil & Gas Cons. Commission Anchorage ,,,o?! nO 0IL tun /OB II ICu41&.I 0~TML , ~ :..:i · · - · mii I · · ~__.~ _._ ::~ : .':.:: J _ I -- 3111'.18' -- CAMCO MANOR(t. 31/2 2 ilul) ,)'rS 31/2"92e N-lO 31 d'rS 3t/2'' g 2o ~-IC) SlID -- 4888 IS' -- CAMCO MAN0II[L 30/2.. 8AD 08 20dTS 3u~" tZu N.lO Olio 24tS ~4 812 S 490.40' t OUP dT JZ JTS 3 SI?I.I]' -- CAMCO 2 PUP JTS 3t/2" 9.2m N~ I~0 O tiTS 30/2' 9.20 N-lO eNO 6142.J2' I pup dT 31~'' 9.20 N-lO 3 UTS 3e/Z" 6247.63' 2 PUP 6 6; 38? 4 6. 245; 6i 6~ 125 JTS 31/2' 9.21 N-lO lliO --10,091.9S' -- CAMCO MANOIIEL. 31/2' 8iq0 III IdT, IfJUP J? 31/2' 9~248 #-80 eli0 --IO,133.02' -- lAKER FH~ PACKEN ?' ZSm xo IND, IMPRESS PUP JT, xo 8RO --,~,,47. S?' - OTIS'S'NiPP~[ P~~~~ X0 ~JO, iSi 00' ~ TOP 0F ~IN~ -- ,o. 4 ~ o oo' - ,o., s ? o~' w, N O0 w GaS ~O~S. 23 JTS SEAL. L.0K. 3E/2"92~ N-80 0lA0 w/ P-s~O TUIIN[D & IEV[t*L.£D C0t*~.AAS 34.~. -- ~S'-SHEAII SUB S CU 42A-.5 CASING 8~ TUBING DETAIL SEC. 5, TTN, Rgw, $.M. ARCO Alaska, Inc. Post Office Bo}r, 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook l'niet/New Ventures Engineering June 6, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Sundry Notice for SCU 42A-5 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to re-perforate the casing in Well SCU 42A-5. We propose to re-perforate the H3 interval from 10886' to 10893' MD and the H4 interval from 10917' to 10920' MD with 2-1/8" hollow carder perforating guns at 4 SPF. Initial rates, shortly after perforating these zones on April 25th, exceeded 900 BOPD but quickly dropped off to pre-perforated levels. If results are positive, we anticipate periodically diverting xylene to these sands to maintain the well's oil rate. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Wes Peirce at 263-4228. Sincerely, T. Wellman TW:WJO:ch:0014 Attachment ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany K~" OIL STATE OF ALASKA ALAS AND GAS CONSERVATION COMMI~SSION APPLICATION FOR SUNDRY APPROVALS '1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360 Anchorage, AK 99510 4. Location of well at surface 1879' N and 498' W of SE corner of Sec. 5, T7N, R9W, SB&M At top of productive interval 1804' N and 17' E of SL At effective depth At total depth 1969' N and 72' E of SL 11. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet 5. Datum elevation (DF or KB) 167' KB feet 6. Unit or Property name Soidotna Creek Unit 7. Well number SCU 42A-5 8. Permit number 9. APl number 50-- 133-20232-01 10. Pool Swanson River - Hemlocl~ NONE Casing Length Size Surface 74 ' 18" Intermediate 3,385' 10-3/4" Production 10,410 ' 7" Liner 321' 5" Perforation depth: 10,886- 10,893' MD 10,917- 10,920' MD 10,988- 10,992' MD Tubing (size, grade and measured depth) 3-1/2", N-80, 10,828' MD Packers and SSSV (type and measured depth) Cemented Measured depth True Vertical depth Driven 0 - 74' 0 - 74' 1,575 SX 0 - 3,385' 0 - 3,385' -- 0 - 10,410' 0 - 10,076' 75 C. F. 10,410 - 10,731' 10,076 - 10,397' RECEIVED. B 19B$ FHL 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation June 6, 1988 14. If proposal was verbally approved Name of approver Sul:)sequent Work Reported on F°rm N°'/~'~Dated ~''~~~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ /.,4~~~..___ Title Cook IN let Engineer lng Manager Date ¢/-¢, -~' Commission Use Only Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy Returned commissioner by order of the commission Date~'/'r ~"]" Form 10-403 Rev 12-1-85 Submit in triplicate E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual' Rams Swab Valve Double Master Valves Wellhead SCU 42A.5 PERFORATING PROCEDURE OBJECTIVE: To increase production by perforating the casing opposite the H3 and H4 sands. WF~LL STATUS: Minimum Tubing Restriction: Sidetrack completed 10-9-81. No open-hole logs available for this well; cased- hole logs (9-29-81) available are: CBL, VDL-Waveform, GR-CNL and TDT-K. Perforated (10-4-81) 10988-10992' MD with 3-3/8" hollow carrier gun @ 4 SPF (16 holes Total). H3/H4 zones were perforated for the first time on 4-25-88 using 2-1/8" hollow carrier perorafing guns. At that time, tubing tail was noted to occur at 10,754' MD (not 10,827' MD). The well is currently flowing 266 BOPD (209 BWPD, GOR = 90 Mcf/STB). Wellhead pressures as of 5-26-88 are, FTP = 2750 psig PC = 425 psig SC = 120 psig Otis "S" Nipple @ 10,147' MD has 2.875" ID. Before Proceeding: Confmn with Anchorage that both the BLM and AOGCC Sundry Notices have been approvecL PROCEDURE: 1. MIRU Slickline Unit. Pressure test lubricator t~ 4000 psig. 2. R1H with a gauge ring to top of fill.' Last Slickline tag occurred on 4-21-88 to a depth of 11,002' MD using a 2.8" gauge ring. 3. RDMO Slickline Unit. 4. MIRU Wireline Unit. Pressure test lubricator to 4000 psig. 3. RIH with a tool string consisting of, from the bottom, a bull plug, a 6' 2-1/8" hollow carrier perforating gun loaded with 4 feet of 4 SPF (0°- phase) perforating charges, a f'u-ing head, a CCL, weight bar, and a cable head. The onsite Operations Engineer should tie-in the perforating guns. 6. Position the gun so that the bottom shot perforates the 5" liner at 10920' MD. 7. Perforate the casing with the gun described in step #5. POOH with the spent perforating gun. 8. RIH with a tool string consisting of, from the bottom, a bull plug, a 10' 2-1/8" hollow carrier perforating gun loaded with 7 feet of 4 SPF (0°- phase) perforating charges, a firing head, a CCL, weight bar, and a cable head. The onsite Operations Engineer should fie-in the perforating guns. 9. Position the gun so that the bottom shot perforates the 5" liner at 10893' MD. 10. POOH with the spent perforating gun. RDMO Wireline Unit. .,}. ,. 11. Test the well on the following days after perforating is complete: 1, 3, 6,.1'0 and 15. Oil & Sas Cons: commission 'Alaska HI si·TI ilo 8iL M plo -dl~J ,~1 ,N. ,c, .,., ,,iN,u.. ;Zl .umm,m,mum :**0.% i ~ dYl, IPUP ,dY I&/~' · 1 · m-00 · *llOJ.4t* e CAMCO MAN0tE~ II/~" IR0 01 PUP JYl 1°/2" ·.l · #.00 0lEO 48 d?l II/"~" t.l· Nolo l~O -- 1liT.Il' -- CAMCO MAts0tEL 31/~" llEO I! 4lIS IS' -- CAK0 MAts0AE~ 3t/Z'' IA0 II PUP J~S 31/2.* 920 ts*10 lA0 20JTS 3l/~" 920 ts-lO 0SE0 -- S411.iO' --CAMCO MANOAEL. 3t/2" lA0 OS t PUP ,,iT 2~"1" t. 2 e ts-lO 01EM -- S171.t1' -- CAMCO MANOAE~ 3 l/z** I A0 04 Z PUP dTS 31/Z"9.2· ts-lO eno t ,JTS 3¥8" 1.20 ts.lO 0SE0 ---"' ll42.12' ,-., CAMCO MAts0AEI. 31/2" 1AD mS I PUP dT 31/~" 9.20 ts·tO 8sE0 3 ,JTS 3Y2" t 20 ts*lO 0SE0 ,-.-, 6247.61' ,-, CAMCO MAN0#E~ 31/l" liE0 aZ Z PUP aTE 3l/~" 9.20 N-I0 0SE0 -,-,10,091.IS* -, CAMCO MAts0IEE~ 31/Z" lA0 · I laT, IPUP aT 31/2"1.248 ts-lO "-'-10,133.02' ,.- lAKER FHA. PACKER ?" 200 xO liE0, IUTTRESS PUP ~T, XO ~ 1~,I4F. SY* -- OTIS 'S* NIPPL~ POS x0 m tO,IOI OO' --TOP OF 10,401' 4lq" dNH IOZ'O 10/Il ~00,400 00' 080,4870~' wiN00w 80,480' 4 JN~ oO/ll 23 JTS SEAl. I. OK. 38/2"92a N-lO lAD w/ I 8 8~ 81Z ~ 8, 38? d I 34, t. S. I. .---~2'oSNEAIE JO.IlL* 4'Qlt~ 4a#M PII~I tO/Ii JO.Ill' TOll OP fflSN S CU 42A- 5 CASING 8~ TUBING DETAIL $E¢. 5', TTN,RBW, $.M. Nee ~0/! ARCO Alaska, Inc.'~( Post Office Bo~( 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 David S. Joiner Engineering Manager Cook Inlet/New Ventures May 16, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Report of Sundry Well Operations: SCU 42A-5 Dear Mr. Chatterton: Attached is a Report on Well SCU 42A-5 regarding the perforation of the H3 and H4 intervals of the Hemlock formation. If you have any questions, please contact Tom Wellman at 263-4304. Sincerely, D. S. Joiner DSJ:WJO:ch:0013 Attachment ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASI~~ '3IL AND GAS CONSERVATION COMitY' ~ION REPORT tJi= SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate I~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360 Anchorage, AK 99510 ~-Location of wellatsurface 1879' N & 498' W of SE corner of Sec. 5, T7N, R9W, SB&M 5. Datum elevation(DF or KB) 167' KB 6. Unit or Property name Soldotna Creek Unit 7. Wellnumber SCU 42A-5 At top of productive interval 1804' N & 4'7' E of SL At total depth 1969' N & 72' E of SL 11. Present well condition summary Total depth: measured true vertical 8' AP pr°val ~:~ m_,~r~,,jO 9. APl number 50-- 133-20232-01 10. Pool Swanson River-Hemlock feet feet Plugs (measured) Feet Effective depth: measured true vertical feet feet Junk (measured) Casing Length Size Surface 74 ' 18" Intermediate 3385 ' 10-3/4" Production 10410 ' 7" Liner 321 ' 5" Perforation depth: Cemented driven 1575 SX ___ 75 C.F. Measured depth 0-74' 0-3385' 0-10410' 1019'1-10731' ~ueVerticaldepth 0-74' 0-3385' 0-10076' 9871-10397' Tubing(size, grade and measured depth) 3-1/2", N-80, 10,754' MD Packers and SSSV(type and measured depth) Baker FHL (7", 29#), 10,133' MD 12. Stimulation or cement squeeze summary Intervals treated(measured) -- Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Wate>Bbl Casing Pressure ~bing Pressure 198 17,623 116 420 3,100 249 17,394 107 410 3,000 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Cook Inlet Engineering Manager Date Submit id DuplicatE~.,.,._,.. DAILY REPORT OF WELL OPERATIONS SCU 42A-5 Perforate H3/H4 Sands 4/21/88 4/22/88 4/24/88 4/25/88 MIRU slickline unit. Pressure test lubricator. RIH with 2.8" gauge ring and tagged fill at 10,999' MD. POOH. RD slickline unit and secured well. MIRU Schlumberger E-line unit and pump track. Pumped 20 Bbls of lease crude down the tubing. RIH with 11' of 2-1/8" hyperdome charges in a hollow carrier with a CCL and a magnetic decentralizer, charges wired to select fu'e 4' and 7'. Tied in CCL to CBL and attempted to perforate 10,916 - 10,920' MD and 10,886'- 10,893' MD. POOH. No shots fired. RD Schlumberger and secured well. MIRU Schlumberger E-line unit and pump track. Pumped 20 Bbls of lease crude down the tubing. RIH with 11' of 2-1/8" hyperdome charges in a hollow carder with a CCL and a magnetic decentralizer. Charges wired to select fire 4' and 7'. Tied in CCL to CBL and attempted to perf 10,916' - 10,920' MD and 10,886'- 10,893' MD. POOH. No shots fired. RD Schlumberger and secured well. MIRU Schlumberger. RIH with 11' of 2-1/8" hyperdome charges in a hollow carrier with a CCL and a magnetic decentralizer at 4 SPF, 0° phase. Charges wired to fire 4' and 7'. Tied in CCL to CBL and perforated 10,916' - 10,920' MD and 10,886' - 10,893' MD. POOH. All shots fired. RD Schlumberger and secured well. HI "!'~ :.. J e.l.i---- EL. EVATION 140 11 ,ITS, IPUP --'Z503.45' --, CAMCO MA#OREI. $1/2" IRC) e! 45 ,,ITS 31,/"Z'' 9.~a, N-e0 BRO 3S97.26' -- CAMCO MANDREL. 31/2'' eND l? UTS 31/2'' 9 2M N-SG 8RO -- 4665.16' -- CAMCO MANOREL $1/2" eRD B6 20J?S 38/2" 9:'ii N-6C) 8RD -- S4ge.40' --CAMCO MANOREL. 8 PUP ,IT 3~/2" 9.2ii N-SO SRO -- se?e.6~' -- CAMCO MANOR(~ 2 PUP uTS ~t/Z" 9.Z~ 8 ~TS 31/2" 9.2. N.80 ~ 6142.62' -- CAMCO MANDNE~ J PUP dT 3i/2" 9.20 N*80 3 uts 3~/2** 9~2~ N*eO ~ 624?.63' ~ CAMCO MAN0~ 3J/2** 2 PUP JTS 3l/2'' 9.20 N-80 0Oi4' 4~/2" ~p1 SOZ D TWtCE 5/?2 126 dTS 3 l/2'* 9.2 ~ N-e0 · --10,091.96' -- CAMCO MANDREL. 31/2'SR0 #l I,IT, IPUP JT 38/2" 9248 N-e0 SRO --10,133.02' -- BAKER FHL. PACKER ?" 29# XO eND, BUTTRESS PUP ,IT, XO ORD --I~,I4T. S?' -- OTIS ~S' NIPPLE POS 2 xo --IO, iBi 00' --TOP OF LINCR t0,402' 4~" uHo~ SQZ'O tO/el -- ~O,410.O0' --~O,4S? 0~' WINDOW 10.4~0' 4 JNPF lO/II 23 JTS SEAl. L.OK. 3I/2"92~t N-e0 eNO w/ P-lBO TURNED &SEvEt. L. ED C01..L. ANS I?~ 2485 ~378 949 I4 2 6J2 6~ 367 245. 6.1~ 92.~ 3827 6.4 34.5 9.4 I.~ 5~ -- ~2'-SHEAR SUB -- ,,~.gn ~' - 10.908' 4°Otr 4J#l~' PfNF! lO/el ~ 100994.00' EFF~CTIYE DEPTH TOP OF FISH S CU 42A- 5 CASING 8~ TUBING DETAIL SEC. 5, T7N,R9W, S.M. ARCO Alaska, Inc.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 David S. Joiner Engineering Manager Cook Inlet/New Ventures April 20, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Sundry Notice for SCU 42A-5 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to perforate the casing in Well SCU 42A-5. We propose to perforate the H3 interval from 10886' to 10893' MD and the HZ[ interval from 10917' to 10920' MD with 2-1/8" hollow cartier perforating guns at 4 SPF. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Tom Wellman at 263-4304. SincerelY, D. S. Joiner DSJ:WJO:ch:0011 Attachments RECEIVED APR 2 1 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieidCompany STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing [] Time extension .-1 Change approved program ~ Plugging C Stimulate ~ Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator 5. Datum elevation(~3~=XffMKB) ARCO Alaska, Inc. 167' KB feet 3. Address 6. UnitorPmperty name Post Office Box 100360 Anchorage, AK 99510 Soldotna Creek Unit 4. Location of well at surface 1879' N and 498' W of SE corner of Sec. 5, TTN, Rgw, SB & M At top of productive interval 7. Well number SCU 42A-5 8. Permit number 3677' N and 482' W of SL At effective depth At total depth 1969' N and 72' E of SL 9. APl"'"number 50-- 133-20232-01 10. Pool S~anson River - Hemlock 11. Present well conditiOn summary Total depth: measured true vertical feet Plugs (measured) feet NONE Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Surface 74 ' 18" Dr i ven Intermediate 3,385 ' 10-3/4" 1,575 SX Production 1 O, 410 ' 7" -- Liner 321' 5" 75 C.F. Perforation depth: Measured depth True Vertical depth 0 - 74' 0- 74' 0 - 3,385' 0 - 3,385' 0- 10,410' 0- 10,076' 10,410-10,731. ' 10,076-10,397' RECEIVED Tubing (size, grade and measured depth) 3- 1/2", N-80, 10,828' MD Packers and SSSV (type and measured depth) Baker FHL Packer (7", 29#), APR 2 t Alaska 0il & Gas Cons. Commission 10, 133 ''-M/~ch°rage 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation April 27, 1988 14. If proposal was verbally approved ......... ., Name of approver aa ~ ~ ,, Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~.'/ ~/~, ~ TitleMgr., Cook Inlet Engineer in9 Commission Use Only Conditions of approval Approved by ;' ................................... Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test ~ Location clearancel ~#ro~eU Copy ' R'efumeo Comm~Aoner by order of the commission Date ~/',- 2- ~- '~'~ Submit in triplicate SCU 42A-5 PERFORATING PROCEDURE OBJECTIVE: To increase production by perforating the casing opposite the H3 and H4 sands. WELL STATUS: Sidetrack completed 10-9-81. No open-hole logs available for this well; cased- hole logs (9-29-81) available are: CBL, VDL-Waveform, GR-CNL and TDT-K. Perforawxi (10-4-81) 10988-10992' MD with 3-3/8" hollow carrier gun @ 4 SPF (16 holes Total). The well is currently flowing 220 BOPD (120 BWPD, GOR = 78 Mcf/STB). Wellhead pressures as of 4-13-88 are, FTP ' 3100psig PC = 350 psig SC = 150 psig Before Proceeding: Confirm with Anchorage that both the BLM and AOGCC Sundry Notices have been aooroved. -- PROCEDURE: 1. MIRU Slickline Unit. Pressure test lubricator to 4000 psig. 2. RIH with a 2.5" gauge ring to top of fill. Last wireline tag occurred on 3-14-88 with a 2.0" gauge ring to fall at 10,987 ' WLM (11,005' MD). 3. RDMO Slickline Unit. 4. MIRU Wireline Unit. Pressure test lubricator to 4000 psig. 5. RIH with a tool string consisting of, from the bottom, a bull plug, a 6' 2-1/8" hollow carrier perforating gun loaded with 4 feet of 4 SPF (0°- phase) perforating charges, a fu'ing head, a CCL, weight bar, and a cable head. The onsite Operations Engineer should tie-in the perforating guns. 6. Position the gun so that the bottom shot perforates-the 5" liner at 10920' MD. 7. Perforate the casing with the gun described in step #5. POOH with the spent perforating gun. 8. RIH with a tool string consisting of, from the bottom, a bull plug, a 10' 2-1/8" hollow carder perforating gun loaded with 7 feet of 4 SPF (0°- phase) perforating charges, a firing head, a CCL, weight bar, and a cable head. The onsite Operations Engineer should tie-in the perforating guns. 9. Position the gun so that the bottom shot perforates the 5" liner at 10893' MD. RECEIVED 10. POOH with the spent perforating gun. RDMO Wireline Unit. 11. Test the well on the following days after perforating is complete: 1, 3, 6, 10 and 15. Alaska 0il & Gas Cons. Commission Anchorage NOTE: The attached Cased-Hole Reservoir Analysis presentation is off d~pth bv 4 ft. Do not use this log to tie-in the perforating guns. E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension L Manual Rams SWab Valve Double Master Valves NQI'E NO Wff,, iU# lroIl flIQII ICU 41-$ lleOlllLL. EI. EVA?ION 149 Z~ K B OI aT1, IPUP ,IT ).Z o N.O0 ONO "'"B'ZSO~.4S' ", CAMCO MANONEL. 31/Z" eNO oB 4~ ,ITS 31~' $.2o a,.O0 INO -,--- 3197.2S' -- CAMCO MANON[t. 31/2'' eNO Z PUP JTS SI/z" 3; JTS 3t/2'' 9 ---- 480$.15' -, CAMCO MANGOES. 3;/Z" SRO "~S Z PUP J?S 31/Z'' 92e N-SO SRO 20,J?S 3;/2" $ZB ~-SO SRO S498.40' --CAMCO IdANOR~L* 31/Z'' eno ~S PUP dT 3~'2" ~.2e N-lO SRO Si?i.E,' -- CAMCO MANONC~ 31/2" SNOB4 PUff UTS 3 I/Z" ~.2 e N-~ 8~0 dTS 31/Z' ~.2 ~ N-R0 eNO I? i.40' ;:571.30' S SC' 949 ~4 20' 6 40' 6 2Q' 367 63 HI ---- 6142.62' -- CAMCO MANOR[L* 3 I/2" I PUP JT 31/2'' 9.28 N-80 3 UTS 3¥2" $ Z:O N-OB -- 6247.63' -- CAMCO MANON[~ 3t/Z 2 PUP JTS 31/2'' 9.20 N-SO 0014' 4¥2"dH0~ S4Z0 TdtC~ S/72 S ~O' 6 lC' 92.41' 6 50' tO ,ITS 31/2'* 9.2# N-80 SRO 382? --10,091.9S'- CAMCO MANONEL* 31/2*'SNOOI I~T, IPUP JT 30/2'9.20 N-80 SRO --10,153.02' -- OAKEN FHI. PACKER ?" 2940 XO SRO, BUTTRESS PUP JT, XO eNO -- lO, IS?.S?' -- OTIS 'S* NIPPL*Exo P°s2 RECEIVED ---lO, tgi 00' --TOP OF tO,4OZ' 4E/Z" j#IB# SQZ'O t0/IJ '--' JO,41O 00'--tO,4S? OC'.' WINOOW IO.41O' 4 j#pll ~0/It APR 2 ! Oil & Gas Cons. Commission Anchorage 23 J?S SE;AL. LOK. 3t/2"92- N-OO OR0 W/ P-riO ?ORN[O& S~:v~L.t.£O COt. gAaS 6.49" 34.5B' 9.4S' S.lO' .SO' 677 85' --- oO,827.42'-S)4EAN SuB .cjo' '-- t0,028.32' -- 5 CU 42A - ,5 CASING & TUBING DETAIL tO.lie' 4'Q# 4J#~ P(f~! 10/0! tO,lO4 ~* [FIECTIV~ O~YN ~ YO~ Off ~SH SEC. 5, TTN, R9W, S.M. ALASKA ~ I L SI'tXTE Ll' ALASdA AND GAS C@NSERVATION COM~IISSION 3001 Porcupine Drive ~ Anchorage, Alaska 99501 (907) 279-1433 · . Receipt af'the following material c'~; ~ ~ ~/ · - ;. QUANT I TY · . . which wa's ,transmitted via is hereby acknowledged' DESCRIPTION Lo2 - ~ ,., ~,?:. ~: .... ..,.,: ... ,~; ,.'~" '. · :.,,-:..:~' :?' .: ~ .::..":.:.. ~,,~.:t.'~t: ~, '... t~. '~..: ~' ", --.-..,~.: .:t:~:..., <..¥ Copy sent t~ sender " YES~ NO ALASKA O~~ _ STATE OF ALASKA AND GAS CONSERVATION COM~ 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 ~SION Receipt o.£ the · QUANTITY I! .h following material which was transmitted via ~/~-~-//~k is hereby acknowledged: DESCRI PT ION I! Copy YES sent t.9. sender ALASKA OIL AND GAS CONSERVATION COMMISSION June 17, 1982 JAY S. HAMMOND, AOVEItNOR 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501'-3192 TELEPHONE (907) 279.'-1433 .Mr. T. L. Perryman Chevron USA, Inc. P.O. Box 7-839 Anchorage, Alaska 99510 Dear Mr. Perryman: We wish to thank you for the material forwarded to the Commission in response to our letter of April 21, 1982. However, all of the requested material was not received at that time or during the subsequent interval. Again we wish to bring to your attention that the following required material has not yet been received: We 11 Beluga River U. #214-35 COmp le tipn.. Da te 3/7/81 Missing Material -Samples (dry ditch cuttings ) -Mud Log-Directional Survey-DST/Prod. Test Reports-Digitized E. Log Tape Soldotna Cr. U. #21-4A ~ Soldotna Cr. ,U. #42 Soldotna Cr. U. #41-9A 3/7/81 10/5/81 6/2/81 -Certified Survey Plat -Digitized E. Log Tape -Digitized E. Log Tape -Digitized E. Log Tape S%mnson Riv. U. #31-33WD 5/29/81 -Inclination Survey -Digitized E. Log Tape Swanson Riv. U. #32-33WD 5/29/81 -Well History -Certified Survey Plat -Inclination Survey -Digitized E. Log Tape Please submit the above material at your earliest convenience since you remain in violation of Title 20, Chapter 25 of the Alaska Administration Code. Very truly yours, Harry W. Kugler Commissioner HW K/WVA / 9* lh LOGS: CO~,!PENSATED NEUTRON: CEMENT BOND LOG: THERMAL DECAYTIME NEUTRON 10,956'-10,340' 10,981'-10,170' 10,976'-10,181' LOG: 10,979'-10,180' PERFORATIONS: 10,988'-10,992' 10,402' 4 HP F Chevron Chevron U.S.A. Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 T. L. Perryman Area Operations Superintendent Production Department May 25, 1982 WELL COMPLETION INFORMATION · :~State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. Kugler Dear Mr. Kugler: Enclosed is the material.requested in your April 21st correspondence. Also included with this transmittal is information on Soldotna Creek Unit well #323-4. ~ Not included are mechanical drawings for wel~_~.~..2._-~,~SCU 44-8A and SCU 41-9A. Our drafting department is ~loaded. I will forward these drawings to you when they have been completed. Also missing are the requested samples and core chips from Beluga River Unit well #214-35. There were no core samples taken from this well. Should there be any questions contact this office. Very~, DMW:dmw Enclosure Anct;o~ a,g~ ~OMPLETION 'REPORT -;R~EDR'!_LL~ AREA: SWANSON RIVER FIELD - KENAI LAND OFFICE: ANCHORAGE PROPERTY: SOLDOTNA CREEK UNIT LEASE NO: A-028996 WELL NO: SCU-42A-5 API NO: 50-133-20232-01 ,. · . [OCATION AT SURFACE: 1,879' N & 498' W of' 'S.E. COR., SEC. 5;-T7N, R9W, S.M; LOCATION AT TOTAL DEPTH:- ELEVATION'. 167' K.B. DATE: November, 1981 - .. · 1',969·',.·N & 72' E of SURFACE BY: ~::~' - .. ~ 7~~ . ~ _ A~EA SUPER¥I SOR DRILLED BY: 'BI{INKERHOFF SIGNAL INC. RIG #58 · DATE COMMENCED REMEDIAL WORK: 7/29/81 10/10/81 DATE COMPLETED REMEDIAL WORK: RETURNED TO PRODUCTI ON: ORIGIN~k~i~DSPTH' 11,170 M.D. REDRILL"'DEPTH: 11,18o ~.D. EFFECTIVE DEPTH: lO,99~, M.D. SL~IARY PLUGS: CAS I NG: LINER' 18" Driven at 74' 10-3/4" cemented at 3,385' 7" cemehted at 10,410' Window milled in 7" csg. 10,410' - 10,457' Redrill 5" Cemented .~0,191%-10,993' Sidetrack . ..Pt'ugs ,.~.: 11,046' - 10,852' 10,852' - 10,490' 10,490' - 10,416' . ,~ t Er:EIVED , - Kick off Moving Brinkerhoff Rig #58' from SCU 2 l-A4 to SCU 42-A5. TD: 11, 170, PBD .11, 123' July 30, 1981 ContinUed moving Brinkerhoff Rig #58. Commenced ~igging up July 3!, 1981 Continued moving Brinkerhoff Rig #58. Continued Rigging up. August Continued Rigging up raised Derrick and began mixing mud. August 2, i981 86 P.C.F. Continued mixing mud. Rigged up GO. Int. and shot 1-1/3" hole at 7869'. Rigged up Halliburton. Killed well with 280 BBLS. of 86 P.C.F. mud. Circulate and condition mud. August 3, 1981 85 -P .C .F. Continued circulating and"conditioning mud. R/D x-mas tree. Installed and tested Class III Bope. Tested choke manifold and kill line to 5,000 P.S.I. Tested hydril to 3,000 P.S.I. Test witnessed and approved by representative of the U.S.G.S. R/U to circulate and condition mud. August 4, 1981 85 P.C.F. Continued to circulate and condition mud. Pulled Brown HS-]6 Free at 7892'. Brown CC Safety Jr. at 10343 would not release. Jet cut w/Dialog 2-3/8" tubing at 10406. Circulate out gas cut mud. AUgust 5, 3981 85 P.C.F. Circulate out gas and oil cut mud. Recovered 327 jt's 2-7/8" tubing, eight camCo mandrels and Brown HS-16 PKR. August 6, 1981 84 P.C.F. Changed out 2-3/8 rams w/3-1/2" ram. Tested same. RIH w/overshot August 7, 1981 83.5 P.C.F. Circ @ 8000' gas cut mud and oil cut mud. Engaged fish @ 10406. Well was building~up 200 psi in 10 min., release fish and circ 2 hrs. Mud cut from 11.4 ppg to 10 ppg. Engaged fish and manually backed off tbg. POOH, Recovered, 1-20' cut off, 12 jts 2-3/8" tbg, Otis XA sleeve, 1 jt 2-3/8 tbg, Baker FH Hyd. Pkr., Otis ,'S" Nipple 1-Blast jr. Top of fish @ 10871. August $, 1981 83.5 P.C.F. R.I.H. w/OS and fishing tools - tagged top of liner unable to worx 4-1/8" O.S. down liner P.O.H.R.I.H. w/bevelled screw-in sub. 'Finished TIH w/bevelled ~ in sub, encountered solid obs~a-Ction at liner top. POOH,screw-in sub scarred on outside, turning on metal. PU 6" mill and TIH, dressed top of liner, POOH and PU 4-1/8" slightly concave csg mill, TIH. August 10, 1981 Worked through tight spots and fil~ down to top of fish @ 10871. Circ. bttms up, POOH and Ld Mill. PU-4 '1/83! O.S. and TIH. Tagged fish @ ~ 10871 unable to get overshot to grab~ POOH, L.D.O.S. PU 4-1/8" x 3-1/8" shoe and TIH, tagged fish. .~" August 11, 1981 83 P.C.F. Worked shoe down over fish, 3 times. POOH & LD Shoe. PU 4-1/8" Flat bttm mill & TIH tagged fish @ 10865'. Milled 3' and tagged top of fish at 10,871. August 12, 1981 82 P.C.F. Continued milling fish. POOH w/mill twisted off at x/o to DC's leaving 3-1/8" DC's Junk basket, and mill in hole. Top of milling assembly fish @.10443. P/U O.S. and TIH. Engaged fish, .Chain OOH, recovered milling assembly. LD 12 3-1/8 DC's. Attempted to engage fish. RIH w/0.S. August 13, 1981 Attempted to engage fish w/o success. POOH LD 0.S. RIH w/impression lock and tagged fish. POOH I.B. No marks on bttm of I.B. scratches on sides. PU and RIH w/4-1/8" x 3-1/8 shoe, worked down to 10869. Attempted to cut obstruction w/no progress. August 14, 1981 POOH, LD shoe. PU n~w shoe and 1 jt. 3~13/16" wash pipe and TIH. Worked on fish for 3 hours POOH. Shoe worn our on bottom. Markings showed to have swallowed fish by 1'. PU r~ew shoe~and ~IH, cut on 'fish for 2 hr made 3". ! August 15, 1981 POOH, shoe worn out w/scars on inside. RIH w/OS w/3-1/16 grapples, engaged fish. Pulled 70,000 9 over string wt. jars tripped. O.S. came loose, POOH. PU new 3-16" grapple and TIH. Engaged fish and came free. POOH. A~gust 16, 1981 84 P.C.F. Recovered remainder of XA sleeve and collar from top of PKR. August 17, 1981 Continued to mill on packer. 84 P.C.F August 18, 1981 84 P.C.F. Continued cut on pkr, washed over pkr down to 10880'. POOH, PU overshot w/ 2-1/~" grapple to catch 2-5/16" fishing neck and TIH, engaged fish. POOH, recovered pkr. Pulled mandrel into below pkr. PU 4-~/8" x 3-18" shoe and TIH washed from 10879 to 10899, attempted to cut to slips on pkr ~/o success. Top of fish @ 10879. POOH August 19, 1981 (.~ ~.~.. e~"~4'5 P.C.F. POOH. RIH w/fishing assy to top of fish at 10879. Work ~vershot over. fish. Recovered 2 Baker FH Packers, Otis XA Sleeves (2), Otis "S" Nipple, Baker Blast Joint, Camco D Nipple. Tubing parted 5-1/2 below. Camco nipple, 35 ft. of 2-3/8" tubing left in hole. Made up fishing assembly 92~R.I.H. washed to 11,12'3. August 20, 1981 - 83.8 P.C.F. Corrected pipe figures show cleaned out to 11,006'. Circ. clean, POOH. Ran CNL-GR Log from 10956' to 10340' R.I.H. to I0958' w/fishing assembly. Washed to 11080'. Circ. clean. Pulled out to 11,046'. Set 400' cement plug as follows: Ahead - 10 cu. ft. water, slUrry 40 cu. ft. Class "G" Cmt w/2% CFR-2. Displaced cement with 410 cf Mud. Good returns throughout job. POH to 10350'. Squeezed 12 CF of cement away. Pump pressure increased from 800 to 1200 psi. Shut in well for 1 hr. Well flowed back 5 cf when opened.' Shut in well for additional 1/2 hr. P.O.H. August 22, 1981 R.I.H. Open ended. Tagged top of cement at 10,852. Set 56CF cement plug as follows: 34 CF Water ahead, 56 CF Class "G" Neat cement, 10 CF water behind. Displaced w/409 CF Mud at 4 BPM. P.O.H. to 10,122 W.O.C. Tagged top of cement at 10490'. P.O.H. August 23, 1981 R.I.H. w/mill. Milled Section in 7" casing from 10,410' to 10,440'. August 24, 1981 80.8 P.C.F. R.I.H. w/section Mill 92. Cut Window in 7". 10,440' to 10457'. POOH. August 25, 1981 80 P.C.F. R.I.H. w/underreamer to 10410'. Opened milled section to 11' from 10410' to 10457'. R.I.H. Open ended to 10490'. Circ. and cond. August 26, 1981 80 P.C.F. Set 26~' cement plug as follows: 51 CF water ahead. Mixed 65 CF Class "G" Cmt. w/20% Sand, 3/4% CFR-2, 15 CF water behind. Displaced with 400 CF of mud P.O.H. to 10300'. Reversed out. W.O.C.R.I.H. Tagged top of cement at 10,315'. P.O.H. R.I.H. Cleaned out cement to 10,336. August 27, 1981 81 P.C.F. · W.O.C. Cleaned out cement to 10416'. P.O.H. R.I.H. to 10416'. W.O.C. August 28, 1981 R.I.H. Took survey, drilled 6" hole from 10416' to 10462' P.O.H. August 29, 1981 80 P.C.F. R.I.H. drilled F/10,462' T/10,481' P.O.H. R.I.H. Drilled f/10,481' t/10,645'. N 3 E 25° 10,453 August 30, 1981 ~.~.~.. . · <?~ Drilled 6" hole from 10,645' to 10,800'. Took survey~ Drilled 6" hole from 10,800' to 11,070'. N 7° E 26 1/2° 10,780 August 31, 1981 '~ 80 P.C.F. Drilled 6" hole from 11,070' to 11,180'. Circ. ~ condition hole. Pipe stuck 46' off btm. Worked pipe and spotted high vis. pill. No results. Spotted 18 Bbls. Lease Crude. No results. Ran free point indicator'. Had free pipe down to bit. Made back off at top of first monel. POOH w/everything down to top of~'4-3/4" D.C.'s Top of Fish at 10,770'. September 1, 1981 80 P.C.F. R.I.H. w/fishing assy. Jarred on fish. No results. Ran free-point indicator and back off shot to 11,129'. No free pipe found. R.I.H. w/perf, gun to 11,117'. Shot 4-1/4 holes in monel. P.O.H. could not circulate through fish. Shot hole~ with 1-11/16" perf gun in D.C. at 11,020'. P.O.H. September 2, 1981 Circ. through holes shot in collars at 11,020'. Pump rate 8SPM. at 2400 psi. After 3 hrs increased to 18SPM - 2400 psi. Shot second set of 4-1/4" holes at 11,075 pump rate 22 SPM at 2200 psi. Ran free point indicator and back off shot pipe free to top of fish. Perforated collars from 11,070' to 11,073'. No increase in circ. rate. September 3, 1981 80 P.C.F. RIH w/washover shoe, tagged top of fish at 10749'. Worked over top of fish and washed down to 10,770' P.O.H. Shoe had groove worn in bottom. R.I.H. w/shoe Tagged fish 3' lower ~han before. Unable to work over, appears fish stuck on wall. P.O.H. Se~.tember 4, 1981 80 P.C.F. RIH w/wall hook and overshot and latched onto fish. Recovered x-o, oil jars, bumper sub, x-o. Top of fish @ 10,766'. R.I.H. w/shoe. September 5, 1981 Total of 12" made w/two shoes, RIH w/shoe ~3, cut on fish 2-1/2 hr w/o progress. P.O.H. RIH w/diamond shoe. September 6, 1981 80 P.C.F. Cut over, I.B. fell 2 ft. Washed down to 10,801'. Made connection, unable to get back down past tool jr. between IB and 1st drill collar below IB, POH ' RIH w/ saw tooth, washed and reamed to 10,800'. September 7, 1981 80 P.C.F. Washed and reamed to 10,856'. POH, RIH w/screw in sub, engaged fish and lost it. P.O.H. RIH w/wall hook, with spiral grapple. Unable to latch onto fish, POH- Top 'of fish @ 10,770. September 8, 1981 80 P.C.F. RIH w/overshot, engaged fish. RIH w/spud bar, tagged obstruction @ top of IB stabilizer, POH. Backed off at 6,800', screwed back into fish, unable to release O.S. RIH w/string~shot and unsuccessfully attempted to shoot off O.S. Jarred on fish ' ' .came to~ <'~ w/O.S. ~'~'~: S~. free, POOH, '.i~i-:.?~fish at 10,770. RIH '??~?~ O. September 9, 1981 80 P.C.F. RIH w/O.S. - unable to engage fish. P.O.H. No grapple on O.S. RIH w/mill. Mill 10" on IB stab, POOH. ~.i · September 10, 1981 81 P.C.F. Mill on IB stab w/o progress for 2 hrs. RIH w/6" magnet, tagged fish. POH. RIH w/mill. ''~ September 11, 1981 Mill 2 1/2" on IB stabilizer. POH. RIH w/O.S. September 12, 1981 81 P.C.F. Engaged fish RIH w/spur bar, to 11005'. RIH w/F.P.I, top stabilizer only thing free. Over shot released, unable to re-engage fish. POH. RIH engaged overshot, backed off and recovered I.B. Stab.'P.O.H. September 13, 1981 80 P.C.F. RIH w/wash pipe and shoe, washed to 10,799'. Pulled up to make connection, unable to work back over fish P.O.H.. RIH w/6" x 4 3/4 crippled shoe, worked over fish, washed down to 10,850'. ~eptember 14, 1981 80 P.C.F. Wash down to 10,991'. P.O.H. RIH w/O.S. Engaged fish. RIH w/F.P.I, and stringshot. Tagged obstruction @ 10,850', unable to go deeper than 10,970' September 15, 1981 80 P.C.F. Recovered 6- 4 3/4 DC's. RIH w/diamond shoe, worked over fish. Washed from 10997, to 11013. POH. RIH w/crippled shoe. September 16, 1.981 81 P.C.F. Washed 11017-11027. POH, RIH w/overshot engaged fish. RIHw/spudbar, and spud from 10,942' - 10,951', unable to go deeper. POH, released O.S. POH. September 17, 1981 81 P.C.F. RIH w/O.S, and engaged fish. Cleaned out inside of fish from 10,952' to 11,032'. Backed off and recovered 1 D.C. & 1' stab. top of fish at 11,000' September 18, 1981 81 P.C.F. RIH w/shoe & wash pipe. Washed to 11,027, P.O.H., Ri~I.H. w/shoe. September 19, 1981 82 P.C.F. Cont. washing - made 3' , P.O.H. Shoe worn off" . R~jI.H. w/shoe. Cont. washing w/no progress. P.O.H. shoe worn inside and out. R.I.H. w/shoe. ~ ~ep6ember 20, 1981 Washed down to 11,066'. RIH w/O.S, and engaged fish.. ~RIH w/clean out tool and cleaned out bore of fish. RIH w/string shot. September 21, 1981 ~ 80 P.C.F. String shot failed twice to go off. Pulled out for~ third shot. Worked jar - had blind backoff. Collar locator showed backoff above O.S. could not get O.S. back down to 11,060'. Tried to back off at 11,029' - w/o'success. P.O.H. RIH w/wash pipe, and washed over fish. Ran string shot - unable to get into fish...~-Spotted high vis. in Pill around fish. P.O.H. September 22, 1981 81 P.C.F. RIH w/clean out tool. POOH. RIH w/string shot failed to back off twice POOH. RIH w/wash pipe. September 23, 1981 79 P.C.F. .o Washed over fish. Stuck pipe. Freed pipe by spotting pipe lax and diesel. Worked pipe while raising mud wt. to 84.5 P.C.F. - stuck pipe. Worked pipe w/o success. Lowered mud wt. to 79 P.C.F. Spotted 5 bbls of pipe-lax and diesel - worked and freed pipe. - .September 24, 1981 76 P.C.F. Circ. and reduced mud wt. to 75.5 P.C.F. Attempted back off - stuck wash pipe. Unable to free pipe by spotting soak solution and working pipe." POOH. RIH w/shoe. ~p~ember 25, 1981 76 P.C.F. Milled top bushing to ring of safety joint Ring would not mill. POOH. RIH w/ screw-in sub and screwed into fish. Attempted blind backoff. POOH. Backed off at screw-in sub. RIH w/scallop shoe. September 26, 1981 76 P.C.F. Milled on ring of safety joint. Pulled up and unable to get back over fish. POOH. Bottom 4" of mill shoe gone. RIH w/6" Bit to cond. for running 5" liner. POOH. September 27, 1981 76 P.C.F. Ran to 802' 5" 18# N-80 Butt. Liner w/hanger at 10,1.91. Pumped 56 cf caustic water ahead and 75 cf class "G" cement w/ 3/4% CFR-2. Displaced w/10 cf H20 and 490 of mud. Bumped plug. Pulled out of CMT. Reversed out-no cement returned. POOH WOC. ~S~ep.t. emb..e.r 28, 1981 W.O.C. tested liner lap to 3000 p.s.i. POOH. RIH w/4-1/8 bit and cleaned out liner to shoe. Tested liner to 3000 p.s.i. Circ. & Cond. for logging. POH. September 29, 1981 76 P.C.F. Ran CBL, VDL-Wave-Form, CNL, TOTK. RIH. w/4-1/8 mill to mill out shoe. Mill out shoe. Milled cmt about 1 foot and hit fish. RIH w/bailer, laid a 2 sx class "G" cmt plug on bottom at~10,993', POOH. RIH. Perforated 5" liner @ 10,420'. POH, WOC. October 1, 1981 76 P.C.F. W.O.C. tested 7" CSG to 3000 psi, did not hold~Dled down to 750 psi in 10min- RiH and set baker EZ Drill Cmt. Ret. at 10,241. Tested Ann to 3000 psi, pumped down DP - pressured up to 2400 psi then broke through, }{ad full circ. Closed pipe rams and attempted to break down formation w/o success, held 3400 psi. Pumped 20 sx class "G" w/3/4% CFR-2. Pulled out of CMT - Rev. out. P.O.H. WOC, RIH w/6" bit and 7" csg scraper, tagged top of liner. POH. October 2, 1981 RIH w/4-1/8" Bit and drilled on cmt. ret. at 10,241"~% 77 P.C.F. October 3, 1981 75 P.C.F. Cont. drilling on cmt ret. Cleaned out cmt. to 10,425 and drilled out 5" liner shoe at 10,993'. October 4, 1981 Completed drilling out shoe, tagged top of fish at 10,994' circ. and clean hole. POOH . RIH w/3-3/8" hollow Csg gun. Perforated 1Q9~8~' - 10,992' w/4 H.P.F. POOH, Began running 3-1/2" tbg. October 5, 1981 76 P.C.F. Landed 3-1/2" tbg at 10,828'. N.D. BOPE. N.U. X-mas tree. Released rig 11:00 P.M. 10/5/81. ~ October 6, 1981 Tested tree to 5000 psi. Pumped 200 bbl water then displaced tbg and annulus w/lease crude s~t pkr, at 10,133'. Tested csg and pkr to 1000 psi, Began rigging down. October 7, 1981 Cont. Rig doWn. October 8, 1981 Cont. Rig~doQn. October 9, 1981 Cont. Rig'd~n. RECEIVED MAY 2 ? ]982 Ai~,ska Oil & G;~s Cons. Commi~;$jo~ Anchorage Comez. za.s~r~ ~ ~5o~c Lo g 4--2.3- 7 Z 4-Z7-72.. -27.. 4-2_.0-2 4--Z.3- 72. v ~ · tg -/'he. e~c(~ed e~ ue lo?e_. Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 April 21, 1982 We w~sh to bring to your attenticm that th~ belc~-Lndica~ed mater/al cn tl~ follc~ing ~ ~lls has not ~t been reoei~ by the Alaska Oil Beluga River Unit %214-35 (2nd notice; see attac~sd copy of 10/8/81 letter) ~ied Survey Plat -D rec enal -DST or Prod. Test Reports -Digitized E. Log .Tape Soldotna Ct. Unit 921-43% 3 /81 ............ ~ldotna Cr. Unit %42-5A ~..~> 10/5/81 ~ell History -Certified Survey P -Digitized E. Log Tape -Digitized E. Log Tape 8oldotna Cr. Unit %44-8A q~ell History Soldotna Ct. t/nit %41-9A 6/2/81 ~11 I~istory -Elec. Logs -Digitized E. Log Tape Swanson Ri~r b~it %31-33WD 5/29/81 -Inclinatic~ Survey -Digitized E. Log Tape Swanscn River Unit 5/29/sl -Well Iistory -Certifi~ Survey Plat -Inclination SunmS, -Digitized E. Log Tape Please su~t the above mater/al at Imur earliest ccn~ence since you are now in violaticn of Title 20, Chapter 25 of the Alaska Adm/n/strative Ccde. Very truly yours, ' BY ORDeal O,= TH~ · ' ALASKA AND GAS CONSERVATION C(3~ ~ISSION ~ ~... STATE OF ALASKA , , / MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS"" · Drilling well ~i~ REDRILL Workover operation [] 2. Name of operator .... CHEVRON U. S. A. 3. Address P. O. BOX 7-839: ANCH.: AK. 99510 4. Location of Well atsurface 1879' & 498' W of S.E. Cor., Sec. 8, TTN, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 167' K.B. A-028996 7. Permit No. ? 8. APl Number 50- 1 33-2n2_~ 11. Field and Pool SWANSON RIVER FIELD OCTOBER 81 For the Month of ,19 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Tested 7" csg. to 3000 p.s...i. - Did not hold. Set E.Z. Drill cmt. ret. on D.P. at 10,241'. Attempted to break down formation w/o success. Pumped 20 sx. class "G" Pulled out of cmt. and rev. out. Drilled out cmt. ret. at 10,241'. Cleaned out · e ' 5- Perf. w/3-3/8" hollow cmt. to 10,425' and drzll.d out liner shoe at 10-,993'. csg. ~un 4 H.P.F. 10,998'-10,992'. Landed 3%" tbg. at 10,828'. N.D. BOPE. N.U. X-MAS'tested to 5000 p.s.i, pumped 200 Bbl. Water-displaced tbg. and annulus ~--~/l~ase crude, set..PKR. 'at ~T~3' .-' .~ested tbg. and PK~. - o.k. ~ie&sed ~i~ 10/5~. · . 14. Coring resume and brief description i5. Logs run and depth where run 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perf. 4 H.P.F. 10,998:~ -10,992' ECEIVEi) NOV 1 0 1981 Oil & Gas Cons, Commlssfm Anchorar~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 --lit. ¥1 ~Jll CltP__LVHON U.S.A. iNC. TP~\;;S;'IITTAI. '~ ACK:;OWLEDGEHENT OF RECEIPT DITERIAL - (ALASKA) DEPT.: DATE. /F/ ~ :9 ~/ FI) - Folded R - Rolled S - Sepia F - Film X '- Xerox B - Blueline .THE FOLLOWING IS A LIST OF ~TERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE I~Dfl~DIATELY. Fol '=C.l' CNA211~A/T ii II -- I! BY C!LEViION U-.'L.-N. Octc~ber 30, 198]. Mro John Wilson Chevron USA, Inc. P oO. Box 7839 Anchoraqe, Alaska 99510 Enclosed for your reference and distribution to appropriate. persons in your organization are four copies of the Alaska OiL and Cas Conservation Regularly. Tour attention is r~s~ctfully direct~ to 20 AAC 25.536(b).(5) on page 29 which s~ciftes 'the 1~ ~ata to ~ sUb~itted to ~ C~eston u~n c~letion of a well. T~re h~ve ~en nu~ro~s .~as~o~s in the ~st w~re Ch~ron ~itted only a sepia or only a print of t~ logs. The ~st recent ~currence is refle~ on the ~nclos~ trans~ttal dat~ ~to~r 27~ 1981 eig~ed by your Mr, L, Hantsh wherein only sepias ~re $~mitt~ on the S~ 42-5RD well. Please also send t~ prints as ~on as ~sible. As a rotter of tnteres.t, two gentle~en from your San Francisco worki~ ~re tn our sample ~xa. mination fact~i~ie~ exa~ntng ~tllia~ Van Alert Petrole~ Geologist Enclosures Chevron .(CHEVRON U.S.A. I~"C. · T~.\;"~'.ilTTAI, AND ACK:iO:,HLEDGEMENT OF RECEIPT OF ~t&TERIAL (ALASKA) DATE_ /9/'~- 7 29 ! FI)- Folded - Rolled S - Sel~ia F - Film X ' - 'Xerox B - Blueline PLEASE CHECK AND ADVISE I}DfEDIATELY ..qCU 4,2-5' AD RECEIVED B'¥ BY OCT 2 9 1,~.~ Alaska Oil & Gas Cons. Corn niission . Anchorage Chevron · (.CHEVRON U.S.A' I~-~C. T'tL'\:---~';:"I'TTAL"~:~D ACK";o?'LEDGEHENT OF RECEIPT O~ ~LATERiAL .. DEPT.: PLACE :~ ATt: . FOLLOWI~:G IS A LIST OF MATERIAL ENCLOSED HEREIN. (AL,~KA) DATE~ ]9 ~/ FD - Folded ~ - Rolled- S - Sepia F - Film X'- Xerox B - Blueline PLEASE CHECK AN~ ADVISE I}D.m-DIATELY. 5// R£CEIVc_ D ~y RECEIVED OCT 2 9 1~ Oil & Oas COns. Commission Anc~.~orage · · 'WELL .... RUNS '.. .. · · i ,i · TRANSMITTAL AND ACKNO%FLEDGEb~NT OF RECEIPT OF }tATERBLL - (ALASKA) TO: /~~~' CC DATE: DEPT.: FOP~'b~T ION FO P~b1T I ON GA2.~L~ RAY GAb~tl RAY GA2-~iA RAY MICRO LOG / · 'THE' FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. CtIECK AZD ADVISE I}~DIATELY. _- · . .. . ~.. .. INDUCTION ELECTRICgL LOG DUAL INDUCTION LATEROLOG ~OREHOLE CO}~ENSATED SONIC BOREHOLE COI~P. SONIC w/caliper BOREHOLE COb~. SONIC w/gamma BOREHOLE TELEVIEWER · CONTINUOUS DIP:'~ZTER - High Res. CD}~ - POLB~OG PLOT CE,X~.NT BON~) LOG CASING COLLAR LOG - Perf. Rec. ~'~D CO}fPENSATED _u~.'~_,.·~,~ DEN. TESTEK FACTOK F F .. - NEUTRON COLL~ .LOG MI CROLATEROLOG MUD LOG NEUTRON LOG PROXIMITY MICROLOG RWA CO,'.fl)ARISON PLOT SANDSTONE ANALYS IS SARABA/qD SIDEWALL NEUTRON POROSITY SONIC TE~tPERATURE LOG PLEASE · XEROX SEPIA CO:'fl~LETIO,N lie PORT DIKECTIO:~AL SURVEY CORE DATA SAP~\B,~D TABULAR LISTING I __'...... I __ Cons. CommissiOn · L i BLU EL IN E i, STATE OF ALASKA ALASKA AND GAS CONSERVATION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL[] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number - Chevron U.S.A. Inc. 80-106 3. Address 8. APl Number P.O. Box 7-839, Anchorage, Alaska 99510 50_133-20232-01 4. Location of well at surface 9. Unit or Lease Name 1,879' N & 498' W of SE Cor. Sec. 5, T7N, R9W, S.M. Soldotna Creek Unit At Top Producing Interval 3,677' N & 482' W of surface 10. Well Number SCU 42A-5 At Total Depthl, 969 ' N & 72 ' E of surface. 11. Field and Pool Swanson River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 167' K.B. A-028996 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions ~/~L43'~/81 K.O. 9/30/81 10/5/81 N/A feet MSLI 1 17. Total Depth (MD+TVD)ll, 180 M~_D 18~.~lur~a§t~D~Eh..~.D+~/.]~)_ · · . 19. Directional Survey 20. Depth whereSSSV set I 21. Thickness of PermafrostN/A 10.759'__~.D. 10.599' T.V.D. YES E~ NO [] N/A feet MD 22. Type Electric or Other Logs Run CBL, VDL - CNL - G.R. 23.' CASING, LINER AND'CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 18" - Line Piled Surface 74' - Driven 10-3/4" 40.5~ I(-55 Surface _q. _qR5 ' I q" ] r 575 · . 7" 29~ & 23~ oN~ & Rllrfa~_~ '10 41 O' 9-,.7/8" - * 5" Liner 189 N-80 10,191' 10,993' 6" 75 C.F. · Abandoned 10,410'-10,731' - Window milled i~ 7" from, 10,410' - 10,457' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25.. TUBING RECORD nterval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3~" 10,828 ' 10, .133 ' 10,988' - 10,992' M.D. 4-%" HPF 10,594' - 10,598' T.V.D. 26. ACID, FRACTURE, CEMENT SQUEEZE,, ETC. . . .. . . -, DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED , ,, . ,, 27. PRODUCTION TEST` ,, D~teCFi~§t Pr, odu.ction~ '" '~ 't' Method of Operation (Flowing, gas .lift, etc.) NoneI , ., Date of Test .~ Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATI© ,; : .. TEST PERIOD., ,. :. ,,.... . , - . FI0v~:Tubing Casing Pressure . .CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24~HOUR RATE, I~ ' ' ' 28, CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~' ~' · None "' ' ' Co~ao :,. .: . Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. " 30~" ..... ~ · · GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ]~emlock 10,873' 10,492' : . · · · · 31. LIST, OF ATTACHMENTS · 32. I hereby certify that the foregoing is true and'correct to the best of my knowledge ~. Area 0perations .. , Signed i~- ~ Title ._q~?t_ Date INSTRUCTIONS General· This form is designed for submitting a complete and correct well completion report and log on ..... all types of lands and leases in Alaska. ~ Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form. and in any attachments. Item 16 and 24: If this well is completed for separate production ·from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item,.27. Submit a separate form for each additional .interval to be separately produced, showing the data,:pertinent to such interval. - -- .: ; Item 21' IhdiCate whether from ground level (G L) or other elevation ('DF, KB, etc.). .,-- . , Item .23;.,.,:Atti~hi~ed supplemental records for this well should show the detailS of any multiple stage cement- ?i, rtg,a'nd .,thei'ocation of the cementing tool. ~..,-~'° Item 27' Method of Onarqf;.~n C~owino G~'~ "~'~ GREAT LAND DIRECTIONAL DRILLING INC. C REPORT OF SUB-SURFACE DIRECTIONAL SURVEY Chevron COMPANY scu 42-5 WELL NAME Swanson River AL 881D32 LOCATION Single Shot 10/2/81 JOB NUMBER Don Burgess NAME TYPE SURVEY DATE En.,gi neer ~b~~~_ t~TLE SIGNATURE 378 10993 DEPTH INTERVAL DATES SURVEY TAKEN FROM TO 8/26/81 9/1/81 FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confidence. Additional copies of your survey report can be made from the original by any blueprint company. RECEIVED OCT 0 9 1981 · aska Oil & Gas Cons. Commission Anchorage CO'!PLETION REPORT CHEVRON USA COMPUTER ~ETHODIRADIUS OF FIELD KETHOD(AVERAGE) GYROSCOPIC/MAGNETIC SINGLE FOR GLDD BY FM LINDSEY WELL SOU 42-5A CURVATURE) COMPUTER DATE(lO/01/SZ) SURVEY DATE(1972/9-21-81) SHOT SURVEY TRUE .V~EAS. DRIFT VERTICAL SUB DEPTH ANGLE DEPTH .SEA 3 0 0 O, 37~ O 45 377, 902 0 0 901, 1394 o 15 1393. 1898 0 20 1897. 2395 O 15 2394., 2899 C 0 2898, 3385 0 30 3384, 4.283 1 15 4282, 4710 1 aO 4718. 5232 2 30 523].. 5369 2 30 5368. 5674 1 40 5673, 5730 1 15 5729. 5765 2 30 5763, 5796 3 30 5794. 5901 7 30 5899. 5965 9 15 5962. 6028 10 15 6024, 6069 lO 0 6065. 6117 10 15 6112, 6243 15 0 6235, 6&a6 20 15 64.28, ~590 20 15 6563, 6775 22 15 6736. RECORD OF SURVEY DR IFT DIREC DEG. TOTAL COOR=, t= INATES O0 -185.00 S O.OOE 98 192.98 S57.00E 97 716.97 N O.OOE 97 120P,-.97- ?.;45.0oE 96 1'712.96 N59,00W 95 2209.95 S40. OOE 95 2713.95 S O,OOW 95 319~.95 S~O.OOW 84 4097.84 N74.00E 69 4533.69 N6g-OOE ~5 5046.35 NVS.00E 22 51E3.22 NEO,OuE 02 548R.02 ~66.00E O0 5549 · O0 S90. OOE 98 5578.98 S67.00w 93 5609,93 SBO,OOW · " OOW 43 5714.43 ,,72. 75 5777.75 NYl,O()W 83 5839,83 N71.OdW 20 5880.20 ~62,00W 45 5927.a5 37 6050.37 NgT.00W 77 02~.77 N24.00W 87 6578 · 87 f~21 · OOw 28 6551,28 - N23.00W O.OO 2.08 S 0.74 --.0.22 ~'.;. 2.43 0,06 ~'! 1.95 S 10.~9 S 6.87 S 1.11 S O. 17 3.40 N 3.70 N 2,89 N 2,43 N 3,i3 6.09 9,56 12,43 17.8"/ N 41,19 N 96.6z, 142.68 .204,84 N 0,00 W 1.13 E 3,60 E 3.72 2.57 E 2,94 E 2,40 E 8.99 19,51 E 3'7.24 E 43,07 E 53.65 E 55,03 E 55,Z0 E - 53.64 E 43,7i E 3~. 57 E 24.78' E 18.18 E 11,81 E 2.75 W 29.20 w 48,27 W 73,39 W CLOSURES D I STANCE ANGLE D Y O,O0 $ 0 0 0 W 2.37 S 28 29 59 E 3.67 S 78 17 44 i 4,CO N 80 5~ 3~ i 4.45 N 56 53 2~ b 2.79 iN 67 13 31 E 2.94 N 88 ~9 ~6 E 3,©9 $ 50 49'~5 E 13.75 $ 40 52 3 E 20.69 S 70 ~5 5 ~ 37,26 S 88 1~ 47 E 43,07 N 89 46 4 E 53,?6 N 86 21 55 E 55,16 N 86 9 5 E ~5,27 N ~6 59 34 E 53.~0 N 87 23 45 E 43,82 N 85 53 ~2 E 35.39 N 80 5 Z3 E 26,56 N 68 53 41 E 22,02 N 55 B7 30 i 2t,42 N 33 27 57 E 41,28 N 3 49 39 ~. 100.96 N 16 48 51 ~ 150,63 N 18 41 B3 W 217,59 N 19 42 40 W OOG LEG SEVERITY DEG/iOJFT O.O00 0,i9~ 0.i43 O.US1 0,017 C.017 0.050 0,103 0.096 0,162 0,159 0.27~ G,744 3.672 3,230 3.837 2,735' 1,587 0.900 1.729 3.807 2.592 G,721 1,092 -0.69 C.27 2.48 ~.Ii -1.92 -~-5~ 3.22 3,77 9.92 12,70 ~l.l~ 96.20 141.96 Z~3.75 CHEVRON WELL 42--5A GYROSCOPIC/SINGLE SHOT ~)CT, 8i RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D ~': DEG · TOTAL 701g 25 30 6959,37 6774.37 Nlg. OOW 297.01 7084 26 0 7017.92 6832,92 N19,00W 323,71 7150 28 30 7076.59 6891.59 N14.00W 352.67 7343 2q 30 7245,39 706C.39 N 8,00W 444.48 7n68 28 0 7354,98 7169.98 N 6.00W 504.15 7522 27 45 7402.71 7217.71 'N 6.0OW 5.29,26 7694 26 30 7555.79 7370,79 N 4,0OW 607.38 7956 2a 15 7792.50 7607,50' N 2.00W 719.49 8119 '21 45 7942.53 7757.53 N 2.00w 7~3',13 8256 21 30 8069.88 7854.88 N O,O0~ 833.61 8446 21 0 8246.97 8061e97 N 3.00W 902.44 8510 20 45 8306,76 8121,76 N 2.00W 925.23 8604 20 15 8394,61 8209.81 N 1,OOE 958.14 8662 19 30 8449.36 8264,36 N 5,OOE 977,83 8758 20 0 8539,71 8354,71 N 7.00E ~903 20 45 8675,64 8490-64 Nll.OOE 1059.94 9066 21 30 8827.68 8642,68 N14,00E 1117,g9 9322 22 15 9065,25 8880,25 NI4,00E 1209.83 9602 22 30 9324.17 9139,17 N17,00E 1312.53 9831 22 15 9535,93 9350.93 N15,00E 1396,32 10077 21 0 9764.61 9579.61 N16.00E 14B3.68 10327 20 30 9998.39 9813.39 N17.00E 1568.61 10453 25 0 10114.56 9929.56 N 7-OOE 1616.19 10780 26 30 10409,08 10224,08 NiO.OOE 1756.68 10993 27 30 10598,86 10413.86 N13,00E 1851.42 COORDINATES I08.77 117,96 W 126.54 W 144.38 151.7i 154,35 W 161.18 167.06 W 169,2S '¢~ 170.16 w 171.97 W 172.96 W 173,25 W 172,22 W 168 · 8~ W 160,93 W 148 · 2g W 125.14 96,66 W 72,63 W 48.41 W 23.25 W 13.14 W 7.85 27. i3 E C L 0 D l ST Ai',~C E S U R E S ANGLE D ~'~ 316.30 374.69 46'/,34 526.48 551-31 628e4.0 738.63 801,22 918,~8 941.25 973,68 992.88 1024.10 1072.09 1127,07 1216.29 1316.09 1398,21 1484.47 1568.78 1616.25 1756,69 1851,62 N 20 6 48 ~ N 20 1 19 w N 19 44 18 w N 17 59 46 ,'. N 16 44 53 V. N 14 51 46 ~ N 13 4 20 ~ N i2 N il N i0 N 10 N 10 I~ 9 N 9 N 8 N 7 DOG LEG SiVb;qiIY DEG/!O~FT 0.769 4,162 0.91~ 1,251 0.463 0,763 0,26~ 0.437 0.575. 0,522 0.181 0.166 0.51i 0.206 3.642 0.494 0,557 ScC'FIOF~ ~IS'I'~:\CE D26,94 716.96 /~O,b'l 922,59 9)5,5G 100~,51 10~7,47 1115,~ l~lo,9g 159~,11 1615.85 155i,62 BOTTO~ HOLE CLOSURE 1851,62 FEET AT N 0 50 22 F CHEVRON WELL 42-5A MEASURED DEPTH AND OTHER DATA GYROSCOPIC/SINGLE SHOT FOR EVERY EVEN 100 FEET OF .,SUb .SEA DEPTH, OCT. &l TRUE MEASURED VERT ! CAL DEP TH DE P T H SUB ND-TVD VERTICAL SEA DIFFERENCE CORRECTION TOTAL COORDINATES 285 285, 385 385. 485 485, 585 585. 685 685, 785 785. 885 885, 985 985. 1085 1085. 1185 1185, 1285 1285. 1385 -13~5. la25 1485. 15a5 15~5. 1685 1685. 1785 1785, 1885 1885, 1955 1985. 2035 2085. 21~5 2125. 2285 2285. 2385 2385. 2485 2485. 2585 2585. 2685 2685. 2785 2785. 2885 2885. 2985 2985. 3085 3085, 3185 3185. 3285 3285, 3385 3385. 3485 3485. 3585 3585., 3685 3685. 100 0 0 200 O O 3OO 0 0 400 0 0 500 0 0 600 0 0 700 0 0 800 O O 900' O O I000 0 0 1t00 0 0 -12C0 0 ...... 0 1300 0 0 1400 0 0 1500 0 0 1600 0 0 1700 0 0 1600 O 0 1900 O C 2000 0 O 2100 0 0 2200 0 0 23OO O 0 2400 O 0 2500 0 0 2600 -0 0 2700 0 0 2800 O 0 2900 0 C 3000 0 31OO O 0 3200 0 0 3300 O 0 34C0 0 0 3500 0 0 i .27 2,13 2.52 2.40 1,94 1,34 0.81 0.71 0.59 0,40 0,13 O.l& 0.~5 0.59 0,56 0.36 0.GO 2,57 2,44 2.06 1,56 1,11 0.79 0.51 0,29 0.14 0,07 0,OO 0,23 0,65 1.23 1.95 2,82 3.90 5.11 0.50 1,20 2,30 3,2i 3,78 3,93 3,67 3,60 3,62 3,67 3,79 3e97 4,33 4,78 5,2~ 5,76 6,16 3,26 2.73 2.39 2,32 2,54 2,78 2,93 3 3,00 2 · 95 2 2,91 2,83 2.66 2.40 2.04 1,88 1.99 E E F E E E E E E E E E E E E E E E E E E E E E E E E E E -FF.. F...' i,.,. E CHEVRON WELL 42-5A ~EASURED DEPTH'AND OTHER DATA FOR GYROSCOPIC/SINGLE SHOT EVERY EVEN 100 FEET OF SUN SEA DEPTH, OCT, TRUE MEASURED VERTICAL DEPTH DEPTH SUB MD-TVD SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORD INATE5 3795 3785. 3895 3885. 3985 3985. aOB5 aOX5. 41~5 4185, 4295 4285. 43~5 ~3e5. a495 44~5. 45H5 4585, 4695 4685, 4785 4785. 4°85 4~8b. 4gg5 4985. 57)85 5035. 5186 5185. 5286 5285. 5396 5385, 5ag6 5485, 55~6 5585. 5686 56£5, 5786 5785, 5886 5885. 5aB~ 5985, 60B9 6085. 619] 6185. 6295 6285. 6400 6385, 6506 6485, 6613 6585, 6720 6685, 6a2B 6785. 6037 6885. 7047 6985e 7159 7085,. 7274 7185. 3600 C, 3700 0 3800 0 3900 C 4000 C 4lOC 0 4200 0 4300 0 4400 0 4500 ,..,"" 4600 0 4700 C'.' 4~C0 0 4aO0 n 5000 C 5100 -1 5200 1 5300 1 5400 I 5500 I 5600 1 5700 t 56.00 2 5900 4 6000 6 6100 c 5200 14 6300 21 6400 27 6500 34 660..0 42 6700 51 6800 62 6900 74 7000 88 C 0 0 O G 0 C O 0 O t C 0 O 0 0 0 1 2 2 5 ? 6 7 1] 12 i4 6,39 7,64 8,76 9,64 10,21 lO,3fi 9,73 ~,99 8. i6 7,22 6.18 5,09 3.~6 2.81 1.65 0,55 0.30 1.22 2.32 3.53 2.56 2,73 7,29 14, 34 30-25 53.75 82,56 115,68 150, C'O 185,77 223.66 264.4-! 308,45 356,85 ~+10.99 2.42 3.18 E 4.28 E 5.66 E 7.28 E 9.03 E 11.2i 13.53 E -15,99 E 18.50 E 21.37 E 2a.42 E 27.75 E 31.40 E 35.32 E 39.51 E 43,79 E 47.73 E 51.12 E 53.96 E 54,21 E 45,52 E 31,37 E 15.26 E 3.45 E 9,04 W 22,79 37,43 51.10 65,42 W 61,20 W 97,07 W 112,71 127,57 139.01 CHEVRON WELL 42-5A ~ GYROSCOPIC/SINGLE SHOT INTERPOLATED VALUES FOR EVEN 1000 FEET TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA 1000 999, 2000 1999, 1814. 3000 2999, 2814. 4000 3999. 3814. 5000 4999, 481~. 6000 5997- 58!2, 7000 6942, 6757, 8000 7832, 7647, 9000 8766, 8581, 10000 9692, 9507- OF HEASURED DEPTH, TOTAL COORDINATES 0,70 S 3,6C E 2.57 N 3,17 E 0.02 S 2,93 E 8,91 S. 4,47 E 3.79 S 28.28 E 7,97 ~! 29.39 E 289,32 N 106.08 w 737,3i N 167.68 ~*: 1093,9i N 153,78 W 1456,90 N 56,01 W 1 OCT, 81 COMPLETION REPORT FOR GLDD BY FM LINDSEY & ASSOC, CHEVRON USA WELL SCU 42-5RD COMPUTER ~ETHOD(RADIUS OF CURVATURE) COMPUTER DATE(lO/01/81) FIELD METHOD(AVERAGE) SURVEY DATEi1972/9-21-81} GYROSCOPIC/MAGNETIC SINGLE SHOT SURVEY TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH 0 0 ..... 378 0 902 0 I39a 0 1898 O 2395 0 2B99 0 3385 0 42~3 1 4719 1 5232 2 _ 5369 2 5674 573~ 5?65 2 5796 3 590] 7 5'965 9 6028 10 6069 10 6117 10 6243 15 6~46 20 6590 20 6775 22 0 0,00 a5 377,98 0 901.97 15 1393,97 20 1897,96 15 2394,95 0 2898,95 30 3384,95 15 4282,84 40 4718.69 30 5231.35 30 5368.22 aO 5673,02 15 5729,00 33 5763,98 30 5794,93 30 5899.43 15 5962,75 15 5024.83 0 6065,20 15 6112.a5 0 6235.37 15 6428.77 15 6563,87 15 6736.28 RECORD OF SURVEY SUB SEA DRIFT DIREC DEG, -182.00 S O,OOE 195-98 S57-00E 719~97 N O,OOE 1211.97 N45,00E 1715.96 N59.00W 22i2,95 S40,OOE 2716.95 S O,OOW ~202.95 S30,OOW 4100.84 ....... N74.00E 4536.69 N69,00E 5049.35 ~75.00E 5186.22 N80,OOE 5491-02 -N6$.OOE 5547.00 sgo-ooE 5581,98 S6?.OOW 5612.93 SBO.OOW 5717.43 i~72.00W 5780.75 N71.OOW 5842"83 N71.OOW 5883,20 N62.00W 5930.45 N37.00W 6053.37 N27.00V~ 6246.77 N24,00W 6381,87 N21.OOW 6554,28 N23.00W TOTAL . ,. 0,00 2,08 ...... 0,74_ 0,22 2,43 1.08 0,06 1,95 10,39 6,87 1-11 0,17 3,40 3,70 2.89 2.43 3.13 6,09 9.56 12,43 17.67 41,19 96.64 142.68 204.8~ COORDINATES · .. C L 0 DI STANCE 0,00 W 0,00 1,13 E 2,37 _ 3,60_.E 3.67 4,00 E 4,00 3,72 E ~+.45 2.57 E 2.79 2.94 E 2,94 2,40 E 3,09 8,99 E 1.3,75 19,51 E 20,69 37,24 E 37,26 43.07 E 43.07 53,65 E 53.76 55,03 E 55,16 55,20 E 55.27 53-64 E 53.70 43.71 E 43.82 34,87 E 35,39 24.78 E 26.56 18.18 E Z2.,02 il,81 E 21,42 2,75 W 41-28 29.20 W 100.96 48,27 W 150.63 73,39 W 217.59 S U R E S ANGLE D M S 0 0 0 W S 28 29 59 E S 78 17 4~+ E N 86 50 30 E N 56 53 24 E N 67 13 32 E N 88 39 46 E S 50 49 55 E S 40 52 3 E S 70 35 5 E S 88 _16 47 E N 89 46 4, E N 86 21 55 E N 86 9 5 E N 86 59 34 E N 87 23 45 E N 85 53 52 E N 80 5 23 E N 68 53 41 E N 55 37 30 E N 33 2_7 57 F i',l3 49 39 N 16 48 51 W N 1~ 41 33 w I",419 42 40 v,; DOG LEG SEVtR~TY DEG/iOOFT 0,000 0.198 0.143 0.05i 0,017 0,017 0,050 0.103 0.084 0e096 0,159 0.273 0.744 3.672 3'230 3,~37 2,735 1.5~7 0,900 1.729 3-607 2,~92 0.721 1,092 SdCTIO~< O I STAkC£ O.OO -2,04 -0,63 0.34 2.54 1.16 0.16 --1.~7 -lC.10 5.1t 4.65 4,14 4,52 ?.19 10.34 18.24 9~.66 £41.08 CHEVRON W E L L A2-5RD GYROSCOPIC/SINGLE SHOT OCT. 81 RECORD OF SURVEY -~..iEASo DRIFT DEPTH ANGLE [') M 7019 25 3O 708n 26 0 7150 28 30 7343 29 30 7458 28 0 752.2 27 45 7694 26 30 7956 24 15 8119 21 a5 8256 21 30 8446 21 O 8510 20 45 8604 20 15 8662 19 30 875R 20 0 9066 2] 30 9322 22 15 9602 22 30 9831 22 15 0077 21 0 0327 20 30 0523 20 45 0660 20 30 1170 20 30 fSOTTOM HOLE TRUE VERTICAL SUB DEPTH SEA DRIFT DIREC DEG. 6959,37 6777.37 7017,92 6835,92 7076.59 6894,59 7245,39 7063.59 7354.98 7172.98 7402,71 7220,71 7555.79 73'73.79 N 7792,50 7610,50 N 7~42~53 7760¥53 - N ~069.88 78~7,88 N 8246.97 8064.97 8306.76 8124.76 ~394.81 8212,81 84a9,36 8267,36 8539.71 8357.71 8675.64 8493.64 . 8827.68 8645,68 9065.25 8883,25 9324.,17 9142.17 .., 9535,93 9353.9~ 9764.61 9582.61 9998,39 9816.39 10181.83 9999,83 10310.05 107~7.75 N19.00W N19.00W Nla. O0~ N. N 6.00W 4. OOW 2.00W 2 ,'COW -' N 3.OOW N-2.00W N 1.OOE g 5.OOE N 7.0OE Nll.OOE N14.00E Ni4,00E ~17,00E N15o00E NI6.00E P';17,0OE N16-0OE 10128,05. N16.00E 10605,75 N16.00E CLOSURE 1853.81 FEET AT N TOTAL COOKDiNATE$ 297,01 323.71 352.67 444.48 504.i5 529,26 719.49 783,13 a33.61 902,44 925.23 958.14 977.83 1010,09 1059.94 .1117.29 1209.83 1312.53 139'6.32 1483-68 1568-61 1634-80 1681.19 1852.8'8 1 49 12 E' 108.77 W 117,96 126.54 144,32 151.71 i54,~5 161,18 W 167,06 t69.28'W 170.16 W 171.97 172.96 W 173.25 172.22 168.83 160,93 W 148,22 W 125,14 W 96.66 W 72,6~ W- 4~.41 W 23.25 W ~,64 t'". 9-65 E 58.~£ E ._ C L O S U'l{ E S DISTANCE ANGLE D F',,~ S 316,30 N 20 6 48 W 344,53 N 20 I 19 V. 374,69 N-19 44 18 W a. 67.34 fi26.q8 N 16 44 551,31 N 15 628.~0 N 1~ 51 ~6 W 738.63 80~.22 N 12 Il 51 W 850.80 N 11 32 i~ W 91B.68 N 10 ~7 20 W 9~1.25 973~68 N lO 1~ 58 W 992.88 N 9 59 i9 1024.10 1072,09 N 1127.07 N 7 1216.29 N 5 54 20 W 131~,09 N 4 12 43 W 1398,21 N 2 58 ~0 W 1'84,47 t~ 1 52 7 W 1634,81 N 1681,22 N 0 19 1853.81 N 1 49 DOG LEG SEVERITY DEG/10OFT 1,366 0,769 4,162 0,915 1,251 0,463 0,763 i.534 U,26~ 0.332 0,~37 0,655 1,504 0,575 0,622 0.b22 0,29~ 0,18i 0o160 0,511 0,206 G,143 G,182 O,0C0 .. :.:,. T I 0!".: 0 i STA;.~CL 319,80 ~39,67 524.09 '60i,95 715,82 777.36 ~7.79 895,53 9i9,27 992,15 1004.22 1i12, 1205,25 1308,80 lj93.31 i*~1.40 1567,0~ 1~.86 1660.65 1853.81 CHEVRON WELL 42-5RD ~.~EASURED DEPTH AND OTHER DATA FOR GYROSCOPIC/SINGLE SHOT EVERY EVEN 100 FEET OF SUB SEA DEPTH, OCT, 81 ~EASURED DEPTH _ . . TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 282 382 5B2 782 ~2 9.32 1082 !!~2 I2B2 1392 1482 15R2 16B2 1782 18.~2 19,82 2O82 2182 2282 2382 2482 25P, 2 26B2 27~2 2~82 29~2 3082 3182 32~2 3382 3~82 3582 36B2 282 382 482 582 682 782 R8 98 108 118 128 138 148 158 168 178 lB8 198 208 218 228 238 2482 2582 2682 2782, 2882, 2982, 30g2. 3182, 3282, 3382, 3482. 3582. 3882. 100 20O 300 400 500 600 700 800' 900 1000 ~--100 1200 1300 1400 1500 1600 1700 1800 1900 .... 2000 2100 220O 2300 2400 250O 2600 2700 2800 2900 3000 3].00 3200 3300 3400 3500 C O' 0 0 0 0 0 0 0 C 1.25 S 0.48 2.11 $ 1.17 2.51 $ 2,27 2,41 S 3,19 1,96 S 3.77 1.36 s 3.93 0,83 S 3.68 C.71 S '3,60 0.60 S 3.62 0.40 $ 3.67 0.14 S 3.78 0.17 iN 3,97 0.45 N 4.31 0.59 N 4,77 0.56 N 5.26 0,37 N 5,75 0,01 N 6.15 2.57 N 3,27 2.45 N ..... 2.75 2.07 N 2,40 1,57 N 2.32 1.12 N 2.53 0,80 N 2,78 0,52 i~ 2.95 0.30 N 3,00 .,~ 0,14 N 3,00 0,07 N 2,95 0,00 N 2,94 0,23 S 2,91 0,63 S 2,83 1.21S 2.67 1,93 $ 2.41 2.79 S 2.04 3,86 S 1.88 5,08 S 1.98 CHEVRON WELL /,2-5RD MEASURED DEPTH AND OTHER DATA GYROSCOPIC/SINGLE SHOT . ~ FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH0 81 MEASURED DEPTH TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 3782 3882 3982 4082 4182 4282 4382 4482 4582 4682 4782 48~2 4982 5083 5183 5283 5483 5583 5683 5783 5883 5985 6086 6!88 629! 6296 6503 6609 671& 682a 69~4 7156 3782 3882 3982 4082 4182 4282 4382 4482 4582 4682 4782 --4882 4982 5082 5182 5282 5382 5482 5582 5682 5782 5882 5982 6082. 6182. 6282, 6382. 6482, 6582, 6682· 6782, 6882. 69820 7082, 7182. o __ o o . O · O O o O · O · O O O · O O O O _3600 ..... 0 ..... C 3700 0 0. 3800 0 0 3900 ..... 0 ........ 0 4000 0 0 4100 0 0 4200 O 0 4300 0 ' 0 4400 0 0 450O 0 0 4600 0 0 4700 ~ ................... 0- 4800 ...... 0 ....... 0.. 4900 0 0 5000 0 0 5100 1 1 520O 1 0 530O ] 0 .5400 1 ..... 0 550O 1 0 5600 1 0 5700 1 0 ~ 5800 2 1 5900 4 2 6000 6 2 6100 9 3 6200 14 5 6300 21 7 6400 27 6 6.500 34 7 6600 42 8 6700 51 9 6800 62 11 6900 74 12 7000 88 14 6,36 S 2.40 E 7,6t S 3,16 E 8,73 S 4.24 E 9.62 S 5.62 E 10.20 S 7.23 E ~,039 S 8098 E 9.75 S 11.14 E 9002 S 13.46 E 8.18 S 15.92 E 7,25 S 18052 E 6o21 S 21,28 E 5.12 S 24.32 E ~,00 S 27,65 E 2.85 S ~1,28 E 1.69 S 35.20 E 0.58 S 39.38 E _ , . 0.28 N ~3,66 E 1.19 N 47.62 E 2,29 N 51003 E 3.50 N 53.89 E 2o61 N 94037 E 2,66 N ............. 45.87 E 7,13 N ~1.85 E 14,02 N 15.68 E 29067 N .... 3.080 E 52.75 N 8,55 W 81,4I N 22025 W 11~.66 N 37,00 W 146,65 N 50,&5 W 184.51 N 64.91 W 222,22 N 80.61 ~ 263,30 N 96e64 W 307,22 N 112.28 W 355.45 N 1Z7023 ~ 409.21 N 138069 W DEPTH VERT/'CAL SUB DEPTH SEA 7385 7499 7611 7722 7834 7944 P054 8161 S269 - 8376 _. 8590 ..... 8.697 8803 8910 9017 9232, . 9448 9556 ~ 9665 977~ o~.q 8 20203 10339 10416 1 0523 1063..9 10737 10e44 G YROScoP z c /S I NGLE ,SHOT · EVERy EVEN 100 FEET OF .SUB V£R T l CA L CORRECTioN ' NiD"'TVD D IFFE. R£rWCE ..... 7282, - 7~00 ..... 1.03 7382, 7200 1 l 7 7482, 7300 129 7582° 7400 7682, 7500 152 7782, 7600 162 ' -7882, .7700 - _172 7982, ......... 7800 1 79 8082. 7900 187 .8182, -' -~282 8000 _ 194. · -81 O0 20-1-- 8382· 8200 '-' 84,92. 208 8582 . ........ ~.300 ........2.14 -8682. 8400 221 '- ........ 8782 8500 227 "- ' ......... 8600 .. 234 8852· 8700 .... 24-2 8982. 8800 --- - 250 " °082' · .... 8900,. 25~5 9182. 9000 266 9282. 9100 274 ..... 9382, . 9200 9482, 9300 " ' ...... 9582, 291 96~2 9400 299 · ...... 9500 306 9782. 9600 9982. 9700 321 9982. 9800 327 1 0;.28.2 · 9900 334 10182. lOooo 34t 10282. IOIOc, .348 20382. 10200 355 1048£· 15 14 12 12 11 10 10 7 8 7 7- 7 6 7 6 7 8 8, 8 9 8 8 7 8' 7 6 7 7 7 SEA TOTAL D£'PTH' COORD ~'R/A T~'.S 464'80 N 147'12 h' 518.40 N 153.21 570,07 N 158.27 620'23 N 162.06 W 714,55 N 166'~8 75L¢' 39 N 168.42 798,66 ,~, 1~9~ 74 83~'38 N 170'17 w 877~27 ~ 170'89 -~ 91~'64 N 172.~9 953,29 ~% 173,31 989,39 ~ ...... !71,13 1025,43 ~ 166,77 ~, 1062.31 [,~ 160,47 ~. 1099,91 f.~ 1~2,40 W 1137'99 ~ 143.05 ~¥ '1176.9~ ;~ 133.34 1216,45 f~ 123,4~ W' 1256.10 N 113,03 W 1295'69 N 101.73 1335.43 N 1375.00 N -- 89.78 k~ 1414.41 .~, 78.4~ W '~ 67.75 1452.65 h; 57'20 ;v 1490,09 ~ 1526,66 ,~ 46'~7 35,88 v~ 1562~57 N 25,09 ~.. 1598.53 N 14.23 1634'80 ~ 1671.08 ~ 3,64 W 1707.05 ~ .- 6,75 E 1742,99 N 17.06 ~ 1778,82 N 27.37 g 37.64 OCT, 81 -.. . I';~E ~ $LI.r'? ED T ~ Lt DEp TH VE,~. T I CA DEPT 1116~ '10732. _. ... ,S ~'A ..! 0600 ........ 382 '" YROScop " - lC/SINGLE ,SHOT ' &'VEry thVEh, lo0 FEET OF VER T l CAL CORRE CT Z oi~ 'TOTAL 1850o~1 COORD Ii'lA T£',S 58°£9 CHEVRON WELL 42-5RD . . INTERPOLATED VALUES FOR GYROSCOPIC/SINGLE SHOT EVEN 1000 FEET OF NEA.SURED DEPTH, TRUE F(EASURED VERTICAL DEPTH . DEPTH 1000 999, _ 2000 1999, 3000 2999, 4000 3999, 5000 4999, 6000 5997, 7000 6942, 800"'~-~ '7.832 · 9000 8766, lC000 9692, 11000 10628, SUB SEA TOTAL COORDINATES 817. 0,70 S 1817, ...... 2,57 .~ 2817, 0,02 S 3817. 8,91 S 4817. 3,79 S 5815, 7.97 5; 6'762, 289,32 N · 7650. 737',31 N . 8584, 1093,91 N 9510, 1456,90 'N 10446, 1795.65. N 3.60 E 3.17 E 2,93 E 4,47 E 28,28 E 29.39 E 106,08 W 167,68 W 153,78 W 56,01 W 42,47 E 1 OCT, 8i CO~PLETI©N REPORT FOR GLDD BY FM LINDSEY & ASSOC. CHEVRON USA WELL SCU 42-5 CO~.~PL)TER ~-'ETHOD(RADIUS 'OF CURVATURE)' COMPUTER'DATE"(IO/01/81) FIELD ~.CETHOD(AVERAGE) SURVEY DATE(1972/9-21-81) 'GYROSCOPIC/MAGNETIC SINGLE SHOT SURVEY RECORD OF SURVEY TRUE MEAS. DRIFT VERTICAL SUB DRIFT DEPTH ANGL~ DEPT~ SEA " DIREC D ~ DEG. " 0 0 0 378 0 ~5 g02 0 0 ..... 139~ 0 15 1898 0 20 2395 0 15 ......... 2899 0 0 3385 0 30 ~283 I 15 .......... 4719 1 ~0 5232 2 30 5369 2 30 ..... 5872 1 40 5938 1 40 6094 1 30 '" 6118 2 30 6178 5 45 6232 6 0 . 6292 7 15 6425 12 30 6573 19 15 6667 21 0 6~03 22 15 6980 21 45 7100 21 30 TOTAL COORDINATES 0.00 -182.00 S O,OOE 377.98 195,98 S57.00E 901,97 719.97 N O.OOE 1393.97 1211,97 N45.00E 1897,96 1715.96 N59,00W 2394,95 2212.95 S40,00E 2898.95 2716.95 ..... S O.OOW 3384.95 3202.95 S30,OOW 4282,84 4100.84 N74-OOE 4718,69 4536.69 .... N69.00E 5231.35 5049.35 N75.00E 5368.22 5186.22 NBO,OOE 5870.88 5688.'88' 'N66.OOE 5936.85 5754,85 N53.00E 6092,80 5910,80 N58,OOE -' 0-00 2.08 0.74 0.22 2.43 1.08 0,06 1.95 10.39 '' 6,87 1.11 0.17 '5.50 6,47 8.92 6116.78 '5934,78 N33, 6176.62 5994.62 N12. 6230.33 6048.33 N 9.00W 6289.93 ~107.93' N20.OOW 6420.91 6238,91 N26.00W 6563,19 6381,19 N13,00W 6651,45 6469e45 N 8,00W 6777.87 6595.87 N 3eOOW 6941.98 6759.98 N 3.00W 7053.54 6871.5~ N 2.00W OOE ..... 9.50 OOE 13,46 18.96 25,65 46.63 84,69 116.47 166,35 232.56 276.7~ S 0.00 W S 1.13 E S 3,60 E N 4.00 E N .... 3,72 E N 2.57 E N .... 2.94 E S 2,40 E S 8.9.9 E S 19,51 E S 37.24 E N 43 · 07 E N 60,52 E N 62.17 E N 65e72 E N 66,31 E N 67,95 E N 68.10 E N 66.36 E N 57,46 E N 4.3.98 E N' 38.09 E N 33.29 E N 29,82 E N 27,89 E CLOSURES D I STANCE ANGLE D M DOG LEG SEVERITY DEG/IOC, FT 0.00 S '.0 0 0 W 2.37 S 28 29 59 E 3.67 S 78 17 44 E 4.00 'N 66 50 30 E 2,79 N 67 13 32 E 2,94'N 88 39 46 E 3,09 S 50 49 55 E 13.75 S 40 52 3 E 20*69 S '70"35 5 E 37.26 S 88 16 ~+7 E 43,07 N 89 4~ 4 E 60,77 N 84 48 i E 62,50 N 84 2 59 E 66.32 N 82 1~ 14 F_ 66.99 N 81 50 4~ ~ 69.27 N 78 47 26 E . 70,69 N 74 Z5 g6 ~ 71.15 N 68 ~2 ~ E 74.00 N 50 5~ g~ E 95.a3 N 27 g~ ~ E 122.55 N 18 ~ 3~ E 169.65 N 11 19 ~ E 234.~7 N 7 18 27 ~ 278.14 N 5 ~5 20 ~ O,OOO O.19a 0.1~3 0.051 0,017 0,017 0,050 0,i03 0,084 ~.162 0,159 0.166 0,572 0,107 4,17i 0,~28 2.10~ $*~ O,Z~7 D I SiA,';C~Z O.OO -2,01 -0.53 0.45 2,6a 1.23 0.24 -i,81 -5,72 1 10,1~ i2,7~ i7,42 ~77.9. CHEVRON WELL 42-5 GYROSCOPIC/SINGLE SHOT OCT, RECORD OF SURVEY TRUE MEAS. DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG, TOTAL 7254 20 45 7197,18 7015,I8 N 7a38 21 a5 7368,67 7186,67 N 3,0GE 398,87 ..... 7681 21 45 7594,37 7412,37 N 5,0bE 488.70 7871 21 30 7771.00 7589,00 h 5.0~E 558.~5 8026 21 45 7915-09 7733,09 N 6.0UE 615.31 ..... 8166 2! O 8045.46-"7863,46 N 6,00E 666,05 8300 21 15 B170,45 7988..45 N 8.0OE ~13,99 8434 21 15 8295,34 6113.34 Nll,GOE 76i,88 · 8578 20 45 8429,78 8247.78 8681 lO 30 8526,49 834~,49 N14-.COE-- 846,82 8798 '16 0 8637,90 8455.90 N 1,OOW 882,15 ......... 8982~19 15 8813,24-- 8631,24'-N 7.00W 9210 25 45 9023,77 8841,77 N 2,00W 1024,60 9475 25 BO 9262,71 9080,71 9664 25 30 9433.30 .... 9251,30 ..... N 1-OOE 1220-52 9892 25 0 9639,51 9457,51 10086 2a 45 9815,51 9633.51 10246 24 30 9960,96 9778.96"- N 10513 24 45 10203,68 10021,68 N B,OOE 1576,95 10829 25 30 10489.78 10307.78 N 3,00E 17i0.93 BOTTO~ HOLE CLOSURE 1713.88 FEET AT N 3 21 42 E CGONDINATES 25,95 'E 26,5D E 32,82 E 38,92 E 44,39 E 49,73 E 5.5,61 E 63,63 E . 74,36 E 86,6.5 E 82,77 E 75,93 E 75,93 E 78,05 E 80,61 E 84.17 ~ 87.65 E 93.48 E 100,50 E C L 0 S O k E b O ! STANCF ANaL F.. D ,v S 33~.22 ~99,76 559.8i ~1~.91 667.91 716,i5 764e53 815,75 °bO,u~ 885,39 94-1,34~.-N i027,4i 1223'.02~N 1320,21 1579,72 3 59 4 7 ~7 4 16 i2 4 27 i4 4 46 27 5 13 48 5 36 ~7 5 ....2 40 '3 39 34 ~ 30 2 3 2~ 20 ~ 2~ 33 E' E E E E E E E E DOG LEG SEVh4ITY OEG/IOOF'F 0.487 u,l~2 0,27i 0.81i 0,389 i.2i~ 3,146 1.802 2.881 0,29~ 0,228 0,157 0,156 0,094 0,237 u; ! .b'[ A?-~ CL ~89,75 959,77 8i~ 122~,00 1~26,Z0 1579.72 CHEVRON WELL 42-5 GYROSCOPIC/SINGLE SHOT · .. MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, OCT, 81 TRUE ~EASURED VERTICAE~"SUB ...... MD=TVD ......... VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION 28 48 78 108 118 1282 .1332 1482 1582 1652 1792 1892 ................. 1982 2082 21~2 ................. 2282 2382 2~82 2532 26a2 2782 2882 2o82 3082 3 lB '2 32a2 3382 3482 3582 3682 282. 100 0 0 382. 200 0 0 482. 300 ......... 0 .... 0 582, 400 0 0 682. 500 0 0 782. .......... 600 ................. 0 ........... 0 882, 700 0 0 982. 800 .... 0 ........ :':' . .. O '1082. 900 ..... 0 '-' 0 1182- 1000 0 0 1282. 1100 0 .. 0 -].. ]382,- ~1200 ' O .............. 0 1482. 1300 O' C 1582. 1400 0 0 1682. 1500 0 0 1782. 1600 0 0 ]882. 1700 0 0 1982, 1800 0 0 2082. 1900 0 0 2182, 2000 0 0 2282, ......... 2100 ........ 0 ....... 0 2382. 2200 O 0 2482, 2300 0 0 2582. 2400 0 0 2682. 2500 0 0 2782. 2600 0 C 2882. 2700 0 0 2982, 2800 0 O 3082, 2900 0 0 3182. 3000 0 0 3282. 3100 0 0 3382. 3200 0 0 3482. 3300 0 O 3582.. 3400 0 0 3682, 3500 0 O TOTAL 1.25 2.11 2.51 2.41 1.96 1.36 0,83 0,71 0,60 0.40 0.14 0,17 0,45 0,59 0,56 0,37 0.01 2.57 2.45 2.07 1,57 1,i2 0,80 0.52 0,30 0.t4 0.07 0,00 0,23' 0,63 1.21 1.93 2.79 3.86 5.08 COORDINATE,.,,% 0,48 E 1.17 E 2,27 E 3,19 E 3,77 E 3,93 E 3,68 E 3.60 E 3,62 E 3,67 E 3,78 E 3,97 E 4,31 E 4,77 E ............. 5,26 E 5,75 E 6.15 E ~ ................. 3'27 E N 2.75 E N 2.40 E N 2,32 E N 2,~3 E N 2.78 E ........ N 2.93, E O0 N :3. E N 3.00 E N .......... E 2,94 E 2,91 E 2.83 i 2.67 E 2.4i E 2,04 E 1.88 E 1,98 E .... CHEVRON i~i~'ELL 42-5 ........ G~FROSCOPIC'/SINGLE SHOT MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. OCT, 81 TRUE MEASURED '" VERTICAL' SUB ..... iq'D-TVD " VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 3782 3782, 3600 0 0 6,36 3~£2 3882, 3700 0 0 7,61 3982 3982. 3~00 0 0 8.73 4082 4082, 3900 0 0 9,62 ~182 4182, 4000 0 0 10,20 4282 4282. 4100 O 0 10,39 a382 ~382, 4200 0 0 9.75 44~2 4tiP2, 4300 0 0 9,02 .a582 .... 4582, 4400_.' ' 0 ......... 0 ...... 8118 4682 4682. 4500 O 0 - . 7,25 4782 4782- 4600 0 0 6.21 4882 4882. 4700 0 .......... - .... 0 ............... 5,12 a982 ....... 4982. 480'0 -0 5083 5082, 4900 0 0 2,85 5183 .......... 5182', 5000 .............. 0 ................................ 0 .......... 1,69 5283 5282. 5100 1 1' 0.58 5383 5382. 5200 1 0 0,28 5483 " 5482, 5300 ' 1 0 .... ' '- 1,13 5583 5582. 5400 1 0 2.12 5683 56~2. 5500 1 0 3,21 fi7~3 5782. 5600 1 0 ~- 4.40 5883 5882. 5700 1 0 5.64 5953 5982, 5800 ! 0 '' 7.24 6093 ......... 6082. ...... 5900 ..... 1 ......... 0 .......... ' '8.76 6183 6182, 6000 1 O 13.95 6284 6282. 6100 2 1 24.70 . 6385 6382, ' 6200 .. 3 1 39,26 6438 6482, 6300 5 2 60,58 6593 6582. 6400 10 5 91.18 6700 6682. 6500 "' 17 .......... 7 128,20 6807 6782, 6600 25 8 167.86 6915 6882. 6700 33 8 208,41 7023 69-82, 6800 41 8 248.45 7131 70~2, 6900 49 8 287,90 7238 7182.' 7000 56 7 326.45 S 2,40 E S 3,16 E S 4,24 E S 5,62 E S 7,23 E S 8,98 E S 11,14 E S 13,46 E ... S .15,92 E S 18.52 E" S 21,28 E S ............... 24,32"E S 27.65 E S 31,28 E S ........... 35,20 'E S 39,B8 N 43,66 N ...... 47'75 N 51,52 N 54,95 ~N .... 58,04 N 60,80 N 63.2'1 N 65,47 N 68,06 N 66,69 N 60.83 N 51.48 N 42.55 N 36.57 N 33.21 N 31,08 N 29,04 N 27,50 N 26,15 · . . E E E E E E E E E E E E E E E E E ...... ~,H~N DATA FOR EVERY EVEN "~,- ASURED DEPTH TRUE VERTICAL sub .... MD-TVD DEPTH SEA DIFFERENCE 745.2 7560 7668 7582, 7775 7682, 7.9. S .3 7782. 7990 7682, ~Og¢' 7992, 82O5 8312 818.2, 8420 F, 282. 8527 · '0'634 8482 5740 8582. ~ S 4 ~ ........... 8682 . 8949 8782, 9055 8882. 9164 8982. 9275 9082. 93 -¢3. 5 9182. "'9L96 .......... 9282 9697 9382, 971B 94~2. 9~28 9582. 9939 9682. 10049 97~ 2. 10159 9882, 10260 99S2. 10379 10082. 10499 10182, 10599 10282, 10719 10'382. 10,920 104~2. 7282. 7].00 62 7382. 7200 7() 7A, 82.- ' 7300 78 7400 86 7500 93 7600 7700 108 7~0~. u 116 7900 123 8000 130 ~100 82oe 1.45 ,, 8o/0 152 .,. 84C0 158 8600 166 8700 173 8~00 181 "' ~900 193 9OO0 203 9100 21~ 9200 225 9300 236 9400 246 9500 257 9600 267 9700 277 9BO0 287 9900 297 lO000 307 10!00 317 10200 327 10300 33B ..... ~.~ bHOT 100 FEET OF SUB SEA DEFTH, VERTICAL CORRECTION TOTAL COORDINATES 8 8 8 7 7 7 7 8 7' 7 6 5 7 12 10 11 11 11 10 11 lC, 10 10 10 lC 10 10 11 364.76 N 25,~2 404.06 .1 26,81 444,00 N 29,30 483,78 N 32,39 523.30 N B5,84 562,77 N 39,30 602.06 N 43.03 641,60 ~ 47,t6 679,97 N 51.26 718,29 N 56,23 -756,78 N., 62.6'5 794.61 lq 70,37 E6~,62 N 8~.32 895.14 N 86,26 927.04 N 83.94 962.99 N 80.03 i005,15 N ..... 76,87 E 1052,64 N 75,19 E 1100.39 N 75,04 E 1148.22 N -76,24 1195.99 N 77.57 E 1243,68 N 78.51 E '129-~, ,~ 64 N 79.7~' k 1337,52 N 81,34 E 1383.79 N 83,38 1429,72 N 85,76 1475.38 N 88,15 1521,06 N 90,55 E 1566,92 N 92,95 E 1613,04 N 95,37 E 1659,92 Al 97,83 E .. 1707,07 N 1OO,30 1 OCT, 81 J .. ii _ ..... · , CHEVRON 'WELL 42-5 GYROSCOPIC/S!NGLE SHOT INTERPOLATED VALUES FOR EVE~ 1000 FEET OF MEASURED DEPTtt, TRUE MEASURED VE,RT I CAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 2000 3000.. z+OOO 5090 6900 7003 ROOF,;, 9000 100,90 .... 99'9, .... 817. ....... 0.70 s _~.6o E 19-°'9. 1~!7. 2..57 N 3.17 E 2999. 2817. 0.02 S 2,93 E 3999. 3817. 8.91 S z,.~+7 E z. 999. z+817. 3.79 S' 28.28 E 5998, 5816, 7,51 N 63.60 E 6960. 677'~, ...... 2:39.96 i'q 29.44 E 7890, 7708. 60.5.73 N 4-3.40 E 8830. 8645. 943.66 N 82,06 E 9737. 9555, i363.23 N 82.a2 E . . . OCT, 81 HORIZONTAL VIEW CHEVRON USA WELL SCU 4:~-5A,SCU 42-5RD, 1~ SCU42~-5 RADIUS OF CURVATURE GYROSCOPIC/MAGNETIC SINGLE-SHOT SCALE: I" = I000' OCT. 2, 1981 TVD=IO,S99'i TMD=IO,995"~ fTVD= 10,788'~ TMD= 11,170' WE'LL 42-5A~\ / /WELL 42 CLOSURE = ~ tI ,~ / CLOSURE NO°50' E-185~' ~}~ N OI°49'E - 1854' 10~400~ 0,400 ', . _. :. ~~ TVD= 10,450 i TMU.= 10,829' ; ,0~000. - I0,000 ~600 9~00 aaoo. WELL 42-5 8400- 8400 8800 CLOSURff~ = NO5° 2 E- 1714' 8000. 7600 8000 7600 7200 7200 6800 6800 ALL DEPTHS SHOWN ARE TVD ~WELL SCU 42- 5A 400, 800- 1200 1600. 2000- 2400 - 2800- $2O0 $600 - 4000 · 4400- 4800- 5200- 5600- 6000- 6400 'VERTICAL SECTION CHEVRON USA WELL SCU 42-5A RADIUS OF CURVATURE GYROSCOPIC/MAGNETIC SINGLE- SHOT SCALE= I" = I000' OCT. Z, 1981 ALL DEPTHS SHOWN ARE TV[:) SO00 9600 I0 TVD = 10,599' TMD= 10,995' Suggested form to }:~ inserted in each "Active" well folder to check for timely con~pliance with our regulations. -- ' 'Opera-to-r,~el 1 Name and Number Reports and Materials to be received by: Date ,Required Date Received . , , Cc~pletion Report Yes · ~'Wel 1 Histow "~"¢ Yes ~re ~ips Core ~scription Registered Su~ey P ~'~ y /~ . Inclination Su~ey ~ ~ , , ~s R~ ~ ~' ~, Yes Digitiz~ ~ta , .... , ..... ,,, ~ ~ ........ ~" , {~ STATE OF ALASKA ' O~ ALASKA ~L AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. CHEVRON U.S.A. INC. 80-106 3. Address 8. APl Number P. O. Box 7-839, Anchorage, Alaska 99510 50-133-20232-01 4. Location of Well 1,879' North and 498' West of the Southeast corner, Section 5, T7N, R9W, S.M. 5. Elevationinfeet(indicateKB, DF, etc.) 167' K.B. 6. Lease Designation and Serial No. A-028996 9. Unit or Lease Name Soldotna Creek Unit 10. WellNumber SCU 42A-5 11. FieldandPool Swanson River Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] 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 25.105-170). Plugged back 7" casing and 5" liner with 40 C.F. Class "G", from 11,046' to 10,852'. Squeezed 12 C.F. cement away and set 56 C.F. Class "G" plug 10,852' to 10,490'. Milled window in 7" casing from 10,410' to 10,457'. Set 65 C.F. Class "G" kick off plug. from 10,490' to 10,315'. Cleaned out cement to 10,416' and kicked off with Dyna drill. 14. I hereby certify that the for.e~oir~ is true and correct to hhe The space below for Commission use best of my knowledge. Title Area Operations Superintendent Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission OCT ! 4 198] Naska Oil & Gas Cons. Date Nlch0rage Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate · ' /~- STATE OF ALASKA,f ~ ALASKA (~_--AND GAS CONSERVAT,ON ~SS~ON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION 2. Name of operator 7. Permit No. Chevron U.S.A. Inc. 71-32 ~ 3. Address 8. APl Number P.O. Box 7-839, Anchorage, AK 99510 50- 133-20232 4. Location of Well at surface 1879' N & 498' W of S.E. Cor., Sec. 8, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 167' KB. A-028996 9. Unit or Lease Name Soldotna Creek 10. Well No. SCU 42A-5 11. Field and Pool Swanson River Field For the Month of. September ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Unable to recover fish. Top of fish at 10,994'. Ran 5" liner from 10,993' to 10,19~'. Milled out shoe. Laid 2 sx. cmt. plug on top of fish. Perf. w/4 JHF at 10,420' in prep. for cementing 7" liner lap at month's end. 13. Casing or liner run and quantities of cement, results of pressur9 tests Ran 802' 5" 18# N-80 Butt. liner from 10,191'-10,993' Cemented w/75 C.F. CL "G". 14. Coring resume and brief description 15. Logs run and depth where run CBL, VDL-WAVE-FORM-CNL, TOTK 10,976-10,180' RE£E!VE_n 16. DST data, perforating data, shows of H2S, miscellaneous data OCT 0 6 ]~! Naska 0il & Gas Cons. Commission fmch0rage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,_~- ! .,- / ---,, 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 Alask~ Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 TP~\NSMITTAL AND ACKNO~EDGEb~NT OF RECEIPT OF MATERI~kL - (ALASKA) DATE: DEPT.:_ /~o0o G/ C. ~,~, · -,..~E FOL.LOWING IS A LIST OF MATERIAL,ENCLOSED HEREIN. co~ (~>~. ~oz~e~~ . SCA~. XEROX INDUCTION ELECTRICAL LOG DUAL INDUCTION LATEROLOG ~OF, EHOLE CO~fPENSATED SONIC BOREtIOLE COMP. SONIC w/caliper BOREI1OLE COb[P. SONIC w/gBmraa BOREHOLE TELEVIEk!ER .!'. CONTINUOUS DIPI.fETER- High Res. CD}~- POLlq~OG PLOT CE~fENT BOND LOG CASING COLLAR LOG - Perf. Rec. COb~ENSATED NEUTRON FOPSbITION ANALYSIS LOG FORMiTION DENSITY LOG F F FORI,iATION TESTER FOP~bkTION FACTOR F F GAI,~hk RAY .' GA>~IA RAY - NEUTRON GA>RtA RAY COLLAR ~LOG MICRO LOG ' " MI CROLATEROLOG MUD LOG NEUTRON LOG PROXIMITY MICROLOG RWA CObfPARISON PLOT SANDSTONE ANALYS IS SAP, AB~D SIDEWALL NEUTRON POROSITY SONIC TE~iPERATURE LOG · " RUNS · PLEASE SEPIA BLUELINE CO~R~LETION ILEPORT DI ?JCCTIONAL SURVEY CORE DATA C.__SARAB,~D TABULAR LISTING Received and checked ,, RECEIVEO--- _--- ; : Alaska 011 & Gas Cons. Commission :. ..... ,:,. A~chorage I ! ~oo ~oo Chevron U.S.A. Inc. 3. Address 8. APl Number / P.O. Box 7-839, Anchorage, AK 99510 5o- 133-20232 4. Location of Well 9. Unit or Lease Name atsurface 1879' N and 498' W of SE corner Sec. 5, T7N, R9W, SB+M 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 167' KB A-028996 Soldotna Creek 10. Well No. SCU 42A-5 11. Field and Pool Swanson River Field For the Month of. August ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operati OhS 8-2-81. Killed well with 86 PCF mud. Nippled up Class III, BOPE, tested and witnessed by USGS. Pulled tubing, left 35', 2 3/8" tubing in hole. Plugged back 7" and 5" liners to 10490'. Milled window in 7', 29#/FT casing 10410'-10457'. Set kickoff plug. Top of cement at 10315'. Cleaned out to 10416'. Drilled 6" hole with DynaDri.1 to 10462'. Drilled 6" hole to 11180'. Stuck pipe 46' off bottom. Spotted 18 bbls. of lease crude. Ran free point. Backed off @ top of 4 3/4" collars. Fishing for 4 3/4" B.H.A. @ end of month. 13. Casing or liner run and quantities of cement, results of pressure tests Plugged back w/40 CF Class "G", squeezed 12 CF, top of cement at 10,852. Set 56 CF Class "G" to 10,490'. Test casing to 3000 psi. Set kickoff plug w/65 CF Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run CNL/GR 10,956'-10,340' 6. DST data, perforating data, shows of H2S, miscellaneous data None hereby certify that the fo[ o' g is true and correct to the best of my knowledge. SIGNED T.L. Perryman TITLE Area Operations Supt. 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in dulplicate · Rev. 7-1-80 DAILY PROGRESS OF DRILLING WELLS Pro-~62 DAYS i/// OLt{~. J-JO] A'~JNC- tiF¢3, ~4!i. L JNG SE:'J LJf' f'f./tC.,IN, iD.?.) NO?TI.[ Vj'L. /2- % 2--- % ,,-.~J ~. r:, ;-'~. WtC~ [ Fl L.(.:C..$ HTd-IP WA'IE R L0~,%% F !LI'E_R OAK[: SOLIDS SAND .... ~__'-.~) v:.~.~ / % .~ m,~ /O, ff. .................. . ........ ....................................... r..:LIMUI ^'! .iV[: DAILY COST DALLY PROGRESS OF DRILLING WELLS Pro-562 DP, Il LING DAYS ...~._~ ...... P. LIM. RO'I AI')NG HMS. 'l t~ P, tl NC). ~,}' ()U'I Pki"'! (:.{'N~ ANNUL AR VEL. PUI~P PRE SE;. PSi(,i' E].tMIN. (D,P,) NOZZLE VFl. { '[ .;SE C-. ;.c~ ....... ,,~.:.~ ..................... sro' R.,~ .............. cr.s ..... /..:$Z ............. ~/~(~,so. r~. G,~ cc ................ ,- cc ~~_ ._J~. ......... ~-- v~[ j p~,~. WA'lIS: t C.~,.g I-{'I,-I-IP WA'iE Fi I. OSE; l: II. TFB OAK[ m.')l SAND OIL [.'.A i.,l-i ALK GALS (% MTN.} ............................................... .... .................................................................................. ~,~aska 0il & ~as Cons .................................................................................... DAILY PROGRESS OF DRiLLiNG WELLS P~o-562 DRILLING DAYS -~? (;L~M.-t:-tO'i,cC! lNG HRS ..... !-3. 'l' 0 FT. ................................................................... RECE"I1/E'~': ................... ........................... 8EP 1 0 :1~8! .......................... AI~:~'~/"d~i"[-'~-~'s cons, commission / ....................................................................... .A.~c.b.o. rag~ ..... DALLY PROGRESS OF DRILLING WELLS Pro-562 DtiJL 1 IN(~ ~A¥S ._.~_..~_ ...... CUM. ROTAI'iNG .i'tRB, ~ ...... _~J'l NO ................. [-:!2 L MA.K[ '1 YPt ! t I:.'I FT. IN HRS. / I HOURS J[ 'I'E. L;()NDii-i0i~ ..... I / 1 f~50 ~ " s~.L L u · " 3' 'fee ......... ¥,,'~ )(=,.~( 1 - t. oN~'t't VIS..~ ..... ~'t l,,~l ~C: DAILY PROGRESS OF DRILLING WELLS PTo-562 f'., / / HOURS Jr'~s O()NDi':t iON ..... / 1 BI1 NO. ,~G $[ ~ t.iP ......................... · ~ 'k ~.) , . -'Jlf't!,l GPM ANNLILA~ VEL. ~I,I'MiN, ~.~.) ~OZ2LE VEL ~/ ,~uo:~o. ~.. ............ ~,.P ............. c:c: .. -. ................... cc .... ~ ..... Yt~ t b)"i. WA'~E F~ LO:~: ~.f~f' ~'A~'~ ~ LOSS ~'I[.TFR CAK[ ~;0~ )DL; SAND CHI OR)D~ OiL CA p~t ALK GALS ............................................................................ : ................................. RECEIVED: ' .... SEP ! 0 ]9~ Alaska Oil & Gas Cons. Comrnissior~ Anchorage .............. DALLY ~rOGRESS O} DRILUNG WELLS Pre-562 C BI'I NfO, t 1- JO ~.i. :~[1 Ur A'~ ../~$77 ......... [OR~^T ~ou .................................... ~.u.~,~P ~-a~ss.. ................................ ps~: ......................................... ,~', DL i"J ti it'{-HF W~,'JF g I D~S J IL~l~: t-~ C'.^Kt= SOt. lbS SAN[} RECEIVEI) SEP 1 O 198! Alaska Oil & Gas Cons. Commission ...................... Anchorage ....... DAILY PROGRESS OF DRJLLING WELLS Pr0.562 O.t~tt ttNt; DAYS __~?. _~.._.CU~,4. ROTATING MAKE-~ YPE IN HRS. '.~6 $l.1 Li? ....... '~' (£co CHLORIDE /~,,,?~/ I OI;:~A'[ ION ......................... PLIMP PRESS... /tNNLil Afl VEL. Fla./MiN. (DJ.L) NOTgi ! Vl.l. FTJSFC. Oil CA pll ALK GALS {% fi4lNJ ............... :- ................ RECEIVED' ........... ................................................................. SEP I"0" '1'981 -Al[~il(a-Oik&i3as' Co ns. Commlssibfi Anchorage IT. TO ........ ~ ....... 'rT, .. : J-STA CONFER FILF: . ANHLIL AR VI L. - C(.: ArK 6At..$ J~,~IN,) Ol'HE R RE t,,{AFiK$ SEp _ 8 J98:1 Alaska Oil & Gas Cons. ...................................................... Anchor~'ge Commission ~'~.~0 FT. LIP IRESS aJ: DR~'LJ,.tN~ WELLS DNll. L 1N(-~ DAYS _ ~_'!~'_._ r":l"Jh~k R.,.. T/k'I'JNG HRS., ........... .~lz t - _M.$.K£ IN. cON'~, -:,: ............................................................................ -FI L F: RECEIVED-- .................................................................... : ................... ~'EP - 4 1981 Alaska Oil & Gas Cons. Commission Anchorage :'ROGRESS OF DRILHN LS P'ro-B62 RE£ E[~I)~ 'Ol$tt'Lfl .J'~_.I~ .... gl~'~ I,,.NNLtt AR VE_I. ]~ ..... tl.'ltlJq. (D-.PA I..,tOZZLE 'Iii ,. SAND DAILY P RES$ OF DRILHNG WELLS Pi-o-5§ IlIB0 ~;n N,:,. _ : ........................... [-:'J~" L ..... ~.~--_-~T-¥~'¥~ ...... [ [ [, ] ...... ii[iiiLI liS' ......... ~&~ ~ ......~NDI~]~]~- ..... ~t'f NO. t t ........................ ~,~-~ ..... ~V~K~-~ ¥~,~" ~ ~ ~ 'T ...... ~T~g~ .... ~--- ............... ........................................... ~;-~"¥kr ~'~T~ ...... -. . IG ~-;~, ~o. ~'J. ......... ~.,~ ............ cc ~ cc.. ~ . ..t~ ........... 1~ ....... '~ .................... ~¢ . ~:," . -,'~ ~ L~ t'~. WA~ t t~ LO~; lt~.}H~ ~A~[ F~ t ('~;~ t IL i L ~ (;AKE SOL IDS ........................................ . ~,.',..~....,,,~:,. 0,:~ 5~. -r,.,,,, lllZq'._ , _N:o.~..~,~...~~,._..ff~....!.!J?.~I.L O~ 'FoP _ · .. .~ b~-~. ~~....~._.z.~..~m.~..~- " ~ - ~ ~.~r~~~,.. ~~_._C~_S~:~~.~. .... , ALASKA (~,.- STATE Of ALASKA AND GAS CONSERVATION CO~MlSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER IX1 2. Name of Operator 7. Permit No. CHEVRON U.S.A. INC. 71-32 3. Address P. 0. Box 7-82t9, Anchorage, AK 99510 4. Location of Well 1879'N and 498'W of the SE corner Sec. 5, T7N, R9W, SB&M 8. APl Number 50- 133-202~2 9. Unit'or Lease Name So]dotna Creek 10. Well Number SCU 42A-5 11. Field and Pool Swanson River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 167' KB I A-028996 12. 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 [] 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 25.105-1'70). Change TD from 11,120' to 11,180'. New TD verbally approved by Blair Wonzell 8-24-81. AUG z Alaska Oil & Gas Cons. Commission /~/~ Anchorage Signed T. L. J~(~r~~Y~_~j TitleArea 'Operations Superintendent Date _~ -_L~2- &/, The space below for Commission use Conditions of Approval, if any: Approved by ORIG;NAt,' SIGII£11 BY [ON;'~i[ C. SbIITH Approved Copy Returned __ . By Order of COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate oq~ ~q pu~ (0£ ~o~d~qO 'opoD oAT~~TUT~P~ ~s~I~ ~ST '9; $~ Xq po~iq~qo~d s~ ~S oq~ ~o s~o%ma Ku~ ~o uo!~nIIOa ~o uo~ma6~ ao ~u~um~ds sq~ ~o~ ~u~%~od~ s~ . ,~88I :'oo~ oIoqmo~og 901-08 'oN ~u=~d ~-~ fkDS'~a~D eu~oPIOS :s~ 0IS66 ~u{s~IW 'oB~aoqou~ 6~8-£ xo~ '0 'd 'Dui ''~'S'fl UO~AOgD 'Toue o/~ UOTBTAT(I oouulIdmoD ~e~l ~oqu'I ' ~OST~odns ~oqu'l ~lo 'Tou~/o/A UOT:~U~asuoD Tu'4u~UO~TAUil .,ilo · Toua O/A uoT~oaS ~U~TqUH '~r~g ~ qSTa ~o 'ITl;aP o~, ~l~ad STtl~ ilo aouenssT atI'4 ;to PaTiIT~ou 5uTeq sT aoqe'l ;1o ~uaar4zeda(l e~[sel~ ek~4 'sosea,l o:~e~E~ aapufl aaTIt Ieoo~I '0f~'8£ il~l oa :~uensancl -uolae~.~asuoo le~uamuo2laua ~o ~uem~audaG ~q~ ~o oAT~e~uasoadoa ~ ~q po~ou~uoo oq ~em no~ suoT4eaodo ~uloumu~oo 086I ~' ST .,~uaaOaCl ~S-Z~ riOS ~o=D eu~oplog ..,,.-'Chevron Chevron U.S.A. Inc. P. O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 October 16, 1980 Mr. Harry W. Kugler Commi ssi oner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Dear Mr. Kugler' Please find attached Form 10-403 for abandonment of SCU wells 21-4, 12-3, 42-5, 44-8, and 41-9. Form 10-401 is al so submitted for the sidetracking and recompletion of SCU wells 21A-4, 12A-3, 42A-5, 44A-8, and'41A-9. Separate application for abandonment and recom- pletion was requested by your office. Mr. B. E. Wondzell has advised us that resubmission of well programs and technical information as included in our original application will not be necessary. Very truly yours, Area Engineer 'MJA'sj Attachments RECEIVED DEC ,..? 1980 Alaska Oil & Gas Corm. Commissior~ Anchorage 100 Years Helping to Create the Future Poma I0-- 401 . REV. I--I--71 STATE OF ALASKA SUBMIT IN TRIPL~- (Other mnstructk)ns ~: reverse side OIL AND GAS CONSERVATION ,COMMITTEE PERMIT TO DRILL OR DEEPEN ][[. ?YPI Or WORK DRILL [] WILL DEEPEN 81NGLI: OT~ER v gONg MI'I.TIPLE ZO N 2. NAME OF OPERATOR Chevron U. S.A., Inc. 3. ADDRESS O~ OPERATOR P.0. Box 7-839, Anchorage, Alaska 4, LOCATION OF WELL At sur£ace 1879' N and 498' W of the Southeast corner of Section 5, T7N, R9W, SB & M At p,'o~o,ed prod. ,.one 1884' N and 81' E of the surface location 37~3' ~'~ ' '~'" ~;:" ~ ~ '~"- ' ~ ' . ,3. DISTANCE IN MILES ~DIRECTION FROM NEAREST TOWN'OR POS~ OFFICe* -- Approximately 16.5 miles from Kenai API #50-133-20232-01 6. LEASE DESIGNATION A~NT) SE:RiAL NO. A-028997 '/. IF IN"DIAN. A-[~-~'I-I'/~I5 OR TP~BE N~ 8. UNIT, FARM OR LEASE NA~ME Soldotna Creek WELL NO. SCU 42-5 ~ 10. FIELD AND POOL, OR V~'ILDCAT Swans on. River ~ ' m S ~C I, T', R'. M', (BOTTOM ~OLE OBJECTIVE~ Sec.5, T7N, R9W SB & M 12. 14. BOND INFOtLMATION: Ty~ationwide Surety and/or No SL 6205862 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 660' 18. DISTANCE FROM PROPOSED LOCATION' TO NEAREST WELL DRILLING. COMPLETED, OR APPLIED FOR. FT. '[16. NO. OF ACRF.~ IN LEASE l 1,120 ' Ilg. PROPOSD DEPTH 11,120' 21, ELEVATIONS (Show whether DF, RT. CR, etc.) 167 ' KB 23. PROPOSED CASING AND :EMENTING PROGRAM ' _~o~,t $150,000 I?. NO. ACRES ASSIGNED TO THiS WELL 40 20. ROTARY OR CABLE TOOLS Rotary APPROX. DATE WORK WILL START~ 10/80 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH q uantit¥ o[ cement A5 iq KXIS'I'ING WK~L 42-5 - ' We propose to sidetrack SCU42-5 to within 50 feet of the existing location per the attached program.~, ~,~)~("~/!/i!~7 b~' f:'?~ ~w pr~u~ive ~ne. JLZZo~.~I iS ~. ~rllL or a~n ~ecltonali~, give p!rt~ent ~' lve~ical dept. Give blowu{ preventer program. - 24. I hereby certl,~ha,t t.,hg, Foregoing Is True an~ Correct (This space folr State ' ) ~ CONDITIONS OF APPROVAl.,, IF ANY: DIRECTIONAL SURVEY REQ~ A.P.I, ~CAL COD]e Area Engineer 3.tYa 3LYa IL/gL/gL * J' * I "I'1 III ii]l-Jlll d H.Ln L LLe:~ .zo mL~ LP~.~m _4-o dol'" -:SI , I i I I I I I I ~JOO'lJ XO 18~30 1¥i'i ']J._':I~OY.-OO U- ~C~ L O.~O~d~ :IJOIJ.¥A:J'I'J aL6ug %qB.La :~e %sal.i' ,S61~'PUg 'N'S 't~6~J 'bILL '~ UO.L:~Das "1"/~ !:i 13g a3so.JO~ 'H '~ 'B'Q'H CZ] 'ON t,i f ~ ! HS~,~O.L JO llNflOO 'ON lO~l ~ 'Oil NO IJ.93~ fi'3S 'mt ~3~ 4B60' ,.o o, :} 10 820 ~.n~_] ' ~ "' '~e ,~ o,.~ ~,:t. · · ~ ~ - ---- ,=;l ..i~/ 0'~ S 7,~ S~x=',,~ %,. ~ '.... o i : ' ~ JT,+PUP JT. Ct~ AT 45° O - T,:). 11,170~ : :, . .. GL. (" CASING AND TUBING fT~t f I-% T' ' f' Jl I ¢~' · 1 1.J¢ ~t. -1. , J~s ..... EU~ h'd Tbg. 205.~-~ . .... ~ {. ., ,. . )7 Jts. 2~" Eh% 5.rd Th~;o ~ .~- 2931.20' 4 . -;Il, ''T~ O -t ' 20 Jts: 2~'~ EL% 8ri Tbg. A336,9/,' C.d-.uO .. lO,~,]'.Eq;:d.tlZL 48¢9.~' ,.~ . ,,,.. ,, :, .... ' 50 Jvd. 2~" EUE 8rd ThE. . . ~ , . 7847,67'-- ~ 7892.18,~ . li Jr. 2~" l:;b% 8rd Tbg. .. ~}~:':'~': "' ' 10 q/q __.10~376.28,/-- ' - ,. z:,-.-~ ~ .... ~ -~ J-. 2s z.E,:, ~zd ~bg. DE 'I',\ I L ,5( 190.i' 1 '"" F: 95'2, 12,9[ . 116~.5{ t565o2-~ i.3.04 750o1'; 13o0C 3~o5~, f-., n;, ,~g ~, ,,.~ u '1 ~05 31.51 H 5 /,*, 0 ?Z H4-5' .. /D - 9- 4,18,03 2ooi 30o85 5 34-.4l 2 °87 1 · 51 16.13 2087 ~0 '" 5 ~./~? .91; 41.15 DRILLING FLUID PROGRAM Sidetrack of SCU 42-5 - Swanson River"Field Basic Drilling Fluid System Medium treated lignosulfonate mud. Optimum Drilling Fluid Properties - Weight - pcf Viscosity-sec/qt., AP1 Fluid loss cc, API Plastic viscosity cps Yield point lb/100 ft.2 2 Gel strength lb/100 ft. Calcium ppm Solidi content % vol. In'['7'''& 5" 66-68 43-47 4-7 18-24 8-12 0-5 9-10 50 Max 7-9' While Redrilling 78-100 43-47 - 4-7 18-24 8-12 10 Max. 9-10 50 Max 14-25.. R em ark s o o Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. Maintain adequate supply of barite and LCM on location. o During milling and redrilling continually monitor (on~24-bour basis) mud system for evidence of high pressure water entry. BE PREPARED TO SHUT WELL IN AND RAISE WEIGHT AS REQUIRED. . 0 . . o . . . . 10. 11. 12. 13. 14. 15. 16. 17. PROGRAM Pull CEV from }DP\ at 7,848 feet · ~' ~..?=% Open XA sleeve at 10,795 feet '-":"'~' Move in drilling rig and kill well with 66-68 pcf m~?. Install safety pl'ug in donut, remove xmas tree. Install and test Class III, 5000 p_~j_~,~., including 5000 psi blow and kill lines. Division of Oil & Gas Conserva~ and U.S.G.S. to w~tness test· Remove plug. Release packers. Uppermost packer is a 2-7/8".x 7" Brown HS-16 packer at 7,892 feet· Remaining hydraulic packers are 2-3/8" x 5" Baker "FH" at 10,830 feet, with a Brown safeiy'~.joint at 10,344 feet; a 2-3/8" x 5" Baker "FH'~ at 10,874 feet: ' 8' " "FH"' _ , a 2 3/ ' x 5 Baker at 10,900 feet; and a 2-3/8" x 5" Baker ~'FH" at 10,940 feet. Pull tubing and production equipment. Clean.-'out 5TM liner + 11,123 feet. Condition mud for logging. Take gallon sample prior to pulling out. Run Dresser Atlas Dual Spaced Compensated Neutron - GR log from clean- out depth to 10,340 feet. Use 0-60% porosity scale and a 0-100 GR scale. Run drill pipe to' + 11,120 feet. Equalize + 400 lineal feet, in stages if necessary, of Class "G" cement. Pull edt of cement, close pipe rams, and downsqueeze to leave top of cement at 10,800 feet. Run bit and tag top of plug; if below 10,800, feet, recement. Plug 5" and 7" to 10,470 + feet. Division of Oil & Gas Conservation and USGS to witness location and hardness of plug. Pressure.'test 7" casing to 3000 psi for 15 minutes· Condition mud to 78-80 pcf. Run a 7" section mill and cut n minimum forky feet window in the 7", 29fi Pll0 casing from 10,4].0'-10,450'. CasJ. ng collars arc located at 10,399'; 10,439';'and ].0,4~].', E-log del)tl~s. N, 6te' Continually monitor mud system for possible high pressure fluid entry during milling and rcdrillin+,~., operations. This interval is normally dri].led ~,~ith 98 pcf mud. BE PREPARI,]D TO S}tUT TIlE WELL Ii'~ Ai',~D R,\IS]:] ,~.I[tl) WEIGI-IT API'ROPRIATELY. Plug window and 7" casing stub with dens/fi, cd Cl. ass "C," cement (126 pcf) premi:.:ed with 3/4% CFR-2. 'Pull out of cement and Bradcnho. ad squeeze + 10 cu. ft. Top of plu,* to be at or above 10,390 feet 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. Clean out cement plug to 10,416 feet. Sidetrack original hole; precise directional control is not required. Run single shots as necessary to ensure adequate deviation from original hole. Preferred direction of move' West. Deviation from present'location to be 25-50 feet. Drill 6" hole to + 11,120 feet (depth equivalent to 11,120 feet in SCU 42-5 R/D original hole). . Condition hole for logs. Take ~ gallon sample of drilling fluid prior to pulling out of hole. · Run Dresser Atlas Dual Induction Focused log with SP and GR. A. Run linear scale for 2" DIFL and logorithmic for 5" DIFL, . B. Use + 10 ~V SP scale and 0-50 ohm-meters for the linear DIFL. C. Use 0-100 GR scale. Condition hole to run 5" liner. Run and cement approximately 910 feet of 5", 18~, N-80 Buttress casing with special clearance Pll0 couplings at 11,120 feet with sufficient densified Class "G" cement premixed with 3/4% CFR-2 to obtain returns above top of liner. Equip liner with 5" x 7" Burns liner hanger grooved for cementing. Use float collar and float shoe. Float collar to be one joint above shoe.~ Clean out cement to float collar. Run Dresser Atlas VBL-CBL-Neutron-CCL log and Dual Detector Neutron Lifetime - GR log from effective depth to above top of liner hanger. Scales to be provided by Engineering representative on location. Pressure test 7" casing, 5" x 7" lap and 5" liner to 3000 psi for 15 minutes. Jet perforate and run completion equipment per supplementary program to be issued after the logs have been run.. Remove BOPE and install xmas tree. Pressure test tree to 5000 psi. Displace completion fluid down thc annulus and up thc tubing with lease crude. Release rig. Place well on production as directed]. Blowout Prevention Considerations' For killing and redrilling i · · o , Potential Problems' A. Gas may be encountered after packers are released,while cleaning out the 5" prior to abandonment and while redrilling. Shut in tubing pressure is approximately 3000 psi. Care must be exercised not to swab the well while tripping or pulling production equipment. B. Extreme caution must be exercised while redrilling due to the possibility of high pressure water entries. The first *400 feet of int&rval"t° be ~edrille~ is normally drilled with 98 p~f mud. The programmed mud weight of 78-80.pcf will overbalance a 5300 psi pressure by 150-240 psi. C. A mud weight of 80-82 pcf should minimize pbtential for lost circu- lation while drilling the Hemlock. However, LCM should be kept on ' hand at all times. D. Any kicks should be handled by normal procedures. Ail personnel should be made aware of these methods and care must be exercised at all 'times. The hole is to be kept full at all times. Maximum anticipated formation pressure' A. 5300 psi in the "G" at window depth 10,410 feet. B. 4600 psi in the Hemlock. Top Hemlock'10~720 feet. Maximum possible surface pressure: 3500 psi. Blowout prevention equipment' Class III - 5000 psi for all work. PROPOSAL FOR WELL OPERATIONS PRO 316-1 Field'' Swanson River Property and Well No.: So!dotna Creek Unit 42-5 Surface Location' 1,879°feet North and 498 feet West of Southeast Corner of Section 5, T7N, Rgw, SB & M. Bottom Hole Location: 1,884 feet North and 81 feet East of the surface location. Plugs: 11,123 feet Total Depth_: 11,170 feet Casing_: 18" conductor pipe driven to 74 feet. 10-3/4" 40.5# cemented at 3,385 'feet. 7" 238 and 298 cemented at.10,731 feet. 5" 183 liner cemented at 11,169 feet, top at 10,499 feet. Perforations' 4' ~" h~les at 8,014 feet (squeezed twice) 4 - ½" holes per foot' 10,844' - 10,868'', 10,884' -.10~894'; 10,914' - 10,934'; 10,052' - 10,986'. See attached tubing detail. Tubing: Junk' Parted tubing at 10,936 feet. Datum: 15 feet above ground level at original KB elevation of 167 feet. CHE~ LIST FOR NEW WELL PERMITS Company C~.~ ~ Item Aplpr ove Date Yes (1) Fee ~f//~_ ~ -/~F~ 1. Is the permit fee attached .......................................... dTm~_ 2. Is well to be located in a defined pool ............................. ~.~.. No .. 3. Is a registered survey plat attached ................................ 4. Is well located proper distance frcm property line .................. ~_ 5. Is well located proper distance frcm other wells ................... 6. Is sufficient undedicated acreage available in this pool ............ Lease & Well No. ~, C, Remarks (4) Casg. ~ 7. Is well to be deviated .............................................. q~f. 8. Is operatDr ~e only affected party ................ :/~ ~ 9 Can permit be approved before ten-day t ................. '~' g~ '~ 10. Do~s oporator ham a Bond in force ................................. 11. Is a conservation order needed ............... ' ...................... ~_~. 12. Is admSnis~r'ativ~ approval needed .................................. ~ 13. Is conductor string provided ........................................ ~ ,, ~ 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in surface and intermediate or production strings .. T6. 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 and burst. (5)mP Additional Requirements: 19. Does BOPE have sufficient pressure rating - Test to ~--~ psig . .~ Approval Reccmmended: Geology: Engineering: rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file· under APPENDIX, .. No special'effort has been made to chronologically organize this category of information. **'~- NSP dOB BECWTSC3 HAVING EXTENDED TASK NAME H4/82.287/18:1q,'.86 HAS ~5 DATA STRI'NGS LISTED BELOW TR~CE OATA STRINGS . . . · · . . · . . . * . · . . . . . . . . . . · · . . . . . . . ~ . . . . . . . . . . . · . . . . '~ . CURVE INFORMATION * NO. OF * * JATA STRING * TRACE SLMLIS 181822~7 SLMLIS 18!822~7 S L M l I S 18 i 822 ;~ '7 SLMLIS 181822~? SLMLIS 181822,~7 SLMLIS 181822i~7 SLMLIS 181822:~'? SLMLIS 18.1822~'? SLMLIS 181822~7 1 N2"TO'TDT~ MSP 1~'17~.5~ 1~997.5~ ~.:5~ -999'25:~ 185G.~8 1 N3TOTOrT~ MSP I~17~'5~ 1~99'?.5~ ~..5~ -999,25~ 8'~2.~8 .i F1TDTDT~ ~SP I~17~.5~ 1~997.5~ ~.5,.~ -999~ 383.758 SLMLIS 181822i~7 SLMLIS 181822~'~ SLMLIS 181822~'? CREATION* GATE ~ g9 ') ~9 1.9 09 ) ~ '0~ ) ~ ) [~ O~ ) ~ ) **~ ~ SI 8DP $IHl ~0 NOIIVNIN~]Zi l.V ~38WAN i09J ~L LL L~g~BTBT SZlWl$ LE~TBT $IIWl$ L~Z~BTBT $IIWl$ = 39Z:I VIVa NI SOBOO3B VtVO ONV ~3OV]N ~O T I I Z I I I I ./ : 9L gL SI BOP SIHI 50 NOIIVNIWM31 iV B38WAN lOlfl ~' £ - 39I~ VIVG NI SOBO33B ¥1V0 QNV B3Q¥'3H 90 W3BNgN LL ) OL 6 · NOI£V3BD ~- WOB¢ - ~0 'ON - NOIZVNBO~NI lA,nD ~ 33V~1 ~ ~NIBIS VIV~ v RO13B 031519 SBNIBIS viva I $,VH B~IB'G:LT/Z.:~g°gB/bH 3WVN NSVI O3ON31X] 9NIAYH ggSl. Bg3g flOP dSN --*- £~ZZ!BgLT SIqWIS CgGTS'T dSW ~IQIQIT~ I L.~'~8~LT S]:lW1$ LB~SGLT SIl~lS dEW 91.01W9I$ I dS~ glOIM9 dSW £1011 l~O I dC:W,~ £iOl. ON I LO~S~LT SIIW1$ £~8~LT $IIWIS £~Z~L.T SI1WIS £B~GLT $IIWIS L~EB~LT SIIWIS ~ L~8GLT SIIWIS [ WOB~ ~ ..-I0 'ON " RO1]fi 0]1511 $9NIalS VIVO ~9: dgW glOl. OlIH T dSW glOlOl£N I dgN glOlOlgN I dSW ~ dSW ZIOINglS I m dgW IlOl~9 I ~ *; iN 3W3a3 NI ' 5NIAVH 13S1. fl33[~ BOP dgN '*** §T 8~ 8 9J)'8 8;~l T 8kl'"lBT 8T dSW TIOIW9IS T ~. AaON3N $31A8 Na~l /N~G 9NIS~ I i · L~Z~GLT SIqW3S £ £GZZS~LT $IIWIS Z. gZ~B~tT $13W15 ZB~8~ll $IIWl$ £ ~B'96T~ S6T : )lI~ VlVO NI S(]aO33a ¥:lVO QNV ~]OV~H _-iO F ILENAME FILEIYPE FiLE ~KEA'ilUN DATE' S POOL i0 CO~NI C LASS bEV ICE FU~M:S TAG DA'iA: FiLE i?'37(>) ORZGi. N Au'CMVS1 ~':~SAXAND 11/01/82 :, ~,, 15.2~.C9 JG~ 7370 ~~- JES2. JOg STAI'I~T'IgS [$ CA.R~ READ 0 SY.$1L~T Pk~NC.H A. EC~RDS · '~,< ,iiii!, 1 //NW DAOt. 05 JO6. i N~AO LO~ 6-03~2 ) tNOI LG..A.S ~CL. AS$:P. // ~S 6LE ~"EL:. 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