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160-038
• RECEIVED STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 0 2 2014 1a.Well St aWEoLL❑COM❑PLETGO❑N OR R❑ECOMP�LETION_REPORT AND LRZ Gas Other Er GCC 20AAC 25.105 20Mc 25.110 Development 0 Exploratory ❑ GINJ Ii] WINJ El WAG 11 WOSPL❑ No.of Completions: _0 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Hilcorp Alaska,LLC Abend.: 5/1/2014 • 160-038/314-240 3.Address: 6.Date Spudded: 13.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 10/30/1960 50-133-10170-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number Surface: 660'FSL&670'FWL,Sec.34,T8N,R9W,SM ' 12/9/1960 Soldotna Creek Unit(SCU)14-34 Top of Productive Horizon: 8.KB(ft above MSL): 151' 15.Field/Pool(s): L--- S jr– GL(ft above MSL): 15' it vY a - 33 Total Depth: 9.Plug Back Depth(MD+TVD): Swanson River/Hemlock Oil 660'FSL&670'FWL,Sec.34,T8N,R9W,SM • 10,640'MD/10,640'TVD- 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 348352.3 • y-2461868 . Zone- 4 .10,870'MD/10,870'TVD, FEDA028990 TPI: x- y- Zone- 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 348331.7 y-2461844.6 Zone- 4 N/A N/A 18. Directional Survey: Yes ❑ No 0 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-dril/Lateral Top Window MC/TVD: N/A N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" Surf 28' Surf 28' N/A 13-3/8" 54.5 J-55 Surf 2,981' Surf 2,981' 18-5/8" 600+1200 6-5/8" 24-28 P-11onN-80 Surf 10,866' Surf 10,866' 10-5/8" 600+600 24.Open to production or injection? Yes ❑ No ❑ 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): 2-7/8" 10,629' 10,299';10,414';10,439'; 10,550';10,602' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No ❑✓ SCANNED JUL 1 02014 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 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❑ • Sidewall Cores Acquired? Yes ❑ No❑ - 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. IBDMS JUN - 2 2014 Form 10-407 Revised 10/2012 j 1 /G I� CONTINUED ON REVERSE /� 4,11 /�/ Submit original�� only `G. (n /� bf'( ` c`- V 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El 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: sporholac hilcorp.com Printed Name: Stan Porhola Title: Operations Engineer Signature: 7101•44---- Phone: 907-777-8412 Date: &A 2//11 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 Weekly Operations Summary /J �`\ Well Name API Number Well Permit Number Start Date End Date SCU 14-34 50-133-101700-00 160-038 4/27/14 5/1/14 Daily Operations: 04/25/2014- Friday Prep doghouse for move, spot crane and pick iron roughneck off floor, ship gen skid, prep derrick for removal, lower dog house and ship out, ship out pump skids, load rig mats and ship, ship HPU skid, spot crane and remove derrick board, Cameron installed BPV on SCU 14-34, spot crane and pick derrick off carrier, ship derrick, Peak pressure washed mat boards at Swanson G&I. Cut up liner and felt on SCU 44-05 and dispose, pick drawworks/carrier and ship out, pick up trash around location on 44-05, add on to liner at SCU 14-34, pick sub base off pony sub and load out, ship out pony walls, pick up remaining mats and liner, break crane down and transport to new location,set mats on 44B-33 well.set pony sub. 04/26/2014-Saturday Transport crane boom from SCU 44-05 to SCU 14-34. RU and spot crane, set sub base on pony walls, set carrier/drawworks section on sub, set derrick, install derrick board, spot pit modules, spot gen sets 1 & 2, spot boiler, spot HPU skid, spot pump modules, spot water tank, prep and raise doghouse, lay liner for catwalk, spot BOP stack and hang off, Peak pressure washed cellar on SCU 44-05. Graded SCU 44-05 with Saxon loader, string electric cords and plumbing, transport portable genset from SCU 44-05 to SCU 14-34, raise derrick, install top drive torque tube, hook up water air, mud lines. Spotted catwalk and beaverslide. Load out remaining items on SCU 44-05. 04/27/2014-Sunday Function topdrive, spot service shacks, complete electrical connections and plumbing connections. Gather up flanges and 1502 connections to RU on tree. RD, transport and RU office trailers on SCU 14-34. RU corn tower. Swap out centrifuge with Halliburton Rep and crane. RU sewer tanks and contain same. Hang bails and elevators. RU standpipe. Tested ESD's and alarms. RIG ACCEPTED AT 12:00 on 4-27-14. Total Safety RU gas detection equipment. Handy Berm bermed entire rig footprint. RU Pason cords and MU circ lines to tree. C/O kickback rollers on drawworks. C/O riser cables in pits. Peak delivered rig water and produce water. Cameron on location. RU lubricator and pull BPV. Open well to choke. 333 psi on tubing, 267psi on annulus, bleed tubing down to 0 psi, pump 290 bbls produce water down annulus, gas&oil to surface, shut down and check f/ pressure, built to 331 psi on tubing and 287 psi on annulus. Bleed tubing psi down to zero and pump 40 more bbls produce water down annulus. Check for pressure, tbg 0- annulus 0. Set BPV with "T" bar and nipple down tree. Install 7 1/16" X 11" adapter spool, set 11" X 11" spacer spool and nipple up BOP'S, set BOP stack, hook up kill and choke lines. Attempt to install flow riser, riser too long. Function audio gas alarms and lights. 04/28/2014- Monday it r Alaska Hilcorp as a, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 14-34 50-133-101700-00 160-038 4/27/14 5/1/14 Daily Operations: Finished nipple up of BOP stack and chain off. Install drip pan and flow line. RU flowshow. Function check rams. Pulled BPV and pump 30 bbls down tubing. Installed 2 way check. MU XO's to 4" test jnt and installed into hanger. Pumped 20 bbls down backside, annulus on vac. Shell tested good. Justin Miller, BLM Rep on location to witness testing. AOGCC Rep Jim Regg waived witness at 23:00 hrs on 4-27-14. Start testing at 11:00 hrs. Test annular at 250/2500 f/10 min. Test BOPE at 250/3000 for 10 minutes each on chart. Total Safety tested gas detection equipment. Had one failure on CMV#7 (loose I grease nubbin cap), tightend cap and tested ok. Received 4" drill pipe and shipped out 4 pipe bunks of 4-1/2" drill pipe on the empty trailers. Recieved Weatherford tubing tongs, power pack and handling equipment. Shipped out excess 4.5" liner. Attempt test on rental TIW,failed low test,Weatherford delivered new TIW while cont testing. With 2-7/8" test joint, tested annular @ 250/2500 psi,tested rams @ 250/3000 psi 1/10 min each, rig down testing equipment. Total test time 17.5 hrs. Had total of two fail/pass tests. Pump 35 bbls produce water into annulus from trip tank and 60 bbls produce water down tubing, pull two way check. Well on vac. 04/29/2014-Tuesday Change saver sub to HT-38 and ready the rig floor to pull tubing. Change to long bails to allow for XO's, RU Weatherford tongs, MU topdrive on 2-7/8" buttress landing joint, BOLD's, PU to 80K on hanger,SO to 72K, make two turns to right to release packer, PU to 90K, SO to 70K. Pull hanger to rig floor, up wt 76K. Pump calculated bottoms up (253 bbls-4378 strokes)to remove any trapped gas at 168 gpm-0 psi. Change out bails on top drive, install 2-7/8" elevators. POOH sloAer,..lay down 2-7/8" 8 rd EUE tubing and jewerly& PKR Fill hole every 15 joints with calculated displacement(1.1 bbls per 15 joints). No returns on the trip out. Rig down flow line & catch pan, install 11" shooting flange on top of Hydrill. PJSM with Priorty E/line crew& rig up lubricator on the 11" flange, close the blinds and and fill stack with water. Test Lubricator @ 250/3000 psi. Pressure leaking off due to o-ring in lubricator. Change out o-ring and retest. Second attempt with a slight leak dropping from 3000 psi to 2900 psi in 5 min. The leak was the weap hole in the top pipe rams. Bleed pressure and work the upper rams, retest. Test Good. 04/30/2014-Wednesday Run in with the E-Line and the bottom Bridge Plug. Correlate depth and set the the plug at 10,320'. Pull out with e-line and pick up the 50' bailer. Install charge on the bottom of the bailer, mix cement and fill bailer. Run into the bridge plug and lay cement on top of the plug. Pull out and fill the bailer with cement. Lay the cement on the plug. A total of 1.1 bbls of cement is laid on the bottom plug bringing the cement up 36'to 10,284', POOH w/wire line and rig down. Strap all tools and make up scrapper assembly: Junk Mill, Scraper, String Mill, HWDP and Jars. Pick up HT 38 heavy weight and drill pipe T/5,026'. Service rig&top drive, check linkage on brakes. Continue picking up 4" HT38 drill pipe. 06:00 at the depth of 6,500'. 05/01/2014-Thursday Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 14-34 50-133-101700-00 160-038 4/27/14 5/1/14 Daily Operations: Continue tripping on picking up singles from 6,800' to 10,200'. Strap and tally the drill pipe as we go. Circulate produced lease water down hole for a bottoms up checking for gas and losses. Rig up and test the casing to 2,600 psi for 30 min. Change out saver sub on top drive. Trip out hole F/ 10,200'T/6,705' with the clean out assembly. Service rig and top drive. Continue tripping out of hole F/6,705 T/5,009'. Install saver sub on top drive & cut 115' drilling line. Continue tripping out of hole F/5,009' to clean out assembly and L/D. PJSM with wire line crew and rig up eline. RIH with Gamma tools and tag cement @ 10,250'. POOH w/wire line and pick up the CIBP. Run in with the CIBP and set @ 9,390'._[Continued -See Drilling's Report for SCU 44B-33.] Soldotna Creek Unit II Well SCU 14-34 ACTUAL SCHEMATIC Actul PTDa160-038ck Nikon)Alaska.LLC API: 50-133-10170-00 CASING DETAIL Size Wt Grade Type ID Top Btm. RKB to Hanger= 17.77' 20" Structural Surf. 28' 13-3/8" 54.5 J-55 Surface 12.415" Surf. 2,981' I 28 P-110 5.791" Surf. 92' 204 28 N-80 5.791" 92' 6,655' 6 5/8" 24 P-110 Production 5.921" 6,655' 10,147' 28 P-110 5.791" 10,147' 10,866' TUBING DETAIL 13-3/8" - 2-7/8" EUE 8rd N/A 10,546' 10,629' JEWELRY DETAIL No. Depth ID Item 1 9,390' - Bridge Plug(set for whipstock) 2 10,320' - Bridge Plug(capped w/70'cement) 3 10,409' - Brown"CC"Safety Joint-Btm half 4 10,410' - Otis"XA"Sleeve 5 10,414' - Brown HS-16-1 Packer --- 1 6 10,420' - Otis"S"Nipple 7 10,426' - Baker Blast Joint 8 10,435' - Brown"CC"Safety Joint 9 10,436' - Otis"XA"Sleeve ,4,;: OF 77.4 THE STATE Ahask� '_T s "7 333 West Seventh Avenue GOVERNOR SEAN PAR\I;I I. Anchorage Alaska 99501 3572 9C7 275 lz33 saws' 1VIAY072014 Stan Porhola Operations Engineer Hilcorp Alaska, LLC Q 3800 Centerpoint Drive, Suite 100 .6 07-.. 0 3 v Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 14-34 Sundry Number: 314-240 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, ej Daniel T. Seamount, Jr. Commissioner DATED this!0 day of April, 2014. Encl. ✓c cz- - STATE OF ALASKA k APR 1 4 2.61'; ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS OC C ; 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑✓ • Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing Q • Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other:❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ • 160-038 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-10170-00 - 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)14-34 - I Will planned perforations require a spacing exception? Yes 111 No No 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028990 Swanson River Field/Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10,870° 10,870 • 10,640 10,640 N/A N/A Casing Length Size MD ND Burst Collapse Structural 28' 20" 18' 18' Conductor 92' 6-5/8" 92' 92' Surface 2,981' 13-3/8" 2,981' 2981' 2,730 psi 1,130 psi Intermediate 6,563' 6-5/8" 6,655' 6,655 8,810 psi 8,170 psi Production 3,492' 6-5/8" 10,147' 10,147 10,230 psi 6,730 psi Liner 719 6-5/8" 10,866' 10,866' 12,120 psi 10,140 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 10,629' Packers and SSSV Type: 5 packers,see attached schematic Packers and SSSV MD(t)and ND(ft): 10,299'MD-10,299'ND 10,414'MD-10,414'TVD;10,439'MD-10,439'ND;10,550'MD-10,550'ND;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n 'Service n 14.Estimated Date for 15.Well Status after proposed work: pq./� y(� /" Commencing Operations: 04/25/14 Oil 9 V Gas I=1 WDSPL E1 Suspended ,yu{ 16.Verbal Approval: Date: WINJ ❑4,l5''GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhda Phone: 907-777-8412 Email soorholaehilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature .X�,¢/`—�r✓``'� Phone 907-777-8412Date 2 / COMMISSION USE ONLY I Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical'? Integrity Test ❑ Location Clearance IDRBDM 4%-f• -, QY © 7 2014 Other: ,1= S Q S 13 6 r S 0- l * I frzspe •o f re ;r b e_- .r-.e_ Cir s 3-1-4_es+. Spacing Exception Required? Yes ❑ No 12( Subsequent Form Required: /Q- L7°1 ) yAPPROVED BY �7/�� Approved by: COMMISSIONER THE COMMISSION Date: q-I /" Submit Form and Form 10-403(Revised 10/2012) ApAvp+Intlitik t alit fir 12 months from the date of approval. Attachments in 9uplicate/ Well Prognosis Well: SCU 14-34 Hilcorp Alaska,LU Date:04/12/2014 Well Name: SCU 14-34 API Number: 50-133-10170-00 Current Status: Producing Oil Well Leg: N/A Estimated Start Date: April 25th, 2014 Rig: Aurora AWS#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-038 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: 1410982P Current Bottom Hole Pressure: -2,200 psi @ 10,500' TVD (Static survey conducted May 06, 2013 10,350' MD) Maximum Expected BHP: —2,200 psi @ 10,500' ND (Static survey conducted May 06, 2013 10,350' MD) Max. Allowable Surface Pressure: -0 psi I (Based on actual reservoir conditions S and min water cut of 50% (0.385psi/ft) will balance reservoir at 4,7866''TVD.) Brief Well Summaryick This well was drilled and completed as an oil well in the Hemlobfc in 1960 as SCU 14-34.The well was worked over in 1962 for gas lift conversion and again in 1973 for Hemlock zonal isolation. The casing scheme consists of a 13-3/8" surface casing @ 2891 and cemented to surface.A 10-5/8" hole was drilled to 10,870'and a 6-5/8" P-110 production casing was run.The well was worked over in April 2013 and a string of 2-7/8"tubing and a mechanical packer set above the Hemlock H-1 bench. The purpose of this work/sundry is to abandon the current perforated interval and prepare the wellbore for re- ✓ drilling operations. A drilling permit application will be submitted separately for the sidetrack. �� I CO4cv'. r*e :ccr„.c ll ljQ. Notes Regarding Wellbore Condition fir, DCcn f rodv�'A� A?' /Pf/ 714'7 ✓`D • Last tag at 10,410'SLM on 5/06/13 w/2.00"gauge ring. '67r- nee, of Of Cc q#ja9 444 a�tv- ed akvr (0 6O10 far Ow" WO Rig Procedure: j ye*rs . P(vyt,', 7-4,) u.elf fete. re4,•rl+ 1. MIRU Aurora AWS#1 WO Rig. gOvid g//0 ' 6.' jm/row / reave j f, I'fie - f j yr 2. NU BOPE.Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/1,500 psi High (hold each Poe AA-041- valve and test for 10-min). Record accumulator pre-charge pressures and chart tests.a. Notify AOGCC 24 hrs in advance to witness. �� ( "-) 4 "WA b. Notify BLM 48 hrs in advance of BOP test. '� 3. Bleed any trapped pressure off tubing and casing. .54 14,.:9 4. MU landing joint and pull tubing hanger free. 5. Release mechanical packer. a. Have E-line on standby if packer does not pull free. b. Watch for drag/sticking of the packer while pulling thru the 6-5/8" casing. 6. SOOH and rack back 2-7/8"8RD tubing. Lay down the packer and all jewelry. 7. RU E-line, PT lubricator to 3,000 psi Hi 250 Low. - 8. RU 6-5/8'_28#CIBP, RIH and set bridge plug at 10,320' MD. 9. RU 3.0"x50' bailer,dump bail 35'of cement on tubing plug(48 gallons of cement)to achieve a cement top at 10,285'. POOH. RD E-line. 0(G. 11 Well Prognosis Well: SCU 14-34 Hilcorp Alaska,LL Date:04/12/2014 10. MU 5-5/8" bit w/6-5/8" 28#casing scraper and RIH on 2-7/8" 8RD tubing out of derrick. a. Need XOs for 3-1/2" IF connections on scraper tools to 2-7/8"8RD tubing. 11. RIH to+/- 10,200' MD. 12. Circulate well clean w/Produced Lease Water. 13. Pressure test casing and cement plug to 2,600 psi for 30 minim 14. POOH. Lay down 2-7/8"tubing, casing scraper and 5-5/8" bit. a. MU 2-7/8" 8RD thread protectors to tubing(332 joints). 15. MIRU E-line. RU 3.0" bailer, RIH and tag cement top at 10,285'. 16. RU 6-5/8" 28#CIBP and GR/CCL tools. 17. RIH and set top of CIBP at+/-9,400' MD in the 6-5/8" 24#P-110 casing(set 3-5 ft above a casing collar). �'�� rl..�..• 18. POOH. RD E-line. 19. Test casing to 2,500 psi for 30 min and chart. 20. Set BPV. ND BOPE. NU dry hole tree. Pull BPV. 21. RD Aurora AWS#1 WO Rig. 22. Turn well over to production in preparation of moving in the Saxon#169 Drilling Rig. 23. Replace IA x OA pressure gauge if removed (6-5/8"x 13-3/8"). Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic Soldotna Creek Unit Well SCU 14-34 . 11 SCHEMATIC Last Completed: 08/01/1973 SCHEMATIC�/I/� PTD: 160-038 v. HIIr ri,Alaska,LLC API: 50-133-10170-00 CASING DETAIL Size Wt Grade Type ID Top Btm. RKB to Hanger=17.77' 20" Structural Surf. 28' 13-3/8" 54.5 J-55 Surface 12.415" Surf. 2,981' 28 P-110 5.791" Surf. 92' 20� 28 N-80 5.791" _ 92' 6,655' 6 5/8" 24 P 110 Production 5.921" 6,655' 10,147' _ 28 P-110 5.791" 10,147' 10,866' TUBING DETAIL IliMil Ilia [ I 13-3/3" 4 2-7/8" 6.5 L-80 Production 2.441 Surf. 10,319' 2 2-7/8" EUE 8rd N/A 10,546' 10,629' JEWELRY DETAIL No. Depth ID Item 1 17.77' 2.441" 7"Tubing Hanger e 3 2 4,001' 2.441" 2-7/8"GLM SFO 1 Mandrel 3 7,103' 2.441" 2-7/8"GLM SFO-1 Mandrel 4 9,080' 2.441" 2-7/8"GLM SF0-1 Mandrel e a k, 5 10,255' 2.441" 2-7/8"GLM SFO-1 Mandrel w/1"orifice 6 10,298' 2.313" 2-7/8" x 6-5/8"T-2 On/Off tool 7 10,299' 2.375" 6-5/8"24-32"ASi-X Ret Packer-Carbide s 5 8 10,316' 2.313" 2-7/8"EUE"X"Landing Nipple 9 10,320' 2.441" 2-7/8"EUE WLEG 8/: 10 10,409' - Brown"CC"Safety Joint-Btm half 9 it 10,410' - Otis"XA"Sleeve 12 10,414' - Brown HS-16-1 Packer =H-1 le 367 13 10,420' Otis"S"Nipple 14 10,426' - Baker Blast Joint si IM i i 15 10,435' - Brown"CC"Safety Joint 12 3 16 10,436' - Otis"XA"Sleeve 0114 -H-2 17 10,439' - Brown HS-16-1 Packer ,.15 18 10,447' - Otis"S"Nipple w • 19 10,449' - Baker Blast Joints-88.88' 1'„1.III 1110M14 17 1820 10,546' Brown"CC"Safety Joint Cut tubing 1s -H-3,4 21 10,547' - Otis"XA"Sleeve @ 10,477' w/2-11/16" 22 10,550' - Baker FH Packer RTC 23 10,557' - Otis"5"Nipple =H-5 24 10,565' - Baker Blast Joint Slickline fish . „y 1, 25 10,597' - Otis"XA"Nipple @ 10,500'on MS26 10,601' Stop Sub _ 4/10/13 20 ►��, O.= 22 27 10,602' - Model"D"Packer 23 28 10,608' - Camco"D"Nipple 29 10,609' - Baker Blast Joint 30 10,629' - Mule Shoe 24 -UH-8 PERFORATION DATA 26 m 25 ►�� gk ►M 27 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft Comments 28N 29 er _LH-8 10,369' 10,369' 10,369' 10,369' 1' 5-1/2"Jet Holes 300 H-1 10,372' 10,402' 10,372' 10,402' 30' 3-3/8"HC Guns %i. 10,372' 10,411' 10,372' 10,411' 35' 4-1/2"Jet Holes H-2 10,422' 10,436' 10,422' 10,436' 14' 2-1/2"Jet Holes -' . . `' H-3,4 10,450' 10,478' 10,450' 10,478' 28' 2-1/2"Jet Holes +�. s, S_felts H-5 10,493' 10,535' 10,493' 10,535' 42' 2-1/2"Jet Holes 3 '- .y 10,566' 10,594' 10,566' 10,594' 28' 2-1/2"Jet Holes 6-5/$/ ' '^ '' UH-8 10,566' 10,601' 10,566' 10,601' 35' 4-1/2"Jet Holes TD=10,870'(MD)/10,870'(TVD) 10,605' 10,633' 10,605' 10,633' 28' 4-1/2"Jet Holes PBTD=10,640'(MD)/10,640'(TVD) LH-8 10,608' _ 10,628' 10,608' 10,628' 20' 2-1/2"Jet Holes Isolated 10,642' 10,660' 10,642' 10,660' 18' N/A 10,669' 10,670' 10,669' 10,670' 1' N/A Updated by DMA 05/20/13 Soldotna Creek Unit Well SCU 14-34 ..11 PROPOSED SCHEMATIC Proposed PlugbackPTD: 160-038 Hikor,,Alaska.Ulf: API: 50-133-10170-00 CASING DETAIL Size Wt Grade Type ID Top Btm. RKB to Hanger=17.77' 20" Structural Surf. 28' 13-3/8" 54.5 J-55 Surface 12.415" Surf. 2,981' 28 P-110 5.791" Surf. 92' 20' 28 N-80 Production 5.791" 92' 6,655' 6-5/8" 24 P-110 5.921" 6,655' 10,147' 28 P-110 5.791" 10,147' 10,866' TUBING DETAIL 13-3/8" 2-7/8" EUE 8rd N/A 10,546' 10,629' JEWELRY DETAIL No. Depth ID Item it 1 9,400' - Bridge Plug(set for whipstock) fie' 2 10,320' - Bridge Plug(capped w/35'cement) 3 10,409' - Brown"CC"Safety Joint-Btm half 4 10,410' - Otis"XA"Sleeve 5 10,414' - Brown HS-16-1 Packer 1 1L/00 'tel) 6 10,420' - Otis"S"Nipple 7 10,426' - Baker Blast Joint 8 10,435' - Brown"CC"Safety Joint 9 10,436' - Otis"XA"Sleeve ,y x' ******;°. 10 10,439' - Brown HS-16-1 Packer 2 I b3Lb I'^ 11 10,447' - Otis"S"Nipple 12 10,449' - Baker Blast Joints-88.88' H-1 13 _ 10,546' - Brown"CC"Safety Joint 14 10,547' - Otis"XA"Sleeve 3 �� 15 10,550' - Baker FH Packer 'x-44 AM 0-_-_-045 16 10,557' - Otis"S"Nipple 7 =H-2 17 10,565' - Baker Blast Joint 8 18 10,597' - Otis"XA"Nipple A fl T. Ill ' ® 10 19 10,601' - Stop Sub 11 20 10,602' Model"D"Packer Cut tubing 12 =H-3,4 21 10,608' - Camco"D"Nipple @ 10,477' 11 w/2-11/16" -- 22 10,609' - Baker Blast Joint RTC 23 10,629' - Mule Shoe =H-5 Slickline fish @ 10,500'on 1111 4/10/13 13 Iii 16 17 =UH-8 19 PERFORATION DATA X111:18 20 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft Comments 21 1C* 2 10,369' 10,369' 10,369' 10,369' 1' 5-1/2"Jet Holes =LH-8 23 H-1 10,372' 10,402' 10,372' 10,402' 30' 3-3/8"HC Guns . . 10,372' 10,411' 10,372' 10,411' 35' 4-1/2"Jet Holes le.` 't F- ,, H-2 10,422' 10,436' 10,422' 10,436' 14' 2-1/2"Jet Holes r.,,,` ., N°' C ,' H-3,4 10,450' 10,478' 10,450' 10,478' 28' 2-1/2"Jet Holes tib: " ' H-5 10,493' 10,535' 10,493' 10,535' 42' 2-1/2"Jet Holes A... s $ '1 10,566' 10,594' 10,566' 10,594' 28' 2-1/2"Jet Holes * 6-s/8" ' f UH-8 10,566' _ 10,601' 10,566' 10,601' _ 35' 4-1/2"Jet Holes TD= 10,870'(MD)/10,870'(TVD) 10,605' 10,633' 10,605' 10,633' 28' 4-1/2"Jet Holes PBTD=10,640'(MD)/10,640'(TVD) LH-8 10,608' 10,628' 10,608' 10,628' 20' 2-1/2"Jet Holes Isolated 10,642' 10,660' 10,642' 10,660' 18' N/A 10,669' 10,670' 10,669' 10,670' 1' N/A Downhole Proposed Updated by STP 04/12/14 i F •. Aurora Well Service 3000#BOP Stack L.0'__J Rig Floor I 6'5'n I. 11" Shaffer 3K J ,(--1 1 1 III 1l 1 -1J 11" Shaffer 3K PIPE RAMS MIMI __ 11" Shaffer 3K BLIND RAMS • Choke Line " Kill Line 11'1" —� /•! _ i• 1 moi 11" 3K=MI : �: ) l KILLSPOOL im L <:> ;; [____1 A i IB i 3,00,0 C [Di D S A .0-... .r. es Win .r. Lir. 14'1" ...Starting Head _ i 11000# - , `u ,u" A -3'`/1S" 5KHCR valve i B -3 1/16" 5K Gate valve :.1 C -3 1116" 5K Gate valve Varies ► 1 D -3 1116 5K HCR valve ® E-3"200#Ball Valve STATE OF ALASKA AL/ OIL AND GAS CONSERVATION COMM ION ' 2 i1 2:31:i REPORT OF SUNDRY WELL OPERATIONS A C 1 1. Operations Abandon [ Repair Well 11 Plug Perforations U • Perforate U • Other U Re- perforate & Performed: P Pull Tubing Stimulate - Frac Waiver Time Extension ❑ new completion Alter Casing ❑ u g � ❑ ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development IO • Exploratory ❑ 160 -038 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 50- 133 - 10170 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028990 Soldotna Creek Unit (SCU) 14 -34 ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): , N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 10,870 feet • Plugs measured N/A feet true vertical 10,870 feet Junk measured 10,500' feet Effective Depth measured 10,640 feet Packer measured See Schematic feet true vertical 10,640 feet true vertical See schematic feet Casing Length Size MD TVD Burst Collapse Structural 28' 20" 28' 28' Conductor 92' 6 -5/8" 92' 92' Surface 2,981' 13 -3/8" 2,981' 2,981' 2,730 psi 1,130 psi Intermediate 6,563' 6 -5/8" 6,655' 6,655' 8,810 psi 8,170 psi Production 3,492' 6 -5/8" 10,147' 10,147' 10,230 psi 6,730 psi Liner 719' 6 -5/8" 10,866' 10,866' 12,120 psi 10,140 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic scow MAY 3 0 2-0 13 Tubing (size, grade, measured and true vertical depth) 2 -7/8" � 6.5# / L -80 10,629' MD 10,629' TVD 5 packers 10,299'; 10,414' 10,439'; 10,299'; 10,414' 10,439'; Packers and SSSV (type, measured and true vertical depth) See Attached Schematic 10,550'; 10,602' 10,550'; 10,602' N /A; N/A MD TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 32 4 58 1200 380 Subsequent to operation: 29 19 63 910 300 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development El - Service ❑ Stratigraphic Daily Report of Well Operations X 16. Well Status after work: Oil 0 • Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -166 Contact Chad Helgeson Email chelgesonahilcoro.com Printed Name Chad Helgeson Title Operations Manager Signature 67/4/7/ Phone 907 - 777-8405 Date j G1 1 74 - SL Form 10 -404 Revised 10/2012 -?- � RBDMS MAY 21 2013 Submit Original Only • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 14 -34 50- 133 - 101700 -00 160 -038 4/2/13 4/27/13 Daily Operations: 04/02/2013 - Tuesday MIRU Pollard SLU, RIH W/ 1.75" Pump bailer, tagged bottom @ 10,438', worked tool and POOH, Bailer empty. RBIH W/ 2.0" LIB, tagged obstruction @ 10,438', POOH. Bailer showed signs of fishing neck laying on side of tbg. RBIH W/ 1.25" Pulling Tool to 10,438', Attempted to latch fish, fish would not latch, POOH. Marks on outside of tool. RBIH W/ same tools with knuckle above tool, attempted to latch, could not latch, POOH. RBIH W/ 2.25" DD Bailer, attempted to beat on FN to try and center up in tbg, sit down and pulled up, over pulled 450 Ibs, attempted several times and POOH, bailer had metal marks on face. Secured well and SDFN. 04/03/2013 - Wednesday Slickline Operations to remove obstruction down past 3rd packer. 04/09/2013 - Tuesday MIRU Pollard SLU, pressure test BOPs, RIH W/ 1.75" X 2.25" Hydro static Bailer, can't get tools to fall past 7,968'. POOH. RIH W/ 2.0" pump bailer, tag obstruction @ 10,462', Worked tool, POOH. Recovered 1/2 bailer body full of sand. RIH W/ 2.0" pump bailer, tag obstruction @ 10,462', Worked tool, POOH. Recovered 1/2 bailer body full of sand. RIH W/ 1.75" pump bailer, tag obstruction @ 10,462', Worked tool, POOH. Recovered 1/2 bailer body full of sand. RIH W/ 1.75" pump bailer, tag obstruction @ 10,462', Worked tool, POOH. Recovered 1/4 bailer body full of sand. RIH W/ 1.75" pump bailer, tag obstruction @ 10,462', Worked tool, POOH. Recovered same. RIH W/ 2.25" Hydrostatic bailer, tag obstruction @ 10,462', Worked tool, POOH. Recovered 1/4 bailer body full of sand. 04/10/2013- Wednesday RIH W/ 2.12" centralizer, 3' stem, 2.25" Centralizer, 1.95" LIB, tagged obstruction @ 10,462', POOH. Fishing neck mark in center of LIB. RIH W/ 2.12" centralizer, 3' stem, 2.25" Centralizer, 2" RB w/ 2.05" Bell guide, tagged obstruction @ 10,468', W /T, POOH. Had small over pull before coming free, No fish recovered. RBIH W/ same tools, attempted to latch again, no success. RIH W/ 3" Prong pulling tool, tagged obstruction @ 10,468', W /T, POOH. Recovered no fish. RIH W/ 2.25" Hydrostatic bailer (4 runs), tag obstruction @ 10,468', W /T, POOH. Recovered bailer body full of sand. RIH W/ 2.25" RIH W/ 2.25" LIB, tagged obstruction @ 10,463', W /T, POOH. Had marks of sand., RIH W/ 2.25" Drive down bailer, tag obstruction @ 10,463', W /T, POOH. Recovered bailer body full of sand. 04/11/2013 - Thursday RIH W/ 2.25" Drive down bailer (10 runs), tag obstruction @ 10,500', W /T, POOH. Recovered bailer body empty of sand. RIH W/ 2.25" LIB, tagged obstruction @ 10,500', W /T, POOH. Had wire marks on face of LIB. We are past 3rd packer, made decision to RD SL Unit and move E -Line Unit in to cut tbg for fishing job. MIRU Pollard E -Line Unit and mast truck, test BOPs, RIH W/ CCL and 2.25" jet cutter, could not get down to desired depth, POOH, MU 1- 11/16" Radial Torch cutter and RIH w /cutter and CCL, made pass across desired depth and made first cut below 3rd packer @ 10,447', in pup below 3rd packer, MU 1- 11/16" Radial Torch cutter and RIH w/ 2nd cutter and CCL, made pass across desired depth and made 2nd cut below 1st packer @ 10,357', ,in joint below 1st packer, leaving 12' of joint of tbg sticking up. MU 1- 11/16" Radial Torch cutter and RIH w/ 3rd cutter and CCL, made pass across desired depth and made 3rd cut above 1st packer @ 10,324', in joint above 1st packer, leaving 10' of joint of tbg sticking up on top of packer. POOH, RDMO Pollard E -Line Unit and Equipment. 04/12/2013- Friday • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 14 -34 50- 133 - 101700 -00 160 -038 4/2/13 4/27/13 Daily Operations: MIRU Williams 405 Workover Rig and associated equipment, installed winterization kit, Well had 1,000 psi shut in pressure on Tbg and Casing, Blew well down to gas buster, hooked up pump and pitts, and gas detection system. 04/13/2013- Saturday Finished rigging up equipment, blew well down to gas buster, pumped 180 Bbls of produced saltwater down tbg and 50 Bbls down annulus, well went on vacuum during process. Installed BPV in tbg hanger, ND wellhead and NU BOP's, Hooked up accum and lines from manifolds. Started testing BOP's withAOGCC repBob Noble, tested BOP's to 250psi low/ 3000psi high, tested annular to 250psi low /1500psi high, tested accumulator and nitrogen bottles, had one flange leak on first low pressure test and fixed, no further failures throughout the rest of the test, AOGCC rep very pleased with test. Removed BPV, installed landing joint with TIW valve in closed position and secured well, SDFN. 04/14/2013- Sunday MI set up pipe racks and LD machine, unloaded 327 joints of 2 -7/8" P -110 WS on north side of PU machine, set 2nd set of racks on south side of machine, steam heated the hanger in the tbg head, completed steaming and backed lock pins out of tbg head, PU to 70,000# before hanger popped free, string is weighing 64,000 #, removed tbg hanger and started LD tbg. LD approx. 7,500' and all 7 gas lift mandrels, well was still on vac this morning. 04/15/2013- Monday SICP -450 psi, Blew well down to gas buster, pumped 50 Bbls of produced water down annulus, well went on vacuum. Continued TOH LD 2 -7/8" Production string. LD total of 10,322' of tbg, MU 4.75" Overshot, loaded with 2 -7/8" Basket grapple W /mill control, 4.75" Bumper jar, 4.75" Oil jar, 6 4 -3/4" drill collars, accelerator jars and 193 joints of 2 -7/8" PH -6 WS, EOT @ 7,563'. Secured well, SDFN. 04/16/2013- Tuesday SICP- 270, Continued TIH W/ 2 -7/8" workstring and overshot, tagged top of fish @ 10,324', engage grapple and PU 43k lbs over string weight, stroked jars 4 times and packer started moving up hole, it had about 28k lbs over string weight of pull, after 42 stands the weight went away, SOOH W/ 100 stands of 2 -7/8" WS. Secured well, SDFN. 04/17/2013 - Wednesday SICP- 180psi, bled well down to gas buster, continued SOH W/ 2 -7/8" WS. LD cut joint, FH Packer, and bottom cut joint, total legnth of 37'. MU new 5- 9/16" Overshot loaded with 2 -7/8" basket grapple, (right hand wickers) left hand release. TIH on 2- 7/8" WS, Tagged top of fish @ 10,359'. MU Power swivel, engaged grapple, and made sure fish was caught. Attempted to straight pull packers free, over pulling 40K lbs, no progress, attempted to release packer by rotating tbg to the right. First tried 14 rds to right before torquing up, worked up and down, no movement. 14 rounds to right, worked up and down, saw tbg pop a little, worked up and would not go all the way back down. Put 19 rds, worked up and down with no movement. Put 18 rds, worked up /down same results. Put 12 rds, worked up /down, saw pop again, worked up and wouldn't go down a little more. Put 30 rds, worked up /down, tbg jumped a little and began dragging up hole, pulling about 10k lbs over string weight. Pulled over for 3', hung power swivel back in the derek, pulled 1 joint out while dragging 10k lbs over and LD. Lost drag on next joint. SOOH W/ 2 -7/8" WS, SOOH W/ total of 60 stands, secured well, SDFN. 04/18/2013 - Thursday • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 14 -34 50- 133 - 101700 -00 160 -038 4/2/13 4/27/13 Daily Operations: SICP- 60psi, bled well down to gas buster, continued SOH W/ 2 -7/8" WS. LD 1/2 joint of tbg and the CC safety joint above the packer. Made decision to run back in with new grapple in overshot. TIH to top of fish, engaged grapple and attempted to pull and rotate packers free, tried for 4 hrs, made decision to leave latched up and bring E -line unit in and try and string shot the packer and CC safety joint. 04/19/2013- Friday SICP- 50psi, MIRU Pollard E -Line unit. MU 5 strands of primer cord. RIH W /CCL & string shot. RIH, sat down @ 10,437'. Logged up across tools and packer, dropped down to put 5' OD string shot across packer, set string shot off and POOH W /E- Line. MU Power swivel & attempted to release packer, packer would not release, attempted to jar on packer again & jarred grapple free. Decided to come out, LD WS & grapple. RD power swivel, and started TOH, LD 2 -7/8" WS, LD total of 175 joints of WS, secured well, SDFN. 04/20/2013- Saturday Continue LD 2 -7/8" WS. LD fishing tool, BHA and overshot. MU test Plug on Test joint, tested BOPs. Tested BOPs to 250 psi low and 3,000 psi high, tested annular to 250 low and 1,500 high (witnessed by Bob Noble, AOGCC). Recalibrated gas detection system. Charted all for 5 mins. 04/21/2013- Sunday MIRU Pollard E -Line unit. RIH W/ GR /CCL logged from 10,402' up to 9,000', sent to office for perforating depths. RBIH W/ GR /CCL, logged from 10,402' up to 3,000'. MU 30' perforating gun on CCL. RIH, tagged bottom @ 10,402' and logged up to 10,000'. Dropped back down to desired depth and perforated from 10,372'- 10,402'. POOH, ensured all shots fired. RDMO Pollard E -Line unit and equipment. 04/22/2013- Monday MU wireline Re -entry guide, SN, packer /on -off tool, 1 jt of 2 -7/8" 8RD and 1st Gas Lift mandrel, TIH W/ 2 -7/8" 8RD tbg installing mandrels per design. TIH W/ total of 161 jts of 2 -7/8" 8RD production tbg. Secured well, SDFN. 04/23/2013- Tuesday Continued TIH W/ 2 -7/8" Production tubing and mandrels per design, total of 217 joints of 2 -7/8" and 4 Gas lift mandrels. MU Tbg hanger, attempted to land production packer several times, could not get packer to set, packer may have released from on /off tool, MIRU Pollard slickline unit. RIH W/ 2.25" GR, tagged RHCP plug @ 10,319', proving packer is still on production string. 04/24/2013 - Wednesday SOOH W/ 2 -7/8" Production string, found packer had released from on /off tool, MIRU Pomreanke Braided Line Unit, RIH W/ shear down GS fishing tool, tagged top of packer at 10,300', latched packer and attempted to POOH, packer appeared to be set, stroked tools at 4,000 #'s multiple times, could not get packer to move. Sheared free GS tool and POOH, RDMO Braided Line Unit. Changed seals in On /Off tool and started TBIH W/ Production Tbg, TIH W/ total of 103 stands, Secured well, SDFN. 04/25/2013 - Thursday • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 14 -34 50- 133 - 101700 -00 160 -038 4/2/13 4/27/13 Daily Operations: Continued TIH to top of packer, sat down and J'd On /Off tool back onto packer, released packer, attempted to move up to desired depth and re -set packer, could not get packer to set at 10,295'. Added a 6 ft pup and set packer @ 10,301'. Landed tbg hanger with 8k Ibs compression. Tested Tbg to 3,000 psi and charted for 30 mins. Tested casing to 2,500 psi and charted for 30 mins. Installed BPV, ND bop's and NU Welhead. Started Rigging down Workover rig and associated equipment. 04/26/2013- Friday Finished rigging down WOR and all equipment, move rig and equipment to next location, attempted to pull BPV, BPV had migrated gas below it, MIRU Cameron Lubricator, Pulled BPV and turned well over to production. MIRU Pollard Slickline Unit, RIH W/ 2" JDC to 10,333', latched prong in plug and jarred free, POOH. RBIH W/ 2.5" GS to 10,338'. Latched plug body and jarred free, POOH with RHCP body, RDMO Pollard Slickline unit. 04/27/2013- Saturday Turned over well to production. Soldotna Creek Unit • n • Well SCU 14 -34 SCHEMATIC Last Completed: 08/01/1973 PTD: 160 -038 Hilrora Alaska, l.i.c API: 50- 133 - 10170 -00 CASING DETAIL Size Wt Grade Type ID Top Btm. RKB to Hanger = 17.77' 20" Structural Surf. 28' 1 13 - 3/8" 54.5 J - Surface 12.415" Surf. 2,981' 28 P -110 5 .791 " Surf. 92' 20 J 28 N -80 5.791" 92' 6,655' 6 -5/8" Production 24 P -110 5.921" 6,655' 10,147' 28 P -110 5.791" 10,147' 10, TUBING DETAIL 13 -3 /S" 2 -7/8" 6.5 L -80 Production 2.441 Surf. 10,319' 2 2 -7/8" EUE 8rd N/A 10,546' 10,629' JEWELRY DETAIL No. Depth ID Item 1 17.77' 2.441" 7" Tubing Hanger 3 2 4,001' 2.441" 2 -7/8" GLM SFO -1 Mandrel 3 7,103' 2.441" 2 -7/8" GLM SFO -1 Mandrel 4 9,080' 2.441" 2 - 7/8" GLM SFO -1 Mandrel a 5 10,255' 2.441" 2 - 7/8" GLM SFO - Mandrel w /1" orifice 6 10,298' 2.313" 2 -7/8" x 6 -5/8" T -2 On /Off tool 7 10,299' 2.375" 6 -5/8" 24 -32" AS1 -X Ret Packer - Carbide 5 8 10,316' 2.313 2 -7/8" EUE "X" Landing Nipple • - • 6 9 10,320' 2.441" 2 - 7/8" EUE WLEG 8 7 10 10,409' - Brown "CC" Safety Joint - Btm half 9 11 10,410' - Otis "XA" Sleeve 12 10,414' - Brown HS -16 -1 Packer H -1 js 13 10,420' - Otis "S" Nipple �" 14 10,426' - Baker Blast Joint 10 ■_•� _ 15 10,435' - Brown "CC" Safety Joint IIPM 11.11.* I•�ill 12 10,436' Otis "XA" Sleeve 13 � 14 H_2 17 10,439' - Brown HS -16 -1 Packer 15 18 10,447 - Otis "S" Nipple =' s` 19 10,449' - Baker Blast Joints - 88.88' ►�. Am / �I 17 20 10,546' - Brown "CC" Safety Joint Cut tubing H -3 @ 10,477' 21 10,547' Otis "XA" Sleeve w/ 2- 11/16" 22 10,550' - Baker FH Packer RTC 23 10,557' - Otis "5" Nipple H -5 24 10,565' - Baker Blast Joint Slickline fish ,y: ,t , 4 25 10,597' - Otis "XA" Nipple @ 10,500' on 4/10/13 26 10,601' - Stop Sub A 1111"7"---..--'411 22 27 10,602' - Model "D" Packer gist 28 10,608' Camco "D" Nipple 29 10,609' Baker Blast Joint 30 10,629' - Mule Shoe UH -8 PERFORATION DATA 10 - 1"',4 ♦g �•, 27 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Ft Comments 28 x 29 LH $ 10,369' 10,369' 10,369' 10,369' 1' 5 -1/2" Jet Holes 30 '" H -1 10,372' 10,402' 10,372' 10,402' 30' 3 -3/8" HC Guns 10,372' 10,411' 10,372' 10,411' 35' 4 -1/2" Jet Holes �x�`t. t3 !ice ✓, ".? H -2 10,422' 10,436' 10,422' 10,436' 14' 2 -1/2" Jet Holes P • ` i.' & H -3, 4 10,450' 10,478' 10,450' 10,478' 28' 2 -1/2" Jet Holes - " H -5 10,493' 10,535' 10,493' 10,535' 42' 2 -1/2" Jet Holes + •k +! 10,566' 10,594' 10,566' 10,594' 28' 2 -1/2" Jet Holes ± UH -8 10,566' 10,601' 10,566' 10,601' 35' 4 -1/2" Jet Holes TD = 10,870'(MD) / 10,870' (TVD) 10,605' 10,633' 10,605' 10,633' 28' 4 -1/2" Jet Holes PBTD = 10,640'(MD) / 10,640' (TVD) LH-8 10,608' 10,628' 10,608' 10,628' 20' 2 -1/2" Jet Holes Isolated 10,642' 10,660' 10,642' 10,660' 18' N/A 10,669' 10,670' 10,669' 10,670' 1' N/A Updated by DMA 05/20/13 OF Ty • • % %yam THE STATE Alaska 011 and Gas KA - := fALAS Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue 9 Anchora e, Alaska 99501 -3572 ALAS' Main: 907.279.1433 APR grt �r� Fax: 907.276.7542 SCANNED 111 J Chad Helgeson Operations Manager Hilcorp Alaska, LLC (60 3 800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 14 -34 Sundry Number: 313 -166 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. ` oerster Chair DATED thisey of April, 2013. Encl. • 443 ... ;p7s 4P i3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . APPLICATION FOR SUNDRY APPROVALS :\ Is ‘,J ti '' ,r i 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair WeC Change Approved Program ❑ Suspend ❑ Plug Perforations El • Perforate 0 • Pull Tubing • Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter Casing] Other Re- Perforate & new completion 0 2. Operator Name: r. Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number Exploratory ❑ Development El 160 -038 • 3. Add 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number Anchorage, Alaska 99503 50-133-10170-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123A Soldotna Creek Unit (SCU) 14-34 • Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA02899p` Swanson River Field / Hemlock Oil , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,870 10,870 • 10,640 10,640 10434 N/A Casing Length Size MD TVD Burst Collapse Structural 28' 20" 18' 18' Conductor 92' 6 -5/8" 92' 92' Surface 2,981' 13 -3/8" 2,981' 2981' 2,730 psi 1,130 psi Intermediate 6,563' 6 -5/8" 6,655' 6,655 8,810 psi 8,170 psi Production 3,492' 6 -5/8" 10,147' 10,147' 10,230 psi 6,730 psi Liner 719 6 -5/8" 10,866' 10,866' 12,120 psi 10,140 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2 -7/8" 6.5# / L-80 10,62g Packers and SSSV Type: 5 packers, see attached schematic Packers and SSSV MD (t) and TVD (ft): 10,337' MD- 10,337' TVD 10,414' MD - 10,414' TVD; 10,439'MD - 10,439' TVD; 10,550'MD - 10,550' TVD; N/A 12. Attachments: Description of Proposal Ig 13. Well Class after proposed work: - Detailed Operations Program n BOP Sketch n Exploratory ❑ Stratigraphi9 Development [✓1 Service [] 14. Estimated Date for 15. Well Status after proposed work: 04/10/13 Commencing Operations: Oil el • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Phone: 907- 777 -8405 Email chelgesonahilcorp.com Printed Name Chad Helgeson Title Operations Manager 674Org . Signature G,% Phone 907 - 777 -8405 Date /3k3. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3/ 3 — /(6.4 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 30 a.) (5: l� S 7` ek4 Ren MS APR 1 0 2013 i Spacing Exception Required? Yes ❑ No ® Subsequent Form Required: / 0 _ c l APPROVED BY Approved by: �;T "" / � COMMISSIONER THE COMMISSION Date: -1 - (3 t^ A 1' Submit Form and t o is2)� Approved application is valid for 12 months from the d of approval. � men tsjn irate 1 1 � � � : ' v f�/ /.." • • s. Well Prognosis Well: SCU 14 -34 Hilcorp Alaska, LLC Date: 4/3/2013 Well Name: SCU 14 -34 API Number: 50- 133 - 10170 -00 Current Status: Oil Producer Leg: N/A Estimated Start Date: April 10th, 2013 Rig: Williams 405 Reg. Approval Req'd: 403 Date Reg. Approval Rec'd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 160 -038 First CaII Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8378 AFE Number: 1321103 Current Bottom Hole Pressure: — 2,200 psi @ 10,500' TVD Flowing tubing pressure @1,215 psi Maximum Expected BHP: — 2,200 psi @ 10,500' TVD Max. Allowable Surface Pressure: —0 psi (Working fluid (gradient of .442 psi /ft) will balance reservoir pressure at 5622 ft. TVD. Brief Well Summary SCU 14 -34 was drilled in October 1960 to a depth of 10,870'. The well was worked over in 1962 for gas lift • conversion and again in 1973 for hemlock zonal isolation. The casing scheme consists of a 13 -3/8" surface casing © 2891 and cemented to surface. A 10 -5/8" hole was drilled to 10,870' and a 6 -5/8" P -110 production • casing was run. Notes Regarding Wellbore Condition Well current well status is a producing oil well in the Hemlock H -1 with a plug in the s- nipple @ 10,421' OBJECTIVE OF WORKOVER Pull tubing and upper three packers to optimize production from the Hemlock 1 -5 interval and redesign an efficient gas lift completion. Work -Over Rig Procedure 1. MIRU a -line, pressure test Lubricator to 1,500 psi. 2. RU radial cutting torch, RIH and cut tubing at 10,357' (10 ft above blast joint), & 10' above XA sleeve at 10,34'. (If accessible 1 cut should be in the pup joint at approximately 10,543' {above the packer at 10,550' }) 3. RD E -line. 4. MIRU Williams pulling unit. 5. Rig up circulating manifold and bleed any pressure off tubing through same to working tank. 6. Install back pressure valve in tbg hanger. Note: If hanger profile is not test worthy, call out slick line with tubing stop /plug and set at 500'. 7. Set BPV in tubing hanger, ND tree, NU 11" BOPE and test to 250psi low /3,000psi high, annular to 250psi low /1,500psi high (hold each valve and test for 10 -min). Record accumulator pre- charge pressures. a. Notify AOGCC 24hrs in advance to witness test. b. Notify BLM 48 hrs in advance of BOP test. • • Well Prognosis Well: SCU 14 -34 Hilcorn Alaska, LLC Date: 4/3/2013 c. Ensure winterization package is installed for the weather conditions. (Crew will be working 12hr shifts and well will be secured nightly with TIW valves and BOPE.) 8. Release test pressure, pull tubing stop or BPV and install handling sub in hanger. 9. Back out tbg hanger hold down pins and pick up on hanger. 10. With hanger free POH with tubing and gas lift mandrels. LD tubing. 11. PU packer retrieval assembly (overshot, bumper sub, jars, drill collars) and 2 -7/8" PH -6 work string. 12. TIH and latch tubing stub, jar packer free. 13. POOH and LD packer. 14. RIH with left hand whicker overshot fishing assembly, latch 2 fish, release HS -16 packer with at least 12 turns to the right to equalize pressure and 28 additional turns to the right to release packer. a. There are 2ea HS -16 packers that are connected together with blast joints and CC Safety joints. (80 rotations minimum to release both packers.) b. CC Safety joint requires 8 turns to the right to release (may come free between packers). ,/ c. If CC Safety joint releases, RIH and pull 2 " HS -16 packer with same fishing assembly. d. If packers do not release, PU burn shoe and wash pipe, RIH and burn packers. 15. POOH, LD packer assemblies. 16. RU slickline, RIH and tag top of tubing stub at approx. 10,543' (if cut was made). a. If cut was not made, RU e-line and cut tubing at 10,543'. 17. PU 6 -5/8" gauge ring or 28# casing scraper and clean casing to 10,543'. V 18. RU E -line and RIH and set CIBP at 10,540' (as deep as possible) 19. RU Gyro and run survey from TD to surface to find inclination and azimuth data on well. 20. Perforate Hemlock (H -1 to H -5) intervals with deep penetration charges with 3 -3/8" OD carrier 6 • spf on 60 deg phase. a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie -in sheet will be provided in the field for exact perf intervals, based on the success of fish removal. Note: Record fluid levels and time of day for each RIH with E -line. 21. RDMO E -line unit. 22. RIH with packer and GLVs per design with new 2 -7/8" 8rd EUE L -80 tubing. Set packer at +/- 10,330'. Land tubing hanger with 4 -8K pounds max of compression on tubing. 23. Drop RHCP plug in well and test casing to 2,500 psi and tubing to 3,000 psi, chart for 30 min ea. 24. Set BPV, ND BOPs, NU Tree, test tree to 5,000 psi. 25. RDMO workover rig and equipment. 26. Turn well over to production. 27. NU piping and flowlines. 28. Gas lift well, unloading fluid from well to production. 29. RU slickline, PT lubricator to 2000 psi Hi 250 low. 30. RIH and pull RHCP prong and plug. 31. Start production, collect oil sample and send in for analysis. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic Z ,,; 1: 8. to t%) o k WCL1l .v u' • , ii :I: [DT,11.'41.4.2473: 4f JTS 2 • Ea Std TU8 , . �iw' 1.940.71' C AICO'MI K11f>jRZy Dq 1 '� -- 2 981 1 47 Jr5. 24' Z0; art TUBI?!0 1 • 3,4511.90' CJJCO Mt L 12.9 1414+7' 9 0 I 311 .ITS . 2j' Z* 2 Srd rUBDq 1181.' r 4,652-4' cico }M mean 12.99+ ea 27 JTS. 24' rs Std TDB s 5,503 .74' CAM) co 44 1�u}a y 1138.33 12.955 • 17 JTS, 2‘1 1LIZ Ord nano ^' - 6,0'39.90' C.}00 !M maw. 523.11 12.94' 1 12 J73. 2%' I= Est TUB= r 6,423.76' C A1�',0 � 3 LIM 12.94+ c. s 6,by.' C,t 2'6* LIZ Ord Tas 218.60 12.93 It 10 41' 1W JTS. 2A SUE Ord TUBDIQ 3666.30* • --1033,��gt + ;I ► _ -r 0 1= 01= 'L' alum 3.111 I I.sss vie Yu PA 2 3/4■ s 6%6 , 2!!f 6.70 K 1 ��' 1 I.,rr•ara. 1 Jr. 2 ME Bid TUBS 0 � "; ,�q 2 SAILS BLAST JTS. 3.680 0D 33.66' \ a • ' ""' +0A1O,23 ' O TIS 9S Sli71d1 xi' SLUTS 'CC' WITTT IT. 1.421 ' 6 ' ► 10,414.02' 3 Sty '.0. • . . �a•,• 10,419.961 BROW )3.16 -1 PAN= 24' s 6r', 28# 3.97+ 1 K.tS 11 I i I III.' 0lI3 •9• JI7?Z , Sysit3aa 14 1.53' Fr ^ 10 4.� ■ Una aI . 07. 3.688' CD 13.71' I 10,435.88' C � 1? SUITT JT , EC M10,43 OTII ' A' SIMI 1. •_• l► awl Ee..16 - 1 P z� 3c6#• 5. ' LA M I.s. PO! Jr. , 2aI 2 2a' H3, ' 10•447.22' OTIS •s' 11rPPia, r tip 1.$811 #3 x B BUST Jr. w :... 10.05' 1.4+s BL AS! JT. 20.31' PUP JT. 2 %6 13.106 BA= BLAST zr. N� ,s r�k i n +1. SAME BLAST J7. I 4.81► RIM BLAST a, 20.25+ al► s was "Pi" 2 0.33`. ` "-.10151•5•7" stag 'CC• PGP JT. 231' 8.09' 77.1 - 10 , 546. 5' �,n 'L. Lima V ' 1.011' sot M 8; -- 10 , 556 .601 B8& 7X P 2; x &V ,281 LIP S .1J NNS OTIS •S• BIPP1Z, Positing' /4 1.51° 6.51 ' POP Jr. 2;' 6 H $ " 2 MUD 31.47 ITS. 6.32' 1 ���q�18c 30.32' .r »� CM '1.1* S E . 2 � i • 3 ' 10 632 .0 5 )C 1L�D 6 PiCaR 2%' x • b.7.1 • . 1000+ v Na 1 I 1 Kress s.35 CV= • • 111PM 2 • ssAS. iu. 3.230" CD 6.35' 1 - i . 165 21 BLQ,R J?. CQr 4s CL 3017.062• CO t9.90; • Ii TOP of PLUG • 10•640' . . I..+. w s . :'~ ° S C U 14 - 3 4 • z i 10,866' T.D, 10,870. CASING & TUBING DETAIL SECTION 34 T. 8 N.,R. 9 VI. { ° STAHOARD OIL. COMPANY OR CAt,JfORIY 1 WESTIN OPU ATIONA INC. . ° - NIL .. 14 • • Soldotna Creek Unit Proposed Schematic Well No.: 14 -34 Mean) Alaska, LLC Last Completed 8/1/1973 CASING DETAIL RKB to Hanger = 17.77' SIZE WT GRADE Type ID TOP BTM. 20 " Structural Surf. 28' I 1 13-3/8" 54.5 J-55 Surface 12.415" Surf. 2,981' d 28 P -110 5.7 Surf. 92' 28 N-80 5.791" 92' 6,655' 6 5/8" 24 P-110 Production 5 6,655' 10,147' 2 28 P 110 5.791" 10,147' 10,866' TUBING DETAIL 3 2 -7/8" 6.5 L -80 Production 2.441 Surf. 10,319' 2 - 7/8" EUE 8rd N/A 10,546' 10,629' •. 4 JEWELRY DETAIL NO. Depth Item e 1 ±17' Tubing Hangar MI s 2 ±2,600' GLM MI 3 ±4,600' GLM 7 4 ±6,300' GLM 8 5 ±7,600' GLM 6 ±8,600' GLM 9 7 ±9,400' GLM 10 8 ±10,000' GLM 9 ±10,300' GLM 11 10 ±10,309' Mechanical packer w/ H -1 on /off tool, x- profile 11 ±10,319' x- nipple & WL Entry Guide Mule Shoe 12 ±10,540' CIBP 13 10,546' Brown "CC" Safety Joint = H -2 14 10,547' Otis "XA" Sleeve 15 10,550' Baker FH Packer 16 10,557' Otis "5" Nipple H -3, 4 17 10,565' Baker Blast Joint 18 10,597' Otis "XA" Nipple 19 10,601' Stop Sub 20 10,602' Model "D" Packer H -5 21 10,608' Camco "D" Nipple 12 C 1 BP 21 10,609' Baker Blast Joint 13 22 10,629' mule Shoe ®EN 14 1111MIIIMI►M 15 PERFORATION DATA 16 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Comments 10,369 10,369 10,369 10,369 1' 5 -1/2" Jet Holes 17 =UH -8 H -1 ±10,372' ±10,411' ±10,372' ±10,411' 39' 3 -3/8" HC Guns 10,372' 10,411' 10,377' 10,412' 35' 4 -1/2" Jet Holes 19 :.. 18 ±10,418' ±10,437' ±10,420' ±10,437' 19' 3 -3/8" HC Guns • .t 111:1"Z 20 H-2 2 10,422' 10,436' 10,422' 10,436' 14' 2 -1/2" Jet Holes 21 IIMIEM 22 LH - ±10,449' ±10,479' ±10,449' ±10,479' 30' 3 -3/8" HC Guns � - H -3 4 2s 10,450' 10,478' 10,450' 10,478' 28' 2 -1/2" Jet Holes • , ±10,492' ±10,526' ±10,492' ±10,526' 34' 3 -3/8" HC Guns • e: r H-5 , 10,493' 10,535' 10,493' 10,535' 42' 2 -1/2" Jet Holes c r i7 �" „' 10,566' 10,594' 10,566' 10,594' 28' 2 -1/2" Jet Holes e, ° ` of , 10t • �, ,kr v UH 8 10,566' 10,601' 10,566' 10,601' 35' 4 -1/2" Jet Holes "4.' i ,`i rr .._ 10,605' 10,633' 10,605' 10,633' 28' 4 -1/2" Jet Holes LH -8 TD = 10,870'(MD)/ 10,870' ( TVD) 10,608' 10,628' 10,608' 10,628' 20' 2 -1/2" Jet Holes PBTD = 10,640'(MD)/ 10,640' (TVD) 10,642' 10,660' 10,642' 10,660' 18' N/A Isolated 10,669' 10,670' 10,669' 10,670' 1' N/A REVISED by CAH:4 /3/13 • v • Soldfna Creek Unit II Well SCU 14 -34 PTD: 160 -038 API: 50- 133 - 10170 -00 Ilik... %t,.l,.. um 04/03/13 Swanson River Williams BOP 2013 • •■ Iil,l I ilil•lilml Mil lit --- -..... 3.46' Shaffer 11" 5M I IMP III ifi III III III 0 Y - Shaffer LWS — : r: 0 ! 2.75' 11" 5M r . 0 1: , MM 2 1/16 10M Choke and Kill * ��' Valves Iil III lit 111 III 0 2.00' _- 741 illif . Ili lit III Ill ill s — E V i NT. • ill 4 I I ri. . ! ' 1 . kik P IN : 4 A i =Ili 1 . f E.• • • o it . a ...•- iv 1 Form ~3160- 5 UNITED STA, (JUNE 1990) DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for Proposals to drill or to deepen or reentry to a different reservoir. Use 'APPMCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPL/CA TE 1. Type of Well Oil Gas ~ Well [~ Well [] Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- 14 Wells Soldotna Creek Unit -- 7 Wells FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. 6. If Indian, Allottee or Tribe Name 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Po<fi, or Explorato~ Area Swanson River Field 11. County or Parish, State Kenai, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent ['-] Subsequent Report Final Abandonment [-] Abandonment r-] Change of Plans r-] Recompleticn [--] New Construction 0 Plugging Back [--] Non-Routine Fracturing 0 Casing Repair 0 Water Shut-Off 0 Altering Casing 0 Conversion to Injection ~ Other Temporarily Abandon 0 Dispose Water (Note: Report results of multiple co~mplefion on Well Completion or Recompletion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any I~oposed work. If well is directionally (killed, give subsudace locations and measured and lzue vertical del:~tm for all markers and zone pertinent to Ibis work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1,1996 to March 31,1997: Soldotna Creek Unit (o~' j¢j SCU 21-8 31~ SCU 34-9 ~-) ~SRU 212-10 {0!" ~SCU34-8 /~SCU41B-9 (,¢~'~RU12-15 ~;Z- I scu 243-81 [.~cu 14-34 OO-! ~SRU 14-15 41A-15 ~ i-~SCU 13-9 L~, ~y.~_~ SRU o~ O - I 0 7 · J SBU 23- 22 * High GOR well that may be produced intermittently Swanson River Unit sRu 2~-27 SRU 331-27 SRU 34- 28 SRU 43-28 SRU 21-33WD SRU 14. i hereby certify th~ the foregoing is tmeand correct. s~on~ t ...... /./// - (This space for Federal and'~ffice use) Dennis L. Groboske ~-~, Petroleum Engineer Date 3/29/96 Apgroved by T'~le Dam C<mcabns of approval, if any: Title 18 U.S.C. Section 1001, makes it a c~ime for any pemon knowingly and willfully to make to any department or agency of the United Slates any false, fictitious or I~audulent statements or rep~esenlalJons as to any matter within its juris(r~clJon. *See Instruction on Reverse Side Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 21 Wells Twelve Month Period: April 1, 1996 to March 31, 1997 Shut-in Wells under Evaluation for Rate Potential P&A Shallow Gas Potential and 'Hemlock Only' P&A Shut-in Wells during Field Blowdown Hemlock Producers Future Shallow Gas P~'oducer with the Hemlock Abandoned SCU 34-8 SCU 243-8 SCU 13-9 SCU 41B-9 SRU 21-33WD SRU 34-28 SRU 43-28 SRU 212-10 SRU 212-27 SRU 12-15 SRU 41A-15 SRU 23-27 SRU 331-27 SCU 14-34 SCU 21-8 SCU 34-9* SRU 14-15 SRU 43A-15 SRU 14-22 SRU 23-22 SRU 24-33 7 Wells 2 Wells 5 Wells ~, ~h GOR well that may be produced intermittently 2 Wells 5 Wells ATTACHMENT 2 SWANSON RIVER FIELD Wells with Temporarily Abandoned Status Change Removed from 1996 Temporarily, Abandoned Status · SCU 34-4 Recompleted in Tyonek G1 and G2 zones · SCU 43A-4 Recompleted in Tyonek G1 and G2 zones · SCU 13-4 Workover to remove tubing fish. Currently producing from Hemlock · SCU 23B-3 Returned to full time production · SCU 314-3 Returned to full time production · SCU 43-9 Returned to full time production · SCU 23-15 Returned to full time production Additions to 1996 Temporarily Abandoned Status · SCU 13-9 Recompleted in Tyonek G2 zone Iow rate oil producer. tkE. GI:IvE. D ~PR 0 ~ Unocal North Amer~'~. Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region March 31, 1994 Re: Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 1994 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment I lists the proposed TA wells using the same-format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SRU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - 1 1994 ~ask~ Oil & Gas Cons. Commission Anchorage Form 3160-5 UNIT,, ,ATES (JUNE 1990) DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different rese~oir. Use 'APPMCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLlCATE 1. Type of Well Oil Gas [] Well [] Well [--J Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage~ AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swan River Unit --- 19 wells Soldotna Creek Unit --- 11 wells FORM APPROVED Budget Bureau No. 1004-0135 Expire~: March 31~ 1 .993 5. Lease Deelgnatlon and Serial No. 6. ff Indian, Allottee or Tribe Name · . · o. 7. If Unit or CA, Agreement Deeignatfon Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field 11. County or Parish, State Kenal, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent r'-] Subsequent Repo~ r-'] Final Abandonment E~ Abandonment ["] Change of Plans !--] Recompletion r-] New Construction r"] Plugging Back J"] Non-Routine Fracturing r-] casing Repair r-] Water Shut-Off ['-] Altedng Casing I'-I Conversion to Injection [] Other Temporarily Abandon E] Dispose Water (Nme: Report re~ub d mulUple conmpleUoll o~l We~l Complel~3n or ~ Re~ and Lo~ fmm.~l ,, 13. Describe Proposed or C0mpieted Operations (Clearly state all pertinent details, and gh~ perlinent dates, including e~T~¢l d~ ol staring any prolx~ed work. ffwell is directionally drilled, give aubeurface locations and muted 8nd true verticBI delX~ for oJI mall(em and a)ne pennant to Ihb w~k.)* As described in attached letter, Unocal requests that the folbwing wells have a temporarily abandoned status for the twelve month period, April 1994 to March 31, 1995: ,~ I' * SCU 23B-3 ~ I SCU 13-4 '5 1 * SCU 21A-4 3 1 SCU 34-4 5' I * SCU 43A-4 / "~//---* SCU 21-8 Soldotna Creek Unit scu 243-8 SCU 341-8 SCU 13-9 * SCU 34-9 SCU 14-34 *High GOR wells that may be produced Intermittently. Swanson River Unit ~' ~ SRU 212-10/"SRU 14-22 $ I SRU 43-28 5ost~ SRU 14-15//-:l~qu 12-15 ~ I SRU 14A-33 5/SRU 23-15 ~J SRU 23-22~u.<;pSRU 24-33 ~5u~I:'SRU 34-15 5l SRU 23-27. ' · SRU 32-33WD %1. SRU 41A-15Jr~SRU 212-27 SRU 21-33WO 5~5~ SRU 43A-15G~ SRU 331-27 ~ u&{o SRU 432-15 ~ SRU 34-28 Conditions of appro~l, if any: RECEIVED APR - l 1994 TrUe 18 U.$.C. ~ 1001, makes it, mime for any person Imowing~ and willfully b:) m to any deperbTmnt or 8gefloy of lf)e United sta/.~f~,~rls' C0mmissi0r fraudulerZ statements or representations as lo any malta' within ils jurisdiclJon. *See Instruction on Reverse Side A~horage Mr. Joseph A. Dygas March 31, 1994 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. DLG:dma , ~~~4~...Dennis L,' ~~rd~;~ske Petroleum Engineer Attachment CC: L. R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC Attachment No. ! Swanson River Field Proposed Temporarily Abandoned Wells: Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for , , Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A -7 5-t5 SCU 13-4 1~).- I~SRU 212-10 ~::)~SCU 34-4 t~[-o5 SRU 23-15 (e~-'~SCU 341-8 (~--:~o SRU 41A-15 (~-"7 SRU 34-28 ez~5~{ SRU 14-22 ~'~-'~ SRU 43-28 ~-t,~ SRU 23-22 ~0'-.'~.~,5 SRU 32-33WD/~I-~'SSRU 212-27 ~,~-"b~ SCU 243-8 ~-~) SRU 331-27 ~Z.-Z SRU 21-33WD~--ZZ. SRU 12-15 IoO--~&SCU 1 4-34 ~O-q~ SRU 23-27 SRU 14A-33 Shut-in Wells during Field Blowdown _ Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned ~z-[~t SCU 21-8' ~b-I~b SRU 14-15 6\-~5 SCU 13-9 (~0-u~[ SRU 34-15 b~-~L~ SCU 34-9' SRU 43A- 15 ~Sq--~DSCU 23B-3' %~-bb SRU 432-15 -~u~-5~ SCU 43A-4' -~.- o~(SRU 24-33 SCU 21A-4' 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells 'High GOR wells that may be produced intermittently APR - ~ 1994 Alaska Oil & Gas Cons. Commission Anchorage Attachment, 2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Temporarily Abandoned Status · SCU 12-15: Shut-in gas lift producer with casing communication. Evaluate for repair or abandonment, · SCU 21-33WD: Shut-in due to wireline fish in tubing. Workover candidate. Removed from 1994 Temporarily Abandoned Status · SRU 24A-9: · SRU 21-3' · SRU 33-5: Returned to full time production after workover. Returned to full time production due commencement of Blowdown in field. Returned to full time production after workover, tO RECEIVED ~PR - 1 1994 Gas Cons. Commission Anchorage Alaska Region Oil & Gas Division ' Unocal Corporation P.O. Box 190247 C-OMM "~ Anchorage,. Alaska 99519-0247 ,.. ..... ~.,,..~ Telephone (907) 276-7600 . ·COMM -" -' _. '/"" _ I~NG ASST I I II March 24, 1993 P~' ~ ~ [FAT TE~'H~ Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in ~wanson...~iver'Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same format as submitted last year by ARCO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Two wells, SCU 243-8 and SOU 21-8 were added to the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. REEEIV'ED MAR ~ 5 199) Alaska 0il & Gas Cons. C0mmis¢o~ Anchorage Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. Yours very truly, Petroleum Engineer DLG:sr Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company RECEIVED' MAR 2 § 199;~ Alaska 0il & Gas Cons. C0mmissio, Anchorage Form 3100-5 (June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals SUBMIT IN TRIPLICATE i. Type of Well [] Oil Gas Well F~ Well F-1 other 2. Name of Operator Union 0il Company of California (dba Unocal) 3. Address and Telephone No. P. 0. Box 196247, Anchorage, Alaska 99519 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) (907) 276-7600 Swanson River Unit Soldotna Creek Unit 17 wells 14 wells 12. TYPE OF SUBMISSION TYPE OF ACTION FORM APPROVED Budget Bureau No. IO04-O!3:5 Expires: March 31,1993 5. Lease Designation and Serial No. 6. If Indian, Allotle~ or Tribe Name 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field I1. County or Parish, State Kenai ~ Alaska CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA I-X] Notice of Intent [~] Subsequent Report ['==] Fi~ Abandonment Notice =]Abandonment n-] Recompletion --]plugging Back [--]king Repair O Altering Casing [~] omer Temporari 1 y Abandon O Cbange of Plans O New Construction O Non-Routine Fracturing O Water Shut-Off O Conversion to Injection O Dispose Water {Note: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for ali markers and zones pertinent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1, 1993 to March 31, 1994' Swanson River Unit Swanson River Unit SCU 21-3 / SCU 21-8*/ SRU 212-10 ~ SRU SCU 23B-31 SCU 243-8" SRU 14-15' SRU SCU 13-4 ~ SCU 341-8" SRU 23-15~ SRU SCU 21A-4 SCU 13-9/ SRU 34-15 SRU SCU 34-4 ~ SCU 24A-9~ SRU 41A-15~ SRU SCU 43A-4J' SCU 34-9'~ SRU 43A-15 SRU SCU 33-5~ S SRU 432-15 SRU SRU 14-22~ SRU SRU 23-22" 23-27 ~ 212-27~ 331-27 34-28~ 43-28 v 14A-33~ 24-33~ 32-33WD RECEIVED Alaska 0il & Gas Cons, Anchorage * High G0R wells that may be produced intermittently. Signed ?,[~V~,,ff~ "~ff//~~ Title Petroleum Engineer Approved by Title Date Conditions of approval, if any: Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements · See Instruction on Reverie Side Attachment No. I Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & An~ and 'Hemlock Only' P & A · Swanson River Field ProPosed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1, 1993 to March 31, 1994 Shut-in Wells until the Field Blowdown Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned SCU 13-4 $CU 21A-4 SCU 34-4 SCU 43A-4 $CU 33-5 SRU 341-8 SRU 34-28 SRU 43-28 SCU 32-33WD $CU 243-8 $CU 21-3 SRU 212-10 SRU 23-15 SRU 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 7 Wells 3 Wells 5 Wells SCU 21-8" SCU 13-9 SCU 24A-9 SCU 34-9" SCU 23B-3" SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 SRU 24-33(2~ 5 Wells Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 Scheduled 'Hemlock Only' P & A in March-April, 1993. High GOR wells that may be produced intermittently. RECEIVED Alaska Oil.& Gas Cons. Commission Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27, 1991) Additions to 1993 Tempor_a_rily Abandoned Status · SCU 243-8: · SCU 21-3: Shallow gas producer ('ryonek). Shut-in due to mechanical problems. Workover candidate. Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Tempor_arily Abandoned Status · SRU 21-22: Returned to production after flowline repair. · SRU 12A-4: · SRU 211-15 Returned to full time production in 1992. Scheduled for full P & A March-April, 1993. Waiting on personnel and rig. RECEIVED MAR 2 5 1993 Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 27, 1991 c©MM dof~M CC SR ~ILE Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 22 West 7th Avenue Post Office Box 13 Anchorage, AK 99513-7599 Subject: 1992 Sundry. Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temPorarily abandon (TA) 32 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected 'to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: . rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only abandonment. RECEIVED DEC ,~ 1 199t Alaska Oil & Gas Cons. Commission Anchorage Mr. J. A. Dy gas Page 2 December 27, 1991 Shut-in wells until field bl0w..d.own, including:. 4. Hemlock producers, and 5. wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in 'which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last ye,ar's TA list were moved into this category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 'Temporarily Abandoned List (Ref: our letter of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, SCU 23B-3, SCU 43A-4, SCU 13-9, SRU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4.107. Sincerely, Ji' C. Winn Acting Regional Engineer JTZ:jlg:0025 Attachment C~ L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation C ~ 1 199~ Gas Cons. Commission Form 3 Z~0-5 (November i 983) (Formerly 97331) UNITED STATES DEPARTMENT OF' THE: INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS not tam Ibis for. fat propomals to drill or to deetMu or pluc back to · different resorvolr. Use 'APPLJCATION FOR PERMIT--" for .uch proi~mmM&) 2. NAMB or OII'IIATOI ARCO Alaska, Inc. 3. aD·Ir. II O1' OPIIiTOB P.O.Box 100360 Anchoraqe, AK 99510 LOCA?ZOI Or wgl,-- (Report Ioc~tlon clearly and la &cGrdmma, with ·ny Stif~ See also si)see 17 below.) ORI§INAt Form approved. Budget Bure·u No. 1004-0135 Expires August 31. 1985 8. 1,141l I)lllO~fITlOl 4lO 111¼L 00. t I~ llOIll, ALl,O'S*lB OI TIIBI NAILS ~, UBi'I' iOlllMll! IAMB Soldotna Creek/Swanson R~ 8. Id, IN OI l,BAll IAMB 10. IIILO AND POOL, OI WILDCAT At su~a~ Swanson River Unit Soldotna Creek Unit 19 wells 13 wells I15. ELtV&~ONO t Show whet. bar Dr. rt. mt. err.) Swanson River Field IUIVBT OB ~ J 12. COOler OB II~lllllI 18. Riff Kenai Alaska 16. Check Apl)rom, ate Box To Indicate Nature aa Notice, Report, or Other DaM w,,,, ..O,-O. r""~ --,I~FI, ,BLT, rI&C'T~ll 'rllifUll? I--I ALTnlIIO CAIIIWO I--"""'t SHOOTING OI ACIDiZING t J ABANDOIIMII"~® Completion or Recompletiol ~eIpOr~ ami Lair form.; 1'~. DI~SC'BiBIK VnOPOSED o· Co~frLETED OPglts?lO.%g. (Clean-Ir state ~11 p4. rtlnP, t detall~, and ~ive IMrttnent dates, lneludhig aspirated date of iterting any proi)os~l work Ir wall ia diructionMl3~ drilled, give subeur(aee ioe&tiuns and me·mated &nd true vertical depUII rot MI m&rksrl and aamco perti- nent to thio lq)fL) · As d~ in ~e attached memo, ARCO Alaska, ~c. recFtests Lhat the foUowing wells have a temporarDy abandoned status: ,~ldotna Creek Unit SCU 23]3-3 SC3J 21"8 SCU 1ZA-4 SCI./341-8 SCU 13-4 SCU 13-9 SCU 21A-4 SCU 24A-9 SCU 34-4 SCU 34-9 SCU 43A-4 S~J 14-34 SCU 33-5 Swanson River Unit SRU 212-10 SRU 14-15 SRU 23-15 SRU 34-15 SRU 211-15 SRU 41A-15 SRU 43A-i5 SRU 432-15 SRU 14-22 SRU 21-22 SRU 23-22 SRU 23-27 SRU 212-27 SRU 331-27 SRU 34-28 SRU 43-28 SRU 14A-33 SRU 24-33 SRU 32-33WD * -High GaR wells that may be produced intermittently. i8. I hereby ce.L-~r3~:~tt-~he fo~reloinf la trde ·nd correct RECEIVE[ DEC 3 7 1991 0il & Gas Cons. Commi Air, ha=-- TITLE Actinq Reqional Eqqineern&~ (Thio space for FederaA or 8tate omc~ uot) APPROVED BY CONDITION~ 01~ APPROVAL, IF ANY: TITLE D&TB *See Inmucfion, on Reverie Side Attachment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total-32 Wells Shut-in Wells under Evaluation for I Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A SCU 12A-4 SRU 212-10 SCU 13-4 ' SRU 211-15 , 'SCU 21A-4 SRU 23-15 SCU 34-4 SRU 41A-15 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRU 21-22 SRU 331-27 SRU 34-28 SRU 24-33 SRU 43-28 ~' SRU 32-33WD ~ ~o SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 9 Wel~' 3 Wells Shut-in Wells until the Field Blowdown Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned ~:~:i:i:i:~:~:i:i:i:i:i:i:!:~:i:i:i:!:.~i:i:.~:i:i:i:i:i:i:i:i:i:~i:i:i:i:i:i:i:i:i:i:~i:i:i:i:i:i:i:..`.i:.::!:i:i:i:~;i:i:i:i:i:i:!:i:i:i:!:i~:i:i:i~:!:i:i:i:~:i:!:i:i:!:!:!:!:i:i:i:E::;!:i:i:i:i:~;i:~:i:i:i:!:~;i:i:i:i:i:!:!:!:i:i:i:~:~:i:i:i:!:i:i:~i:~:i:::i:::i:i:i:i SCU 21-8 * SCU 13-9 SCU 24A-9 SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. For. Temporarily Abandonment Sundry 12/27/91. Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) RECEIVED Anchora~Te Added to 1992 Temporarily Abandoned Status: · SCU 23B-3 & · SCU 21-8: High GOR wells, may be produced intermittently, otherwise shut-in until blowdown. · SCU 1ZA-4: High GOR well, may be produce intermittently, This well is also being considered as a workover candidate. · SCU 43A-4: Shut-in due to mechanical problems. Also being conSidered as a workover candidate for shallow gas. · SCU 13-9: High GOR well, shut-in until field blowdown. · SRU 212-10 & · SRU 212-27: High water rate shallOw fuel gas well, currently not economic to produce based on current fuel gas needs. .. SRU 21-22: Well currently shut-in due to problems with the flowline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily. Abandoned Status · SRU 21-15 & · SRU 314-27: Wells are scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU 14-15, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the TA List for 1992. Attachment 3 Swanson River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming work: · SRU 21'15 & * SRU 314-27: Wells are scheduled for P & A in first quarter 1992. Wells that are used seasonally * SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. R CEIVED DEC 5 1 199! ,Alaska Oil & (~as Cons. uommissio~, Anchoraoe ARCO Alaska, Inc. ~ Post 0'`~ ° ,,,c~. Bo~ 100260 A.~chora9e. -' iaska 995 ',0-0360 December 29, 1989 Mr. J. A. Dygas, Branch Chief Division of Minerals Bureau of Land Mana~ment 6881 Abbott Loop Road Anchorage, Alaska 99507 Dear Mr. Dygas: Attached is a Sundry Notice requesting approval to temporarily abandon 31 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.3-4, paragraph C of the Bureau of Land Management Regulations. All 31 wells are expected to be shut-in for a period of at least 30 days. The wells are separated into four categories: 1. Under evaluation for rote potential. 2. Under evaluation for P&A or future utility. 3. Inefficient producers. 4. Shut-in until blowdown. Several other items have .been attached for your information. Brief explanations are given for each well that has been added or deleted from the temporarily abandoned stares (Reft your letters of 3/1/89 (3160 (984)) and 3/30/89 (3180 (984)) and our letter 12/28/88). In addition, a list of currently shut-in wells which have planned upcoming work that will enable their return to production is attached. If you have any questions concerning this Sundry Notice request, please call StacY Strickland at 2634914. Sincerely, Tom Wellman TW:SLS:jt:0016 Attachment cc: -C. V. Chatterton, Chairman AOGCC A, R. Kukla, Marathon Oil Company S.W. Ohnimus, UNOCAL Corporation RECEIVED DSc2 1989 Alaska 0/1 & Gas Cons. Commissi~ Anchorage Form 3160--5 ~ Hovem~04a' 1983) (Formerty 9--331) ~ .ITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not ~Je .thio germ tar proMia to drill or to de~t~ or piul tmc~ to a 41~l~mt l~rvoir. Um -ApPLiCATION FOR PERMIT--'* fro, ARCO Alaska, Inc. 3. ADDLS~ O~* OPBI~I*Ou Post Offfce Box 100360 Anchroage, AK 99510 4. ~OC&TION al wILL (Re~rt lo~ttoo ciearl7 tod tn accordance with ~ay S~M ~ul~m~· S~ tl~ 89a~ 11 ~low.) At Soldotna Creek Unit - 11 wells Swanson River Unit - 20 wells 14. l~aaul~' NO. IS. sLaVAT~ONS (Show wb~Jter De. rt. on. md.) Form approved. l~zd(et Bureau No. IO~'_ Ol3S E. xotrea &u&~at 31. g. WlLL JO. 10. flBLD &HO POOL, os WILOC&T gUITBY OB Ltl& [[ ~001~! 0Ii ftllllI 1[ ITi~ Kenai [ Alaska 16. Check Apmooflate Box To Indicate Nature o~ Notice, Rel)off, or Oth~ Data lO~IC1 Of IlT1lTlOlq t'O: FRACTURB TIS&'Z ~fUL~IPLI ¢OMPI,RTE :otb.) Temporar i I y abandon IUB~O~UBIP~ ~ M: WATBR Ill~T-Ol~ ~ BAil/JIG WILL IIOOTINO 0l &¢IDIIIII &IAJIDOIfMIIF~® (Other) (NOTS: Ret)oFt regalia ar mul_tilde eomMetfou on Wall Completion or Reeompte~on H~OoFt ~nd ~ tot-m.) I?. U~..qc~l~£ PROPOSED on CO.~IPt. I?ED OpIMIATION~ (Clearly state ~II ~rttne,t detall~, and ;lye ~rtinent ~t~ Inelud~ m~atd da~ of I~ uX ;ro~=~ worL If w~ b dietary d~fl~ give ~~ ~unl ~nd mealUr~ and t~e vertl~ ~p~ fff ~ markl~ ~d Nlm H~- flefl~ ~o ~ ~rL) · As described in thc attached memo, ARCO Alaska, Inc. requests that thc following wells have a temporarily abandoned status: $oldotna Creek Unit ~wanson River Unit SCU 13-3 SCU 13-4 SCU 21A-4 SCU 34-4 SCU 24-5 SCU 33-5 $Cu 33-8 SCU 341-8 SCU 34-9 SCU 3 lA-16 Sl C U 14-34 SRU 34-10 SRU 23-22 SRU 14-15 SRU 312-22 SRU 21-15 SRU 23-27 SRU 211-15 SRU 314-27 SRU 331-27 SRU 31-15 SRU 34-28 SRU 34-15 SRU 43-28 SRU 41A-15 SRU 14A-33 SRU 43A-15 SRU 24-33 SRU 32-33WD SRU 432-15 SRU 12-34 RECEIVED DSc 2 9 IO.,89 Alaska Oil & Gas Cons. C0mmis Anchorage 18. [ bere~y certify r. hst the tore(oiJlg il ~,~e and correct TZTZm Cook Inlet Enginerring Mnna~ (This |pi~tJ for lPodertl or *qtito o~e~ use) APPROVED BY CONDITIONS OIP APPROVAL, 17 ANT: TI~W..B DATB l ~ InmKflom on Revile Side Title tS U.S.C. SeCtion lOOt, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representer, tons al to any matter within ltl jurisdiction. TEMPORARILY ABANDONED WELLS IN SRF Wells under Evaluation Rate _Potential Wells being evaluated for P&A/Future. Utility Wells SI for Inefficient Production Wells SI until B!owdown_ 13-4 34-4 24-5 33-8 341-8 34-9 41A-15 23-22 23-21 13-3 14-15 21-15 211-15 31-15 34-15 432-15 31A-16 312-22 34-28 14A-33 32-33WD 12-34 14-34 21A-4 33-5 34-10 43-28 24-33 43A-15 314-27 331-27 For: Temporarily Abandonment of 12/29/89 SWANSON RIVER FIELD Wells having Changed Temporarily Abandoned Status Added to Temoorarilv Abandoned Status: -- SCU 21A,-4: Well is temporarily abandoned due to inefficient production (high GOR). SRU 32-33 W D: Well is temporarily abandoned due to annulus communication problems. Removed from Temnorarilv Abandoned Status: -- _ $CU, 243-81: This shallow sands gas well has been returned production. SCU 13-9: A workover is planned for this well which will enable this well to be returned to an active status. SRU 212-10: This shallow sands gas well has been returned to production. SRU 23-15: This gas-lifted well has been returned to production. SRU 21-34: A sidetrack is planned which will enable this well to be returned to an active status. RECEI'VED DEC2.1989 Alaska Oil & Gas Cons. Commissio~ Anchorage For: Temporary Abandonment Sundry of 12/29/89 SWANSON RIVER FIELD WELL STATUS UPDATE Shut-in Wells with Planned Upcoming Work* SCU 32A-9: When on-line, this SI well produces gravel. A sidetrack is planned to return this well to actiVe status. *Will not be placed on temporarily abandoned ,tatd IVED Alaska Oil & ~as Cons. Comtni · For: Temporary Abandonment Sundry of 12/29/89 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12!5 Cook Inlet/New Ventures Engineering August.19, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage, Alaska 99523 Dear Joseph: Attached is a Sundry Notice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table ttl were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories' 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in - inefficient production 4. Shut in - save for blowdown Wells in Categories 111 and 112 are currently under evaluation to determine their final disposition. Wells in Categories 113 ahd 114 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, H, F, Blacker Regional Engineer Cook Inlet/New Ventures HFB' JWR' ch' 0006 Attachment CC: C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission TABLE I Wel 1 s under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future UtilitS 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B 1 owdown 43A-15 314-27 331-27 343-33 0~ TO: TRA~_ SMIrTAL~ ACKNOWLEDGEblENT OF RECEIPT OF--~b_~TERIAL- '(ALASKA) DATE DEPT.: PLACE: THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. FI) - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. · , ILl ILl I , I 'RECEIVED BY i iiii i i i REMARKS ON OTHER SLOE, THIS SHE'ET i i - mc. BOX 7-839 ANCHORAGE. ALASKA 99.510 ~ ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COI~,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. 3. Address 8. AMI Number P. O. Box 107839, Anchorage, Alaska 99510 50- 4. Location of Well 660' N & 670' E of the SW Corner, Sect. 34, T8N, R9W, S. B&M 5. Elevation in feet (indicate KB, DF, etc.) 151' KB 6. Lease Designation and Serial No. A-028997 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 14-34 11. Field and Pool 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). 1. A plug was set in the position #3 nipple at 10447' as proposed. However, it was discovered that there was a tubing leak above this plug. 2. A plug was then set in the position ~4 nipple at 10420' to isolate all sands below the H1. This plug was effective. This work was completed on January 20, 1983. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~- ~, ~.~ Title Area Enqineer The space below for Commissio~ use Date Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 3. Address 8. APl Number P. O. Box 107839, AnchorAge, Alaska 99510 50- 4. Location of Well 660' N & 670' E of the SW Corner, Sect. 34, T8N, R9W, S. B&M 5. Elevation in feet (indicate KB, DF, etc.) 151' KB 6. Lease Designation and Serial No. A-028997 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 14-34 11. Field and Pool 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). 1. A plug was set in the position #3 nipple at 10447' as proposed. However, it was discovered that there was a tubing leak above this plug. 2. A plug was then set in the position #4 nipple at 10420' to isolate all sands below the H1. This plug was effective. This work was completed on JanUary 20,.1983. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. _ The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate February 16, 1983 Chevron U.S.A. InC. P.O. Box 7-839 Anchorage, A/aska 99510 Re~ ~ubsequent Reports, .Sundry Notices and Reports on Wells .(Form 10-403) For the following lists of m~otice of Intention To~' Sundry }k)tices and Report on Wells (form 10-403} this office do~s not have on record the "Subsequent Report of~' defining the action taken on the approved intention. Please advise this office by Subsequent Report of the disposition of the intention. We 11 ~Ch~vron..._Dar9 Jeanette Is. i 1/13/82 SRU 23-27 . 5/7/82 SRU 24-33 " 5/7/82 SCU 21-4A S/3/82 SCU 13-34 8/5/82 SCU 14-34 ~/5/~,2 SCU 21-9 ~' 8/5/82 Sincerely, .. I~nnie C". "Smith Commissioner Brief .Description of Intention Brier description Clean out scale plug Clean out scale plug Reperforate Isolate leak in H-"3-4" interval Return H1 and H2 to production Clean out fill in tubi.ng LCS/JKT/g lh STATE OF ALASKA ~ ALASKA Oru AND GAS CONSERVATION COI,..,vllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 3..Address 8. APl Number P. O. Box 7-839, Anch., Ak. 99510 50- OTHER [] 4. Location of Well 660'N & 670'E of the SW CDr., Sec. 34, T8N, Rew., S.M. 5. Eleyation in feet (indicate KB, DF, etc.) 18 'Y~ 12. I 6. Lease Oesionation and Serial No. ^,nbonn~ 9, Unit or Lease Name So!dotna Creek Unit . 10, Well Number SCU 14-34 1 1. Field and Pool Swanson River Field Check Approoriate Box To Indmate 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 25.105-170). It is proposed to perform the attached procedure on Well SCU 14-34. RECEIVED AUG - 6 1982 0it & Gas Cons. Commission Anchorage 14'lhereb~i4~e~r]°~gistrueandc°rrectt°thebest°fmykn°wledge'z-7~_?~ Signed ~l'~/v' ./~ ~ Title Area Engineer The space I::~1~ for cam?i~ U~/ Conditions ~ App~al~t an~: ~ Date 8/5/89 Approved Copy Returned Approved by. COMM ISS ION ER By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WELL' FIELD ' JOB NO' CHEVRON U.S,A. INC. WESTERN REGION ALASKA AREA WELLWORK PROCEDURE SUMMARY LOC.' , --~,N)~'~-': ~.,-"- TYPE WELL' TYPE JOB' ORIGINAL SUMMARY OBJECTIVE ' ,.- SUPPLEMENTAL SUMMARY NO. WELL DATA' K.B. CASING' PBTD PROGRAM , AlP -'-:- ' ' , ' ' , ~ -fA KELt: V DETAILS ATTACHED Distribution: Original to Well File W.D. Sauer (3) Field Office(I) Preparer (I) D.M. Wilson(II AUG - 6.1982 Oil & Gas Cons. CommJssior~ Anchorage Prepared by Date ,/x' ; /~. /': _ ,-.,'-,,'?/?~z_-- ~ III I__I II_ I ~ IIII I ..-- K.B. to TUBI~IG 'x'-'~iEH 17.77' .. t 20" ~ 28, · "..',~' ....... .. DV.C.1478,- 63' JTS. 2-~" EUE 8~ T~RJG 1~.95' 1.~.~' - ~C~CO ~ ~L 12.91' 2981' "' '47' ~. 2~" E~ 8~ TUB~?G 1454.57' 3,458.~'- --C~dCO Z,~ Z~L 12.98' 38 J~. 2~" E~ 8~ TUB~G 1181.~' 4,652.~' - _ C~EO ~ ~~L 12.~' 27 ~S. 2~" E~ 8~ TUB~G 838.33' . 5,503.74' C~,EO ~4 ~~L 12.95' , 17 ~S. 2~" E~ 8~ T~G 523.21' 6,039.~' C~dCO ~4 ~.~L 12~94' ~ · 12 ~. 2~" E~ 8~ T~G 3~.~' 6,~3.76' C~O ~ '~~L 12.~' .7 ~. 2~" E~ 8rd TUBR;G 218.~' 6,65s 6,655.36' C~,EO ~ ~~L 12.93' , 11,7 ~. ~" E~ 8~ T~D~G 3~.~' 14" ~10'334'~ ~ ~ "~" S~ 3.18' -- 10,337.77'-.~. B~ FH PAC~ 2%" ~ ~" , 2~ 6.74' ~ I! .o~e, wso ] I ~. 2%" E~ 8~ TUBinG HI · ~ --10,~09.53~BR0~'~ "CC" S~TY ~. 1.~' lO,&1&.02 - , ~ t,, : 141 :,04zo '~ / ; ~~ .o,, ~,~n,~ o-~* .... :,, 1.53! ~ o ~ II [ ,zpE,,. I B~R Bk~T ~. 3.~8" ~ 13.31' ~ro4sz~n /:,o C'~C~-~ XA o · ,~ . . 3.17' ~~1o~,.22,' );. o)?~ -~,, NIPPY, Posi%ion //3 ~'~-~ 1.58' ~ i I ~ i~c~. '~ ~iP- 't~ ~D~T ~T ' 20.Jl~ ~.~ ~, ,~, ~t-~ i i'~ / ~ ~. 2~, 8.o9' ~ ~ ~.~.,~o- >~OT~ "S" NI~, Position ~2 1,58' 'o'' i U H 8 ~'~ T ~S. ' 30.32' ~ ~ .... ~p ~. 2~', 3.26' ' ~ '~"~ .... "XA" --' ~ STOP SUB 1.00' ~:0~_~ ~ "D" 2%" 2%" ~Y. 3.250" 6.35' ,~ :.~.~7 ~ C~,EO ~;IPP~ 2~" . LH8 ~ '~;~"~: ~c'~'l(-~ .... 2~" B~ B~T JT. C~ 45~ ON B~.3.C~" 0D19.~' q AUG - 6 1982 Alaska Oil & Gas Cons. Commission Anchorage -' ,'.' ' ...... SCU 14-34 CASING & TUBJNG DETAIL T.D. 10,870' SECTION 34 T. 8N.,R. gW. STANDARD OIL COMPANY O~ CALIFORNIA WESTERN OPERATIONS, INC. TRANStqt TTAL (A I, A,% KA ) DEPT. '--~_/'-'/"ff~.~_~~'___p,._/.._. ,,'_. FI.) - 1"o ].d(.;d R - Ro.LLed S ~- Sepia F - F±].m - Xerox B - B]ueline TIlE FOLLOWING IS A LIST OF 1W~TERIAL ENCLOSED tIEREIN. PLEASE CIIECK AND ADVISE.-IMM~:DIATELY. COMPANY WELL HISTORY LOG 2" 5" I I leo' [o---6 J/ /I RECEIVED C.A. White 'Box 937 ~ ii~?.t~¢'° 82901 ' ·- ' Rock Sprin _. . ; Wire Line Well Service ~ ~ Area Code ~:;'i-.' :' ' ~ · .. '-' ...... '-.~ ' .... ~'~ ~" r ' ~ Box 156 ' Casper, Wyoming 82601 ~:~ ' Tel. 362.6488 -; : · . i'i?*/.~: SUBSURFACE PRESSURE SURVEY Producing Formation · Elevation (CHF, DF, KB, etc.) Datum subsea, or :~:-:::~:.-: -tubing set at CaSing set at Production Packer at Perforations Subsurface Controls (Nipples, ere;) instrument Data : - ~Company. Running SurveY - - " · Element - Range & No. ClOck. Range & No. Calibration Date Static Pressure Data_ · ( ) 151 ' KB lO451 10659 ~o886 ( ) Box 962 Soldotna, Alaska 99669 Area Code 913 Tel. 262-4496 Company Standard Oil Company Lease SO U~ Well No 1/4-34 Field Swanson River State Alaska rest Date April 4,1975 Zero Point KB GRD. 10377-10660 C, A. White K2 280-6000psi ii':i;i';!Q ::~'Pressure at Datum O ) 393-0 psig ~-:' (Shuitqn Time )' hrs. . }]~:~7.']{[' ~ ' ShUt'in Tubing ~ pressure-_ ~" -::}~--~'55 ~.:; - Shill-in Casing-Pressure ~"' ~ psig TopofW.ater' -'-" /' -' ' .- Temperature at - - ~ - - - fee - l 70 :-'Dare0f Last Test '-_ - ' ' '. "' Pressure ~ Datum, List Test· :~' psig Shut-in Time, Last Test· 'FI°w Test Data ' Choke Size ' - - . in Period of Stabilized Flow ~ hrs StabilNed Production 5-~ - Oil bbls/day ~ G as MCF / day -Water bbls/day Flowing Tubing Pressure psig 'Flowing Casing Pressure psig Remarks' Operator __ Iq. Go Hopper - r- Static Test Depth Time Press., A p D ..' P, psig AD Gradient ,. 0 3202 200C> 3301 '99 2000 .050 400¢) 3578 277 2000 ,139 6001~ 3741 163 2000 ,081 800( '"-- 3828 8~. 2000 .044 1000t · 3934 106 2000 -,053~ 1020~ ' 3952 · 18 200 '090 1040(1 3970 18 200 '.090 1045~ 3910 t 051r.} 3877 · · , · Press. At Tubing Casing Remarks, Time .ft. hrs. Press_ Press. · ~ . . · · . . ~ ooo · ~ 000~ ' ' ' " fALASKA) RRANS~,:ITTAL buND ACK, ,],EDGMENT OF RECEIPT OF MATERIA. ~ THE FOLLOWING IS A LIST OF ~\TERIAL ENCLOSED HEPgWITH. CHECK AND ADVISE IMzV~EDIATELY. PLEASE ! %c ut fzff .- ¥-'" .. Received and checked by: Da[_~: '; ?',) / ' F~rm N'o. · REV. 9-~0-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE · MONTHLY REPORT OF D.RILLING~ AND WORKOVER OPERATIONS 1. 01'L ~ GA8 [~ OTHER WELL WELL 2. NAME OF OPERATOR Standard 0il Company of California~ W0I 3. ADDRESS OF OPE~ATOR P. 0. Box 7-839, Anchorage~ Alaska 99510 4.LOCATION OF WELL 660' North and 670' East of SW Corner Section 34; T-8N; R-9W; SB&M SUBMIT IN DUPLICATE ...... .. AP, =oD .? 50-1~3-20222-00 I 3ENG , A-208990 J 5 ENG I I G~OL J t SE0 ' I" ~. ~-Z~,F.~ O~ LZASE N~E ...... /- R~v D~ ~. WE~ ~'O. " j SEC SCU 14A-34 ~0. F~ ~ND P~, O~ W~DC~ m , FILE~ Swanson River F~ ez~ .... n. s~c., t., ~., M., (~O~ ~O~ O~ S'EC 34; T-8N; R-9W; SB&M 12. PERMIT NO. 6o-38 13. REPORT TOTAL D~PTH AT END OF MONTH, CPLa_NGES IN HOLE SIZE, CASING A/ND CEMF~NTING JOBS INCLUDING DEPTH SET ~AN-D VOLLrNIES USED, PEI~FO~LAT~ONS, TESTS A2N-D I~ESULTS, FISHING JO~. JUNK IN HOLE A_ND SIDE-TI~ACKED HOLE AND A/~Y OTHER SIGNIFICA/%IT CI-LAJqGES IN HOI~ CONDITIONS. A__u us t Ran in.hole with 2 7/8" sawtooth collar on 2 7/8" tubing and cleaned out 6 5/8" casing to 10,731'. Plugged 6 5/8" casing in two stages from 10,731' to 10,676' and from 10,676' tO 10,482' with 45 sacks and 36 sacks, respectively, Class G cement. Drilled out cement and cleaned out to 10,640'. Jet perforated 6 5/8" casing with two 1/2" holes per foot from 10,628'-10,608';10,594'-10,566'; 10,535'-10,493'; 10,478'-10,450'; 10,436'-10,422'; and 10,408'-10,377'. Scraped 6 5/8" casing with tandem scraper to 10,640'. Ran Model "D" packer on wireline to 10,565'+. Would not go any deeper. Pulled out leaving packer. Milled over. and recovered'fish.. S--craped 6 5/8" casing to 10,640'. Ran Model "D" packer on wireline to 10,586'. Pulled out leaving packer. Milled over and recovered fish. Scraped 6 5/8" casing to 10,640'. Ran minimum ID tool from 10,640' to surface. Ran 5 5/8" swage to 10,640'. No tight spots. Ran Model "D" packer on tubing and set at 10,602'. Measurements varified with neutron-Collar log. Ran 2 7/8" tubing string with jewelry and stabbed into Model "D" packer at 10,602'. Hydrotested tubing to 5,000 psi. Spaced out and landed tubing. Removed BOPE. Installed x-mas tree. Displaced drilling fluid in hole with lease crude oil. Set packers. Released rig at 4:00 PM, August 16, 1973. Will hook up flow lines, etc., after rig is moved and place well on production. 14. I hereby certify t t h £o in is and correct SIGN]~D -- = T~TL,E NOTE-7~por% 0n t~i$ form is required for each calendar month, regardless of the $1atu~ of operations, am~ mu~% be filee in duplicate with the Di~'sion of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Fu,-m P -7 ~ :; SUBMIT IN DL CATE* STATE OF ALASKA (Seootherln- st ructions on OIL AND GAS CONSERVATION COMMITTEE i [ ii iii WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* III II II I I W ELL W ~LL DR ~ Other b. TYP~ OF COMPLE~ON: 2. NAME OF OPERATO~ 3. ADDRESS OF OPERATOR ' ~ '' LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface At top prod. interval reported below At total depth " I ! 13. DATE SPUDDED 14. DATE T.D, 'RE.~CHED 15: DAT~E CO,NLP SUSP O~ ABAND. 5. AP1 NU-MF.~CAL CODE ~. LEASE DESIGNATION A_NI~ SERIAL NO. 7. IF INDIA.N, A.LLOTTEE OR TRIBE NAME 8. UNIT,F.AX/2VI OR LEASE NAME 9. WELL NO. 10. FIELD AND POOL, OR WILDC&T i11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. i! . E~EVATIONS (DF, RKB, RT, GR, ETC)*ll7. ELEV. CASINGHEAD ! INTERVALS DRILLED BY CABI,E TOOLS 231 WAS DIRECTIONAL SURVEY MADE 24. TYPE ELF~CTRIC AND OTHE~ LOGS RUN CASING SIZE 26. LINER I:~EC OL:LD S!Z]~ TOP (}.'ID) I~OTTONi (MD) SACKS CE.MEi'~T* i i i ii 28. PERF©RATiONS OPF2N TO PR O1~ (interval, size and nurnDer) i .ii i CASING RE~)RD (Report all strings set in well) DEPTH SET (1VLD) HOLE SIZE CEMLNTING RECOF~D 27. SC i~ EEN (MD) SIZE TUBING RECOPJ9 /Y).~OUNT PULLED 29. DEPTH SET (MD) ~ PACKER SET (MD) PRODUCTION DEPT~i 1NTE~V.~L (MD) I f%A'iOUN£. 2~ND I'2!ND OF MA'I~2?.IAL USED DATE FIRST PI-iODUCTION [ Fi%ODUCTION MEI[{OI) (Flowh~g, L'ia$ lift, pumping--size and type of pump', [%VELL STATUS (Producing or FLO~V,!~SS. TM BING ]1UA~I2qG PRESSURE .J24'HOUR RA~ IcALc~T~ OI~BB~. ' [GA~MCF' ]WA~BBL' ] OIL GRAVITY-~I (CO.R.) ~l. D'ISPOSITION Or GAS (Sold, used I~r ~uei, vented, etc.) ...... ~2. LIST OF ATTACHMENTS ITEST WITNESSED BY '= ~3.'I hereby certify that the foregoing and attached information is complete and correct as determined from all-available recor'ds *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of' lansJs and leases in 'AlaSka. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attachments. Items ~20, and 22:: If this well is completed for separatc preduction from more th~n one interval zone (multiple completion), so state in item 20, and in item 22 show the p~cJuci~,g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv,~l reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the adlditional data pertinent to such interval. It~m~26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22' above). , , , AIrY OF FORMATION TF__,STS INCLUI')IN(; 'INTERVAL TESTED, PHF_~e'~SURE DATA. A.N~COVERI~' OF OIL. GAS. 35. G I~OL,OG'I(' M AR Kl~q~ WAT~I1. AND MUD NAME M~AS. D~gT)TH. T*RU~ VlgR.T."D~fi~ '~'DATA. A'I'FACI[ I3RIEI~ mmscm:~moNs o~ Ltmrio~-°-C,V, ~0h6gl~Y'. r~A~. ~~ ~' ...... ... ~ . ....... . ... ..... · : .,, CO~!PLETION REPORT - ~ REMEDIAL WORK - STANDARD OIL COMPANY OF CALIFORNIA, WESTERI'I OPERA'F~ONS, INC. OPERATOR AREA: - KENAI PENINSULA, ALASKA LAND OFFICE: ANCHORAGE ~ TSN R9W Seward' B&M . _ ".. -. ~... -.~:. 3.~., ·. . , LOCATION AT.TOTAL DEPTH: SA'ME- - - -'"--' .... .--.-- .. .~ " . . . ELEVATION: 151 KB ._- -....--:':.~ K"B,..i"s~ 15- abov0 ground ~levAtion . - . - ...."'-~.: - :' '~. -.~-,:.'-. ' '-' '. ' - ·., . Area .Supervisor. '. '.. - . _. . . PROPERTY: SOLDOTNA CREEK'UNIT LEASE NO. : A-28990 _ WELL NO.: . $CU i4-34 . 'API NO.: · . ~ LOCATION. AT SURFACE: 66.0' North' and 670' East from 'Southwest corner Section , DRILLED BY: R. B. MONTGOMEI{G :RIG $ 36 (C0NTRAC'TOR) DATE CO~MENCED JULY_ 1~4, 1973 DATE COMPLETED AUGUST ':16, 1973 DATE OF INITIAL PRODUCTION: TOTAL DEPTtI: IO,866' SUMMA RY · ..- PLUGS: lU,Hb~'-lO,'I29' 10;729'-1U,640' CASING: CONDUCTOR CEMENT @ 28 JUNK: NONE '13 3/~ @ .2981 DV @ 1,178' 6 .b/O ~ 1u,~G~' O'v t~ 84~3b ' _ ~V. 9-~9 - ~ "Su~quent Repo~s" ~ Dupli~te STATE OF A~KA ~..P~ ~c~ co~s ~-~" OIL AND GAS CONSERVATION COMMI~EE 5 0-13 3- 2 0 2 2 2 --'1 ..... ~ EN~ .J~ ' ~. ~ D~GNA~ON ~ S~m SUNNY NOTICES AND REPORTS ~ W~ ~- 028990 (Do not u~e thi~ ~o~ ~ot proposals ~ drH~ et to ~eepe~ use ' 'APPLICATION 'FO~' ~'E~'~" ~°r sUch 'P~°~°salS~) ~. GEOL 2. NAME OF OPE~TO~ ~. ~NIT~ FA~ OR ~S~ NAMg Standard Oil Comn,nv. n~ e,~,~-~- W_a.~. Soldotna Creek ,. - - - ..... · ,. P. O. Box 7-.839, Anchorage, Alaska 99510 SCU 14-34 4. LOCATION OF W~L 10. F~ ~D POOL, OR WI~CA' ~tsurface 660'~. ~ 670~E. from S. ~. Cornor of Swanson Ri~or -' ...... Section 34 T.8N, R. OW, Sewer4 B & M om~w) Section 34 T.8N. ,R.9W. Seward B & M. 1~. P~T NO. 13. ELEVATIONS (Show 151 ' K.B. , 14. K.B, is ]_~' abov~ arr~,,n,']_. Check Appropriate Box T~ I,nd:i'c~te Nature of NOtice, Re NOTICE OF INTENTION TO: ~RACTUaE TREAT sHOOT oR REPAIR V,' ELL PULL OR ALTER CASING X.~ MULTIPLE COMPI,ETE ABANDON* CHANOE PLAN8 -- tOther) 60-38 ~ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ,t. LTERIN0 CASINO 8HOOTINO OR aCIDIZINO *BANDONMmNT* (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. July 1973 Commenced operations at 12:01 A.M., July 14, 1973. JUl. 25 DIVISION OF OIL AND GAS ANCHORAGE J~f W. Walker (This epaffor State office use) TITLE APPROVED BY CONDITIONS OF APPROVAL, IF ANY: DATE 7/ /F /73 TITLE DATE See Instructions On Reverse Side ApproVed Copy Returned PERFORATION RECORDS %ORIGINAL) ~- 1. 5-%" jet holes 10,359' 2. 5-%" jet holes 10,669-10,670' 3. 4,%" jet holes per foot 4. 4-%" jet holes per foot 5. 4-%" jet holes per foot 6. 4-%"~jet holes per foot 7. 4-%" jet hole~ per foot 8. 4-%" jet holes per foot 9. 4-%" jet holes per foot 10,377-10,~£2' 10,420-10,437' 1u,~44-10,478' 10,4~3-10,535' 10,566-10,601' 10,605-10,633' 10,642-10,660' REMEDIAL (REPERFORATIONS) : 1. 2-%" jet holes per foot 10,b28-10,608' 2. 2-%" jet holes per foot 10,594-1U,566' 3. 2-%" jet holes per foot 10,535-10,493' 4. 2-%" jet holes~ per foot !0, 47~-10,450' 5. Z-%" jet holes per foot 10,435-10,422' 6. 2-%" jet holes per foot 10,408-10,377' WELL LOGS (ORIGINAL) : Schlumberger IES_log,-in~te.rwal 2. Schlumberger Sonic log, interval 2996-100' 3. Schlumberger tES log, interval 10,873-2998' 4. Schlumberger Sonic log, interval 10,870-299~' Schlumberger Micro log, interval 10,873-~0U0' 6. Schlumberger Neutron Collar log, interval 10,729-8400' 7. Schlumberger Cement Bond log, interval 10,729-6600' Baroid- Mud Logger~interval 8bu0-1U,870' REMEDIAL LOGS.. 1. Go-International Neutron Casing Collar Log DRILL STEM TESTS (ORIGINAL) 1. H.C.T. W.S.C. 2. H.C.T.W.S.O. 3. H.C.T. Prod. on perf'd, interval 10,369'-W.S.C. on perf'~, interval 10,669-10,670 W.S.C. Test on perf'd, interval 10,642-10,660' REMEDIAL: 1. H.C.T. interval 10~668'-10,725' ~o~ PL ',099'0I o~ ,~pg~0'[ mo~ ~zgsnbs o~ q~d9p 9u!I9~!a ',8~9'0I ~ ~uI~ ~ I~poN ~M-e~ ~sS ',0~£'0I o~ ,000'0I mo~j p~66o~ '6oi ~eIIOO 6uys~m uo~n~u I~UOI$~u~s~uI-oD ~£6I '9~-SE XIn£ ',0SL'0I o~ sx~dw~m$ BuTs~o ,,8/5 9 ur~puw~ q~T~ ~Tq ,,8/5 5 u~ -~ioq u~ID o~ .punoz~ iiTd uoT~InolTD ~soI p~dum~ ',0~£'0I o~ PSIIT~ g£6I '~E XIn£ ~od ~L ',0££'0I o~ ,~I£'0I mom~ ~n[ uo Bu!IIIM ~£6I 'TE AIn£ god ~£ ',~I£'0I o$ ~Ioq ~q$ uaop Mun[ psqsnd puw P~II!~ 'II!m sP~Iq .9 ~g~s-y~ dn spwM '~Ioq u! aaMo~d ~o .9 ~ 'lGMOed p~X~AOD~ '~I~ IOO~ p~XX~£ CL6I ,gZ KIn£ god ~4 m~Mo~d '~'0 ,,g/I Z qSYa It!~ '~'I ,,g/t ~ x '~'0 ,,8/g ~ u~M -~no ',gS~'OI pu~ ',~E~'OI ',I6~'OI ~ smsMo~d p~s~I~M '6nId oos~soo p~Aour~M ~L6I 'I~-0g XIn£ ~d LL · A~Mo ~saA '!sd 000~ oq.$uamd!r~ba II~ pa~sa~ . CA6I '6I KIn£ ~od AL CL6I '8I-9I XIn£ · p~!r~b~= s~ uressAs aO~ m~u 6u!~o!~q~M -sure~ ~£6I '~I KIn£ '~0~ III ss~IO !sd 000~ .0I PaII~$SU! pue aaa~ s~m-x paAom~M -~nuop u! 6nId oms~soO PaIIW~SUI 'pn~ ~od AL q~!a IIaa PaII!M 'm'~ I0:gI ~e suo!~w~ado p~ou~m~O~ July 27 and 28, 1973 SCAB Job No. 1 Stabbed through retainer at 10,638'.. Breakdown was immediate with commu- nications ~above retainer at 15 cubic feet rate at 2600 psi. Mixed 20 sacks Class "G" cement, treated with 1% CFR-2. Preceded cement with 40 cubic feet of water. Equalized cement through retainer with 5 cubic feet of water and 337 cubic feet of mud. Pulled up to 10,585' and reversed out 14 cubic feet of cement. Cement in Place at 4:30 a.m. 74 pcf Ran 5 5/8" bit and 6 5/8" casing scraper. Drilled retainer at 10,638' and cleaned out to 10,750'. Circulated out and prepared to recement. SCAB Job No. 2 Ran open ended drill pipe to 10,750'. Equalized 48 sacks of "G" cement, mixed with 0.75% CFR-2. Preceded cement wi-th 10 cubic ~et of water. Displaced with2 cubic feet water .and 338 cubic feet of mud. Pulled to 10,400' and~backscuttled out contaminated mud. Lost 40 cubic feet of mud. Cement in plaCe-at 5 p.m. 74pcf July 29, 1973 Ran 5 5/8" bit and casing scraper' Located cement at 10,452' and cleaned out to 10,750'. Ran 6 5/8" Baker squeeze tool and set at 10,634'. Tested perforation at 10,642' to 10,660' and blank casing to 10,750', with 2500 psi for 15minutes. Test okay. 74 pcf July 30-31, 1973 Go-International perforated four 1/2" holes from 10,708' - 10,721'. Ran Howco tester. HCT No. 1, 10,708' - 10,721' - Tool assembly from bottom up: HT 500 tem- perature recorder, two outside recorders, flush joint anchor, two subs, type C packer, VR safety joint, hydraulic jars, two inside recorders, hydro-spring tester, dual CIP valve, and 10,636' of 2 7/8", 6.45# per foot drill pipe. Packer set at 10~668'. Opened tester with 1000 psi Gas cushion at 8:45 a.m., July 31, 1973. Bled cushion off. Flowed Gas 5 hours, 45 minutes at 1900 psi. Final shut-in ~three hours. Reversed out at 5:45 p.m., July 31, 1973. PRESSURE DATA: Depth Gauge IH ISI IF FF FSI FH Top Inside 10,654' 5787 5166 3479 3429 5166 Expired Bottom Inside 10,659' 5765 5136 3495 3330 5136 Expired Top Outside 10,690' 5792 5162 3637 4059 5162 Expired Bottom Outside 10,694' 5792 5161 3641 4056 5161 Expired ConclusiOn: Test conclusive, zone gas productive. Maximum bottom hole temperature 160°. 74 pcf August 1, 1973 Ran 2 7/8" sawtooth collar and cleaned out sand bridge at 10,714'. Could not circulate below 10,731~. Plugged casing as follows: Cement Job No. 3 Equalized 45 sacks of "G" cement. Treated with 0.75% CFR-2 through open ended drill pipe at 10,731'. Preceded by 10 cubic feet of water. Displaced with 339 cubic feet of water and mud. Pulled to 10,431' and backscuttled out trace of cement. Cement in place at 7:40 a.m. 74 pcf August 2, 1973 Ran 5 5/8" bit, 6 5/8" casing scraper, and located top cement at 10,482'. Drilled out hard cement to 10,640'. 74 pcf August 3, 1973 Made up Go-International 7" lubrictor. Jet perforated two 1/2" holes per foot with 3 3/8" O.D. gun and charge as follows: 10,628 to 10,608 10,594 to 10,566 10,535 to 10,493 10,478 to 10,450 10,436 to 10,422 10,408 to 10,377 40 holes 56 holes 84 holes 56 holes 28 holes 62 holes 74 pcf August 4, 1973 Ran 5 5/8" bit, 6 5/8" casing scraper to 10,640'. Conditioned out. Go- International. Ran Baker Model "D" packer. Packer stopped at 10,565', collar locator at 10,557'. Hole tight. Pulled. Left rope socket, collar locator, setting tool, and Baker ~odel "D" packer in the hole. 74 pcf August 5, 1973 Ran 5 5/8" x 6.83 overshot - dressed with 3 1/4" grapple and bumper jars. Pushed fish to 10,630'. Engaged fish. Pulled and recovered all of fish. Ran in with reamer and reamed to 10,366'. 74 pcf August 6, 1973 Reamed to 10,640' circulated out. Ran Baker Model "D" 6 5/8" packer. Packer stopped at 10,586' because of tight hole. Pulled left rope socket, collar locator, setting tool, and 6 5/8" packer in hole. Top at 10,574'. 74 pcf August 7, 1973 Ran 5 5/8" x 6.83' overshot dresses with 3 1/4" basket grapple, bumper sub, and jars. Pushed fish to 10,630'. Engaged fish pulled to 10,610'. Packer hung up. Jarred tree. Pulled and left Model "D" packer in the hole. August 8, 1973 8,! · Ran 5 / O.D. x 4 1/2" I D. mill with 3 1/4" packer retriever. Located packer at 10,610'. Milled 2' over packer. Pulled and recovered packer. 74 pcf August9, .1973 Ran 5 5/8" bit and tandem 6 5/8" scrapers. Reamed to 10,640'. Hole tight from 10,640' to 10,460'. Circulated· : 74 pcf August 10, 1973 . ~n Dia-Log minimum I.D. profile log from 10,640' to surface. 74 pcf August 11, 1973 Ran 5 5/8" O.D. swadge with'bumper sub and jars to 10,640'. No tight places, pulled out.. Ran Baker 6 5/8" Model "D" packer on 2 7/8" tubing and set at 10,602' E Log depth. Packer positioned with Go-International. Ran Neutron Collar Log. ~ 74 pcf August 12, 1973 Made up production jewelry. Unable to broach tubing. 74 pcf August 13, 1973 Laid down 341 joints of tubing due to internal scale. Picked up new 2 7/8" tubing. 74 pcf August 14, 1973 Ran 2 7/8" production tubing and hydro tested to 5000 psi. Spaced out and landed tubing with Cosasco plug installed. 74 pcf August 15-16, 1973 Removed Class III BOPE, installed tested x-mas tree. Pulled Cosasco. Dis- placed drilling~fluid with lease crude oil by circulating down annulus and through sliding sleeve at 10,334' and up tubing. Closed sleeve at 10,334'. Pressure up annulus at 2100 psi and set packers. Released rig ~t 4 p.m., August 16; 1973. 74 pcf J. W. Wilson 6.6 $$ .,>-- CAI~O 3,458.~' -~ C~ 38 . ___ ._&,652.~'- 27 , ~{ ~ . 12.94~ L :.. '~~ / · 7 6~'~ ] ':: "11,7 ~. ~" E~ 8~ TUB~G 3~.~' 10 334. ln'~ ~, wso . :.-' ":'-'~0,~9-53'~.C~ "CC" S~TY /u~414.u4 .... :lO.Zlq.~, ~ ~O~ ~16-1 10,~7.~ B~R B~T ~. 10.05 ' ~"~*~' ~ ~T ~. 20.31' ~P ' ~ B~T ~. 4.81 ' B~R ~T ,~,[,~ ' B,~ B~T '~ ~10,5~.04' ~- ~'~ . . ,~,~.w ~OT~ =S ~,~,~ ~t. ' '1 =. ' ' ~os~10,597.8~'~~ "v~ ~~ 3.16' ~ u. ~ub 1.00' '~A~ 1.2~L D P,,C:~q 2~' x 2=' S~ ~Y. .250' OD 6.35' ' C~.~O ~ I, P~ - . · 91 ' TOP of PLUG * 10,6~' T.D. 10,~ Form P--3 /f~ Stabrntt "Intentions" in Triplicate / ~. ~V. 9-~9 ' ' ~ "Su~quent Repo~s" ~ Dupli~te STATE O'F A~KA %.~m N~c~ CoD~ OIL AND GAS CONSERVATIO'N CO'MMI~EE SUNNY NOTICES AND REPORTS ~ W~ ~ 028990 Us~ "AP~hlCATION'Fo~ ~'E~iT~' ~or s~ch'p~o~osalS.) . . ~[LL W~L~ ~ OTHER , Stan4_a ra Oil Co~gan~ o~ .Cal$~orn!a, ~.0. z. Sol~o~na 'Creek P.O. Box ?-839, Anchorage, ~l~ka 99510 SCU 14-34 At surface 660' North and .670' East from Sou~west corner gwa. n~nn R~v~r 11. SEC., T., R., M., (B~OM HO~ ~ ........ of Section 34, T-8-N, R-9-W, SB&M o~m~v~ FILE: Sec. 34, T-8-N, R-9-W, 13. C , 151 ' KB 60-38 ~4. Check Appropriate Box To I,nd',i,cate Nature of N~tice, Re ~ort, or Other Data ' NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT ~~ ABANDONS REPAIR WELL CHANOE PLANS ~ Other) , , WATER SHUT-OFF B REPAIRINO W~ILL ~ FRACTURE TREATMENT ALTERING CASING 8HOOTINO OR ACIDIZINO ABANDONM~NT* (Other) (.NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (CleaI'ly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. Pro~o sal : SCU 14-34 has been shut in for several years because of high WOR and GOR. The producing intervals in the well have been segregated with multiple packers. Recent test gauges of the lowest interval (the 'H8-9 sands)'are nearly 100% water. The H9 sand is suspected as the water source because of the lack of nearby gas injection. While the workover is being done, the H10 sand will be perforated and formation tested. Program: Kill well, Install 10", 5000# BOPE and test to 5000 psi. Pull tubing and packers. Drill out plug from 10,729'-10,750'. Squeeze the perforated interval from 10,642'-10,660' with cement. 'Drill out cement. Pressure test perforations to 2500 psi. Perforate 6 5/8" casing from 10,708'-10,721' with four 1/2" jet holes per foot. Run cased hole formation test on perforations from 10,708'-10,721'; if interval is productive run 10,721' of 2 7/8" x 2 3/8" tubing with packers at 10,340', 10,492', 10,540', 10,601' and 10,636'; if interval is not productive, squeeze perfo~.~a~o~~~ 10,708'-10,721'. Run 10,633' of 2 7/8" x 2 3/8" tubing with packer~t~_~~'~~li~ 10,492', 10,540' and 10,601'. Return well to production. U% ~ ~S~a TITL~ Area S~pervisor Di~~e/~, ~973 16. I hereby certiff~tha, t th,~ ~oregg~Pt is ~ue and correct (This space ~ State~'~;~l/ - CONDITIONS OF See Instructions On Reverse Side Approved Retumed ~i a ,CHORAGE ° ALASKA P. O. BOX 7-839 ~ ~)~3 PRODUCING DEPARTMENT TELEPHONE BR. 7--6201 C. V. CHATTERTON DISTRICT SUPERINTENDENT CONFIDENTIAl] COMPLETION REPORT - Pa~KER AND GAS LIFT INSTAIJuATION ' SOLDOTNA CREEK UNIT 14-34 Page 2. SECTION 34,~ T. 8 N., R.~ ~ w:Lt _Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR O_ctober 27..~, 19,~2' Started moving rig at 11:00 P.M. October 28, 1962 Moved rig and rigged up. 0.ctober 29, 19,62, Conditioning mud and repairing drawworks. 09t..o.~er 30, Killed well with 84~ Black Magic mud. Pulled 2 7/8" tubing out of hole. Removed x-mas tree and installed BOPE. 0c...to~er 31,,,_ !~9~2 Ran casing scraper. mandrels° Reran 337 joints 2 7/8" tubing equipped with packer and K.B. to landing flange Landing flange 49 joints 2 7/8" Camco MM mandrel 45 joints 2 7/8" Camco MM mandrel 40 joints 2 7/8" Camco MM mandrel 32 joints 2 7/8" Camco MM mandrel 29 joints 2 7/8" Camco MM mandrel 26 joints 2 7/8" Camco MM mandrel 27 Joints 2 7/8" tubing w/RD valve tubing w/RD valve tubing w/RD valve tubing w/RD valve tubing w/RD valve tubing w/RD valve tubing Camco MM mandrel w/CEV valve 78 joints 2 7/8" tubing Camco. Sleeve valve i joint 2 7/8" tubing Brown CC safety joint Pup joint Brown 2 7/8" X 6 5/8" HS-16-1 packer 2 Joints 2 7/8" tubing Camco D nipple 8 joints 2 7/8" tubing Venturi shoe Tubing Landed At: TUBING DETAIL K~ B. Depth 17.00 .8o .17.80 1558.33 1576.13 13.oo 1589.13 1421.46 3010.59 13. co 3o23.59 1263.09 4286.68 13.05 4299.73 1008. o8 53o7.81 13.o3 532o.84 915.60 6236.44 12.96 6249.4O 824.20 7073.60 13.08 7086.68 696.22 7782.90 13. oo 7795.9o 2458.31 10254.21 2.62 10256.83 30.45 10287.28 1.CT 10288.35 10.25 10298.60 5.92 lO 3O4.52 63.19 10367.71 · 92 10368.63 252.46 lO621, o9 · _65 10621.74 i0, 621.7~ COMPLETION REPORT - pACKER AND GAS LIFT INSTALLATION SOLDOTNA CREEK UNIT 21-3~ SECTION 34~ T. 8 N.~ R. 9 W.~ Seward B & M STANDARD OIL COMPANY OF c~LIFORNIA, WESTERN OPERATIONS' Page - Total 337 joints 2 7/8", 6.5~, N-80, EUE 8R Rg 2. November 1,.. 1962 Removed BOPE. Reinstalled and tested x-mas tree with 4500~ psi - OK. Black Magic mud with oil and flowed well. Set packer at 10,299' .~ Displaced Rig released at 1:00 P.M., November 1, 1962. Returned well to production. SR~: pb -/ - UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE' S .. MONTHLY REPORT OF OPERATIONS State ............ K~skg: ......... County ....... K..e.n__a. i.. _Pcn±~T._~..a ~eld ........ ~W~SO_ n ._~Y~ .................. T~e follo~n~ is a correo~ report of operate;o'ers a.n.d prod~,ctio~ (i~ch,lin~ drillin~ and produ, cin~ wells) for tke montk of ............. P~O_~r .................... 19._~ .................... ~.9~na Crsek._P~t .................... 8N WELL No. (6) I Remedial work Btaok ~gie ~, 2 7/8" t' moved ~FE ~ Set ~ck~ro ~ ~g released N Richfield Files 3h ~-ommenced October ~, 19620 Killed well with ~. Pulled j2 7/8" t~Ubingo R.~n casing scraper. ~bing equi~d wit~ ~acker.. Landed tubingo Re- reinsb~ll~d x-mas ~ eeo Displaced mhd with oilo ~turn~d w.~_~ 'bo production. ~vembe r 1, -M. H. Soyster · B. ~ruce - c. I w. Perry Ro ! R. RAtter reducing 1962. NOV 8 Petroleum Branch k Division of Mines and Minerals laska Dept. of Natural No~l~.~There were ........................................ rum or sales of oil; ................................................. M cu. ft. of gas sold; ............................................. runs or sale~ of gasoline durh~g the month. (Write "no" where applicable.) NoTE.~Report on this form is required for each calendar month, regardless of the status of operations, and mus~ be filed in duplicate with tho supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. (~alztl~ry 1~0) ' 11)---267t~5-6 u.s. ~ovz~:~T ~qi.T~o oPFlc~ ORIGINAL COMPL~TION REPORT - NEW ~ELL 8TAN~ OIL CO.ANY OF CALIFORNIA - WESTERN OPEP~TIONS INC. - OPERATOR ._ . AREA: Ken~i Peninsula, Cook Inlet Area: Alaska PROPERTY: Soldotna Creek Unit LAND OFFICE: Anchorage LEA. SE N0~: 028990 ~LLNO.: SCU 1~,34 I~TION: Surface: Section 34, Township 8 north, Range 9 west, Seward 660' N. & 670' E. from SW Corner Sec. 34 (ProJ.) T. 8 N., R. 9 W., Seward B & M. ELEVATION: 151' K.B. DATE: February 21, 196I DRILLED BY: Reading and Bates Drilling Company DATE COMMENCED DRILLING: October 30, 1960 DATE COI~PLETED DRILKKNG: December 23~ 1960 DATE OF INITIAL PRODUCTION: January28, 1961 PRODUCTION: Daily Average 490 Flowing Oil 485 Gravity 37 7° lee.ee.... ®e.... Water 5 TP 17'75 t..-.... G~s .......... 80 Bean ......... 8/64 SUMMARY TOTAL DEPTH: 10,870' PLUGS: 10,870- 10,729' JUNK: None. CASING: 20" Conductor cemented at 28'. 13 3/8" casing cemented at 2981' in 2 stages: 6 5/8" 1st Stage around shoe with 600 sacks. 2nd Sta~~ethrough DV at 1478' with 1200 sacks. casing cemented at 10,866' in 2 stag~s: 1st Stage around shoe with 600 sacks. 2nd Stage through DV at 8~95' with 600 sacks. COMPLETION REPORT - PACKER AND GAS LIFT INSTAI~TION STANDARD OIL COMP~ OF CALIFORNIA - WESTERN OPERATIONS INC.. - OPERATOR AREA: Kenai Peninsula, Cook Inlet Area, Alaska pROPERTY: Soldotna Creek Unit LAND OFFICE: Anchorage LEASE NO.: 028990 -. ~ NO.: SOU 14-34 Section B4, Township 8 North, Range 9 West, Seward B~M. LOCATION: Surface: 660' N., & 670' E. from S.W. Corner Section 34 (Proj.) T. 8 N., R. 9 W., Seward B & M. ELEVATION: 151' K.B. DATE: April 2, 1963 CONTRACTOR: Santa Fe Drilling Company, Rig ~35 DATE COMMENCED REMEDIAL WORK: October 21, 1962 DATE COMPLETED REMEDIAL WORK: November 1, 1962 SUMMARY TOTAL DEPTH: 10~ 870' PLUG~: 10,870 - 10,729' CASING: 20" cemented at 28' 13 3/8" cemented at 2981' 6 5/8" cemented at 10,866' COMPLETION REP~ ORT SOLDOTNA CREEK UNIT 14-34 Section .34, T' 8 N,, R. 9 W., Seward B & M STANDAaO OIL CO' OF CALIFORNIA, W.O.Z.' ..... bPw~RAT6~ Page 2. PERFORATION REcoRDs: 3. 4. 4-. 5. 6. 7. 8. 9. i "' Jet holes -" Jet holes i" jet holes · " jet holes -" jet holes i" Jet holes · " jet holes " jet holes "jet holes lO, 369 '- 10,669 - 10,670'. per foot 10,377 - 10,412-'. per foot 10,420 - 10, ~37'. per. foot 10,444 - 10,478' per foot 10'493 10,535'[ per foot 10'566 - 10,601'. per foot 10,605 -~ 10,633' per foot 10,642 10, 660' [ ~LL SURVEYS: 6. 7. 8. Schlumberger LES log, interval 2998 - 100'. Schlumberger Sonic log, interval 2996 - 100' Schlumberger IES log, interval 10,873 2998~. Schlumberger Sonic log, interval 10,870 - 2995' · Schlumberger Micro log, interval 10,873 - 9000'. Schlumberger Neutron Collar log, interval 10,729 - 8400' Schlumberger Cement Bond log, interval 10,729 - 6600'. Baroid Mud Logger interval 8500 - 10,870'. DRILL STEM TESTS: 1. H.C.T-WoS.O. on perf~d, interval 10,369' W.S.O. 2. H.C.T.W.S.O, on perf'd, interval 10,669 -~ 1~,-~70' W.S.O. 3. H'C.T, Prod. Test on Perf'd. interval 10,642 - 10,6~-0" ~ COMPLETION ~?ORT SOLDOTNA CREEK UNIT 14-34 Section 34, T. 8 N.~ R..9 ?~ Seward B & M STANDARD 'OIL CO. OF CALIFORNIA, W.O.I, - OPERATOR Page B. October 30' 1960 Spudded 4:00 AM 10/30/60. Drilled 12{~'' hole 25 - 437' October 31, 1980 Drilled 12~" hole 437 - 2,676' November l, 1960 Drilled 12~" hole 412' drilled 2239' drilled 78 pcf mud 2,676 - 3,000' 324' drilled Conditioned mud. Ran Schlumberger I-ES log~ interval 2998 - 100'; Sonic log 2996 - 100'. Opened 12¼" hole to 18 5/8" hole 25 - 281' 256' opened 78 pcf mud November 2, 1960 Opened 12~." hole to 18 5/8" hole 28I - 2~ llO' 1829' opened 80 pcf mud November 3- 4, 1960 Opened 12-~" hole to 18 5/8" 2~ llO - 3, O00' 890' opened Circulated and conditioned, mud. Ran 13 3/8" casing. Cemented 13 3/8" cmsing at 2981' in two stages with 1800 sacks construction cement using Halliburton Power Equipment. Pipe froze at 2981'. !~st St~ag~.: with 600 sacks around shoe. Mixed in 35 minutes and dlsplaced in 30 minutes with rig pumps. Pumped ~0 bbl' water ahead. 800 psi working pressure~ 1600 psi final pressure. Good circulation throughout. Avera. ge slurry weight llT~. COMPLETION P~ORT SOLDOTNA CREEK U~IIT 14-34 ~ect~.n~ 34~ .T~'.~8 N., R. 9 W~, Seward B & M STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR Page 4. November 3-...4;. 1960 C.o_n_t.i.n_u_e__d ~n~d_ ~St~ge: with 1200 sacks through DV Collar at 1478'. Mixed in 70 minutes. Displaced in 15 minutes with rig pumps. Pumped 50 bbl. water ahead. 800 psi working pressure. Closed DV Collar with 1500 psi final pressure. .Vull circulation throughout and good cement returns. CASING DETAIL: All 2984' or 74 jnts. Above K.B. 3 Landed at 29~' _November .5~. 1960 Flanged up. Installed BOPE. at 1477'. Tested with 1600 psi OK. November 6, 1960 Drilled 12-~" hole 3,000 - 3,785' Drilled l0 5/8" hole 3,785 - 3,849' ~ovember ~7, ~196~ Drilled lO 5/8" hole Tested to 1500 psi OK. Drilled out shoe. 785' drilled 64' drilled 3,849 - 4~100' 251' drilled Brake band bolts stripped. Blocks fell on floor. temporarily. Made trip out of hole. Waited on repairs. 78 pcf mud Drilled out DV Collar 78 pcf mud No~ember 8, 1960 Waiting on repairs. November 9~ ~960. Drilled lO 5/8" hole 4,100 - 4,556' 76 per mud Worked on brakes, welded 76 pcf mud Completed repairs on evening tour. 456' drilled Ran in hole. 76 p cf mud COMP ~L~TION REPORT SOLDOTNA C~ UNIT Section 3~, T. 8 N,, ~R.....9 W.~ Seward B & M STANDARD OIL C~' 0F CALIFORNIA, W.O.I. - OPERATOR Page 5. November l0 - December ~ 1960 · : : ,. ,~L J ,, ,.~ ,,, , , Drilled 10 5/8" hole 4,556 - 10,778' 6222' drilled Mud logging unit installed at 1:45 AM 11/24/60. Commenced logging at 8500'. December 9,..._1960 Drilled lO 5/8" hole 75 - 100 pcf mud 10~ 778 - 10,870' 92' drilled Ran Schlumberger I-ES log, interval 10,873 , 2,998', Sonic log interval 10,870 - 2995' Microlog interval 10,873 9000' , " . 101 pcf mud December.10- ll~ 1960 Conditioned hole to run casing. Laid down DP & D.C.s. Ran 6 5/8" casing landed at 10,866'. Cemented 6 5/8" casing at 10,866' (casing froze 4' off bottom) with 1200 sacks of construction cement treated with O. 3% HR-4 retarder, using Halliburton Power Equipment. 1st Stage: around shoe with 600 sacks of cement. Circulated one hour. Pumped 50 bbls. of water ahead, mixed 600 sacks of cement in 35 rains, with Halliburton truck, displaced in 30 mins. using rig pumps. Average slurry weight llT~. Bumped plug with 1400 psi. Full circulation. 2nd Stage: through DV Collar at 8495', with 600 sacks of cement. Dropped DV bomb, opened DV ports in 65 rains. Pumped 50 bbls. of water ahead, mixed. 600 sacks of cement in 40 mins. using Halliburton truck, displaced in 35 rains, with rig pumps..: Closed DV ports with 2600psi. Average slurry weight llT~. Full circulation. CASING DETAIL: Top Next Next Next Next Next Next Next Next Bottom __ _ 2 joints or 84.80' 1 joint or 6.93' 152 joints or 6578.88' 1 joint or 6.8l~' 45 ~.oints or 1836.05' DV Cdl!ar or 2.00' 40 Joints or 1647.51' 3 joints or 123.44' 1 pup joint ' 14. ~2' Ali Above K.B. Landed at 263 Joints or 10, 88~. 94 ' 19.94' 6 5/8" s8~, ~ zzo, 8 R 6 5/8" 28~, P 110,, X-over 6 5/8" 28~, N-80, 3.T. 6 5/8" 2~, P 110, X-over 6 5/8" 2~ P 110, 8 a 6 ~/8" 2~, P 110, 8 R 6 ~/8" ~, ~ ~o, 8 R 6 5/8" ~, ~ zzo, 8 R 6 5/8" 2~, ~ zzo, 8 ~ Equipped ~h B~er Flexiflow shoe and float collar, ~lliburton DV Collar at 8495'. 100 p cf mud Page 6. Decembe~r..t2,.. 1960 Removed BOPE. Cut of 6 5/8" casing put packing in place, tried to pressure up, would not hold over 500 psi. Pulled out secondary packer and installed new rubber' gaskets. Set BOPE down, pressure tested to 3500 psi for 30 mins. OK. Flanged up BOPE. Tested blind rams to 1500 psi OK. Commenced picking up DCs and D.P. Decembe.~ 13, 1960~ Completed picking up D.P. D.O. cement and DV 8470 - 8~95'. 2700 psi for 15 mins. OK, Ran to top of cement at 10,732' conditioned mud prep. to run logs. Tested DV with · Circulated and Decem~b_er 14~ !960. Ran Schlumberger Neutron Collar log interval 8400 - 10,729' and Cement Bond log interval 6600 - 10,729'. Ran Schlumberger jet gun and perf'd. 5 - 2 holes at 10,369'. H.C.T.W.S.O. ~1 on 5 - ½" jet holes at 10,369'. Tool assembly as follows: 2 outside BT recorder, 5' of Perfs., 6 5/8" Type "C" hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester, and dual closed in Valve. Used 2410' of water cushion. Ran on 10,324' 2 7/8" EUE tubing. Set packer at 10,341', 17' of tail to 10,358'. Opened tester at 1:36 PM for 35 min. ISI pressure. Puff blow of air then dead for balance of test. Opened tool to surface at 2:11 PM for one hour flow period. Closed tool at 3:11 PM, for 30 min. FSI pressure. Pulled packer at 3:41 PM. Recovered 10' net rise all drilling fluid. Charts indicate tool open. PRESSURE DATA: IH ISI IF FF FSI FH Top Inside BT Bottom Inside BT Top Outside BT Bottom Outside BT 6384 1539 llSO llSO 1255 6384 6383 1514 1183 1183 1257 6383 6458 1527 1122 1122 1239 6458 6453 1531 1137 1132 1244 6453 W.S ~0. OK. Ran Schlumberger jet gun and perf'd. 5 - ½" holes at 10,669 - 10,670'· 93 pcf ~d December 15, ~. 1960 HUT W.S.0. ~2 on 5 - ½" jet holes at 10,669 - 10,670'. Tool assembly ~s before on 10,608' of 2 7/8" EUE tubing used 2538' of water cushion. COMPLETION REP. ORT SOLDOTNA CREEK UB~T 14-34 S~ecti0.n 3~,_. T, 8 .N., R. 9 W,., Seward B & M STANDARD OIL CO.. OF CALIFORNIA, W.O.I. - OPERATOR Page 7- December 15,~ 196© C_o__nt_i__nu_e_d_ Set packer at 10,625, 17' of tail to 10,642'. Opened tool at 5:03 AM for BO min. ISI pressure. Puff blow then dead. Opened tool to surface at 5:33 AM, for one hour flow period. Dead. Closed tool at 6:33 AM, for 35 min. FSI pressure. Pulled packer loose at 7:08 AM. Recovered 10' net rise all drilling fluid (with trace of oil). Charts indicate tool open. PRESSURE DATA: IH ISI IF FF FSI FH Top Inside BT Bottom Inside BT Top Outside BT Bottom Outside BT 6570 4577 1177 1191 4679 6570 6548 4578 1147 1159 4688 6584 6671 4640 1174 1186 4743 6671 6656 4627 1176 1186 4737 6656 W.S.O. OK. Ran Schlumberger Junk pusher to 10,725'. Ran in with strip gun to 10,400' and hung up. Ran in with junk pusher to 10,531' and stopped. Ran in with 5 5/8" bit to 10,500' and broke circulation. 87 p cf mud DeCember.. !6z 196.0 Circulated and conditioned mud to 10,729'. Ran Schlumberger Jet gun and perf' d. 4 - ½" holes per foot interval 10,642 - 10,660'. Halliburton Formation Test ~1 on perforated interval 10,642 - 10,660'. ~Tool Assembly: Same as on W.S.O. tests except 10' perf'd, tail pipe. Ran on 10,579' 2 7/8" EUE tubing. Used 2538' (27 stands) water cushion. 5/8" bean in tester. Set packer at 10,596' with 22' of tail to 10,618'. Opened tool at 5:42 PM for 46 minute ISI pressure. Light blow and dead. Opened tool to surface at 6:28 PM. Immediate light blow to dead after 36 minutes (7:04 PM). Pulled packer at 7:35 PM to reset packer and wash perfs. Reset packer at 7:47 PM. Immediate light blow to dead after 16 minutes (8:03 PM). Shut-in for final shut-in pressure at 8:l0 PM, for 30 min. FSI. Pulled packer at 8: 40 PM. .Back-. scuttled rise to sump and obtained samples. Mud Filtrate Salinity 74 G/G. Samples Cut./Tot. Water 'Emulsion SD. & MD. Water Salinity 1 80.0 73.0 2.0 5.0 al 2 100.0 100.0 0.0 0.0 74 G/G 3 24.0 0.0 22.8 1.~ ~ 24.0 20.0 0.0 ~.0 20 ~/~ 5 30.0 0.0 29.4. O. 6 -- At Tool 90.0 0.0 0.0 90.0 -- COMPLETION REPORT SOLOOT~A CREE~ U~T 14-3~ Section~ 3~,' T. 8~., R. 9 ~W.,.Sew~rd ~ & M . S~~ b%L d6',"OF'~~$, "w'o~i$'. ' OpEmT0~ Page 8. Decem, ber 16'~!96o C.o__nt_i_n.u_e.d_ PRESSURE DATA- IH ISi IF FF FSI FH Top Inside BT Bottom Inside BT Top Outside BT Bottom Outside BT 637R 5463 5200* 6362 5456 5 340.* 6451 5516 5430-* 6437 5513 545O-* * Field pressures. Ch~rts indicate tester partially plugged. 52oo* -- 6372 5340-* -- 6362 543o.* 6451 5450-* -- 6437 Test conclusive. December 17, 196Q 88 pcf mud Ran Schlumberger junk catcher to bottom. Ran in 4 5/8" bit. C.O. to bottom. Circulated and conditioned mud. Ran Schlumberger Jet gun and perf'd. 4 -½" hOles per foot 10,633 - 10,605'; 10,601 - 10~566'; 10,535 - 10,493'. December 18 - 19, 1960 88 pcf mud Ran in with Schlumberger jet perforating strip gun, pulled off sinker and perforating strip. Fish consists of knuckle joint, 6" X 3" X 1/8" plate, 42' steel strip, and 2' lead weight inside of 3" galvanized conduit tube. Ran in with 4 5/8" bit milled on fish for 3 hours. Ran in 2 7/8" DP and put 30,000~ pressure on fish, would not move. Picked up 20' of 5~" O.D. wash over string. Washed over fish 10, 556 - 10, 580' and stopped. 89 pcf mud 'Decem~er~ .2.0.~.. 196o Picked up 37' more of 5½" O.D. wash over pipe. Washed over fish 10,580 - lO~ 585'. December 21, 1960 88 pcf mud Washed over fish 10~585 - 10,586' and broke through. Ran to bottom. Circu- lated and conditioned mud. Ran Schlumberger Jet gun and perf'd. 4 - 5' holes per foot 10,478 - 10,444'; 10,437 - 10,420'; 10,412 - lO~ 377' · Tore out Schlumberger, laid down wash pipe. 88 pcf mud December 22, 1960 Ran in with 4 5/8" bit on 2 7/8" D.P. to, 10,320', C.O. jet shot debris to 10,720'. Circulated and conditioned mud 2½ hours. L aid down D.P. Ran 334 joints of 2 7/8" tubing with Venturi shoe on bottom and Cosasco plug installed. Landed tubing at 10,546' with hanger at 10,529'. Tore out BOPE. Commenced installing Xmas tree. 88 pcf mud COMPLETION REPORT SOLDOTNA CREEK UNIT Section 34. T. 8,,N;~.,R. 9 W.,, Seward B & M STANI~ 0IL CO. OF CJILIFORNIA~ W.O.I. - OPERATOR Page 9. December 23~ 1960 Finished installing Xmas tree. Tested with 3500 psi for 15 mine. OK. Retrieved Cosasco plug. Commenced displacing mud with crude oil at 2:15 AM. Pumped 50 bbls. of water ahead~ followed with 345 bbls. of crude oil. Displaced through tubing with pressures from 900 psi to 1400 psi. Formation oil to surface at 4:~0 AM. Representative gauges: Flow Rates Total ~ ~ Bean Size ~-,i~~ .... Ga~_ .T~,.g.:,, Press. Csg. Press. Cut Mud S &_____~M 10/6~ 16~a B/,o 3oo MCF/,O 16a5 psi lSOO ps~. 2.o~ 2.o - 8/64 936 B/D 350 MCF/D 1750 psi 1600 psi 0. l~ - 0.1% Subsequent gravity 37.7°. Shut well in at 7 AM. Installed Cosasco plug. Shut in pressures; 1900 psi tubing pressure, 1750 casing pressure. Flowed a total of 235 bbls of Formation oil. Rig released lO:00 PM 12/23/60. JDK: LO COMPLETION REPORT SOLDOTNA CREEK UNIT 14-34 Section 34, T. 8 N., R. 9 W., Seward B & M STANDARD OIL 'C'O.' OF cALiF0~, W'.0'I. - OPERATOR Page 10. 73' 136' 406 ' 904, 1562 3485' 3785' 4317' 5590' 6065' 6432' 6648' 6 oo' 7049' 7621' 7738' 7911' 8052 ' 8217 ' 8272 ' 8368 ' 8500 ' 8625 ' 8735' 8868 ' 8973' 9o83' 92 34-' 9330' 9525' 9708 ' 9965' 10, 079 ' 10~ 326 ' 10,402' 10~ 538 ' 10~646' 10,730' t0,870' DEVIATION DATA: Degrees 0° - 00' 00 - 15' 0° - 45' 0° - 30' 0° - 30' 0° - 45' 0° - 45' 0° - O' 0° - 7' - 30" 0° - 15' 10 - 7' - 30" 10 - 30' 0° - 45' 1° - O' 0° - 0° - 45' 1° - O' 0° - 45' 1° - 15' 1° - 30' 1° - 45' 1° - O' 0° - 30' 0° - 45' 0° - 30' 0° - 30' 0° - 45' 0° - 15' 0° - 30' 0° - 15 ' 0° - 30' 1° - O' 0° - 30' 0° - 30' 0° - 30' 0° - 30' 0° - 45' 0° - 30' 0° ~ 45' 0° - 53' COMPLETION REPORT SOLDOTNA CREEK UNIT WELL 43-33 Section 33~ ...T.;....7 ..~;, R. 9 w;, .Seward B~& M STANDARD 'OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR Page 13. DEVIATION DATA Deoth ~eErees 219' 558' 2423' 2701 ' 3015' 3700" ~o5~ 4454' 4975' 5383' 5833' 62Ol, 6468' 6780~ 6980' 7126' 7263' 7315 ' 0O - 30' 0° - 30' 0° - 30' 0O - 30' 0° - 30' 0° - 7.5' 0° - 30' 0° - 7.5' 0° - 30' 1° - O' 1° - O ' 1° - 30' 0° - 45' O° -. 30 ' 1° - O' o° - 45' 1° - O' 1° - O' (Setting depth of first whipstock) UNITED STATES DEPARTMENT OF' THE INTERIOR G£OLOGICAL SURVEY Budget Bureau No. Approval expires 12-31-t~J. LAND OFFICE ____A~_ ~_ra~l~ LESSEE'S MONTHLY REPORT OF OPERATIONS The followi~ is a correct report of operations and prod[ection (incl~din~ drillin~ and prod~cinV~ wells) for the montk of .......... ~.~ ................ 19_.~Q_, ~ol~t~ C~ek U~t ............... J~ent's address ..... r ....0 .... ~ 7-8~ ................................. Compa~y .... ~cho~, A~s~ ___ Si~ne~ ....... ~ ~ ~ ........................ ~C. AND 311. TWP. 8N I GRAVITY [ GALLONS OF BARRELS Or [ REIvlARKS Y~%? Dl,s CU. F?. OF GA8 I GASOLINE WATER (If (I, drilling, depth: if ~hut d .......... ' ~ECOVERED llOlle: So $[;~t~) ~ date ~d roaul~ of t~t for g~oliae · . c.llt~ut of gas) RgW Drilled 1 "hol~' 9558' - 10,870~. ~n ~S, So~e a ~c~ ~gso Cemehte~ . "casl~ at 10,866' ~th 1200 sacks. Installed and tested ~E~. D.O. ~ and tested ~th 2700 psi, OK. ~n Neuron }ColOr ~g & Oe~nt '~nd ~g~ Es~blished W.S.O.'s at 10,369' and ~0,669 - 10,670'. ~ ~ on [:errs. 10,'6h2 - 10,660'. Reco~red ~ t ~1974~' net ~se, all oil ~xed ~th ~ter cuS~on. Jet perf'do ~ - ~-" holes per foot 10,633 - 10,605'; 10,601 - 10,566'; 10,535 - 10,4~3'. ~ stri9 ~ mud si~er';in hole.: ~lleO on fish~ Washed ove~ fish} pus~d j,~ t° bottom. ~et perf'id. ~ - ~" holes per foot ~o, ~¢8 - ~o, ~'; ~o, ~37 ~- ~o, ~o, ;. ~o,~m ~ ~o, 377'~ c.o. 2 7/~" tubi~ at 10~5~'.~ Ins~lle~ and tested ~s t~e. Disp~ced ~ma ~th Oilo Flow~a wen t~ou$ ~0/64" be~, 16~2 B/D oil, [~oo ac,/o~ ~, ~ ~ut, ~ ~a._ s~ ~u~.: ~9o0 ~.~ ~.~., U.S. So ' M*O ~d E~lo~tion / NoTs.--There were ....................................... runs or sales of oil; ...............................................M cu. ft. of gas soht; runs or sales of gasoline during the month. (Write" ~o" where applie~blc.) NoTE.--geport on this form is required for each ca. lend0.r month, regardlesq of the ,' ..... ::,f ,)l)erizt~ons, a~ld mus$ bo filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise direet~~I. "~3~ tl~e s,~pervS:~or. (January 1050) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOG ICAL SURVEY Budget Bureau No. 42-R3~6.5. Approval expires 12-31-00, L^,D omc~ .... .--A~---c-..~hg--r~--g~e- UN'? ...... ~~. O~ ...... LESSEE'S MONTHLY REPORT OF OPERATIONS Sta~e ......... ~.l__a_.s___k~._ ............. Go~nty Kenal peninsula Field Svanson River ......................... TAe followin~ is a oorreot report of operations a~ prod~ctio~ (incl~di~ drillin~ a~d prod~ein~ wells) for tke mo~tk of .......... ~.y~r .... 19 ~ , ~ot~ C~ek ~t .... ........... ........... ......... ~hP~g~-'~~ ............................. ~e~t's t~tl~~ ~r~e~ ~¢~*~g~~ ...... REMARKS ~ LP ~ ~ ~ Cu. F,. o~ O~s WATER (H (i~ drllli~, da~th; if shu~ d ....... ,; BAR~ O~ OIL ORA~Y (~ thou~nds) ItEcOvERED none, so state) ~EC. AND RANGE ~ DITS OASOLINR date ~d r~uit of t~t for ~ol~e , 3k 8~ 9W .lea m~" ~le 2~76 - 30~'o ~ ~ s~ So~c ~gs 2~ - 100'. 3/8" ~s~ at ~X'. i~tallea Oolh~ testes ~th ~ pal Drilled ~ e~ to 1~ pzio~ ~o0, ~ ~ cc -ti 011 lor~tiol I rs~er (3) ~char~ MurDhlL - C. I W. Perry MolLo ltill ~J~ .... Bishop R. [Jo Misbee] M cu. ft. ot' gas sold; runs or sales of oil; ................................................ NoTs.--Therc were __1 ................................... ............................................. runs or sales of gasoline during thc month. (Write "no" where applicable.) filed in NoT~.~I~eport on t~his form is required for each calendar month, regardless of t~he status of operations, and must b0 duplicate with tho supervisor by the 6th of the succeeding month, unless otherwise directed by the/ supervisor. 1C--25766-$ O. $. ~.,.,VERNM~ItT PRINTING OFFICE For~u 9-329 (January 1950) ;,,,s :i!., (SU~MIT, IN TRIPLICATE) ONITED STATES DEPARTMENT OF TH~ INTERIOR /s~ . Bt~lget Bureau N'o. 42-I1358,4. A ppr~val o~xpi r~- 12- 31.,80. RECEIVED ~ OC~ 13t~O SUNDRY NOTICES AND REPORTS ON WELLS : -~:: ~ . ,. , ' ]:' ' ! ~ - - '" a,,-~ NOTICE O~ INTENTION TO DRILL ._ ~:-....,~.. .............. ,: ,' ..... ~..X~ _[, SUBSEQUENT REPORT ~ WATER SH~EF ........ NOTICE oF INTENTtO~ TO CHAN~ PiAnO.' .................. ~(; SUBSEQUENT REPORT OF SHOOTING OR ACIDIZI~ ......... : ....~ .... NOTICE OF INT~-TI~ TO TES~ WATER SHUTOFF j~ ~BSEQUENT RE~RT OF AL~RING CA5~ .:~_::: ................ NOTICE ~ INTENTION TO RE-DRfLL'OR REPAiR WELL ....... , SUB~QUENT REPORT OF RE-DRILLING OR REPAIR NOTIce OF IN~ENTION TO SHOOT OR-ACIDIZE ................ ~ ...... SUBSEQUE~ REPORT OF ABANDONMENT ..... ' ................. '"NOTI~ ~ INTENTION TO PU~ Or ALTE~ CASING _.:,::_.;.... : .... :' SUP~EM~TARY WELL HISTORY ................ : NOTICE OF ~NTE~T~On TO a~a,eon WELL ..................... i ......]~ ............... ' ................................... j ....... :-.~..: ............. .,:~ ................................. . ,~ ---;5-"~;;':~~ ........ .. rlNDICATE ABOVE BY CH~CK MARK ~]ATURE OF RE~OR~, NOTICE, OR O~HER DATA) Well No. - The ~levation of the derrick fl~r'above sea ~vel is l~__ ft. (~~) ~ ~" DETA I LS~ OF WORK . . (State n~mes ~ a~d ~ pec ted de pt hs '~0 05~i~e ~ands~ s~ow si~es, wei~hti,..nd lengths ~ pro~d cssi ng~;, ndical~ m uddlnl jobs, cement- ;._. jng points, and all other im~rta~t propo~d work) -... ~.:-.~-~ ~., ~ ~ ~ ~ ~8" lam a 7/8" tmh:u,e sat ea,,pt,~. I ~et'~tand that this plan of work must receive.approval in wrltinI by the ~loi~.~ai 5ur~ey before operations may be-co,nmenced. . Company .'l~iMl~ll~ ~ ~Alff.~.~ ~ _~~t..3~.~..~...,.,. ............... · ~Title ,~lddltlildl~ GPo 8 62040 'Oil & Gas Section · '~--'-: .... { Mines and Miner UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budgpt Burpau No, 12 Iia56,',. Approval expires I2-31-~J. LA"D OFfiCE ...~~ge LEASE NU~,"~ ~~ ............. LESSEE'$ MONTHLY REPORT OF OPERATIONS State ....... ~s__ka_ ............... County ___K.?~_i__..pen!' n~ula F~etd Sweden River The folIowi~ is a correct repor~ of op(.'ratio~s a~d prod~ctio~ (incl~di~ drilli~ and prod~cinff wells) for the month of ......... October ............. ~6g_ ............ $~on ~ver · ~..o..~ ~-~ ~~o~~ ~~~o ~, ..... ......... s~ '~uaa. a ~':oo ~ ~o/~o/~: ~ ~ ' Drinea ~" ~oze t& 2676'. NotE. There were. ........................................ runs or so, les o£ oil; ................................................ M cu. ft. o6 g,~s sold; ............................................ FUllS or sales of ga~:ol~ne d,,ri~:~ the monfb. (Write "no" why're No'r~. i{ei)ort ~,n tt~is form is re, luired for each calen(hw mcn, tiL i'mz~,r,'JJe~:~ of tho ~:'~'~1~1~ ,,f ~)p.~:':tt~o~', ad;d mu~t be ~led in duplicate with the supervis,)r hy tho 6th uf tim succeeding mouth, unless ot,l;erwise directed l,v (January i~ez. fs 37.7° APPLICATION F°R PERMIT TO DRILL~ DEEPEN OR PLUG BACK APPLICATION TO DRILL NAME OF COMPANY OR OPERATOR DEEPEN [] r City -DESCRIPTION OF' WELL AND LEASE %Vell number Name of lease 80! _cl_ot;na_~ T_lnt t PLUG BACK [] DATE September ~-9, 1960 feet State Elevation (ground) · 5o. _ · %Vell loc~tion (give footage from section lines) Section--township--range or block & survey : '6(~' :N and (:~:~-:~.-~.E~ of--S~ ¢oraer See, .~, ~. 8 ~.~ R, ~ W,:~ Se~ B ~ M Field & reservoir- (If wildcat, so sta~e) . . _ _. ~ J County . ~ver ~:eld ~ock Resedit [ Ke~i Pe~u~ Distance, in miles, and direction from nearest town or post office 16 ~~ ~°~h o~ ~~ · · ~ Nearest distaneo from Broposed location Distance from proposofl loe~tlon to noarost ~rllling, to property or loase !ino: eompleto~ or appHod~for well on tho ~amo loaso: ~0 feet ~650 ~roposed depth: Rot~ary or cable tools 10,900 ' Rotary Approx. date work will start October 15, 1960 N,'umber of acres in lease: Number of wells on lease, including this well, completed in or drilling to this reservoir: If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of bond Remarks: (If this is an application to deepen or plug bacl/, briefly describe work to be done. giving present producing zone and expected new producing zone) RECEIVED OCT 5 CERTIFICATE: I, the undersigned, state that I am the-- ....... A/J.~ Oil & Division of i'"/[h~cs and ;": - ~'l:nerals A1~1 ~ S~ OIL ~0. OF aALIiK)RNIA o~ the W~'~'~e~',~ Op,:r~ioas, (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts state~l~ttler~in ~are~true,~orrect and complete to ~r.,g;n.~ s~gnea the best of my knowledge. J.T. C~OOKER Permit Number: Approved By~-_~~"~--~- ii' _ ....... D. D. Bruce, Petroleum Geolo~st Notice:. Beforq-gt~l~il%g ilt t~Xorrrt..b~e ~u~ thaC~ you have given aH inftd~a~i0fl F~qti~. l~d~hl~/li~l~l~ary correspond- ence ~}~s[hj~s~p..vs{d~.atural Remurc.~ See Instruction on Reverse Side of Form Signature , _T T, Alaska Off and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. I Effective October 1, 1958
