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160-021
• IP RECE1V'ED • STATE OF ALASKA JAN 21 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLET N REPORT Ag6C la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ' Suspended' , 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑Q • Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband 1/17/2016 '' • 160-021 /315-718 3.Address: 7. Da a Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK K 99503 6/3/1960 50-133-10104-00 • 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 806'FSL,926'FWL,Sec 4,T7N,R9W,SM,AK 7/31/1960 Soldotna Creek Unit(SCU)314-04 • Top of Productive Interval: 9. Ref Elevations: KB: 160' • 17.Field/Pool(s): GL: 145' • BF: 143' . Swanson River/Hemlock Oil • Total Depth: acx,1 /7, ' 10. Plug Back Depth MD/TVD: 18. Property Designation: .847.FSL,315#''FWL,Sec 4,T7N,R9W,SM,AK 10,850'MD/10,850'ND FEDA028997 • 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 343081.9 • y- 2456758.9 • Zone- 4 .11,520'MD/11,520'TVD• N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 343223.7 y- 2456746.9 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes ['attached) No ❑✓ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/ND: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary oz. 6 N/A ✓/ n-- s c 377 77_ C-c l 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" Surf 30' Surf 30' 13-3/8" 54.5# J-55 Surf 3,005' Surf 3,005' 17-1/2" 600 sx+1100 sx 7" 23-29# N80 P110 Surf 11,041' Surf 11,041' 9-7/8" 24.Open to production or injection? Yes ❑ No ❑✓ 25.TUBING RECORD If Yes, list each interval open(MD/ND of Top and Bottom;Perforation Size SIZE DEPTH SET(MD) PACKER SET(MD/TVD) and Number): N/A N/A 10,296'MD/TVD N/A 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. SCANNE® `.ale2 3 2c j Was hydraulic fracturing used during completion? Yes❑ No Q Per 20 MC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A . Date of Test: 'Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: 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 —► Form 10-407 Revised 11/2015 `, CONTINUED ON PAcgE Submit ORIGINIAL only" 1 z -1%.t I, ,.1).-/f�f�� RBDMS LI- JAN 25 1916 . rz: z. , ✓� • • ,28.CORE DATA Conventional Core(s): Yes ❑ No Sidewall Cores: Yes ❑ No [✓] . If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No ❑� Permafrost-Top If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval information, including reports,per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Summary of Operations,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Joe Kaiser-777-8393 Email: ikaiser(C7hilcorp.com Printed Name: Chad Helaeson Title: Operations Manager Signature: /5/' Phone: 777-8405 Date: viih(4. INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange 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 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records 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. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. 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. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 314-04 Rig 169 50-133-10104-00 160-021 12/17/15 1/17/16 Daily Operations: 12/17/2015-Thursday Slickline job. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. Pressure test lubricator to 250 psi low and 2,500 psi high. MU 2-3/8" chemical cutter. RIH w/2-3/8" chemical cutter and tie into schematic. Make a correlation pass and figure out what depth the jewelry is. Figured if we make cut at 10,124' (per Baker instruction) that it would be in the Baker packer mandrel where it susposed to be cut. Spotted shot and severed mandrel in packer at 10,124'. Ran an after cut log and showed a good cut. Tools hung up around 10,100' but worked them free without much trouble. POOH. Cutter looked good.Well on a slight blow. Sent before and after cut logs to town. Rig down lubricator and turn well back over to field. 01/11/2016- Monday Hilcorp Swanson Orientation and bear training with all daylight personnel. Work on rig acceptance checklist. Troubleshoot Iron Roughneck. Repair#2 shaker. PT surface lines to lower IBOP (1,600 psi/test good). Set popoffs to 4K. Finish installing ground rods throughout rig and camp. Continue work on steam lines, test rig ESD's. Continue hauling water to rig and pits. Continue Pason upgrade. R/U to kill well. Fill gas buster. 0 psi or flow when opening up well. Bring pumps on @ 2.6 BPM w/no pressure. Pumped away 127 bbls before seeing significant pressure increase and returns. Circulated hole volume with minimum losses @ 4 BPM/474 psi. 5-10 total bbls oil w/slight gas back to surface, skimmed and hauled 45 bbls off for disposal . Lost a total of 198 bbls to well for entire circulation. Shut down pumping for 1 hr then filled the hole again to check static loss rate. Saw 1.2 bbl static loss rate. R/D circulating equipment. Blowdown lines, choke and drain gas buster. Install BPV (NOS-James Craycroft). Nipple down production tree. Install blanking sub over BPV in hanger. Modify cellar grating to accomodate 11" 5M flange diameter w/ DSA. Install 2' spool and set stack. Tighten flanges and begin hooking up flowlines and Koomey lines. 01/12/2016-Tuesday Continue to nipple up BOPs. MU choke and kill line flanges. RU accumulator lines to BOP stack and function test. Get stack measurements. Start to RU equip for BOP test. Pason hand got most all of the new updated equip installed. Finish RU to test BOPs. Perform pre-test to ensure everything would test for BLM in morning.Test w/3-1/2".Test annular to 250 psi for 10 min and 2,500 psi for 10 min.Test all other BOP equip 250 psi for 10 min and 3500 psi for 10 min. Change out test jt to 4-1/2" and do same tests on annular and upper rams. Built containment for mud products trailers on 22-4 Pad. RD 4-1/2" test equip and rig back up to test with 3-1/2". Cumulative losses to well 198 bbls. • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 314-04 Rig 169 50-133-10104-00 160-021 12/17/15 1/17/16 Daily Operations: 01/13/2016-Wednesday Start#1 BOPE test and wait on BLM inspector(no show). Contact BLM and inquire about witness. BLM Amanda Eagle waived witness on 1-13-16 at 9:58 AM. Inform AOGCC of BLM witness waived. Continue testing BOPE while waiting on AOGCC response. Mr. Regg w/AGOCC confirmed their decision of waive of witness of BOPE test at 12:46 pm. Continued testing BOPE as per regulations on 3-1/2" and 4" test jts 250/3,500 psi 10/10 combining pre-BOPE test charts and retest of gas detection system. RD test equipment and blow down lines and equipment. Muster both new crews at office for Swanson River orientation and wildlife refresher. Hold PJSM and break down test jt. Sand location. RU line from valve to choke manifold. Pull BPV. MU landing jt and RU to circ down tbg. Circ at 2.5 BPM and 180 psi. Hole took 20 bbls to fill. Got back about 1 bbl oil and it cleaned up. Circ 75 bbls and shut down. Shut in and blow down line. Back out LDS. Open valve. Pull 120K to unseat hanger and 145K to pull packer free,Attempt to slack off but pkr wouldn't go down. PU until hanger was above the table w/a constant up wt of 88K. Up wt when packer was landed was 80K so it is dragging 8K. Close annular and circ taking returns through choke and poorboy degasser. Circulating at 2.5 BPM at 165 psi. RU Weatherford equip while circ. Shut down an establish lost rate at 4.5 BPH. Have PJSM. Lay down landing jt and hanger. Blow down all TD and choke manifold. Started to lay down tbg and it started flowing back. RU and circ tbg vol. Blow down TD and POOH laying down 3-1/2" tbg. Daily losses to well 20 bbls. Total losses to well 218 bbls. 01/14/2016-Thursday Continue POOH laying down 3-1/2" gas lift completion f/9,300' t/5,000' w/pipe in good shape. Service rig, grease traveling equipment, check brakes and change filters in HPU while monitoring well w/ 1 BPH static loss rate. Continue POOH laying down 3-1/2" gas lift completion pipe still good shape both OD& ID and 10 bbls over cal fill. Continue POOH laying down 3-1/2" gas lift completion w/complete recovery. Last GLM was open. Pipe still in good shape both OD & ID . Hole took 14.7 bbls over cal fill for complete trip and no norms were nothing above background. RD Weatherford. Clear and clean rig floor. Load out all completion tools and clear location for E-line equip. Install 6- 7/16" wear bushing. Static loss during this time was .9 BPH. Hold PJSM and RU Pollard E-line. Flange on end of 7" lubricator was 12-1/4" so we had to make up a 3-1/2" tbg lubricator to set below upper rams. Run #1, run 6" GR to 10,175'. Didn't tag anything. POOH. MU running tool for CIBP. Run#2, RIH w/7" CIBP. Daily losses to well 15 bbls. Total losses to well 233 bbls. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 314-04 Rig 169 50-133-10104-00 160-021 12/17/15 1/17/16 Daily Operations: 01/15/2016- Friday Continue RIH w/ E-line run#2 w/7" CIBP and pull tie in pass f/ 10,175't/9,800' and set top of CIBP @10157'jmid jt). cAel Good indication of set and weight loss of 60#wait 5 min and log off(ok). RIH and set back down and confirm set @ 10,157' WLM RKB. POOH loss rate fell to zero inspect running tool (ok). Pressure test 7" csg&CIBP 10,1571t/ (O 1,700 psi w/ 102 gals on chart for 30 min w1 no_lossigood test) bleed off w/102 gals back. E-line run#3 and #4 w/5" dump bailer w/total 55 gals of NEO Super Slurry System 17ppg class "H" gray lid expanding cmt system for total cal footage of 35'. E-line RIH #5 w/6" GR tie into CCL log of CIBP set and tag.TOC started taking weight on green cmt @ d� 10,116' w/full set down @ 10,128' WLM RKB. POOH. E-line RIH #6 w/7" CIBP and pull tie in pass log on depth and set c.,,tgo` top of CIBP @ 7,413' ( 5'above collar of 44'jt):Good indication of set and weight loss of 55#wait 5 min and log off 146 (ok). RIH and set back down and confirm set @ 7,413' WLM RKB. POOH RD E-line. RU and test 7" csg to CIBP at 7,413' to 3,500 psi for 30 min on a chart.Took 153 gal to press up and bled back 151 gal. Good test with no bleed off. RD and blow down test equip. Started shimming the TD while testing. Note : 48 hr notice given of pressure test of csg witness waived by BLM Petroleum Engineer Mutasim Elganzoory and 24 hr notice given of cmt operations and tag of P&A cmt plug witness waived By AOGCC Jim Regg. Finish shimming.TD while moving E-line equip and bringing tubulars on location. Get ODs, IDs, and lengths of BHA. MU BHA and get first 2 jts of HWDP picked up. Jack and level derrick. Check torque on TD, iron roughneck, and tongs. Continue RIH. PU HWDP and DP. Had to steam out HWDP due to ice in tube and it wouldn't drift. Continue RIH PU DP. Putting 20 jts at a time on pipe racks and strapping them. Daily losses to well 2 bbls. Total losses to well 235 bbls. 01/16/2016-Saturday RI_H with whipstock mills. PU 4-1/2" DP to 7,413' and tag CIBP. Check crown saver and rig smart. POOH standing back DP to 3,020'. Service rig. Change out a couple hyd fittings on the TD. Set drilling torque at 14K. Strap DP. RIH PU 4- I' 1/2" DP to CIBP at 7,413'. Circ bottoms up. Running#1 mud pump to make sure everything was working good, then swapping to#2 to check it out to#2 pump not pressuring up. Swap back to#1 and finish circ. Work on#2 pump and get it running good.Attempted to POOH but it was flowing back. MU TD circ and mix salt pill. Daily losses to well 0 bbls. Total losses to well 235 bbls. Finished mixing all our 6% KCL PHPA 9.8 ppg mud. e Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 314-04 Rig 169 50-133-10104-00 160-021 12/17/15 1/17/16 Daily Operations: 01/17/2016-Sunday Continue circ build and pump dry job. POOH f/7,413' w/cal displacement. Service rig and open TDS elect box chk contacts. PU and move up BHA#2 BOT one trip whipstock window milling assy w/gyro data UBHO sub and scribe same (verify scribe, bolt and sheer screws). RIH slow w/ BHA#2 (one trip whip stock and window milling assy) filling pipe every 30 stds. Tag CIBP at 7,413' w/5K. Lay down 1 sng and PU a 15' pup. Set pipe in slips 1-1/2' off of CIBP. Hold PJSM w/e-line and gyro hands. RU e-line and warm up gyro tools. RIH w/gyro taking check shots every 1,000'. Latch into UBO sub and make 3 check shots, 213.30°, 210.72°, 210.74°. Turned pipe to the right 1/2 turn and took another check shot of 38.54°. Bumped the pipe back to the left and worked the pipe .Took another shot 24.71° and 24.58°. Took 2 more shots to check and they were 24.62° and 24.21°. Set down 5K and took one last check shot of 24.28°. POOH w/gyro. leaving wireline rigged up we picked up a 10' pup. Up wt 39K down wt 39K.Set down and shear bottom trip anchor at 125K. PU to 150K to ensure set. Set back down to 110K and shear bolt. PU and we lost 5K and whipstock was set. RD wireline and get equip off pad. Stage vac trucks and dragon tank in prep for displacing. LD pups and PU stand. Displace produced water with 9.8 ppg 6 % KCL polymer, taking produced water returns to skim pit. Pumped at 6.5 BPM and a final press of 1,219 psi. Mill window f/7,394't/7,402'. Pumping 6.5 BPM, 1,221 psi, 80 RPM, 6 to 8K ,. torque, 1 to 2 WOB. Avg ROP 2 FPH. Recovered 75 lbs metal. Daily losses to well 0 bbls. Total losses to well 235 bbls. This is the last report on the predrill portion AFE. STA12--7— t W 32z-c- . 0 • Swanson River Unit + Well: SCU 314-04 SCHEMATIC Completion Ran: 6/02/2005 Irlcorp Alaska,LLC PTD: 160-021 API: 50-133-10104-00 RKB:160'/GL:145'AMSL CASING DETAIL KB-THF:17.0' Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top .� * t� 20" Conductor Surf. 30' Yes Surf. 20" + 13-%" Surface 54.5 J-55 8RD Surf. 1,500 30' DV Collar 1,500' 1,503' 17-'/" 1,100 sx Surf. I 13-N" Surface 54.5 J-55 8RD 1,503' 3,005' 3,005' 600 sx 2,290'Calc 7" 29 Surf. 303' R '' 7" 26 303' 1,296' 13-3/8" 7" Production 23 N-80 BTC 1,296' 4,793' 5,720' 3,005' `! 7" 26 4,793' 6,306' 650 sx CBL 7" 29 6,306' 7,509' DV Collar 7,509' 7,511' 10 CBL TOC 11,040' 5,720' 1 7" 29 N-80 BTC 7,511' 7,996' tp> 7" 26 7,996' 9,654' , 7" Production 29 9,654' 9,662' 650 sx 9.105' n �, P-110 8RD CBL w klp AL" , ; 7" 26 9,662' 9,705' w * J: 1 7" 29 9,705' 11,040' JEWELRY DETAIL No. Depth Length ID OD Item CBLTOC «r', 1 7,413' 7"Cast Iron Bridge Plug(set for whipstock) 9,105' 41 a'42 10,157' 7"Cast Iron Bridge Plug Po k"r 3 10,281' - - - HES"EZ"Drill Cmt Retainer(Set on wireline 5/31/05) 4 10,296' - - Junk SAB Packer(Milled and Pushed to depth) 444 ia' tr g CBL TOC 10,116' gid = y+l G-1 1 41 Al .116alis T 3 44, 4 H_1 PERFORATIONS 4 4211011p ,.,' H-1 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments ++: q H-2 6/08/05 G-1 10,207' 10,256' 10,207' 10,256' 49' 6 2-1/4"Poweriet .. H-3 8/10/60 H-1 10,291' 10,297' 10,291' 10,297' 6' 4 H-5 8/10/60 H-1 10,302' 10,306' 10,302' 10,306' 4' 4 ;," H 7 1/14/00 H-2 10,318' 10,333' 10,318' 10,333' 15' 6 Reperf 1/14/00 8/10/60 H-3 10,354' 10,365' 10,354' 10,365' 11' 4 H-7 1/14/00 H-5 10,376' 10,432' 10,376' 10,432' 56' 6 Reperf 1/14/00 H-10 8/09/60 H-7 10,450' 10,456' 10,450' 10,456' 6' 4 7" H-10 1/14/00 H-7 10,464' 10,545' 10,464' 10,545' 81' 6 Reperf 1/14/00 11,040' -., 8/08/60 H-10 10,588' 10,655' 10,588' 10,655' 67' 4 TD=11,520' PBTD=10,850' 8/07/60 H-10 10,670' 10,674' 10,670' 10,674' 4' 4 Max Deviation=2.75 deg @ 7,147' Downhole Revised:6/08/05 Updated by DMA 01-20-16 OF Th. • • ,e,� 1%%%sv THE STATE Alaska Oil and Gas — :A ofLAsKA Conservation Commission yx 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS1)' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson k), 0 )-1 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 et Re: Swanson River Field, Hemlock Oil Pool, SCU 314-04 Ak,Allirl " t - 1?l Sundry Number: 315-718 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 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, Daniel T. Seamount, Jr. Commissioner J./— DATED this I day of December, 2015 Encl. RBDMSWEC o a MS 111 ' RECEIVED STATE OF ALASKA NOV 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 nG CI 1.Type of Request: Abandon ❑ Plug Perforations I J Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ,,i) Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing [IOther: _Prep for Sidetrack E 2.Operator Name: 4.Current Well Class: -0146 5.Permit to Dnll Number: Hilcorp Alaska, LLC - Exploratory ❑ Development [l 160-021 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service [; 6.API Number: Anchorage,AK 99503 50-133-10104-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B. Rule 5 i Soldotna Creek Unit(SCU)314-04 • Will planned perforations require a spacing exception? Yes ❑ No ❑I 9.Property Designation(Lease Number): 10. Field/Pool(s): FEDA028997 • Swanson River/Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,520 11,520 10,281 10,281 1,024 10,218' 10,296' Casing Length Size MD TVD Burst Collapse Structural Conductor 20' 20" 20' 20' Surface 3,005' 13-3/8" 3,005' 3,005' 2,730 psi 1,130 psi Intermediate Production 11,041' 7" 11,041' 11,041' 6,340 psi 3,830 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic , See Attached Schematic 3-1/2" 9.3#/N-80 9,981' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"BOT Premiere Pkr;N/A ., 10,119'MD/10,119'TVD;N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: j`t-i7 Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development [j Service L 14. Estimated Date for 12/15/2015(Eline) 15.Well Status after proposed work: Commencing Operations: 1/7/2016(Rig 169) OIL ❑ WINJ ❑ WDSPL ❑ Suspended 2 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Title Chad Helgeson Operations Manager Signature 7,17/1": Phone 907-777-8405 Date I.Vzc.y(5--- COMMISSION USE ONLY ' Conditions of approval: Notify Commission so that a representative may witness Sundry Number. t ;Is Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: fr . o pa- 136 ( 7:5't A I&c m O p f / ` r. • ,. 4r "f V„`e.-� r 1 9 ,/ ' C� 1 t l L (�� Post Initial Injection MIT Req'd? Yes ❑ No ❑ v / C Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: i z':: - •./ ' RBDNI I, sqyne(.Ui� APPROVED Y /' / /5 Approved by•� � COMMISSIONER THE COMMISSION l2 Date: {/J{/ L 4. 3:1.1 5 IM 'OPT PS �p�mmnSubmit Form and For.l 0-403 Revised 11/2015 ORtettimAti for 12 months from the date of approval. _ i/ q/ tt ents in Duplicate c((h"j /h/ • • Well Prognosis Well: SCU 314-04 Ililcoro Alaska,LL Date:11/20/2015 Well Name: SCU 314-04 API Number: 50-133-10104-00 Current Status: Shut-In Gas Inj. Well Leg: N/A Estimated Start Date: December 15th, 2015 Rig: Saxon 169 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-021 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907)952-8897 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (C) AFE Number: 1512837P Maximum Expected BHP: —2,045 psi @ 10,400' MD (Based on pressure survey 3-16-05) Max. Predicted Surface Pressure: —1,005 psi (Based on 0.1 psi/ft gradient) Brief Well Summary SCU 314-04 was completed as a Hemlock oil producer in 1960 producing at 1,000+bopd. It was converted to a gas injector in 66'. A plug was placed over Hemlock Bench 10 in 74'. Gas recovery began in 1999 with the initial rate of 10MMCFD dropping to 1MMCFD in 2004. A cement retainer was placed over the depleted Hemlock perforations in 2005 and recompleted in the Tyonek/G-Zone completed. The G-Zone did not produce oM economic volumes and the well has been SI since 2006. Cbl f Q(p(�,v�if" T u 1tln� RWO Objective: Pull completion and plug back well in preparation for sidetrack./ -\V, „vett w�P Ut 01,, K• ' pndo f � Notes Regarding Wellbore Condition cfie 7 i��f.rA Oh t'l ri1 v l • Tubing and casing will be filled full of produced f before the tubing is cut. , d/id otyt�krr�. r Kolb' Pre-rig Procedure: s G(( 1.• {i I l 1. MIRU Slickline, PT Lubricator to 250 psi low/2,500 psi high. S L 0diC1 JG11Uy � 2. Make 2.5"GR run and tag bottom. POOH. fO ,lQ,o+ �we� 3. RIH with shifting tool (BO ort-latch) and open sleeve at 10,105'. POOH IPI ��t 4. RD Slickline. v OA/ PT Lubricator to 250psi low/2,500 500psi high. 5. RU E line, / , g 6. RU chemical cutter. 7. RIH and cut packer assembly at+/-10,125' MD.Cut will release_Racker seats. POOH. 8. RD E-line. yK> K RWO Procedure: 1. MIRU Saxon 152...Rjz. 2. Kill well with 8.6 ppg PW by pumping down tubing, returning up annulus. 3. Set BPV. ND Tree. Notifications prior to BOP testing a. Notify BLM 48 hrs in advance of BOP test. b. AOGCC 24 hours at http://doa.alaska.gov/oac/forms/TestWitnessNotif.html 4. N/U 11"x 5M BOP as follows: 1 • • Well Prognosis Well: SCU 314-04 llilcorp Alaska,LL Date: 11/20/2015 a. BOP configuration from Top down: 11"x 5M annular BOP/11"x 5M double ram/11"x 5M mud cross/11"x 5M single ram. b. Double ram should be dressed with 2-7/8"x 5"VBR in top cavity, blind ram in btm cavity. c. Single ram should be dressed with 2-7/8"x 5"VBR. d. N/U bell nipple, install flowline. 5. Run BOP test assy, land out test plug (if not installed previously). a. Test BOP to 250/3500 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min. Se r b. Ensure to leave "A"section side outlet valves open during BOP testing so pressure does not ' Ie s build up beneath the test plug. Confirm the correct valves are opened!!! c. Test VBRs on 4-1/2"test joint and 3-1/2"test joint. d. Ensure gas monitors are calibrated and tested in conjunction w/BOPE. 6. R/D BOP test assy. 7. MU landing joints to the hanger. BOLDS. 8. Pull tubing hanger to the floor. (If tubing will not come free,see contingency procedure below.) 9. POOH with the completion string. Lay down all the 3-1/2"tubing, packer with tailpipe, and completion jewelry. a. Send GLMs to Pollard for redress. 10. Clean and clear floor. 11. Ensure well is full of fluid. 12. RU E-line. 13. RIH w/6.00"GR to 10,160'. a. If casing doesn't drift, MU bit and 7"scraper assembly on drill pipe, RIH to^'10,200 MD. Circulate well clean. b. POOH w/drill pipe and lay down bit and scraper. 14. RIH with CIBP and set at 10,157'. 15. RIH with bailer and dump 35' of cement. (57 gallons) 16. Tag top of cement and confirm TOC at 10,122'. 17. RD a-line. 18. PT casing to 1,500 psig for 30 minutes. k 1i4 19. ***Remaining prpcedure to be included on the Permit to Drill for the sidetrack*** Contingency Procedures(if cutter doesn't successfully free the packer assembly): 20. RU E-line, RU grease head, PT to 500psig. 21. MU tubing cutter. 22. RIH with tubing cutter assembly to 10,115'. Cut tubing. 23. POOH with tubing cutter assembly. LD tubing cutter assembly. 24. RD E-line. 25. Pull tubing hanger to the floor. ,A 26. POOH with the completion string. (If completion string will not come free, contact Engineer) `7 27. Lay down all the 3-1/2"tubing, packer with tailpipe, and completion jewelry. 2 . in • • Well Prognosis Well: SCU 314-04 flacon)Alaska,LL Date: 11/20/2015 a. Send GLMs to Pollard for redress. / r 28. Clean and clear floor. 29. Ensure well is full of fluid. 30. RU [-line. 31. MU w/6.00" GR to 10,110'. RIH and tag bottom. POOH. LD GR assembly. a. If casing doesn't drift, and MU bit and 7" scraper assembly on drill pipe and TIH to "'10,115' MD. Circulate well clean. b. POOH w/drill pipe and lay down bit and scraper. 32. MU w/7" Cement Retainer and set at+/- 10,110'. POOH. 33. RD E-line 34. Hold a pre-job safety meeting over the upcoming squeeze operations. .1 v;.. 35. TIH w/ DP and sting into retainer. ' 36. Set down 10k- 15k lbs to verify retainer is set. 37. Establish an injection rate of 1 bbl/min. 38. Unsting from retainer and circulate hole clean. 39. Mix and pump 15 bbls of 15.8 ppg class "G" cmt per below recipe. Ensure cmt is pumped at designed weight. Ls .,,,, - ;,,f, t" /0 r„ g 1'� `' 40. Displace DP with 128 bbls of 8.6 ppg PW 5 y3 C, t> `J�` 41. Sting into retainer 42. Displace DP with 10 bbls of 8.6 ppg PW effectively squeezing in 10 bbls of cement. 43. Unsting from retainer, break off top drive at the floor, pull 3 stands to"9,950',drop DP wiper ball '4V and circulate a good surface to surface volume while slowly rotating DP. 44. POOH w/ DP standing back 45. PT casing to 1,500 psig for 30 mintures.V i/l_"-- -,- 46. ***Remaining proce ure to be included on the Permit to Drill for the sidetrack*** Calculations: /I-so •i s- Section: Calculation: Vol (BBLS) Vol (ft3) 7" Casing: 10,100' x .0394 bbl/ft= 397.9 2,232.45 4.5" DP: 10,100' x .0142 bbl/ft= 143.3 806.38 Annular Volume 7" -4.5": 10,100' x .0197 bbl/ft= 198.9 1,116.94 Slurry Information: System Conventional Density 15.8 lb/gal Yield 1.16 ft3/sk Mixed Water 4.829 gal/sk Mixed Fluid 5.168 gal/sk Expected Thickening 100 Bc at 05:48 hr:mn Expected ISO/API Fluid 19 mL in 30.0 min at 170degF/ 1000 psi Loss Code Description Concentration Additives G Cement 94 lb/sk D047 Anti Foam 0.2% BWOC D080 Dispersant 0.07% BWOC 3 i • Well Prognosis Well: SCU 314-04 llilcora Alaska,Lb Date: 11/20/2015 Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Proposed Schematic(contingency) 4. BOPE Schematic 5. Current Wellhead Schematic 6. Blank RWO Procedure Change Form li 4 • 0 El Swanson River Unit Well: SCU 314-04 ACTUAL SCHEMATIC Completion Ran: 6/02/2005 Hilcory Alaska,LLC PTD: 160-021 API: 50-133-10104-00 RKB:160'/GL:145'AMSL Casing Detail KB—THF:17.0' Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 1 41 4 20" Conductor Surf. 30' Yes Surf. 20" 13-%" Surface 54.5 J-55 8RD Surf. 1,500' 30' a DV Collar 1,500' 1,503' 17-%" 1,100 sx Surf. 3,005' 13-%" Surface 54.5 1-55 8RD 1,503' 3,005' 600 sx 2,290'Calc il 2 7" 29 Surf. 303' ' y 7" 26 303' 1,296' 7" Production 23 N-80 BTC 1,296' 4,793' 5,720' 13,005' 3 7" 26 4,793' 6,306' 650 sx CBL I 7" 29 6,306' 7,509' w, i DV Collar 7,509' 7,511' 9 CBL TOC 24 5,720' 1f f 4 tio4 7" 29 N-80 BTC 7,511' 7,996' 11,040' to 7" 26 7,996' 9,654' 9,105' 7" Production 29 p_110 8RD 9,654' 9,662' 650 sx CBL a • 15 ,• 7" 26 9,662' 9,705' +�„-F 7" 29 9,705' 11,040' 1 it . 6Tubing Detail Conn ID CpIgOD #� 3.5" Tubing 9.3 N-80 CS Hyd Surface 9,961' 2.920" 3.915" i 7 3.5" Tubing 9.3 N-80 8RD 9,961' 10,141' 2.992" 4.500" 8 Jewelry Detail I= itNo. Depth Length ID OD Item i ` Seaboard ECO Tension Tbg Hngr,3H BPV w/3'pup jt,3-1/2" CBL TOC 19 1 15.83' 3.99' 2.992" 9,105' ► D in x w (Set w/ overpull) 1 10 .1,4.71..' + 2 2,266' 8.47' 2.867" 5.968" 3-1/28RP"SFO-2Pin GLM,wto/CS 4'& Hydril 6'3 1/2"XO pup26K jts rb 11.i./ i' 3 3,799' 8.46' 2.867" 5.968" 3-1/2"SFO-2 GLM,w/4'&6'3-1/2"X0 pup jts*Mr 4 5,214' 8.48' 2.867" 5.968" 3-1/2"SFO-2 GLM,w/4'&6'3-1/2"X0 pup jts Mt MI 12 5 6,392' 8.49' 2.867" 5.968" 3-1/2"SFO-2 GLM,w/4'&6'3-1/2"X0 pup jts ` 13 a 6 7,397' 8.48' 2.867" 5.968" 3-1/2"SFO-2 GLM,w/4'&6'3-1/2"X0 pup jts 14 > 7 8,252' 8.49' 2.867" 5.968" 3-1/2"SFO-2 GLM,w/4'&6'3-1/2"X0 pup jts 15 .1' 8 8,993' 8.49' 2.867" 5.968" 3-1/2"SFO-2 GLM,w/4'&6'3-1/2"X0 pup jts 9 9,495' 8.47' 2.867" 5.968" 3-1/2"SFO-2 GLM,w/4'&6'3-1/2"X0 pup its A '7 5 ' . • • II Swanson River Unit Well: SCU 314-04 PROPOSED SCHEMATIC Completion Ran: 6/02/2005 Hilcorp Alaska.LLC PTD: 160-021 API: 50-133-10104-00 RKB:160'/GL:145'AMR Casing Detail KB-THF:17.0' Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top * 20" Conductor Surf. 30' Yes Surf. 20" ,, t;, , 13-%" Surface 54.5 J-55 SRD Surf. 1,500' 30' ,` DV Collar 1,500' 1,503' 17-,4 1,100 sx Surf. 1 , 13-%" Surface 54.5 J-55 8RD 1,503' 3,005' 3,005' 600sx 2,290'Calc 7" 29 Surf. 303' ,� 7" 26 303' 1,296' 13-3/8"4� '' -. 7" Production 23 N-80 BTC 1,296' 4,793' 5,720' 3,005' 7" 26 4,793' 6,306' 650 sx CBL 7" 29 6,306' 7,509' CBLTOC ., DV Collar 7,509' 7,511' 9�' M 5,720' 1, 7" 29 N-80 BTC 7,511' 7,996' 11,040' ?, ..;, 7" 26 7,996' 9,654' .. y' 7" Production 29 9,654' 9,662' 650 sx 9,105' P-110 8RD CBL 9. 7" 26 9,662' 9,705' yGlw . 7" 29 9,705' 11,040' I �U` Tubing Detail Conn ID CpIgOD 3.5" Tubing 9.3 N-80 CS Hyd Surface 9,961' 2.920" 3.915" 3.5" Tubing 9.3 N-80 8RD 9,961' 10,141' 2.992" 4.500" i Jewelry Detail No. Depth Length ID OD Item CBL TOC :: 1 10,157 7"Cast Iron Bridge Plug(Proposed) 9,105' , ,7 2 10,281' - - HES"EZ"Drill Cmt Retainer(Set on wireline 5/31/05) sit 3 10,296' - - - Junk SAB Packer(Milled and Pushed to depth) 7. 1 CBLTOC 10,122' t- -.._i___.- _ 1 a14 ® G-1 3 ,.. H-1 Perforation History e. "' H-1 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments H-2 6/08/05 G-1 10,207' 10,256' 10,207' 10,256' 49' 6 2-1/4"PowerJet a`,,.'> H-3 8/10/60 H-1 10,291' 10,297' 10,291' 10,297' 6' 4 ;'4' 8/10/60 H-1 10,302' 10,306' 10,302' 10,306' 4' 4 - H-5 H 7 1/14/00 H-2 10,318' 10,333' 10,318' 10,333' 15' 6 Reperf 1/14/00 8/10/60 H-3 10,354' 10,365' 10,354' 10,365' 11' 4 _ ` att H 7 1/14/00 H-5 10,376' 10,432' 10,376' 10,432' 56' 6 Reperf 1/14/00 x H-10 8/09/60 H-7 10,450' 10,456' 10,450' 10,456' 6' 4 p. , -- H-10 1/14/00 H-7 10,464' 10,545' 10,464' 10,545' 81' 6 Reperf 1/14/00 11,040' 8/08/60 H-10 10,588' 10,655' 10,588' 10,655' 67' 4 TD=11,520' PBTD=10,850' 8/07/60 H-10 10,670' 10,674' 10,670' 10,674' 4' 4 Max Deviation=2.75 deg @ 7,147' Downhole Revised:6/08/05 Revised ByJEK 11/20/15 • • 0 II Swanson Unit PROPOSED SCHEMATIC Well: SRiver04 Completion Ran: 6/02/2005 flacon)Alaska,LLC (Contingency) PTD: 160-021 API: 50-133-10104-00 RKB:160'/GL:145'AMSL Casing Detail KB-THF:17.0' Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top G„ 20" Conductor - Surf. 30' Yes Surf. 20" % A: 13-3/4" Surface 54.5 J-55 8RD Surf. 1,500' 17-%" 1,100 sx Surf. 30' DV Collar 1,500' 1,503' %li 1+' 13-%" Surface 54.5 J-55 8RD 1,503' 3,005' 3,005' 600 sx 2,290'Calc 7" 29 Surf. 303' k4•,‘, r 7" 26 303' 1,296' 13-3/8" if, 7" Production 23 N-80 BTC 1,296' 4,793' 650 sx 5,720' 3,005' 7" 26 4,793' 6,306' CBL 7" 29 6,306' 7,509' 9-%" CBL TOC DV Collar 7,509' 7,511' 11,040' 5,720' J 7" _29 N-80 BTC 7,511' 7,996' "I�'".i 7" 26 7,996' 9,654' 1,,1 ,. 7" Production 29 9,654' 9,662' 650 sx 9,105' P-110 8RD CBL lit `� 7" 26 9,662' 9,705' 7" 29 9,705' 11,040' „lit i'ird " Tubing Detail Conn ID CplgOD ill 3.5" Tubing 9.3 N-80 CS Hyd Surface 9,961' 2.920" 3.915" Crl �_ 3.5" Tubing 9.3 N-80 8RD 9,961' 10,141' = 2.992" 4.500" ilfoo i Jewelry Detail No. Depth Length ID OD Item CBL TOC 4 1 10,110' HES"EZ"Drill Cmt Retainer(proposed) 9,105' 2 10,119' 6.82' 2.870" 5.980" BOT Premier Production Packer,784-63-6001,7"26-29 w/3-1/2"TC-II Box x Pin(XO Above&Below) 3 10,138' 1.53' 2.635" 4.500" HES"XN"Profile Nipple,2.75"Profile,2.635"No-Go i. 4 10,139' 1.92' 2.992" 4.500" WLEG 5 10,281' - HES"EZ"Drill Cmt Retainer(Set on wireline 5/31/05) 6 10,296' Junk SAB Packer(Milled and Pushed to depth) iti CBL TOC -9,975' S` . a:At r C- 1 a4 /0 Vic. • G-1 5 ,z(i':, H-1 Perforation History H-1 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments H-2 6/08/05 G-1 10,207' 10,256' 10,207' 10,256' 49' 6 2-1/4"PowerJet . H-3 8/10/60 H-1 10,291' 10,297' 10,291' 10,297' 6' 4 H-5 8/10/60 H-1 10,302' 10,306' 10,302' 10,306' 4' 4 H-7 1/14/00 H-2 10,318' 10,333' 10,318' 10,333' 15' 6 Reperf 1/14/00 8/10/60 H-3 10,354' 10,365' 10,354' 10,365' 11' 4 LIA H-7 1/14/00 H-5 10,376' 10,432' 10,376' 10,432' 56' 6 Reperf 1/14/00 H-10 8/09/60 H-7 10,450' 10,456' 10,450' 10,456' 6' 4 7" ` H-10 1/14/00 H-7 10,464' 10,545' 10,464' 10,545' 81' 6 Reperf 1/14/00 11,040' rl, 8/08/60 H-10 10,588' 10,655' 10,588' 10,655' 67' 4 TD=11,520' PBTD=10,850' 8/07/60 H-10 10,670' 10,674' 10,670' 10,674' 4' 4 Max Deviation=2.75 deg @ 7,147' Downhole Revised:6/08/05 Revised By JEK 11/20/15 • 0 Swanson River Unit • Ili SCU 314-04 BOP 11/20/2015 Ililrnrp tla.kn.lit • r lil Iil Iii lil h ii iii�til 3.5" f 1 Model 6011i 11"-5006 Iii.ifil ifti n - milmsE '. imil __. 1 3.00' , CO,. T-3 Energy —z 3 . IIModel 7082 :.al, 11"-5406 IIIIIIII _ - 2.00' + • I�� .. 1I+ JII i iti I!1 til 111 III 2 1/16 5M Kill Side lir 41111111.1t 1/8 SM Choke Side ' ' - - 1.41' �'`3 r Model 7682 - — � �� Ahabrik 11"-WOO _ - it! III isi iii III Ii) 1111 ill ri:l lis II t I I j iL M MI fia,. r'8'' i • Swanson River SCU 314-04 Current 11/20/2015 Ililr..rl. tl+r.la.11,11.1. Swanson River Tubing hanger,Seaboard, SCU 314-04 Tension type,7 X 3 1/2 EUE 13 3/8 X 7 X3 1/2 8rd lift and 3 1/2 EUE susp, w/3"type H BPV profile,left to release,right to catch BHTA,Bowen,3 1/8 5M FE X 3"Bowen top O 1s IIMP A- �0, `\yl'OOO Valve,swab,CIW-F, , jw� SQ' .t 34 3 1/8 5M FE,HWO,DD ¢' <//'' , �' trim „\$yCr ,,'ss' ��\\'yF```�` I. Valve,Wing,WKM-M, - �.'y.� - :.', 3 1/8 5M FE,HWO,DD ,10.� , I .,��, ,C 1,s� trim ■ 1 Lr Valve,master,WKM-M, -,5". ' 3 1/8 5M FE,HWO,DD - c trim . r' Valve,master,WKM-M, 3 1/8 5M FE,HWO,DD 2' _' � trim �'. Adapter,Seaboard, lfl ill 71/165M X31/85M, Completion spool, -. ® w/5"PP seal pocket ,JaiilSeaboard-S, ' . 7 1/16 5M FE X 7 1/16 5M •a , = FE,no outlets on head III � "s• 1l1 i!1 I i!i Tubing head,Shaffer T55-L1, _ 13 5/8 5M X 7 1/16 5M,w/2- 2 1/16 SM SSO,7"Type 1 r!u �� secondary seal in head 1-111 Lill Valve,CIW-F,21/16 SM FE, HWO,AA (- • J -> -. , Qty ri • �� �" ' : III.._.111111 : 6.1,1111 _ III I5.�. .. „ Casing head,Shaffer KD, 13 5/8 3M X 13 3/8 SOW,w/ lei . : til 2-2"LPO,7"casing hung of with KD slips and packoff 1, . Valve,plug,2"LPO,HWO, asst' tin ii*Imi AA . • 0 2 C a 2 � a f k � 7 0 U - ° 6 > § . F % o ■ / \ 4: § f Ea.« ® Cr) oc 7 Tij ƒ E i cif \ Q 2 U) \ � « kmF > _ _ 22 E \._ a g / % .0 -0 a a 2 \ Vs_ z a a (N k.0 � � 9 Co 2 ■ to k9- -0 a_I- \ � @ et _ c. 9 C.) \ E @C 14. 0 �k _ I CO/ a) = o c co / C < f 0 2 E § O k o .2 J o E . a. a) SR 14-) C L \ 2 2 § � 2 = O c Lu ■ -FD g CO kk CU \Q O $ § O CD rx 14 en - cco ECa p U qQ @ 2 � g 0 ea as @ . a 0 e gg 2 2 0 Ea / � « it a .. 7 / + k I U Q e > 2 > o g O. a / :3 U 2 Cl) CO ¢ a U) • • Schwartz, Guy L (DOA) From: Joe Kaiser <jkaiser@hilcorp.com> Sent: Monday, November 30, 2015 10:36 AM To: Schwartz, Guy L(DOA) Cc: Chad Helgeson; Monty Myers Subject: RE: SCU 314-04 (PTD 160-021) Guy, Per your conversation, here are the remaining procedures up to the milling window. 46) RU E-line to set CIBP. RIH w/CIBP and set at 7,400' (5' above a collar) 47) RD E-line and test casing/CIBP to 2,500 psi for 30 min. 48) PU 6.059"window milling assembly and DP and cleanout to CIBP 49) POOH standing back, PU Whipstock,and mills and TIH to CIBP 50) Orient whipstock and set at 45 deg azimuth. Mill 6"window and 20'of new formation at 7,400'. Please let me know if you need anything else. Joe Kaiser KEN Operations Engineer Swanson River Field (kaiser@hilcorp.com 907-777-8393 Office 907-952-8897 Cell From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, November 25, 2015 2:51 PM To: Chad Helgeson; Joe Kaiser Subject: SCU 314-04 (PTD 160-021) Chad/Joe: For any sidetrack, the P&A sundry must include the operational steps up to milling the window. Please forward the additional steps needed after step 18/46. An email with the steps will suffice. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 1 • S Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task es nsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the atrici or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patri ' or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for 4enr1f" Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab m4,r1'1' for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab J R l 1, in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there MeAChiffN is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change 1e A,(4/, the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. ') ) Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com 1 hó- 0ð-i UNOCALi> Debra Oudean G & G Technician Date: June 15, 2005 To: AOGCC Helen Warman 333 W. ¡th Ave. Ste#100 Anchorage, AK 99501 ~~1:iL'illliD ·,'1: }i.~_~[~: ~~li~ r!~1~[~:t~~TI~~;I~¡)~~!:) ~Æ ~,';¡ ¡tI4~, i~;~ ~~~ .~.I SAU I Schlumbergeri 194-0840 ¡ 501331014101 i PLUG SETTING RECORD 51NCH 3/17/2005: 3920-4063 1 1 i pds 32A·15 :! ! WEATHERFORD RETRIEVABLE I I PLUG SCU : Schlumbergeri.!~Q.:.9.?1Q i 501331010400 i PRESSURE TEMP SURVEY 314·04 i ¡ i COMPLETION RECORD 2.25 HSD , : , : POWERJETS SCU Schlumbergeri 199-0540 ! 501331012501 : PLUG SETTING RECORD 3.5" 21A·09 Ii: MAGNA RANGE BRIDGE PLUG . i ! CEMENT DUMP BAILER SCU ' Schlumbergerl 160-0210 ¡ 501331010400 I ABANDONMENT RECORD JUNK 314·04 : ._-: I BASKET/GUAGE RING CEMENT : RETAINER SCU Schlumberger! 174-0540: 501331011001 "COMPLETION RECORD 2 HSD 43A·04 ::. POWERJETS EZ DRILL SQUEEZE I. PACKER SCU ' Schlumberger! 199-0540 1501331012501 COMPLETION RECORD 2.5 HSD 5 INCH ¡ 5/4/2005: 10050-10450 : 1 21A·09 ! POWERJET 6 SPF 60DEGREE , PHASING ]~f~~o.~.1 ~~~IU_:b~.~~t~~-~1~~.I5~~~~~0~~7~~:I~~~~R~§!I~~,;~.C~_R:D1 :~~ ~~D t~~~~j.~:.~~~~05111 0240-1 ~30 11 _ ..L II __11~_~s_.. 6/8/2005 9900-10185 1 : dlis, las, pds );. ~'( I 4/30/2005 10530-10675 l' pds . 5/30/200510185-10192 : 1 l' pds j 3 ),fù . 6/11/2005' 2215-2224 1 1 pds 1: pds ¡ ~ 5ÇAN~'jE~ ('. r" c·..., ,) [,,' t¡ b~¿OC~j Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. I " .' 'I/l (; I~ 7:J . Receive By: t L; Üvj Jate--::JI 8 \ . _>l. /f ~ ~~;-' f~0,- ~À( f<l~ } STATE OF ALASKA ) ALA\:Jt<Ä OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations ro.Aldjw~~n U Repair Well U Performed: J U N ?Al€er é~Mffg D Pull Tubing D 2. opera~:~~1~~~~r~~~tI~~~~~~Y~f"~~~~~~~ Shutdown D Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations lJ Perforate New Pool D Perforate 0 4. Current Well Class: Development [] Stratigraphic D Stimulate U Other lJ Isolated Hemlock Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 160-021 Service D 6. API Number: 50-133-10104-00 9. Well Name and Number: SCU 314-04 10. Field/Pool(s): Swanson River I Hemlock, G Zone 7. KB Elevation (ft): RKB to Tbg Hngr = 17' ',8. Property Designation: Soldotna Creek Unit 11, Present Well Condition Summary: Total Depth measured 11,520' true vertical 11,520' feet feet Plugs (measured) 10,281' Junk (measured) 10,296' Effective Depth measured 10,281' true vertical 10,281' feet feet Casing Length Size Structural Conductor 20' 20 Surface 2,988' 13 3/8" Intermediate Production 11,024' 7 Liner MD TVD Burst Collapse 20' 2,110 psi 520 psi 3,005' 2,730 psi 1 ,130 psi 11,041' 6,340 psi 3,830 psi 20' 3,005' 11,041' Perforation depth: Measured depth: See Attached SCANNEDJUL Û 7 2.005 True Vertical depth: See Attached Tubing: (size, grade, and measured depth) 3-1/2" L-80 10,141' Packers and SSSV (type and measured depth) 7" BOT Premiere Pkr 10,119' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFL JUN 2 4 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Oil-Bbl Prior to well operation: Well SI Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 41 39 15. Well Class after proposed work: Exploratory n Development fJl 16. Well Status after proposed work: Oil[] Gas D . WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 5 550 150 Service n x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 305-1 03 Contact Steve Tyler 907263-7649 prín::~a:~~ 2°~7 Title Drilling Manager Phone 907-276-7600 Date ~ -/1--05-' Form 10-404 Revised 04/2004 Submit Original Only ) ') PERFORATION ATTACHMENT Isolated Hemlock Perfoations 10291 '-1 0297' 10302'-10306' 10318'-10333' 10354'-10365' 10376'-10432' 10450'-10456' 10464'-10545' 10588'-10655' 10670'-10674' Added G Zone 10201' - 10251' ~ I, Well Name SCU 314-4 Primary Job Type Workover Jobs - --..----.-.------¡;,rl;:-Nõ-...----------- -.------ uT ------- . ---~_~~~~~=~~.. ~.__-~-_=_--~:-_-- ~--.- . - --~~~::§~çi--··~- - --- -- m - .n. i 164021 ---------.---- - -------·-¡:ty¡er _____________._____________.________________________ _._ ~ iLl: j : I' j ;:: JJjJ ï in¡¡) Field Name SWANSON ì ~~ 1 ~; r,~~:':W, Ii ¡'ill' it: " , 'fÚ¡,,¡ ) . . ~tt.l.(.~'~ ;~, ~.!1, f 1fI1~,!; ~Rt"~ ',' '. ~ ' ~ ~ ~'... "",.. '.,.' '~~k~ 1·' J,~ ~...I!} 4 ;.r'.I:l'~i'~~:·~Ij""',·, if ~!~'·.1·~' l !:¡:Lór~;g,,, [,IT ,--" n___, ,!!~¡I!Ln, .1. ""J . J) ~¡»'.II"';¡ ~'''_'J:III J ~.';.J.~ ~~i¡' l' -.-. , ~ ____ ~ IAPI/UWI lease/Serial 501331010400 FEDA028997 --- -'IP¡'lmary Wellbore Affected Main Hole .g;rJ',"F '[' Ii" ) ~, .", ,,-.. I >\11. - rJ'~" ; . ~1: 1; I' I .1. rJ! I =- - ~ r - 11 --..".. io 'I' 1, or...i9. KB Elev (ftKB) 160.0 ::=--n-~Ji_:ïi~~-nn~-..-..,;x _ Daily Operations 5/31/200500:00 - 6/1/200500:00 Operations Summary PJSM wI wireline. RIH wI EZ drill corelated to set at 10281'. RD wireline, NU tubing spool, and BOPs. PJSM. Test BOPs, choke and floor valves.RU and RIH wI DCs, LD same. RU, PU production jewlery, 6/1/2005 00:00 - 6/2/2005 00:00 Operations Summary RIH Gas Lift I Rod Pump Completion and tag retainer at 10286' tubing measurments, Space out tubing and rig up to reverse circulate well to diesel with tubing at 10283'. Change over well with 55 bbls clean lease water ahead of 373 bbls of diesel. Check well and well was balanced. POH with excess tubing and make up hanger. Land hanger, run in lock down screws and "J" mandrel out of hanger. Drop down 35" and prepare to run test plug, Reentery guide at 10141' and packer at 10119'. ____..__.".___.. __·__·.._.."·..,._·____ø...,_..,, _" .._ ,_ _.._._.,,-~._----_._--,._."_._,_._--_.,--'-.__._- ~._'.._------_._--_.._..._--,. ----.-------.---.--,--..--.---...,-.--....-.....'--.-.. , 6/2/200500:00 - 6/3/2005 00:00 Operations Summary RU slickline and set 2.75" plug at 1 0140' I XN nipple. Pressure up tbg string to 4100 psi setting the production packer at 10119'. Pull test plug free and RD slickline. Test to confirm packer set. Pull! mandrel into hanger body and J into hanger with rgt turn, Over pull on string was 26K Ibs, NU BOP. NU tree. RD pulling unit. -----..-...,,--------- ----------.--- --.-..---"----,.-.,,.- ..--"'..-----..-....-.---. . 6/3/2005 00:00 - 6/4/2005 00:00 Operations Sum mary -..----.---------..---------.--..................-... -..-----...-...-..-.--.-... Set up temporary gaslift lines to well. Test same. RU wireline. PJSM. RIH and pulled dummy valve from gaslift mandrel #2, Unload 133 bbls of diesel to prepare wellbore for perforating, by gaslift through empty mandrel at 3798' WLM. RIH and pulled 6 remaining dummy valves, 2 of 9 dummy valves missing. - 6/4/200500:00 - 6/5/2005 00:00 Operations Summary , ~;;.~~~ ~~~~i:/~:~~:~ i~o~o~ndrels No ~o~::e:::g:~e tw~_~s~ng_ dU:~ :al:es. the valves ~re_ ::bottem. ~hUt in ~n~s~ I RU slickline. RU and run a pressure and tempgradient survey to confirm diesel has displace water over projected perf interval. RIH stoppiing every 1000 ~' feet to TD (10281'), POOH at 60 ftlmin to 9000'. and increased to 100 ftlmin to surface, POOH. 6/8/200500:00 - 6/9/2005 00:00 Operations Summary -- ------- - - .. --- ------ --- ---.--., _~U Eline. RI Perforated G zon~~_,~~!~~~_1_0,~~~_:.._~..~~...!:~~~~~~..C!"~mp Survey ~0~~_~~i9_.P_~_'!._~~<2.~_~..!?_§~.~~:_I..~~~~I! 9~~r to pr~_~~tion. 6/9/200500:00 - 6/10/2005 00:00 Operations Summary-- ---- - - .--- ----.- --- -- -- - - . -- - ---- . ~ost Catch-up .__.,..__._~_.- .._-,~.__.---,,,.,,'-_..,.._._. - .------,-_..-_. ._.,._--,---,_.._-,.,'''-.,......-,-".~ _..._..-~..-.,_..~-_._- --. . ...~. -..- ------_..__.__..~_.,--------_.-.-..._._... .--,-.-........- 1 ..~.,"""n_ - -_·~tII..._....~ ~ 'mlJ\ ij 'U' if '{ J J~~ r- ~ ~2____ O_; ~u:¡\IOII~m·_~--··-LIiI!"¡,¡,. ! II ..--1 i' ''1"'1" ') r. . ¡ ¡' ¡-"I I !,..' f.,~ J Well Name I SCU 314-4 Primary Job Type " Abandon Zone Jobs F'" ~ 64022 Field Name SWANSON API/UWI 501331010400 ¡..-:i . i 'Á' :; ~f-:i '!;,' ~,(~¡ ~1t"'''\:'¡] .~:=- . ~~ ..1 '.' ';1 t' ."".~ ~'i .. I .. t;' ~~~n~tl':n~ ':n:~ :,,~_ l··~.i~J ~ui;· i,~ Lease/Serial FEDA028997 í~=~~Ÿ:~õrë)~ffëëîë-a------ -.... , fÆ~O !I ;m !ß~~lWì!$\r-! ; ,.¡",-WÙ'Mi Orig KB Elev (ftKB) ,Water Depth (ft) 160.0 --. Ii ~: I ... ,:<.11...;;.....,4,"/..¡, ,/k, , ._-------_.._---~---_.- n__,__u....._ "._'"___.._ _R~_._.._·_··_.·,...··_·_··,,····__· AFEN6. ~;:::~~l~:---~::~~O¡FL. ..~ ~ Daily Operations 5/23/200505:00 - 5/24/200500:00 Operations Summary---'-"-'--- . MI/SpoURU Production Hoist. Raise derrick. ND tree, NU BOPs. Spot coil tank and berm. ¡I 5/24/2005 00:00 - 5/25/2005 00:00 ~ Operations Summary .--. ¡ Rig up test BOPs, Pump LCM pill down tubing. ~ 5/25/2005 00:00 - 5/26/2005 00:00 -------.-.---.-.-----,------.-.. . -""--...-----,.-...------..-,.-------.-----.-..'-...----...."."-,--.-,.....--....".".,,..-..------.---.. ~ ~ Operations Summary "-------.-.,.,--------.-...."--"--"-..--~-_.....,,'--,,..'-.."..-, ._._,._~___._..m....__.__."___..._. . Pump 2nd LCM pill. Pull hanger and release anchor from packer. Circulate out excess LCM short way, Circulate long way. POOH 50 stands of tbg to ~~idnight. _ ________ _______..__.____.______.._..____________________ ____ .. ..____.._.. 5/26/200500:00 - 5/27/200500:00 : Operations Summary Finish POOH wI 3-1/2" tbg string. Standing back same. LD Anchor BHA. PUMU pkr mill BHA. RIH tag SAB pkr @10,197' MD. I 5/27/2005 00:00 - 5/28/2005 00:00 K Operations Summary ~. Mill on SAB pkr @ 10,197' DPM. ~5/28/2005 00:00 - 5/29/2005 00:00 > , Operations Summary il Mill/Push pkr to 10,282' DPM, Trip OH to CO mill. ¡1~~~~~~~u~~:a~~ - 5/30/2005 00:00 _____ m_.._______.____.___..__=--=~--____-------·-·-·-·----·-·------.-. --.--.--.--.--.... I ~~~~~i ~~:~ ~~~~1~~~:~~Ó:%~-!~?~-~~,2!?~!?1g,?-~7'. No f~_~_~~rpro_~r~ss. POOH wI milling assy. lOperations Sum mary ____n__.______. .---- -..--... no ....... ~ LD milling assy, Attempt to establish injection rate & pressure in HK. pressure wellbore to 3000 psi. pressure stabile @ 2970 for 30 min. RU Eline. RIH wI ~ 6" Junk Basket GR. Set down @ 9923'. POOH, MU 5.7" GR. RIH tag junk pkr @ 10,296' Tie-in log depth. POOH. MU cmt retainer onto setting tool. RIH. \ --- --- ---------- ---- J ~ --------_..__.__._--_.._....~._..__.._....._-,..._,..~_.----_..-... --- --,-~._.._---"._.._-".._-". ---_._..._....__._._.-_.---,------,.-...~,_...- . ------- .·.__.._._.,._,..__._..·R._.._.... .-.. ..._._..._._....~---..~~-".__.- __ _..__ ."...._ __._"..~ ..._.__. __... ,.,,__..._"d_"'''·''~.''_ _~"'._.._m..·".__._........._._______,___·____· ___ ...__.~.__. _._" ___.n~..~_..__.______··___·_·___,__·__·____ . .._.._......u_._.____..·".,.._._w..__...__',. l I , i l ~ â -, I ~~IBiBl! ~~_n ~" ~ IIV II .----- l_...._n__:: ---......,,;0- _n___n_ - ._.____n--l -.-- -._~ ~ UNOCALe Original RKB to Tbg Hngr = 17' ~~,~- - 1 r - -~~ ',',~ I ~r , l'~ ' ~,þ C::::J'~ .' '~ ~. ¡ i ..~ c::::::TJ : .~ I .~ .¡ ~. II c::::J ~ ¡ ~ { ..~ ~·l ~ '"'I ,Ot tJ..' :í-. ~4 ~! ;"', '~',1 ,'. ?;:, ~:~ )oJ, ~=: ~oiiI'\ .~ ~ " j~7; ~ I ;,¡. . . ~r'~ ~,:~ If;; ~~4 ~~ :i ),; ~ I~' II~.\ i~ !.... ~-,~ ~"4.it -.~ !'I.1> 1;40 ' 4 ',..:~ ';0\: ~~ look l~~. >, ~ :,1, ',~,~~'~~'I(~L ~~ . , ~,t--.--",", .~ ~ f~ , ~ "~ :'.< ~ 'f:l0'291' ~ I' ~ '1m¡ <' '"" ,~"_'?: ::=lIO,3IS' ~"O,333' ..: ~':10,354' ~-. ~IO,365' ,'., ~'10376' ~~0:432' JilO,450' =;':10,456' ~0,464' ~ 10,545' ~JO,5SS' ..JI0,655' ~IO,670' -':;,10,674' ~;¡ ,'.,.: ~..: ',1 :-,. , ~ '.'</ r;. 1· .".. I, ...... .. 6~t I.': TD= 11,520' PBTD= 10,850' Max Deviation = 2° @ 5700' ) Buttress 12.615 6.184 6.276 6.366 6.276 6.184 ,) Swanson River Well SCU 314-04 Proposed Completion Tub n 9 Top Btm Hole Cmt Cmt Top Surf 20' Yes Surf. Surf 1500' 1100 sx Surf 1500' 1503' 17-1/2" 1503' 3005' 600 sx 2290' (Calculated) Surface 303' 303' 1,296' 1,296' 4,793' 650 sx 5720' Thru DV @ 4,793' 6,306' 8467' CSL 6,306' 7,509' 7,509' 7,511' 9- 7 18" 7,511 ' 7,996' 7,996' 9,654' 650 sxs 9105' 9,654' 9,662' Round CBL 9,662' 9,705' Shoe 9,705' 11,041 ' Surface 9981' Cas i n 9 & Size Type Wt Grade Thrd lD 20" Conductor 13-3/8" Surf Csg 54.5 K-55 12.615 DV Collar '~, ~ 13-3/8" 7" 7" 7" 7" 7" DV Collar 7" 7" 7" 7" 7" Tubin~ 3-1/2" NO. eLM #1. eLM #2. eLM #3, eLM #4. eLM #5. eLM #6. eLM #7. eLM #8. eLM #9, seD 314-04 Proposed Schematic 05-05 Surf Csg 54.5 K-55 ~ ~ Prod Csg 23 N-80 ~ 29 29 N-80 ~ Prod Csg ~ P-IIO ~ 29 15.0' Original RKB to Tbg Hngr I 9.3 I N-80 I CS Hyd l. Depth Lene:th ID 15.83' 3.99' 2.992 2266' 8.47 2.867 3799' 8.46 2,867 5214' 8,48 2.867 6392' 8.49 2.867 7397' 8,48 2.867 8252' 8.49 2,867 8993' 8.49 2.867 9495 8.47 2.867 9967' 8.48 2.867 9,979' 0.8' 2.935 9,980' 5.99' 2,992 9,986' 1.08' 2.75" 9,987' 3.97' 2.992 9,991' 4.13' 2.813 9,996' 3,9' 2.992 9,999' 94.25' 2.992 10,094' 6' 2.992 10,100' 1.37' 2.75 10,101' 3.97' 2,992 10,105' 4,13' 2.813 10,109' 8.09' 2.992 10,117' 1.92' 2.97 10,119' 6.82' 2.870 10,126' 2.05' 2.97 10,128' 3.95' 2.992 10,132' 5,99' 2,992 10,138' 1.53' 2.635" 10,140' 1.92' 2.992 10,263' MD 10,281' DIL 10,296' DIL 2. 3. 4. 5. 6. 7. 8. 9. 10. 8rd 6.184 6.276 6.184 6.276 6.184 2.992 JEWELRY DETAIL Item Seaboard ECO Tension Tbg Hn¡,'T, 3H SPV wi 3' Pup Joint, 3-1/2" 8rd Pin x Pin wi XO to CS Hydril 3-112" SFO-2 eLM, Max OD = 5.968" w/4' & 6' 3-1/2" XO pup joints 3-112" SFO-2 eLM, Max OD = 5.968" w/4' & 6' 3-1/2" XO pup joints 3-1/2" SFO-2 GLM, Max OD = 5,968" wi 4' & 6' 3-112" XO pup joints 3-1/2" SFO-2 eLM, Max OD = 5.968" wi 4' & 6' 3-112" XO pup .ioints 3-1/2" SFO-2 eLM, Max OD = 5.968" w/4' & 6' 3-1/2" XO pup .ioints 3-112" SFO-2 eLM, Max OD = 5.968" wi 4' & 6' 3-112" XO pup joints 3-1/2" SFO-2 eLM, Max OD = 5.968" w/4' & 6' 3-112" XO pup joints 3-112" SFO-2 eLM, Max OD = 5.968" wi 4' & 6' 3-1/2" XO pup joints 3-112" SFO-2 eLM, Max OD = 5.968" wi 4' & 6' 3-112" XO I)UP joints Crossover, 3-112" CS Hyd Box X 3-112" 8rd Pin Pup Joint, 3-112", 8rd BxP Rod Pump Seating Nipple, 3-112" 8rd BxP Pup Joint, 3-112", 8rd BxP CMU Sliding Sleeve, 810-79-4439 3-1/2" x 2.81 3-1/2" EUE Pup Joint, 3-112", 8rd BxP (3) Joints of 3-112" tbg, 8rd BxP Pup Joint, 3-1/2", 8rd BxP HES "X" Profile Nipple, 2.75" Profile Pup Joint, 3-1/2", 8rd BxP CMU Sliding Sleeve, 810-79-4439 3-112" x 2.81 3-112" EUE Pup Joint, 3-112", 8rd BxP Crossover, 3-112" 8rd Box X 3-112" TCII Pin (BOT Provided) BOT Premier Production Packer, 784-63-6001, 7" 26-29# w/3-1I2" TCII box X pin Runnin !, OD 5.98" Crossover, 3-112" TCII Box X 3-1/2" 8rd Pin (BOT Provided) Pup Joint, 3-1/2", Srd BxP Pup Joint, 3-112", 8rd BxP HES "XN" Profile Nipple, 2.75" Profile WLEe, 3-112", 8rd Box HES "EZ" Drill Cmt Retainer JUNK PKR PERFORATION DETAIL Interval Accum. Top Btm Amt spf Conunents 10,207' 10,256' 49' 6.0 10,291' 10,297' 6' 10,302' 10,306' 4' 10,318' 10,333' IS' 10,354' 10,365' II' 10,376' 10,432' 56' 10,450' 10,456' 6' 10,464' 10,545' 81' 10,588' 10,655' 67' 10,670' 10,674' 4' e zone Perfs, 2-114" Power. Isolated Isolated Isolated Isolated Isolated Isolated Isolated Isolated Isolated REVISED: 9/1/2004 by SLT ') ) ¡¡-:::;::¡ : :1 ~b :11.1 :1 L.:¡ FRANK H. MURKOWSKI, GOVERNOR AI1ASIiA. OIL AM) GAS CONSERVATION COM1tllSSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 Tim Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 ;~ "'1~ \, Ilttl~ v r Re: Swanson River SCU 314-04 Sundry Number: 305-103 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed fonn. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day fal~s on oliday or weekend. A person may not appeal a Commission decision to Superi Court unless rehearing has been requested. C;4e~) L fi ' J'o~_ No ~ alnnan DATED this3 day of May, 2005 Enel. SC/~NNED MAY I 1 2005 Abandon L:J Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 160' 1. Type of Request: 8. Property Designation: Soldotna Creek Unit 11. Total Depth MD (ft): 11,520' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 10195' to 10,689' Packers and SSSV Type: .. STATE OF ALASKA ALA:.. } OIL AND GAS CONSERVATION COMM~ JON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: ,/ / Development 0 Stratigraphic 0 "-' ~ A-. ~ /4/ ¿'-'OS * S~f"O; Suspend U Repair well 0 Pull Tubing 0 PerforateL:J Waiver U Stimulate 0 Time Extension 0 Abandon Hemlock Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 1600210 /- o 6. API Number: 50-133-10104-00-00 / Other U Service 9. Well Name and Number: SCU 314-04 / 10. Field/Pools(s): Swanson River Field/Hemlock, G-Zone PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 11 ,520' Length Plugs (measured): Junk (measured): 10,192 to 10,225 Collapse Effective Depth MD (ft): 10,850' Effective Depth TVD (ft): 10,850' MD TVD Burst Size 30' 3004.5 30" 30' 30' 13-3/8" 3004.5' 3004.5' 2,730 PSI 1130 psi 7" 11,040.30 11,040.30 6,340 PSI 3,830 PSI 11040.3 Perforation Depth TVD (ft): 10195' to 10,689' 3-1/2" Retrievible packer Tubing Size: Tubing Grade: Tubing MD (ft): 2-7/8" N-80 to 34',3-1/2" N-80 to 10,154' Packers and SSSV MD (ft): 10,192 12. Attachments: Description Summary of Proposal L:J Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Timothy C. B;?;.ande Yurg Title Drilling Manager Signature '7 =-VC Phone 907-276-7600 Date ð/ ---, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness / Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 16. Verbal Approval: Commission Representative: Pe4'· 13. Well Class after proposed work: Exploratory 0 Development 0 //) . 15. Well Status after proposed work: ~005 Oil 0 Gas 0 Plugged WAG D GINJ 0 WINJ o o /~ Service 0 D Abandoned o WDSPL . Date: Contact Chantal Walsh 263-7627 4/18/2005 Sundry Number: ,3os--/tJ~ Location Clearance o 2So.o PS:· R =CEIv=n ",-I fe.,dlA-l ~ fM1. il t:-v... he ( ,l b V<..Ï p ~ -e<.oe ~A· ,\ S a,yJ J?, '7fJ. ve d . PR 2 B Z005 RBDMS BFl MA \' I) 9 2D05 COMMISSIONER ORIGINAL Ab~lk~ QU &. Gus Con~. Commissior: APPROVED BY "~~h9r~~ h ,,- THE COMMISSION Date: 6/7 OS ubmit in Duplicate Form 10-403 Re~d 11/2004 \. ) .) Swanson River Soldotna Creek Unit SCD 314-04 Operation Summary · MIRU SL. RIH Gauge tbg. Tag fill. Run bombs. POOH. RD · Prep Location for rig. · MISpotlRU Production hoist NO Tree. NU BOPE. Test same / · · MU Land Joint. PUt unseat tbg hngr. Attempt to rotate anchor out of pkr. If unsuccessful, RU Eline RIH w/ cutter to 10,160'. PU 30k over. Cut tbg @ 10,160'. POOH RD Eline. POOH standing back 3-1/2" tbg. BO/LD 2-7/8" equipment. If tbg was cut, PUMU overshot/fishing BHA. RIH latch anchor. Rotate/Remove same. POOH.PUll1p xylene and/or Pep 2 treatment. · · · · PU Motor, mill, pkr catcher & drill collars. RIH on 3-1/2" tbg. Mill SAB pkr. POOH.w/ same. IC 101;:,[(:. ' . e~ PUMU Cmt Ret w/ Slide Valve. Set @ 10,250'. RU Cementers. Pump cãk Vol + Displacement. PU above ret~T. sa . POOH to 5000'. PUMU RTTS. Rlset @ 100' below hngr. Disconnect f/ RTTS. POOH - ND BOPE.~U Seaboard tensionhngr Parent bOWI~U BOPE. Test same. ? PUMU RTTS retrieving tool. RIH latch/release RTTS. POOH LD same. Continue POOH wI tbg. LD BHA. PU completion equipment. RIH to 10,120'. PUMU h,ngr. Rlland hngr. Un-"J". RIH·to 10,120'. Space-out to land land tbg in tension. RU slickline. RI w/ N test toolto XN. Pressure set pkr. RD Slickline NO BOPE. NU Tree · · · · · · Oemobe rig. RU Eline. RIH perf G zone sand @ 10,201' - 10,251 '. POOH. RD Eline. Slicklinepressure bombs. · · RECEIVED APR 2 5 2005 Alaska Oil & Gas Cons. Commissiop Anchorage UNOCAL8 ti- - .L Sldg Slvc 10,154' MD 10,172' DlL PkrTop 10,192' MD 10,209' DlL EOT 10,224' MD 10,242' DlL Current ~ :~ ¡ \ ~ :( ì 'I :~ ¡ J - - L Sldg Slvc 10,154' MD 10,172' DlL EOT 10,224' MD 10,242' DIL Cement Retainer SCD 314-04 Proposed Schematic _ 04-05 ~ If } ~ \- r F r ¡~ r ~ I tc r ~ ¡ ,~ ~ r ..~ .~ ') 11- - I '11 ~~ r 1, f ) ~ f ¡ ~ i. ~ ,I, I" l ¡ ,~ ¡ I: ~' I, ~ t L ~ ~ ,t Ii ; ~ ~ :f ~. 1'< I ~ .þ t ¡ .~ '~ f I t /.PkrTop 11 (10,192' MD I 10,209' DIL' : t r===--' II ' Ii- R! ~t.Ji~,.I,",.,_,.'...lL, =10,291' = 10,297' =-= 10,302' = 10,306' =10,318' = 10,333' = 10,354' = 10,365' = 10,376' =-= 10,432' = 10,450' = 10,456' =-= 10,464' = 10,.'\45' = 10,588' = 10,655' = 10,670' =-= 10,674' 1()2-~O I CT P&A Cement Retainer ) Swanson River Well SCD 314-04 Proposed Completion QJ - - [J, , '.' ~ ':.l' ~ ..1. . '.\. ! I .~ , ~~"J ¡ f ~ ! ! I : \\ (~'"J :; .~.. ¡I (~ I 'i,¡ I' 1:1 ~I ( ";J n ì! If ¡ ,~ ~:·'t·<J !.. ...t,. ~ ~ I L -L .L ~ 10,354' 10,365' 10,376' 10,432' 10,450' 10,456' 10,464' - - L ~ t II II ':¡'¡;'¡,k.'~"":,',.;,~l:J.I'I' _ Cement Retainer ~ec°rftFtE IVE 0 APR 2 5 2005 Rod Pump Installed Alaska Oil & Gas Cons. Corræi%~D: 3/14/2005by SLT Anchorage Well Name SCU 314-4 Primary Job Type Workover Most Recent Job Job Category Completion/Workover ftKB (MD) o 30 302 1,29€ 1,50C 1,502 2,29C 2,46~ 3,002 3,00~ 3,674 4,792 5,70C 5,30~ 7,50S 7,50S 7,51C 7,99~ ~,654 ~,661 ~,704 0,15· 0,15. 0,19: 0,19! 0,191 0,20. 0,21. 0,21! 0,22. 0,29 0,29' 0,30: 0,301 0,31: 0,33: 0,35· 0,36! 0,371 0,43: 0,451 0,451 0,46- 0,54! 0,58. O,65! 0,671 0,67· 0,68, O,68! 0,851 0,95: O,95! 1,03, 1,041 1,041 1,38~ 1,431 1,521 ftKB (TVD) o 30 302 1,296 1,500 1,503 2,290 2,465 3,003 3,005 3,674 4,793 5,700 6,305 7,507 7,508 7,509 7,994 9,652 9,659 9,702 Incl 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.0 2.0 1.3 2.0 2.0 2.0 2.0 0.7 0.7 0.5 Primary Job Type Slick Line-Gauge Ring Depth Markers ~mCr)SPrStnZn WJ-Z ~~ ¡ Z :2: Z · · · · · · · · · · · ~ -~ ~ I ... , ~ \ ~ ~ I ~ I 1è: ~ ~ ~ r ~ ~ ~ ~ "f: ~ ~ r ~ ~ ~ ~ ~ ~ ~ r ~ ~ ·~I J J J ~ J ] ~ J ~ ? J 1.\ ~ ~I J. ~I ~I :~I j -j¡I :itf ~ Lease/Serial FEDA028997 I Primary Well bore Affected Main Hole Secondary Job Type Actual Start Date 1/13/2000 End Date Main Hole: 4/19/2005 9:01 :57 AM Formations Final Logs Schematic - Actual ~ ~/1-1¡ Casing Joints, 20, i- 19.124,0,30.0 ~ ..:....... -, aSlng Olnts, ,. , ~ 0, 302.6 ~i. \. 3-2, Casing Joints, 7, 6.276, 303, 993.1 ~2-1' Surface Casing, 133/8, ~. 12.615,0,1,500.0 ¡(.~" - 2-2, Stage Collar, 13 3/8, ~ 12.615,1,500,2.5 2-3, Surface Casing, 133/8, - 12.615, 1,503, 1,500.0 ~ 2-4, Float Shoe, 13 3/8, ~ ~ ~ 12.615, 3,003, 2.0 ~ i.'.'... ~ 3-3, Casing Joints, 7, 6.366, ~ ~ 1,296, 3,497.0 ~ \ :i!: 2-1, Standard Segment, 3 I 1/2,0,10,154.0 .. 3-4, Casing Joints, 7, 6.276, ! . ~ 4,793,1,.512.7. , i 6,305, 1,202,8 ~ .. ¡. ~ 3-6, Stage Collar, 7, 6.184, I J 7,508, 2.5 ~' ¡, 3-7, Casing Joints, 7, 6.184, , 7,511, 484.6 3-8, Casing Joints, 7, 6.276, 7,995, 1,658.5 3-9, Casing Joints, 7, 6.184, 9,654, 7.6 3-10, Casing Joints, 7, 6.276, 9,661, 43.0 2-2, Sleeve, 3 1/2, 10,154, 4.0 2-3, Standard Segment, 2 7/8, 10,158, 34.0 10,195-10,196 1-1, Retrievable Packer, 3 1/2,10,192,12.0 1-2, Standard Segment, 2 7/8, 10,204, 10.0 1-3, Landing Nipple, 27/8, 10,214,1.0 ~ 1-4, Standard Segment, 2 7/8,10,215,9.0 10,291-10,297 ~ 10,302-10,306 10,318-10,333 ~ 10,354-10,365 10,376-10,432 ~ 10,450-10,456 10,464-10,545 \ \ 10,588-10,655 \ 10,670-10,674 10,688-10,689 "'" 3-11, Casing Joints, 7, 6.184, \ 9,704, 1,248.3 ~3-12, Float Collar, 7, 6.184, 10,953, 2.5 \3-13, Casing Joints, 7, 6.184, 10,955, 82.8 3-14, Float Shoe, 7, 11,038, 2.5 RECEIVED APR 2 5 2005 Alaska Oil & Gns Cons. Commission Anchorage ",.. UNOCAL Date: i /~'2- / 6:3 Transmittal Form Unocal Alaska Regulatory Filing ) ") Submitted by: f)fI 11 ha YYì Well Nam~U3lf-O"'( Project Manager: ~ ~ Type of Form: ~,AOGCC 10-401 ¡u AOGCC 10-403 D AOGCC 10-404 D AOGCC 10-407 D BLM 3160-05 (Notice of Intent) D BLM 3160-05 (Subsequent Report) Sent to: Sent via: D Bureau of Land Management 6881 Abbot Loop Anchorage, AK 99507 ,£' AOGCC 333 W. 7th Avenue Anchorage, AK 99501 ~ 0 Courier 0 Drilling Personnel RECEIVED APR 2 5 2005 Page 1 of 1 Alaska Oil & Gas Cons. Commission Anchorôge ) ) Subject: RE: Swanson River Well Servicing Unit \ From: "Walsh, Chantal ~Petrotechnical" <walshc@unocal.com> \,-,'"'1 -" b?- Date: Tue, 03 May 2Q0514:27:55 -0800 \OV To: Winton Aubert <winton......8ubert@admin.state;ak.us> CC:·"Harness, Evan" <eharness@unocal.com>, "Tyler, Steve Lt' <tylersl@unocal.com>, "Klemmer, Stèphanie J" <klemmers@unocaJ.com> . Winton, We will have at least one H2S detector on the Well Service Unit. Thank you, Chantal -----Orig i na I Message----- From: Winton Aubert [mailto:winton_aubert@admin.state.ak.us] Sent: Tuesday, May 03, 2005 8: 14 AM To: Walsh, Chantal -Petrotechnical Subject: Swanson River Well Servicing Unit Chantal, Unocal's request for variance for the Swanson River well servicing unit proposes a single methane detector. 20 MC 25.066 requires three methane detectors and three H2S detectors for drilling and WO rigs. Is it possible that the proposed well servicing unit include at least one H2S detector? If not, please provide a technical justification. Thanks, Winton Aubert AOGCC 793-1231 (' t. ) ) ./ o~\ . \ l.of). Winton, In response to your phone call the other day regarding the 403 Sundry Application for the well SCU 314-04 I have the following: The line item: NU BOPE. NU Seaboard tension hngr Parent bowl. NU BOPE. Test same. The above mentioned Seaboard tension hanger is a two bowl hanger which enables setting the tubing in tension. The proposed rod pump completion for the well (we are designing for this option to lift the well when it can no longer lift off of the gas lift design), requires the tbg is set in tension. Further to this we will be testing the BOPE at 300psi low and 5000psi high. The cement volume to be used to isolate the Hemlock is designed at 25 bbls or 125 sacks of G neat cement. We are currently working on a letter to address the Pulling Unit equipment. The unit is currently stacked at Swanson River. Last year we worked with you to obtain a variance for the BOP configuration. We are putting together a new letter addressing the individual wells we anticipate working over this year. We will be getting this out to you later this week. Thank you, Chantal ) ) RECEIVED, AP ~ 2. n 2CJD5 UNO'CALti) -- Alaska Timothy C. Brandenburg Drilling Manager Unocal Alaska Tel 907.263.7657 Cell 907-3507920 Fax 907-263-7884 E-mail: brandenburgt@unocal.com AJaska Oil (~ Gas Gons. Cornmissi(m Anchorage April 29, 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. ih Avenue Anchorage, Alaska 99501 Re: Request for Variance-Swanson River Mr. Aubert, We are requesting a variance of 20 AAC 25.285 (c) (9) and (10). We are preparing to perform well intervention work with a "well servicing unit" provided by Nabors Alaska Drilling, currently stacked at Swanson River. We augmented the BOP equipment on the unit to satisfy our internal standards. Last year we worked with you to obtain a variance to work over several wells in the Swanson River field. We continue to believe the proposed system is superior in well control capabilities to BOPE configurations that are presently in use in the United States and Canada for wells with equivalent pressure and flow regimes. \ (P{7~ o~1 We are greatly appreciative of your consideration of this proposal and look forward to meeting with you to discuss any issues with the proposed configuration. Attached you will find a brief description of the wells to be worked on; the highest maximum anticipated surface pressure (MASP) and the proposed BOP configuration. Additionally you will find a schematic of the proposed BOPE layout. Sincerely, '7 .~ :f C../Š Timothy C:-Brandenburg Drilling Manager Attachments ~NED NO\f 1 '7' 20D5 Union Oil Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage. Alaska 99501 http://www.unocal.com ) ) Well Descriptions Well Work Inventory SCU 32-08 SRU 23-15 SCU 22-04 SCU 314-04 JtoQ-O~' SRU 14-15 SRU 12-15 Reservoir The highest BHP of any well to be worked on at this time is 3000 psi @ 10,900' TVD (Hemlock) which is equivalent to a .275 psi/ft gradient or a 5.29 ppg EMW. Fully evacuated, the MASP would be as follows: 3000 psi BHP - (10,900' TVD x .1 psi/ft Gas Gradient) == 1,910psi MASP. Proposed Confi~uration BOP's Annular,5K 7-1/16" or 11" Double gate, 5K, 7-1/16" or 11" Mud Cross, 7-1/16" and 11" (optional based on BOP height) Accumulator 1 - 90 gallon Bounty Accumulator System 9-10 gallon Barksdale Control Valves Marsh Gauges 1 - Pump, Union Pump Comp., Model #BIT-532-55 1 - Newman Electric Motor 4 - 11 Gallon Nitrogen Bottles Pits The pit consists of a 150 bbl tank partitioned into 50 bbl compartments. Pump The pump is an Western Roughrider 1000 Triplex on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line will consist of 2", 3000 psi Iron or 2", 5000 psi hoses with integral Fig 1502 hammer Unions. Kill Line Valves The kill line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16", 5K valves attached to either the mud cross or the tubing spool annulus valve. ) ') Choke Line Valves The choke line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16". 5k valves that will be attached to either the outlet below the lower rams on the double gate or the mud cross. Choke Line The choke line will consist of 2",5,000 psi hoses with 2-1/16" 5m API Flange. Choke Manifold The choke manifold is 2-1/16", 5K with two manual chokes and four valves. Choke Return Line/Gas Buster Line The gas buster line will consist of 2", 5000 psi hose with 1502 Unions. The line will run from the choke manifold to the gas buster. Gas Buster The gas buster is located in one of the three 50 bbl compartments of the pits. It is constructed with an open bottom that utilizes the hydrostatic level in the tank for the water leg. The gas buster vents vertically. Gas Detection Weare proposing that a single gas LEL monitor be placed at the work platform. PVT We are proposing to work with out a PVT system as the wells to be worked will not be capable of circulation at surface or the reservoir will be isolated. UNOCALSWANSON ~ -.............. ~ ~ r- I I I II Pipe Ram II I I " Blinds II I I ---- I I ~ ~SAI ~ 2" 5M MGV 2" 5M MGV I m œ .. ' [JJ11" or 7-1/16" 5M Annular 5M Studded Top and Flanged Bottom ~11"or7-1/16"5M DBL .-, ~ Optional 3 11"or7-1/16"5M Drilling Spool w/2 ea4" 5M OTL 12", 5m Hose wI flange connections. 1 11" or 7-1/16" 5M Hydril Annular BOP 2 11" or 7-1/16" 5M Shaffer LWS Double BOP 3 11" or 7-1/16" 5M Drilling Spool w/2 ea 4" 5M OTL (Optional) 4 2 1/16 5M Manual Gate Valve 5 2 1/16 5M Manual Gate Valve 6 2 1/16 5M Manual Gate Valve 7 2 1/16 5M Manual Gate Valve ..--,. 2" 5m High Pressure hose. To Flow Back Tank ) ) REC [-''''' 'V['""" D·' ":":~ u"""" '~,''''' ,. I' _0111I, ' ~",' ' A P H 2. n 2. U (] ~:)' UNOCAL{fØ ''',,-- Alaska Timothy C. Brandenburg Drilling Manager Unocal Alaska Tel 907.263.7657 Cell 907-3507920 Fax 907-263-7884 E-mail: brandenburgt@unocal.com Ala$ka Oil & Gas Cons. GOfllmissiolP Anchorage April 29, 2005 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Request for Variance-Swanson River hó - D ?-I I . V "3 I - Oy.. G(/ Mr. AUbert,/,/--) (þ) \JJ'* We are requesting a variance of 20 AAê 25.4.651c)}9) and (10). ~---,/ / ,/ We are preparing to perform well intervention work with a uwell servicing unit" provided by Nabors Alaska Drilling, currently stacked at Swanson River. We augmented the BOP equipment on the unit to satisfy our internal standards. Last year we worked with you to obtain a variance to work over several wells in the Swanson River field. We continue to believe the proposed system is superior in well control capabilities to BOPE configurations that are presently in use in the United States and Canada for wells with equivalent pressure and flow regimes. We are greatly appreciative of your consideration of this proposal and look forward to meeting with you to discuss any issues with the proposed configuration. Attached you will find a brief description of the wells to be worked on; the highest maximum anticipated surface pressure (MASP) and the proposed BOP configuration. Additionally you will find a schematic of the / proposed BOPE layout. Sincerely, "7 ~;J,c.h Timothy C:'·Brandenburg Drilling Manager Attachments Union Oil Company of California / Unocal Alaska 909 West 9th Avenue, Anchorage, Alaska 99501 http://WWN.unocal.com ) ) Well Descriptions Well Work Inventory SCU 32-08 SRU 23-15 SCU 22-04 SCU 314-04/ SRU 14-15 SRU 12-15 Reservoir The highest BHP of any well to be worked on at this time is 3000 psi @ 10,900' TVD (Hemlock) which is equivalent to a .275 psi/ft gradient or a 5.29 ppg EMW. Fully evacuated, the MASP would be as follows: 3000 psi BHP - (10,900' TVD x .1 psi/ft Gas Gradient) = 1,91 Opsi MASP. / Proposed Confiauration BOP's i Annular, 5K 7 -1/16" or 11" Double gate, 5K, 7-1/16" or 11" Mud Cross, 7-1/16" and 11" (optional based on BOP height) Accumulator 1 - 90 gallon Bounty Accumulator System 9-10 gallon Barksdale Control Valves Marsh Gauges / 1 - Pump, Union Pump Comp., Model #BIT-532-55 1 - Newman Electric Motor 4 - 11 Gallon Nitrogen Bottles Pits The pit consists of a 150 bbl tank partitioned into 50 bbl compartments. Pump The pump is an Western Roughrider 1000 Triplex on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line will consist of 2", 3000 psi Iron or 2", 5000 psi hoses with integral Fig 1502 hammer Unions. Kill Line Valves / The kill line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16",5K valves attached to either the mud cross or the tubing spool annulus valve. ) ) Choke Line Valves / The choke line valves will consist of, at a minimum, 2 ea. manually operated, 2-1/16". 5k valves that will be attached to either the outlet below the lower rams on the double gate or the mud cross. Choke Line The choke line will consist of 2",5,000 psi hoses with 2-1/16" 5m API Flange. Choke Manifold The choke manifold is 2-1/16", 5K with two manual chokes and four valves. /" Choke Return Line/Gas Buster Line The gas buster line will consist of 2", 5000 psi hose with 1502 Unions. The line will run from the choke manifold to the gas buster. Gas Buster The gas buster is located in one of the three 50 bbl compartments of the pits. It is constructed with an open bottom that utilizes the hydrostatic level in the tank for the water leg. The gas buster vents vertically. ~- Gas Detection We are proposing that a6 gas LEL monitor be placed at the work platform. ' (.~~/ PVT We are proposing to work with out a PVT system as the wells to be worked will not be capable of circulation at surface or the reservoir will be isolated. UNOCAL SWANSON ~ ............... ~ ~ I I ~ ~ I I I II Pipe Ram II I I II Blinds II I I / / l ~~SAI~ 2" 5M MGV 2" 5M MGV L m [I] 0]11" or 7-1/16" 5M Annular 5M Studded Top and Flanged Bottom ~11"or7-1/16"5M DBL '~/ ~ Optional 3111" or 7-1/16" 5M Drilling Spool w/ 2 ea 4" 5M OTL / / 12", 5m Hose wi flange connections. 1 11" or 7-1/16" 5M Hydril Annular BOP 2 11" or 7-1/16" 5M Shaffer LWS Double BOP 3 11" or 7-1/16" 5M Drilling Spool w/2 ea 4" 5M OTL (Optional) 4 2 1/16 5M Manual Gate Valve 5 2 1/16 5M Manual Gate Valve 6 2 1/16 5M Manual Gate Valve 7 2 1/16 5M Manual Gate Valve - 2" 5m High Pressure hose. To Flow Back Tank MEMORANDUM State of Alaska Naska Oil and Gas Conservation Commission TO: Cammy O. Taylor ~0~ DATE: July 25, 2002 Chair a/ ~ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder /~'~..,.)~/! Unocal Petroleum Engineer-~J~'~~ Swanson River Field Swanson River Unit FROM: Lou Grimaldi Soldotna Creek Unit Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. '... WellI 312-9 .Imypelnj. I I'TiV. DiI 101501T%ingl '9'50'I 900 I 950' I '920 I In'tervall 4 , P.T.D.I 16o-028 ImyPetestI P ITestpsil 25~8 ICagingI 14501 2r~0.1 56201 2620I P/F '1 P' Notes: i We, I i'r nj.I I T.V.O. I I"YuU", I -, 00 I a?0' I ' 70 I P.T.D..I 160.021 ITyPetestl ,' P' ITestPsil 2~S, I',casingl 1950I 270e I 27001 2700,1 PIF I -P Notes: ..... Welll" '2'43L4' I T~,~)e Inj. I :WO '1 f.~/,.D.' I' 2892"1 T~bing' IVacuumlVacuumlVa'cUumlVacuumllntervalj 4 P:T.D.I 16i-029 'lTyPetestl P 'lTestpsil 1500 I CasingI 1000 I 16401 1'164oi"'1 16401 PIF ]" P Notes: Or!~linal PTD # WellI 31-33WD I Type Inj. i :WD ! T.V.D.'I 19':17 I Tubing I' 900 I 900 I '.oo I .oo 'llr tervalJ 4' ,, P.T.D.I 180-114 I'TYPe{estl P IT. est,)siI 1'~00 I Ca,sin~ll, 50 I" t630-I ~570'1 15201 PIF I P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. :G= GAS INJ. S = SALT WATER INJ. N = NOT INJECTING :WD = Water Disposal Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test'$ Details Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test dudng Workover O= Other (describe in notes) I arrived at Swanson River Field and met with Ken Cassidy (Lead Operator), we reviewed the test procedures and tested the wells noted above. All wells tested "OK" with the exception of 31-33WD which had to be pressured up twice. This well was on injection when I arrived and the tubing and annulus were pulsing in concert due to the close proximity of the pump and small annulus area (5 1/2" inside 7"). This required the injection to be halted, the casing was pressured up and was declining faster than allowed. We waited for approximately one hour for the well to stabilize and repressured the well, this time the decline was within allowable limits and passed the MIT. The parts of the field I was in were very clean and presentable, the roads were well maintained and travel was easy. M.I.T.'s performed: Four Attachments: None Number of Failures: None Total Time during tests: 5 houm ,cc; D~c He.lt~,n (,Unocal, Foreman) MIT report form 5/12/00 L.G. MIT Swanson River 07-25-02 LG.xls 8/5/2002 Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907,) 263-7889 Fax: (907) 263-7828 E-marl: childersd@.unocal, com UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL April 4, 2000 To: Lori Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: "~?' "? "" ; '?~?'1~"~;~'~"~;'~;~;?.....~.,,,~,~ '~'' ';' ' ~'' ' ' .~;~'~'~:~?'.,,::~,~ ::,' z :¥ ~:~,~ ~. ' ~:~ ~;.:;~ ": "'~.~v, ,'.:~ ~ ::. ~...,-,,~...~:, ~: .... , ........ .~../ .:?~el~,~ :~. ~ .~',~P~G~E~*.~' ~,~'.~',~,~'-~,, :~:SCA~E~ ~¥EOG..~: ~,.INTER~AE~,, · .~ :COPIES~ ~.'~. ~M~lUm~ ~",~.: ...... -, .' ,-,". .,~ ~ ~.. ,~,.. ',~: '~',, ,.~ ,'.,'~ ~ "'-',.~,. · ,.:~.,,.'~.¢'~t.~ ~.. ..... · . · '~.,' ~'~,..~( k, '.~ ~ ~ ...... ~ ,.~ · ,'~, '~' ~ ,~"' '~, ~ , ~' ," '",' ~ I~, ~SCU 1~9 )~'l'hem~a Deca~ Time Log 15 inch j ~/6/99i6400-10714' '~ ~ B-.Lin. ' ~o: ~z~scu ~:'~ ................. ]"P'~'~ii~'~'"'~'~ ...................................................................... l"~"i'~'~'fi .............. ~ .................. Z~5~'i"~"~'i'~'~':i"b~'~ ................ i ......................................................................... ~"'i"~':Li~'~ ................. '] scu' ~2:9 ..... i'p'e'~0~ii~O'"R'e~0~d ................................. ~S"i'n~'h ..... l ................. ~)5~'I"~"~'i'~':i"5~'~5 ................ t .......................................................................... ~"i'~ii'; ........................... I ~SCU 12-9 lPedoratmg Recor~Correlat~on Loo ~5mch 1/16/00110000-10500 ~ 1 B-Line r .................................................... 1 ~,','," ..................................... ~ ..................................... ~ ............................................................... i ............................................................. ~ .......................................... ~ SCU 12-9. Pedoratin~ Recor~Correlation Lo~ ~5 inch ~ 1/16/00i 10000-10500 1 Film I~' ~o ~ ~CU 12A-3 l Pedorating Recor~Correlation Log ~5 inch 3/15/~0200-10550......... ~ ~)~.~:~._ ~org~g Recor~Correlat~on Log ~]'5 inch 3/15/00 10200-10550 1 FIm ! ...... ; ............................. ; .......................................................................... ; ............................... ~ ........................................ ~ ............................................................. ~ ......................................................................... ~ ................ : ............................ ~SCU 12A-3 Poss~set Plug 5 Cement ~5mch ~ 3/11/00 ~10200-10545 ~ l~B-bne SCU 12A-3 PossisetPlugS'Cement ~5inch , 3/11/00 10200-10545 1 Fire " ~ ............................................................ ~ .................................................................................................................................................................................................................................... J ......................................... ~ ................................................................................. ~ ................................................ I ~o, o %fiSCU 14-4 Pedorating Recor~Correlation Log 5 inch 1/14/00 10000-10610 1 B-Line ~ '"~b'0""~'4':~ ................... ~'~'~'~'ii'~'~'"~'~'~i~ii~'~'"G'g'"'"'[~'"i'~ ............................ i')'i'~)~'~"'"i"~'~b:'~"~'i"5 ................. ~ ........................................................................... ~"'"~'i'i~ ............................. I~'OZ~ "~'0'"~'~"~:~ ...................................... ..~.~,[~.~.ng: ..................................................................................... Record. '~5 .............................................................................. inch NI/00i .......................................................................................................... , .......................................................................... ~ ?~0'"~'¥~:~' ........ ~e~2r~in_g~Record 5 inch NI/00110500-10700 I 1 Film ~,SCU 22-4 MD Com os~te F~eld Pnnt 15 tach 10/8/99~10340-11140 ~ 1 B-Line ~ ~SOU 22-4 M D Composite Field Print ~5 inch 10/8/99 ~ 10340 11140 1 Film ~ ~'"~'~'0"~'~:~ ......... ~'~-'~~i'te Field Print ~,Sinch ,~ .0~$ ~.~.~.:.~ t~1~i°n Record 5 inch 1/14/00~10200-10570 ~ ~ SCU 43B-8 ~ Pedorating Record/Correlation Lo~ 5 inch 3/16/00~ 10200-10500 ! ~ E ~ E I ~'1 E~ine ........................................................................................ Pleose ocknowledge r~pt' ~y signing' ' ........................... ond returning: ............................................................................... one copy of th~s: ................................................................................ tr~nsmiffol ~~g07)l ............ 263-7828,"~ ................... Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Dan Williamson Drilling Manager Wednesday, March 29, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn' Mr. Robert Christensen Subject: Soldotna Creek Unit Well SCU 14-4 APl No. 50-133-10104-00 10-404 Perforate H2, 5 & 7 benches Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the H2, 5 & 7 benches in well SCU 14-4. The following intervals were perforated on 1/14/00: Bench Top Bottom Feet H2 10,320 10,333 13 H5 10,380 10,432 52 H7 10,466 10,530 64 Total: 129 If you have any questions, please contact Ralph Holman at 263-7838. Sincerely, Dan Williamson Drilling Manager ORIGINAL RECEIVED · . , Apr 10 2000 AIIiII~ Oil & Gas Cons. Commissi°n Anchor'41e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 160' RKB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Soldotna Creek Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number / . 680' FSL, 680' FWL, Sec. 4, T7N, Rgw, SM SCU 14~4 At top of productive interval 9. Permit number/approval number/ 680' FSL, 680' FWL, Sec. 4, T7N, R9W, SM 60-0021-0 At effective depth 10. APl number 680' FSL, 680' FWL, Sec. 4, T7N, R9W, SM 50-133-10104-00 At total depth 11. Field/Pool 680' FSL, 680' FWL, Sec. 4, T7N, R9W, SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 11520 feet Plugs (measured) true vertical 11520 feet Effective depth: measured 10850 feet Junk (measured) true vertical 10850 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 30' 20" Yes 30' 30' Surface 3005' 13-3/8" 1700 sx 3005' 3005' Intermediate Production 11040' 7" 1300 sx 11040' 11040' Liner Perforation depth: measured 10291-10297, 10302-10306, 10318-10333, 10354-10365, 10376-10432, 10450-10456, 10464-10545, 10588-10655, 10670-10674 true vertical 10291-10297, 10302-10306, 10318-10333, 10354-10365, 10376-10432, 10450-10456, 10464-10545, 10588-10655, 10670-10674 Tubing (size, grade, and measured depth) 3-1/2", 9.3# @ 10,224' Packers and SSSV (type and measured depth) Baker "SAB" @ 10,192' RFC V n 13. Stimulation or cement squeeze summary .. , Intervals treated (measured)ORIGINAL Treatment description including volumes used and final pressure A~I~I[ 0~ & ~ C0o$. ~ion 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 4766 0 0 1150 Subsequent to operation 4 8492 0 0 - .1150 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed:~,~,~~{/'~i~~~'~'¢/~ Title: /~~~_~/!~., Date: ~.c"~,~...~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Unocal North American ' Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL May 5, 1994 Alaska Region Commissioner Russ Douglas Alaska Oil and Gas Conservation Commission 3~01 Porcupine Drive Anchorage, Ak. 99501 Dear 'Commissioner Douglas: Application for Sundry Approvals Mechanical Integrity Tests Swanson River Field Union Oil Company of California (dba Unocal) requests approval to perform the attached Mechanical Integrity Tests on the following wells in the Swanson River Field: c~)-~iw~ SRU 31-33WD u~\- ~.q; SCU 43-4MD L~- 2_\ SCU 323-9 (~0~ SCU 314-4 The last well listed above, SCU 314-4, was scheduled for an M.I.T. in 1993, but due to tubing to casing communication, this well could not be tested in 1993. The tubing was pulled from this well and replaced in December, 1993 and the well is now ready to be / tested. The above proposed M.I.T. tests are being done to satisfy the requirement to test 25% of our Class II Injection wells per year. If you have any questions, please contact me at 263-7816. Very truly yours, Petroleum Engineer R F.. C F. IV F-.D Gas Cons, Commission Anchorage ,--., STATE OF ALASKA ALAS~ 'IL AND GAS CONSERVATION CO~'~IISSION APPLICATION FOR SUNDRY APPROVALS '1, Type of request: Abandon m Suspend Operations shutdown Alter easingm Repair well __ Plugging __ Change approved program Pull tubing Vaflance 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 680~ FSL, 680' FWL, Sec. 4, T7N, R9W, SM At top of productive interval Same as above At effective depth Same as above At total depth Same as above 5. Type of Well: Re-enter suspended well__ Time extension Stimulate m Perforate __ OtherX__ (MI'F) 6. Datum elevation (DF or KB) 160'RKB 12. Present well condition summary Total depth: measured true vertical 11520 11520 feet feet R£C£IV£D MAY '1 2. 1994 Ataska 0il & Gas Cons. Commissio Anchorage Plugs (measured) feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 314-4 9. Permit number 10. APl number 50-133-10104-00 11. Field/Pool Swanson River/Hemlock Effective depth: measured 10850 true vertical 10850 feet feet Junk (measured) Casing Length Size Structural Conductor 30' 20' Surface 3005' 13-3/8' Intermediate Production 11040' 7' Uner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth Yes 30' 600 sx 1st stage 3005' 1100 sx 2na stage 30' 3005' 650 sx 1st stage 11040' 650 sx 2ncl stage 11040' 10291-10297, 10302-10306, 10318-10333, 10354-10365, 10376-10432, 10450-10456, 10464-10545, 10588-10655, 10670-10674 1029 1 - 10297, 10302-10306, 10318-10333, 10354-10365, 10376-10432, 10450-10456, 10464-10545, 10588-10655, 10670-10674 3-1/2', 9.3#, N-80 to 10154', 2-7/8', 6.5# N-80 to 10224' Packers and SSS'V (type and measured depth) Baker "SAB" pkr. @ 10192' 13. Attachments Description summary of proposal m Detailed operations programX__ BOP sketch _ 14. Estimated date for commencing operation ~15. .. July 20, 1993 16. If proposal was verbally approved Oil m Gas Name of approver Date approved Service Injector 17. I hereby cerilJfy, th~he fo,r. qg, qinD, issue angj;t3~rrect to tl~e best of my knowledge. I: '-'/~/ FOR COMMISSION USE ONLY Status of well classir~:ation as: Conditions of approval: Notify Commission so representative may witness Plug Integrity w BOP Test Location clearance _ Mechanical Integrity Test~~'~ S-'~bsequent form required 10- Suspended Date 9. ~'~A,~,,~''' Approved by the order of the Commiss~n ur~g=nal Signed By 0avid W. Johnston Commissioner Form 10-403 Rev 06/15/88 ,~pproved Copy Returned SUBMIT IN/'TRIPLICATE PC & SC Loading and PC pressure Test SCU 314-4 Objective; To load the PC and SC and verify mechanical integrity on the PC. Well Data: Tubing: 3-1/2, 9.3#, N-80' to 10,154'; 2-7/8", 6.5#, N-80 to 10,224' PC: 7' 23#, 26~ and 29# N-80 to 11,040' MD SC: 13-3/8' 54#, J-55 to 3005' MD Top packer depth: 10,250' MD Capacities: Tbg. x PC = .0264 Bbls./Ft. PC x SC = .1070 Bbls./Ft. Current Pressures: Tbg. -- 5000 psi, PC = 650 psi, SC = 260 psi Procedure; Load PC and SC le Install a two-pen recorder on the well to monitor the SC and PC pressures. e Shoot fluid levels on the SC and PC. (Skip to step #10 if no load is needed on the SC or PC). Calculate needed load volumes to fill SC and PC. Assure that this fluid is on location for load. 3. Monitor tubing, PC and SC pressures throughout the job. 4. Hold safety meeting. 5. RU choke and gas buster to SC, as needed. 6. Blow down SC pressure without allowing fluid production. 7. Hook up pump track to SC and pressure test lines to 4500 psi. Load SC with lease water containing .25 % WT676 corrosion inhibitor finishing with a 5 Bbl. crude cap. Do not exceed 300 psi during pump- in. e Repeat steps 5-8 for the PC, as needed, using a 3000 psi maximum injection pressure for step #8. (Several 1000 psi blowdown/loads may be required). RECEIVED MAY ] 2 ]994 Gas Cons. Commissiort Anchorage NOTE: Contact the AOGCC (279-1433) and BLM (271-4417, 248-3010) at least 24 hours prior to testing the PC so that an agency wimess can verify the test results. 10. 11. Pressure up PC to 500 psi over current pressure (2000 psi minimum). Hold for five minutes (observing tubing, PC and SC pressures). If less that 50 psi is lost in five minutes, increase pressure by 500 psi. Hold for five minutes. 12. Repeat step fill until 3600 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. 13. Rig down. R£C£1V[D MAY 'l 2 1994 u~ & Gas Cons. Commission Anchorage SWANSON RIVER FIELD $~U 814-4 ACTUAL 3/10/94 20' @30' ~3 3/a' e3oos' 23/aJ/2od~ N-8o FROJf 0-7005' P-IlO FROId 78~-~54' ~01 P-IlO BELOW 0554' A) 3 1/2" 9.3// N-80 CS-HYDRIL @10,154' (337 JTS) PERFS e10,291-10,207' PERFS O10,302-10,306' = PEP, FS O 10,318-10,333' -'.; PERFS 010,354-10,365' PERFS 0!0,376-10,432' -'- PERFS 010,450-10,456' = PERFS 010,464-10,545' = PERFS 010,588-10,655' = PERFS 0i0,670-10,674' = 7" @11,040' ~ 1) OTIS 'XA' SLEEVE 010,154' 2) 2 7/8' 6.5# N-80 ORD EUE 010,158' (1 JT) 3) BAKER SAB PI(R W/MILLOUT EXT. 010,192' 4) tO'2 7/8' 6.5~ N-80 8RD EUE PUP 010,204' 5) OTIS 'X' NIPPLE 010,214' 6) 8' 2 7/8' 6.5{~ N-80 8RD EUE PUP 010,215' 7) WlRELINE RE-ENTRY GUIDE 010,224' RECEIVED M/kY 1 2 1994 uti & 6as Cons. Commission Anchorage TD 011,520' PBTD 010.850' STATE OF ALASKA --- ALAL . OIL AND GAS CONSERVATION COMM ;:::)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Pull tubing _ _ Alter casing 2. Name of Operator Union Oil Company of Califomia (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 4. Location of well at surface 680' FSL, 680' FWL, Sec. 4, 'I'TN, R9W, SM At top of productive interval Same as above At effective depth Same as above At total depth Same as above __ Plugging _ _ Perforate __ Repair well ~X Pull tubing __ Other_ _ 5. Type of Well: Development _ Exploratory __ Stratigraphic.__ Service X_ 6. Datum elevation (DF or KB) 160' RKB 7. Unit or Property name Soldotna Creek Unit feet 8. Well number SCU 314-4 9. Permit number/approval number 60-21/93-316 10. APl number 50-133-10104-00 11. Field/Pool Swanson River- Hemlock 12. 13. Present well condition summary Total depth: measured true vertical 11,520' feet 11,520' feet Effective depth: measured 10,850' feet true vertical 10,850' feet Casing Length Size Structural Conductor 30' 20" Surface 3005' 13-3/8" Intermediate Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth Yes 30' 30' 600 sx 1st stage 3005' 3005' 11 oo sx 2nd stage Production 11040' 7" 650 sx 1st stage 11040' 11040' 650 sx ~,nd stage Liner Perforation depth: measured 10291'-10297'; 10302'-10306'; 10318'-10333'; 10354'-10365'; 10376'-10432'; 10450'-10456 10464'-10545'; 10588'-10655'; 10670'-10674' true vertical Same as above Tubing (size, grade, and measured depth) See Schematic Packers and SSSV (type and measured depth) See Schematic / PR 994 Stimulation or cement squeeze summary Intervals treated (measured) None Gas Cons, c0mm%ss'ton Anchorage Treatment description including volumes used and final pressure None 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Shut in Gas Injector Inject 41,046 450 Tubing Pressure 5000 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations x_ 16. Status of well classification as: Oil _ _ Gas __ Suspended _ _ Service Gas Injector Signed G. Russell Schmidt ,~~~itle Drilling Manager Form 10-404 Rev 06/15/88 Date 04/04/94 SUBMIT IN DUPLICATE SWANSON RIVER FIELD 814-4 ACTUAL 3/10/94 20" @30' 7" 83/86/29// N-e0 FROM 0-7895' 7" 25# P-IlO FROM ?895-9554' 7" 29# P-110 BELOW 9554' A) 3 1/2" 9.3# N-a0 CS-HYDRIL @10,154' (337 JTS) PERFS @ 10,29 I- 10,297' PERFS @ 10,302-10,306' -- PERFS @10,318-10,333' ~ PERFS @ 10,354-10,365' PERFS @ 10,376-10,432' PERFS @ 10,450-10,456' = PERFS @10,464-10,545'= PERFS @ 10,588-10,655' PERFS @10,670-10,674'= 7" @11,040' 1) OTIS ")IA'' SLEEVE @ 1 O, i 54' 2) 2 7/8" 6.5# N-80 8RD EUE @10,158' (1 JT) 3) BAKER SAB PKR W/MILLOUT EXT. @10,192' 4) 10'2 7/8" 6.5# N-80 8RD EUE PUP @10,204' 5) OTIS "Xf' NIPPLE @ 10,214' 6) 6'2 7/8" 6.5# N-80 8RD EUE PUP @10,215' 7) WIRELINE RE-ENTRY GUIDE @10,224' RECEIVED APR 1 1 1994 gia~ka 0{{ & (]as Cons. Commissio~ Anchorage PBTD @10,850' TD @11,520' SCU 314-4W0 DAY 1 (12/19/93) 13-3/8"@ 3005' 7" @ 11,040' 8.5 FILTERED LEASE WATER COMMENCE OPS AT 2401 HRS 12/18/93. MOVE AND RIG UP AWS RIG #5 ON SCU 314-4. DAY 2 (12/20/93) 13-3/8" @ 3005' 7" @ 11,040' 8.6 FILTERED LEASE WATER + 3% KCL COMPLETED RIG-UP OF AWS RIG #5. PULL BPV. R/U SLICKLINE AND RETRIEVE PS PLUG (FOUND AT 10473', ORIGINALLY SET AT 10293'-SUSPECT WORN PROFILE ALLOWED PLUG TO FALL). 3 HRS REPAIRED DAMAGED CHARGING PUMP. DAY 3 (12/21/93) 13-3/8"@ 3005' 7" @ 11,040' 8.6 FILTERED LEASE WATER + 3% KCL RIGGED DOWN DIVERTER. CUT CASING. WELDED BOWL ON TO 13-3/8" CASING. RECEIVED APR 1 1 1994 Oil & Gas Cons. Commission Anchorage SCU 314-4W0 DAY 4-8 (12/22-26/93) 13-3/8"@ 3005' 7"@ 11,040' 8.6 FILTERED LEASE WATER + 3% KCL CHANGED DSA AND WORKED ON LOCK-DOWN BOLTS. TEST BOPE. PULL BPV. SUCKLINE OPEN XA SLEEVE. STABILIZED WELL: BULLHEAD 40 BBLS AND CIRCULATE THROUGH SLEEVE ABOVE TOP PACKER. AI-I'EMPTED TO PICK-UP TBG HANGER - STUCK. WORKED TBG HGR FREE (STRING WT. INDICATED TBG PARTED - CANCELLED PLANS TO CUT TBG.) CIRCULATED AND PULLED TBG 28' WITH INCREASED STRING WT. AT THAT POINT. POOH W/630' TBG. MADE UP STORM PKR AND RAN BACK IN AND SET AT 200'. TESTED PKR AT 1,000 PSI - OK. REMOVED BOPE AND REMOVED TBG HEAD SPOOL. REPLACED AND TESTED NEW TBG HEAD SPOOL AND RE-INSTALLED BOPE. SET TEST PLUG AND TESTED BOPE - OK. RELEASED STORM PKR AND POOH W/TBG. (PRESSURE TESTED 13-3/8" X 7" ANNULUS AT 1,000 PSI TO CHECK 7" CSG - OK) CONTINUED POOH AND RECOVERED 4 PRODUCTION PACKERS ON TBG. (FOUND TOP PACKER RELEASED, REMAINING POSSIBLY NEVER SET.) RAN 3-1/2" COMPLETION STRING COMPLETE W/PRODUCTION PKR AND JEWELRY. LANDED COMPLETION STRING AND SLICKLINE SET PX PLUG IN X NIPPLE AT 10,214'. PRESSURED TBG TO 3,000 PSI AND SET PKR @ 10,192'. TESTED ANNULUS - OK. SET BPV. REMOVED BOPE AND INSTALLED SEAL FLANGE. DAY 9 (12/27/93) 13-3/8" @ 3005' 7"@ 11,040' 8.6 FILTERED LEASE WATER + 3% KCL TESTED SEAL FLANGE AND INSTALLED 3" 10,000 PSI XMAS TREE. TESTED TREE AT 10,000 PSI-OK. RELEASED RIG AT 0600 HRS 12/17/93. COMMENCED RIG MOVE TO SRU 21A-34. RECEIVED Z~PR 1 1 1994 .~,~.~;~,~ u~ & Gas Cons. Commission Anchorage '~KA OIL AND GAS CONSERVATION COt .?SION REPOHT OF SUNDRY WELL OP RATIONS// 1.0oerations performecl: Ol:)era~n s~utcmwn __ Stimulate__ ~uggmg __, e __ / G Pull tubing __ Alter casing __ Re0air weft X Pull tubing __ Other __ y.~_._/ 2. Name of Operator 5. Type of Well: 6. Datum elevation Union Oil Company of California dba Unocal Development - 160 RKB Exploratory _ 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 680' FSL. 680' FWt_. Sec. 4, TTN, Rgw. SM At top of productive interval Same as Above At effective del3th Same as Above At total depth Same as Above Stratigraphic Service X feet 7. Unit or Property name Soldatna Creel< Unit 8. VVell number SCU 314-4 9. Permit number 60-21 10. APl number 50-133-10104-O0 11. Field/Pool Swanson River-Hemlock 12. Present well condition summary Total depth: measured true vertical 11.520 feet 11,520 feet Effectrve depth: measured 10.850 feet true vertical 10,850 feet Plugs (measured) Junl< (measured) Casing Length Size Structural Conductor 30' 20" Surface 3,005' 13 3/8" Intermediate P rod uction 11,040' 7" Liner Cemented Measured depth True vertical depth yes 30' 30' 600 sxs 1st statue 3,005' 3,005' 1100 sxs 2nd st-age 650 sxs l_. st .st .age 11,040' 11,040' 650 sxs zna s[age Perforation depth: measured 10,291-10,297'; 10,302-10,306'; 10,318-10.333'; 10,354-10,365; 10,376-10,432; 10,450-10,456';10,464-10,545'; true vertical 10,588-10,655'; 10,670-10,674' Same as above Tubing (size, grade, and measured depth) 3 1/2" ]',I-80 CS Hydriii to 10,151' RECEIVED Packers and SSSV (type an0 measured depth) 13. Stimulation or cement squeeze sUmm~ry Intervals treated (measured) Baker SAB @ 1 O, 192' FEB 1 6 1994 fill .~. Treatment 0escnption including volumes used and final pressure 14. Prior to welt operation S ubsecluent to oberation l& .~tac.ments " Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure --- 39,279 --- 38,463 16. Status of weft classification as: Oil __ Gas __ SuspenOed __ g~ect to the best of my knowledge, Title ~-~Cc~,~ Fnrm 1(3-4Z~ R~v fiR/1.rdRR 1,000 700 ~bingPre~ure 5,080 5,000 Gas Injector Date 47-~/~+ RI JRMIT IN I')1 IPl I~AT~- Depths Relative to Top of Wellhead Swanson River Field SCU 314-4 Actual 12/26/93 20" @ 30' Tubing Hanger w\ 3 1/2" CS Hydrili box down BPV profile Cameron H 13 3/8" @ 3,005' 7" 23/26/29# N-80 from 303' to 7895' 7" 26# P-110 from 7895' to 9554' 7" 29# P- 110 Below 9554' L 3 1/2" 9.38 N-80 CS Hydrill to 10,151' 3 1/2" Otis XA Sliding Sleeve @ 10,154' Joint 2 7/8" 6.5 # N-80 EUE Baker 2 7/8" Anchor Seal Assembly Downhole Jewelry Perforations From 10,291'. 10,297' Perforations From 10,302'- 10,306' Perforations From 10,318'-10,333' 10,354'- 10365' Perforations From 10,376'- 10,432' Perforations From 10,450'- 10,456' Perforations From 10,464'-10,545' Perforations From 10,588'-10,655' PefforaUons From 10,670'-10,674' Baker "SAB" Packer @ 10,192' Otis 2 7/8" "X" Nipple @ 10,214' Wireline Re Enty Guide to 10,225' RECEIVED FEE~ 1 6 1994 Alaska Oil & Gas Cons. Commission Ancflor~oe 7" @ 11,040' TD @ 11,520' PBTD @ 10,850' ,Swanson River SCU 314-4 Completions Summary 12/26/93 Total depth: measured 11.520 true vertical 11,520 feet Plugs (measured) feet EffectrVe depth: measured 10.850 true vertical 10.850 feet Junk (measureO) feet Casing Structural Length Size Cemented Measured depth True vertical depth Conductor 30' 20" yes 30' 30' Surface 3.005' 13 3/8" 600 sxs 1st stage 3.005' 3,005' 11 O0 sxs 2nd stage Intermediate Production 11.040' 7" 650 sxs 1st stage 11.040' 11.040' 650 sxs 2nd stage Liner Perforation depth: measured 10,291-10,297'; 10,302-10.306': 10.318-10,333'; 10,354-10,365; 10,376-10.432:10,450-10,456';10,464-10.545'; true vertical 10,588-10,655'; 10,670-10,674' Same as above Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) as per attached schematic 3 lrz' 9.3# N-80 CS Hydnll to 10.151' 7" Baker SAB @ 10,192' FEP~ '~ 6 ~994 Gas Cons. 6ommissior, Anchorage Operations Summao SCU 314-4WO DAY I (12/19/93) COMMENCE CPS AT 2401 HRS 12/18/93. MOVE AND RIG UP AWS RIG #5 ON SCU 314-4. DAY 3 (12/21/93) REPAIR MUD PUMP SUCTION LINE/MUD PUMP. CIRCULATED WELL ABOVE TOP PACKER TO COMPLETION FLUID AND BULLHEADED 50 BBLS TO ZONES. SLICKLINE SHUT XA SLEEVE AT 10,215' AND SET X PLUG IN PROFILE. TESTED @ 1500 PSI-OK. SET BPV. N/D X-MAS TREE-N/U BOPE. TEST BOPE AND REPAIR LEAKS. DAY 4-8 (12/22-26/93) CHANGED DSA AND WORKED ON LOCK-DOWN BOLTS. TEST BOPE. PULL BPV. SUCKLINE OPEN XA SLEEVE. STABILIZED WELL: BULLHEAD 40 BBLS AND CIRCULATE THROUGH SLEEVE ABOVE TOP PACKER. ATTEMPTED TO PICK-UP TBG HANGER - STUCK. WORKED TBG HGR FREE (STRING WT. INDICATED TBG PARTED - CANCELLED PLANS TO CUT TBG.) CIRCULATED AND PULLED TBG 28' WITH INCREASED STRING WT. AT THAT POINT. POOH W/630' TBG. MADE UP STORM PKR AND RAN BACK IN AND SET AT 200'. TESTED PKR AT 1,000 PS! - OK. REMOVED BOPE AND REMOVED TBG HEAD SPOOL. REPLACED AND TESTED NEW TBG HEAD SPOOL AND RE-INSTALLED BOPE. SET TEST PLUG AND TESTED BOPE - OK. RELEASED STORM PKR AND POOH W/TBG. (PRESSURE TESTED 13-3/8" X 7" ANNULUS AT 1,000 PS! TO CHECK 7" CSG - OK) CONTINUED POOH AND RECOVERED 4 PRODUCTION PACKERS ON TBG. (FOUND TOP PACKER RELEASED, REMAINING POSSIBLY NEVER SET.) RAN 3-1/2" COMPLETION STRING COMPLETE W/PRODUCTION PKR AND JEWELRY. LANDED COMPLETION STRING AND SLICKLINE SET PX PLUG IN X NIPPLE AT 10,214'. PRESSURED TBG TO 3,000 PSI AND SET PKR @ 10,192. TESTED ANNULUS - OK. SET BPV. REMOVED BOPE AND INSTALLED SEAL FLANGE. DAY 9 (12/27/93) TESTED SEAL FLANGE AND INSTALLED 3" 10,000 PSI XMAS TREE. TREE AT 10,000 PSI-OK. RELEASED RIG AT 0600 HRS COMMENCED RIG MOVE TO SRU 21A-34. TESTED 12/17/93. RECEIVED FEB 'i 6 I994 l,.t~,~ka 0il & Gas Cons. Commission Anchorage .------, STATE OF ALASKA ALASKJ iL AND GAS CONSERVATION CC ,/IISSION APPLICATION FOR SUNDRY APPROVALS VD 1. Type of request: Abandon m Suspend m Operations shutdown t Re-enter suspended well__ Alter casingt Repair well X_._ Plugging ~ Time extension ~ Stimulate __ Change approved program Pull tubing _ _ Variance __ Perforate Other__ 6. Datum elevation (DF or KB) 2. Name of Operator Union Oil Company of California dba Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 . Location of well at surface 680' FSL, 680' FWL, Sec. 4, 'I-/N, R9W, SM At top of productive interval 5. Type of Well: Development:~F_ F_xplorato~y Stmtigraphi~ Rrr..C iV D 160 RKB 7. Unit or Property name Soldatna Creek Unit 8. Well number SCU 314-4 9. Permit number Same as Above At effective depth Same as Above At total depth Same as Above t 0v 1 8 1993 Gas Cons. Commissi0~ Anchorage 10. APl number 50-133-10104-00 11. Field/Pool Swanson River-Hemlock feet 12. Present well condition summary Total depth: measured true vertical 11,520 feet Plugs (measured) 11,520 feet Effective depth: measured 10,850 true vertical 10,850 feet Junk (measured) feet Casing Length Size Structural Conductor 30' 20" Surface 3,005' 13 3/8" Intermediate Production 11,040' 7" Liner Perforation depth: measured 13. Attachments ORIGINAL Cemented Measured depth True vertical depth yes 30' 30' 600 sxs 1st stage 3,005' 3,005' 11UU sxs 2ncl s[age 650 sxs _1. st stage 11,040' 11,040' 650 sxs 2no stage 10,291-10,297'; 10,302-10,306'; 10,318-10,333'; 10,354-10,365; 10,376-10,432; 10,450-10,456';10,464-10,545'; true vertical 10,588-10,655'; 10,670-10,674' Same as above Tubing (size, grade, and measured depth) 3 1/2" EUE to 10,211 '; 2 7/8" to 10,633' Packers and SSSV (type and measured depth) as per attached schematic Description summary of propos~X Detailed operations program___ BOP sketch X 14. Estimated date for commencing operation November 26, 1993 16. If proposal was verbally approved Oil ~ Gas t Name of approver Date approved Service Gas Injector 17. I her~DE cert~ that ~J~e~fo~o~g is t~and correct to the best of my knowledge. 5. Status of well classification as: Suspended__ Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity m BOP Test_ Location clearance _ Mechanical Integrity Test ~ Subsequent form required 10- Approved by the order of the Commission Original SJgnu.. David W. d0hnst0~- Form 10-403 Rev 06/15/88 Approved Copy Returned Commissioner -Date ///' ~'~/'?a SUBMIT IN TRIPUCATE SWanson River Field SCU 314.-4 Workover Procedure 11/19/93 1. ~ up electric line and chemical cut tubing O 10,220'. 3. Kill weB. Set BPVor plug in "XA" Sleeve at 10,215'. 4. Nipple down tree and nipple ~up B.O.P. Test B.O.P. to 5,000 psi. Retrieve tubing. o RIH with Tristate High Pressure packoff on. Baker Packer and Engage tubing stub. 7. RIH with new completion string. 8. Pressure test robing/casing annulus to· 1,500 psi. 9. Install BPV; nipple down B,O.P. Nipple up-tree; pressure test to 10,000 psi. 10. Release RECEIVED NOV 1 8 199b AI;~ska Oil & Gas Cons. Commission Anchorage Swanson River Field SCU 314-4 Proposed 11/19/93 20" ~ 30' 3 1/2" 9.3~ N-80 CS Hyddil to 10,200' 3,005' 7', 23/2§/29~ N'80.from 303' to 7895'. 7" 26~ P-110 from 789.5' to 9.554' 7" 29~ iP- 110 Below 9554' Perforations From 10,291'-10,297' Perforations From 10,:~02'-I0,306' Perforations From 10,318'- 10,333' 10,354'- 1036.5' Perforations From 10,376'-10,432' Perforations From 10,450'- 10,456' Perforations From 10,464'-t0,545' · Perforations From 10,588'. 10,655' PerforaUons From 10,670'- t0,674' 7" O 11,040' TD ~ 11,520' Downhole Jewelry Baker "DB" Packer with Floating Seals ~ 10,200' Tristate High Pressure Overshot Packoff Baker 7"x 2 7/8" "FH" Packer ~ 10,250 Otis "S" Nipple Pos 4 ~ 10,293' PBTD ~ 10,850' Otis "XA" Sleeve ~ 10,327' Baker 7"x 2 7/8" "FH" Packer ~ 10,364 Otis "S" Hippie Pos 3 ~ 10,376' Otis "XA" Sleeve ~ 10,409' Baker 7"x 2 7/8" "FH" Packer ~ 10,435' Otis "S" Hippie POs 2 ~ 10,473' Otis "XA" Sleeve ~ 10,506' Baker 7"x 2 7/8" "FH" Packer ~ 10,5§2' Camco "D" nipple ~ 10,600' End Tubing ~ 10,633' RECEIVED NOV 18 1993 Al~s~ Oil & Gas Cons. Commission Anchorage L:A'NDING · · I ' o0 · ~ · oo .o t,~ANOREL TO .KB 17' '~'~' EUE , ~. TM ~gTi~ XA' ..SLEEVE '/" ?.~' ~ Z.TM [UE 8/:iKfR "FH' OTIS PO..5 fl ~5"IVII::FL£ IJ ,6S° ts* OT, IS 'XA' SL[.[."/(. '7' ~' - 2TM E, JE I~Kr,..R 'FI.i" F/~,~. OTIS ?OS 3 '5"UIPR_E: OTI.5 'X/i' 5LEDJE '7" Zcl*, 8,TM El,[' BAKER 'Fir' PKR · t.. I I I .. ~ r3~z' . J ¢S(I. 9SS4'"I.D. IS ?" 20 P OTIS RECEIVED NOV 1.8 199~ Oil & Gas Cons. Commission Anchorage '7,:' 2"1" B/tff..~ Ff.I,L' PKR -'/b 'ID 8.?/0. CAMCO 'g" k)!l::l:L£ 10215 IOZ~ IO"t'13 I0~? I0~0 Contract Exhibit E OPTION I FILL-UP KILL LINE ( 3 FLOW I ANNULAR BOP 10" 3000 psi PIPE RAMS 10" 5000 psi BLIND RAMS 10" 5000 psi ~ SPOOL ll~o" 50o0 psiS.. ? unOKE 5000 psi ][ Ii 3" 5000 psi [ PIPE RAMS 10" 5000 psi I LINE=~> BOP STACK 10" 5'000 psi RECEIVED v 1 8 199~5 Gas Cons. Commissk Anchorage 1. Type of request: STATE OF ALASKA ALASKA;,-~., AND GAS CONSERVATION COM~,flSSION (~, ,~ APPLICA..ON FOR SUNDRY APl. tOVALS '" .... o u o,- w,,_ '"";"2.4.3 I Change approved program __ Pull tubing __ Vadanoe __ Perforate -- , .O~h, erX__. ,(MIT) Type of Wel: 6. Datum elevation (DF or KB) ~ ~ 1601:1KB /"~' 2. Name of Operator Union Oil Company of California (tJnocal) 3. Address P.O. Box 196247 Anchorage, Alaska 99619-6247 4. Location of well at s~fac, e 680' FSL, 680' FWL, Sec. 4, 'ITN, R9W, SM At top of produclive Interval At effective deplh At total depth J5. RECEIVED JUL o 199 Alaska Oil & Gas Cons. Com~tss'to~ Anchorage 7. Unit or Properly name ~dotna Creak 8. Well number SCU 314-4 9. Permit number ~'~ -..2 I 10. APl number 50-133-10104-00 11. Field/Pool 8wanaon River/Hemlock 12. Present well condition summary Total deplh: measured true vertical 11520 11520 feet Plugs (measured) feet Effective depth: measured 10850 true vertical 10850 feet Junk (measured) feet Casing Length Size Structural Surface 30O5' Imermedlate Production 11040' 7' liner Perforation depth: measurecl true vertical Tubing (size, grade, and measured depth) Cemented Measured depth True vertical deplh 20" Yes 30' 30' 13-3/8" 600 sx 1st stage 3005' 3005' 11oo sx 2n(:l stage 650 ax 18t stage 11040' 11040' 10291-10297, 10302-103(~, 10318-10,3,33, 10354-10365, 10376-10432, 10450-10456, 10464-1~, 10588-10655, 10370-10674 10291-10297,10302-10306, 10318-10,3,33, 10354-10,365,10376-10432, 10450-10456, 10464-10545, 10588-10655, 10670-10674 3-112' to 10211 ', 2-7/8', $.5# N-80 to 10677' Packers and SSSV (type and measured depth) Baker 'FH" @ 1025O', 10364' & 10435'; Baker 'FHL' @ 10662' Description summary of proposal_ Detailed operations programX__ BOP ~ketch _ 14. Estimated date for commencing operation !15. .... July 20, lgg3 ......... 16. If proposal was verbally approved Oil __ Gas __ Name of approver Date approved Service Inlector Status of well clasalfioation aa: FOR COMMISSION USE ONLY Condit~ o~ approval: Nomy Commission so representaltve may wllness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Teat.~ ~bsequentform required 1-'~-. /-,/~ ~ ...Approved. by,the order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W. Joh~.sJJpn Approved Copy Returned _ Commissioner Date SUBMIT I~1TI:JlPLICATE E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension RECEIVED ',JUN 15 I~8~ Alasl~ 011 & Gas Cons. Commission Anchomcle Manual Rams Swab Valve Double Master Valves J~ · Wellhead RECEIVED J U L 2 0 199) Alasl~a Oil & Gas Cons. Commission Anchorage PC & SC Loading and PC Pressure Test SCU 314-4, SR 45 To load the PC and SC and to verify mechanical integrity on the PC per the AOGCC requirements. This testing must be witnessed by the AOGCC before July 1, 1989. Well Data: PC: SC: Top pkr. depth: Capacities: Current Pressures: 3-1/2" EUE tbg. to 10,211' MD 7" N-80; 23, 26 and 29# to 11,040' MD 13-3/8" 54# J-55 to 3,005' MD 10,250' MD Tbg x PC = .0264 Bbls/ft. PC x SC = .1070 Bbls/ft. Tbg=5150psi; PC = 2550 psi; SC = 150psi ]Procedure: Load PC and SC . Install a two-pen recorder on the well to monitor the SC and PC pressures. . Shoot fluid levels on the SC and PC. (Skip to step #10 if no load is needed on the SC or PC). Calculate needed load volumes to fill SC and PC. Assure that this fluid .is on location for load. 3. Monitor tbg., PC and SC pressures throughout the Job. 4. Hold safety meeting. 5. RU choke and gas buster to SC, as needed. 6. Blow down SC pressure without allowing fluid production. 7. Hook up pump truck to SC and pressure test lines to 4500 psi. . Load SC with lease water containing .25% W1'676 corrosion inhibitor finishing with a 5 Bbl crude cap. Do not exceed 300 psi during pump-in. e Repeat steps #5-8 for the PC, as needed, using a 3000 psi maximum injection pressure for step #8. (Several 1,000 psi blowdown/loads may be required). RECEIVED JUL i 0 1B~ Alaska Oil & Gas Cons. Comm~ssio~ 'Anchorage PC & SC Loading and PC Pressure Test SCU 314-4, SR 45 Page Two Contact the AOGCC (279-1433) and BLM (267-1243) at least 24 hours prior to testing the PC so that an agency witness can verify the test results. PC Pressure Test 10. Pressure up PC to 500 psi over current pressure (2,000 psi minimum). Hold for five minutes (observing tbg., PC and SC pressures). 11. If less than 50 psi is lost in five minutes, increase pressure by 500 psi. Hold for five minutes. 12. Repeat step #11 until 3600 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. 13. RDMO. JUL ~ 0 1995 Alaska Oil & Gas GoDs. 'Anchorage J, : ' "I4'A'NblNG MANOREL TO .KB 17' · . . · · · .;, 8t:ir, L~ "Ftl' PKR · e,e · · ~",' EL/E , 2. '/" ELI[ OTIS XA' 5LF. EWE "/" ?.q' ,r Z"'e' EUE O.ilS P05't . fl OS' 0 -"'*' ~TtS ' X/i' OTIS F'OS 3 '.S'UIFFI.[ OTIS '~' SLEDJE BAKER 'Fir' PKR : - · :. d UL ~ 0 Alaska Oil & Gas Gons. 10215 10250 lorn3 IO3~ IO31lo 10'i'l~ IO5'~ 1092 103C0 tO~.t3 STATE OF ALASKA ' ~ ALA,.,c,A OIL AND GAS CONSERVATION COMMI~_. ON REPORT OF SUNDRY WELL OPERATIOI II P [ ! £ A T E 1. Operations performed: Operation shutdown __ Stimulate__ Pluggingm Pull tubing ~ Alter casing m Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK Pedorate __ Pull tubing ~ Other _~X M I T J5. Type of Well: Development g Exploratory g I Stratigraphic ~ 99510 Service ._~ 4. Location of well at surface 680' FSL, 680' FWL, Sec. 4, T7N, Rgw, SM At top of productive interval 6. Datum elevation (DF or KB) 160' RKB 7. Unit or Property name So ldotna Creek Unit 8. Well number SCU 314-4 9. Permit number/approval number Same as above. ~effe~ivede~h Same as above. ~totalde~h Same as above. 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production Perforation depth: 10. APInumber 50-- 133-10104-00 11. Field/Pool Swanson River-Hemlock 10,850 feet Plugs (measured) feet 10,850 11,520 feet Junk(measured) 11,520 feet Length Size Cemented Measured depth 30' 20" yes 30' 3,005' 13-3/8" 600 sx 1st atage 3,005' 1100 sx 2nd stage measured 10,291-10,297'; 11,040' 7" 650 sx 1st stage 11,040' 650 sx 2nd stage 10,302-10,306'; 10,318-10,333'; True vertical depth 30' 3,005' 10,376-10,432'; 10,450-10,456'; 10,464-10,545'; 10,588-10,655'; trueve~icai Same as above. ~bing(size, grad~andmeasuredde~h) 3-1/2" to 10,211', 2-7/8", 6.5~, N-80 to 10,667'. PackersandSSSV(typeand measureddepth) Baker 'FH' ~ 10,250'~ Baker 'FH' ~ 10,364'~ Baker 13. Stimulationorcementsqueezesummary Intervals treated (measured) N/A 14. feet 11,040' 10,354-10,365'; 10,670-10,674'. 'FH' ~ 10~435' Baker FHL @ 10~562' ~ · Treatment description including volumes used and final pressure Representative Daily Average Pr~u~ion or Injection Data ........ chnr~n~'o' ~um~SSiOr~ Oil-Bbl Gas-Md Water-Bbl Casing Pressure AnTObl~ressure Prior to well operation -- 3 9,9 5 3 -- 2,5 0 0 4,7 0 0 Subsequent to operation -- 40,460 -- 2, 100 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 4,800 Service Gas Injector Signed Title Cook Inlet Engineering Manager Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE · .. . i i mllll .............. PRl~.:~r. ~-~- 15'~11q 30 iff. iq" . .......,~::._,~.,-.:. .... .- · ~ ,., ' ,, ~~: B : l~ ~m ffi i I i iii1~1 i i i i [ i iii IL iN .,. ~. ~ ~ I Ill I I I I i i m ii i mil I II i i i - . . ~ ........ , , il . ' ' Ill ti I IU _ ~m iml ~ III II I I I I l i i lmm I I I Il I I I ~ I I I I I I Ill Ill film I I I I Il I lmmI I Il I I lllll lllll I I Il I I Il Il ii ii i i i i .... ............. iii i i I ii II I II II I I II I I i Eli I S REP SI~ "2~} A~ 25.030(a) ,;.:..~ ~,C 25.t~12(c) 23 ~ 2~.2~2(d) I I ,/ ARCO Alaska, Inc. Post Office B~'x 100360 Anchorage, Alaska 99510-036G Telephone 907 263 4724 · T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures June 14, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: ARCO Alaska, 'Inc. requests approval to perform the attached mechanical integrity tests on SCU 314-4, SCU 332-4, and SCU 321-9. This testing is designed to demonstrate tubing and production casing integrity in accordance with the AOGCC Injection Order No. 13, Rule 6. It is being done to satisfy the requirement to test 25°/6 of our Class II wells per year. Plans are to perform the MIT's as soon as possible as the testing deadline for the 1988-89 program is June 30, 1989. Please contact Carol Baker at 263-4643 if you have any qUestions concerning this matter. Sincerely, T. S. McCorkle TSM: CMB: ch: 0017 Attachment cc: G. ~ Graham A. R. Kukla UNOCAL Corporation Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 STATE OF ALASKA '-" AL,,vXA OIL AND GAS CONSERVATION COMMI',....,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Alter casing __ Change approved program Suspend __ Repair well __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension ~ Stimulate __ Pull tubing __ Variance ~ Perforate ~ Other X I5. Type of Well: · Development Exploratory Stratigraphic Service 2. NameofOperator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510 4. ~cation~well~surface 680' FSL, 680' ~top~produmiveinterval Same as above. ~effectivedepth Same as above. ~to~aldepth hame as above. 12. Present well condition summary Total depth: measured true vertical FWL, Sec. 4, T7N, R9W, SM 11 ' 520~_ feet Plugs (measured) 11,520~t~ feet 10,850~2 feet Junk(measured) 10,850J feet None Size Cemented Effective depth: measured true vertical MIT Testing 6. Datum elevation(DForKB) 160' RKB Z UnitorPropertyname Soldotna Creek Unit 8. Wellnumber SCU 314-4 9. Permit number 10. APl number 50-- 133-10104-00 11. Field/Pool Swanson R i ver-Hem lock RECEIVED IUN 15 1989 Alaska 0il & I~as Cons. C0mmlsslon Measured depth J~rlcJl~rruac~veertical depth Casing Length Conductor 30 ~ Surface 3,005 ' IXt~~e Production 11,040 ' Perforation depth: measured 20" yes 30' 30' 13-3/8" 600 sx 1st stage 3,005' 3,005' 1100 sx 2nd stage 7" 650 sx 1st stage 11,040' 11,040' 650 sx 2nd stage 10,291-10,297'; 10,302-10,306'; truevertical Same as above. feet 10,318-10,333'; 10,354-10,365'; 10,376-10,432'; 10,450-10,456'; 10,464-10,545'; 10,588-10,655'; 10,670-10,674' Tubing (size, grade, and measured depth) 3-1/2" to 10,211', 2-7/8", 6.5#, N-80 to 10,667'. Packers and SSSV (type and measured depth) Baker 'FH' @ 10,250', Baker 'FH' @ 10,364', Baker 'FH' @ 10 435' Baker FHL ~ 10,562' , 13. Attachments Description summary of proposal ~ Detailed operations program .zX_.._ BOP sketch ,K 14. Estimated date for commencing operation 115. Status of well classification as: 16. If proposal was verbally approved I Oil ~ Gas ~ Suspended Name of approver Date approved Service Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~~~ /~ -/~/~cC--~,'~ Title Cook Inlet Engineering Mgr. FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BQR Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ¢ ORIGINAL SIGNED BY LONNIE O. SMITH Approved by order of the Commissioner JApproval No. Approved Copy Returned _ Commissioner Date FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE E-Line BOPE's ,. Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Maste~ Valves Wellhead PC & SC Loading and PC Pressure Test SCU 314-4, SR 45 Objective: To load the PC and SC and to verify mechanical integrity on the PC per the AOGCC requirements. This testing must be witnessed by the AOGCC before July 1, 1989. Well Data: PC: SC: Top pkr. depth: Capacities: Current Pressures: 3-1/2' EUE tbg. to 10,211' MD 7" N-80; 23, 26 and 29# to 11,040' MD 13-3/8" 54# J-55 to 3,005' MD 10,250' MD Tbg x PC = .0264 Bbls/ft. PC x SC = .1070 Bbls/ft. Tbg= 5150psi; PC =2550psi; SC = 150 psi Procedure' Load PC and SC . . Install a two-pen recorder on the well to monitor the SC and PC pressures. Shoot fluid levels on the SC and PC. (Skip to step #10 if no load is needed on the SC or PC). Calculate needed load volumes to fill SC and PC. Assure that this fluid .is on location for load. 3. Monitor tbg., PC and SC pressures throughout the job. 4. Hold safety meeting. 5. RU choke and gas buster to SC, as needed. 6. Blow down SC pressure without allowing fluid production. 7. Hook up pump truck to SC and pressure test lines to 4500 psi. 8. Load SC with lease water containing .25% V~rI'676 corrosion inhibitor finishing with a 5 Bbl crude cap. Do not exceed 300 psi during pump.in. e Repeat steps #5-8 for the PC, as needed, using a 3000 psi maximum injection pressure for step #8. (Several 1,000 psi blowdown/loads may be required). PC & SC Loading and PC Pressure Test SCU 314-4, SR 45 Page Two Contact the AOGCC (279-1433) and BLM (267-1243) at least 24 hours prior to testing the PC so that an agency witness can verify the test results. PC Pressure Test 10. Pressure up PC to 500 psi over current pressure (2,000 psi minimum). Hold for five minutes (observing tbg., PC and SC pressures). 11. If less than 50 psi is lost in five minutes, increase pressure by 500 psi. Hold for five minutes. 12. Repeat step #11 until 3600 psi is reached. Hold pressure for 30 minutes, noting initial and final pressures on all strings. 13. RDMO. '-': e.. n MANDREL · -= TO.KB 17' 3""' EUE ,~ 2.. '/" £U£ ~TIS XA' 5LF_EVF.. -/" 29' ~ 2TM EUE 8,qr~ "FrI' CKR OTIS POS 'i ~'~:IFFL£ OTIS 'XA' SLEE'2L "l" ~,' , 2TM E'dE BAK~ 'FH" FK~ OTIS F'OS 3 '.S"UlPfL~ OTiS 'X/:i' 5LF~JE 7" ~!' · 2''~' £UE BAKER 'FH" PKR OTIS :y~ '7" 29k BAr, ER'FI+L' PKR-Y,Z) lC) ~.?/~' - ¢J~MCO ' g" MIFFLE - ~HEFIR 10215 IOZ.~) : ! I0~0 ~,i '.'~J -~111. ' ~1':~r~~11 I~ ~.,~oo' · bi' ~l -''~ * ~11 i~~"~~s, ~~.~ ~u~o ~o,o6~.~, · f I ~ !- :~o,os~.o~ ~ ~," ~ ~. z~ ~ ~.~, ' 'il ·/' ' ' ¢ ' ' . !~.{.11-?'"/ . ~ ~. ~. ~ ~~ ~.o~, ~l' ~~~ ..... 10~39~*~91 ~ C~ ~ F~~ ' 12.9~e '1~iili,,..,. / · · "1. ~-:..-:-~-~{~I~.!'.~,._.- . ':~... I.. ~ , ..: ~: . ..' : .... · i~ :'~ ' :'"'?~!:~''''~- - · '1 ' ~,~,2~~~ ~.~, . ;:.... . .~ ,k;~,.- , , -' . · .'~,~ ~:.. '/~:~,1~ I ~.....'_,. I ~ ~o~ ~ ' ' .a, .' ' elO~' . .m~eg · · · " - '-/ -. "~~' ..... · / ,~. i:' -~: · ~a.~:'. : ~o,~.~9,~~ ~ ,~'. · ' .~, . t..; .. -~-..i?,,: ,o:~.~,~. ~,~ ~ ~. ~. '. ~.~, / ' : ~i i'."'"* '--' · ' ' / t ; · ~i iw~o i,e,~'. -'- .--.' - · ~,...,. ~~ - ~o,~, ~o~ ~ ~ ..... ,,, - T~ ,~ .. _ ~. .." . ' . - : - - - -' - . ~ ~ 11j~~ ~ · ' CASING ' ' ' · . ~;~:;o" ',. SCU ~1.4-4 2~ ..8o ~o~'-,~ge' ' ' z~ Ne0 ~296' ~93' ~ASING & TUBING DETAI z6' N-e04793'-e~0~' SECTION 4 T. 7 H.,~W. 2~e N.8oezo5'-7895' . --. - "'"~ "" -" ":~- ....... SWANSON RIVER WELL. ~l I~/Bo ._- SRU ~ 81 --SRU 5l ~/Sf ~_ SRU ~'S~CU ~SCU ~ SCU ~ SCU .~ SCU ,.SCU ~ SCU 5 r /~/-'r~ - SRU 312-22 314-2-7 331-27 323-4 332-4 341-4 341-8 312-9 321-g 323-9 432-15 TYPE Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Water Injector STATUS AS OF 1/1/88 Shut-in ...~ Shut-i n "Shut-i n Injecting Injecting Injecting Shut-in Injecting Injecting Injecting Shut-in GRU13/2c RECEIVED FEB2~ ""' :'-' Al~sk~ Oil & G~8 ¢on~. Commission Ancflorag~ ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.2.52 ARCO Alaska, Inc. 110500 SWANSON RIVER FIELD - UNIT 051950 August 1987 09-Sep-87 Name o~ Operator Fi eld and Pool Month and Year of Injection :1. WELL. : NO. · '514-4 1.5.5-101 ~1~4-00 I 52.5-4 I .5.52-4 I 341-4 I 341-8 I 525-9 1412-10 I .521-~ ~ 45-4WD l l l I : l 1 I 2. API NUMBERI3. C~4. FIELDI5. DAYSI TUBING PRESSURE 50- ~ LI & POOL I Al CODE I OPER l&. MAXI7. AVERAGE PSIG I SI I I PSIG I l___SI I I ...... I 772100 I 1.55-1010~-00 IG I 772100 I 0 I 0 I 155-10107-00 IG I 772100 1.5.5-10109-00 IG I 772100 I 50 15,550 I 1.55-10120-00 IG I 772100 I 0 15.5-1012.5-00 IG I 772100 I 30 I5,550 I 133-1012&-00 IG I 772100 I .50 15,.500 I 1JJ-101~8-00 ~ I 772100 155-2020&-00 lB I 772100 1.55-10125-00 I8 I 772100 I 50 15,450 I 1.5.5-10111-00 ID I 77205& I I I l 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 t 4,~58 0 5,005 5,141 0 4~945 4,928 0 0 0 I I I I I 1 I ' I l I l I I I I I l CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION I I B. MAXIg. AVERAGEI10. LIQUID I11. GAS I 15. LIQUID I 14. GAS PSIG §500 0 1,040 2,860 0 1,240 2,600 0 0 1~9&0 0 PSIB I (BBL) I (MCF) '1 (BBL) I (MCF) I ~ I I I I 2, .559 I I .59 ~ 259 0 I I 0 1 656 I I .51,6.52 2,.576 I I .57,120 0 I I 0 I 1~109 I I 40,485 2,568 I I .55,148 0 I I 0 I I 0 1 1,815 I I 25,706 0 I 0 1 I I I I I I I I I l .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 1 I I 1,177,1&5 C ) 948,955 ,. 0 1 1~214~475 I 054~ 428 I I I 0 1 I I I I I I I I I l I' I I l 1 I I l 0 0 771,182 II hereby certify that the foregoing is true and correct to the best of my knowledge I Signed ~, ~ ITitle ~ ~,C A/~'J ~'~ ~'% ' ~ Date Form 10-405 Rev. 12-1-85 INSTRUCT IONS ON REVERSE SIDE 115. I I I I I I I I I I I I I I I I I I I ITOTAL I 0 I &,279,814 I I I Submit in Duplicate ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTIONREPORT 20 AAC 25.252 ARCO Alas;ca, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051994 Fi eld and Pool August 1987 Month and Year of Injection WELL|2. API NUMBERIS. CI4. FIELD NO. I 50- I LI & POOL t I Al CODE I l___SI 1312-22 1133-101~7-00 IG I 772100 1314-27 1133-10154-00 IG I 772100 1551-27 1153-1015&-00 IG I 772100 1452-15 1135-10141-00 IG I 772100 121-55WDI155-101&2-O0 ID I 77205& I31-35WDI135-2055&-O0 ID I 77205& 152-55WDI.155-101&4-O0 ID I 77203& 141-35WDII55-101&7-00 ID I 77205& 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 1 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 : : :. 5. DAYS IN OPER 29 29 30 PSIG I PSIG I PSIG I I I I I I I I I 875 I 754 I 820 I 746 I 0 875 I 759 I 0 850 I 751 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 t I I I I I I I TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION I I I I 6. MAXI7. AVERAGEI8. MAX 9. AVERAGEIIO. LIOUID Ill. GAS 15. LIQUID I 14. GAS I PSIG (MCF) (BBL) I (MCF) I I ' I I I I I 0 1 0 I ' I 1 I I I ' I I I ' I ' I I ' I I I ' i 5O II hereby certify that the foregoing is true and correct to the best of my knowledge Date Z INSTRUCTIONS ON REVERSE SIDE I I I S i gned I l : ITitle I (BBL) I 2,675 2,770 2,071 145 Form 10-405 Rev. 12-1-85 115. t I I I I I ITOTAL I I I I I I I I I 77,581 I I 80,518 I I 62,119 I I 4,352 I 1 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 1 I I I I I I' I I I I I l I I I I 224,370 I 0 I I I Submit in Duplicate PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE BAY' PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUOHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUOHOE BAY PRUDNOE BAY PRUOHOE BAY PRUDHOE BAY PRUDNOE BAY UNIT S-11 UNIT S-1~ UNIT T-1 UNIT T-7 UNIT U-3 UNIT U-h UNIT UNIT U-9 UNIT U-lO UNIT X-6 UNIT X-11 UNIT 'X-23 UNIT X-2~ bNIT X-26 UNIT Y-3 UNIT UNIT Y-6 UNIT Y-7 UNIT Y-'11RD PRUDHOE BAY UNIT Y-18 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL SWANSON RIVER, HEMLOCK OIL POOL ARCO ALASKA INC SOLDOTNA CK UNIT 31h-h SOLDOTNA CK UNIT 323-h SOLDOTNA CK UNIT 332-q SOLDOTNA CK UNIT 3~1-q SOLDOTNA CK UNIT 3~1-8 SOLDOTNA CK UNIT 312-9 SOLDOTNA 'CK UNIT 321-9 SOLDOTNA CK UNIT 323-9 ............ SOLDOTNA CK UNIT h12-10 SOLDOTNA CK UNIT 3~3-33 UNIT OR LEASE TOTAL 309,53~ 264,~25 17h,~67 380,162 602,357 515,072 26h,751 183,322 2~,173 29~,661 lh9,980 173,5~ 262,057 282,3~ 76,~92 49,131 8~,323 22,223 ~3,679 306,~29 14,519,526 39,536,156 8h,~5,002 39,536,156 88,810,1~0 SOLDOTNA CREEK UNIT SHUT-IN SHUT-IN 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 1,1h8,650 31 1,080,598 31 871,~02 31 1,090,670 31 153,799 6 1,246,967 3O 7h9,378 31 1,089,518 31 7,~30,982 ~;975;o~o 7,115,160 1,2~1,h72 2,275,741 2,727,957 2,791,~76 2,551,632 1,790,980 1,767,557 6,17~,166 5,618,096 3,530,3h2 5,273,083 3,169,181 3,gh2,h03 1,968,753 2,653,~03 102,6h0 597,32'1 6,~09,296 1,388,876 294,7~2,9'15 233,327,280 207,759,3b0 231,76~,932 218,69~,6~7 30~,0~,302 33,033,8~2 170,911,513 111,~13,676 - - ENHANCED RECOVERY - - WELL NAME AND NUMBER ARCO ALASKA INC SWANSON RIV UNIT 331-27 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL TRADING BAY, MICDLE KENAI C OIL POOL UNION OIL CO CF CALIFORNIA ADL-18751 TRADING BAY ST. A-SRD-2 TRADING BAY ST A-12RD TRADING BAY ST A-26 TRADING BAY ST A-29 UNIT OR LEASE TOTAL POOL TOTAL TRADING BAY, MIDDLE KENAI D OIL POOL UNION OIL CO OF CALIFORNIA ADL-18T$1 TRADING BAY ST A-SRD-2 TRADING BAY ST A-19 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL ALASKA INDIVIDUAL WELL PRODUCTION FOR HARCH, 1987 OIL(BBL) WTR(BBL) GAS(MCF) DAYS S~ANSON RIVER UNIT SHUT-IN 7,b30,982 7,~30,982 SHUT-IN SHUT-IN -...,..,~// SHUT-IN / SHUT-IN SHUT-IN CUM. OIL CUM. WATER 413,934 15,582,616 h,~98,822 6,267,061 7,3~8,68~ 21,618,156 CUM. GAS 28,263,659 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.232 ARCO Alaska, Inc. 110500 Name of OPerator SWANSON RIVER FIELD - UNIT 0519~4 Fi eld and Pool December 1986 Month and Year of Injection I1. WELL:2. API· NUMBER~5. C:4. FIELD~5. DAYS~ TUBING PRESSURE I CASING PRESSURE :DAILY AVERAGE INJECTION~TOTAL MONTHLY INJECTION : I NO. I 50- I LI & POOL I IN I I I I I I I t Al CODE I OPER I&. MAXI7. AVERAGEI8. MAXI~. AVERAGEIIO. LIQUID 111. GAS I 15. LIQUID I 14. GAS I I I I SI I I PSIG I PSIG I PSIG I PSIG I (BBL) I (MCF) I (BBL) I (MCF) I I___SI I I~12-22 115~-10147-00 I G I 772100 I 514-27 1155-10154-00 I G I 772100 t ~ 1-27 I I I I I I I I I I I I I I I I I I I . . · _.. ; ! 15~-1015~-00 I G I 772100 I 155-10.141-00 I G I 772100 I I I I I I I I I I 1 I I I I I I I 1 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 t .- 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 t 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 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 I I I I I I I I I I I ...... I I I I II hereby certif~ that the forego~i'ng is true and correct to the best of my knowledge ~Signed .... ~'~-~.-- --~-?- ...................... Supirvi,~lX-, New Ventures Compliance and Revenue ~.~~_ ITitle Date ........ Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE 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 1 I I I I I I I I I I I I I I I I I I I I I I I l I I I I I I I I I I I I I I I I I ~ .I.-- , , KECEI\, D I I I I I I' ,J, '~i'~ ~ ~'I 115. I ' : Alaska 011 & Gas C~;.,I ..... :~nlss~on : : - /.inchon?-: I I I I I I I I I I I I ' ITOTAL I 0 I 0 ' I I I ' Submit in Duplicate ! I I I I I I I I I I I I I I I I I I I ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 N~me of Operator SWANSON RIVER FIELD - UNIT 051950 Fi eld and Pool December 1986 Month and Year of Injection Il. WELLI2. API NUMBERIS. CI4. FIELD:5. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTION:TOTAL MONTHLY INJECTION I ' I NO. I 50- I LI & POOL I IN I I I I I I . I I Al CODE I OPER 16. MAXI7. AVERAGEI8. MAXIg. AVERAGEIIO. LIQUID III. GAS I 15. LIQUID I 14~ GAS I t I I SI I I PSIG I PSIG I PSIG I PSIG I (BBL) I (MCF) I (BBL) I (MCF) I I I I___SI I I ...... I I ...... I I I I 514-4 1155-10104-00 IB I 772100 I 50 15,500 I 5,015 12,500 I 1,560 I I 52,501 I I 975,018 1 I 525-4 1155-10106-00 IG I 772100'I 50 15,650 I '5,278 15,250 I 1,976 I I 29,526 I I 885,785 I --! 552-4 I155-10107-00 IG I 772100 I 50 15,500 I 5,071 I 700 I 594 I I 24,058 I I 721,155 I :~,i.-~::..t 541-4 1155-10109-00 IG I 772100 I 50 15,550 I 5,157 I1,200 I 849 I I 29,951 I I 898,524. I :~:;'1 541-8 I15~-10120-00 IG I 772100 I 50 15,500 I 4,882 11,400 I 1,548 I I 25,121 I I 695,626 I I 512-9 I155-10125-00 IG I 772100 I 50 15,000 I 4,697 12,850 I 1,267 I I 55,165 I I 1,054,878 I I 525-9 1155-10126-00 IO I 772100 I 17 15,200 I 5,140 11,600 I 1,588 I I 25,550 I I 450,602 I 1545-55 1133-10168-00 IG I 772100 I 0 I 0 I 0 I 0 I 0 I I 0 I I 0 I 1412-10 1155-20206-00 IG I 772100 I 0 I 0 I 0 I 0 I 0 I I 0 I I 0 I I 521-9 1155-10125-00 IG I 772100 I 50 15,540 I 5,150 11,600 I 1,089 I I 20,970 I I 629,091 I t t 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 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 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 t 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 Ira~_~j~- I :~ here~x ~erti~X that ~-*~[~ is tr,e ~-E~rre~t to the ~est o~ mx kno, iedee '""~" :~" ~ ....... ~" ~ i St~n~d ....................... I SuperV~i~sor~ Ne~ Ventures Compliance and Revenue I ITitle Date -_ _ ~.~/?_ ...... 0 I 6~288~655 I I I I Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SID~ Submi~ in Duplicate I I I I15. I I- I I l | I TOTAL I I LEASE NO. IENHANCED RECOVERYI COHP.DATE 4 + STATUS PRODUCT JAN FFR HAR ~~ SHANSON R[VER, HENLOCK ARCO ALASKA INC SOLDOTNA CK UNiT 3]4-4 UNIT051950 OIL ALASKA INDIVIDUAL HELL%ODUCTION FOR 1986 APR NAY JUN JUL AUG SEP OCT AP! l~-lOlO4-OO ., YEAR ~ NOV ~FC TOTAL CUM. 08/15/60 HTR 1OINJ GAS 1055857 1026390 1189909 1165806 1228646 1211657 1257286 1288352 1503704 1123075 1022955 975018 15808653 291785545 SOLDOTNA CK UNTT 323-4 APT UNIT051950 OIL 06/01/61 HTR GINJ GAS 926806 895795 101~489 1021315 10938~7 109595~ 11107~2 1160265 1165222 986857 950909 885785 125059~2 230168775 SOL~OTNA CK UNiT ~-~ AP~ UNIT051950 O,L 06/05/60 HTR 1G[NJ GAS 729520 69~699 694207 76~55~ 848986 ~08659 ~55755 906429 908925 775879 7550~ 721~55 9~65572 20555~8~5 SOLDOTNA CK UNiT ~6]-6 AP~ 1~-1 nl oq-nn UN[T051950 05/21/60 HTR [G[NJ GAS 964182 959897 1105510 1004702 1191650 1125455 115189~ 1167267 1142665 989567 1047597 89852~ 12728fi66 .S.OL~OTNA C[ UNiT ~6~-~ APL UN[T051950 07/14/61 HTR lO[NJ GAS 772050 721011 855765 795562 858795 85180[ 877~66 885~19 861~54 802085 790782 695626 9761772 217114264 SOLOOTNA CK UNiT ~]2-q APT ~-]n]2~-nn UN[T051950 ~0/09/60 HTR lO[NJ GAS 1150860 1105246 1275468 1219454 1266462 124282[ 1268188 1518592 [512222 [120ql5 1159677 SOLDOTNA CK UNTT 52~-q APL ~-~n]~-nn UN[T051950 OIL 07/19/61 NTR 1GINJ GAS 787999 770786 9~1316 857121 859651 824009 859794 852454 865~1 701058 657884 629091 95~6564 51111755 UNZT051950 07/17/61 HTR 1GZNJ GAS 868162 887705 105740~ 1002092 10~1~5~ 1027008 105~526 1105~48 1110180 1002927 967125 SOLDOTNA CK UN[T 412-10 APT UNIT051950 06/11/72 HTR ° 1H[NJ GAS SOL.DOTNA CK UNIT UNIT051950 03/08/61 HTR · 1G[NJ GAS -. SNANSON RTV UNIT UN[TO51994 10/24/59 HTR " IGINJ GAS SHANSDN RIV UNIT UNIT051994 OIL 0~/04/~1 NTR 1GINJ GAS 343-33 432-15 34-15 APT 133-lO]A~-OO 13888, APT 133-10141-00 111413676 · APT 133-10142-00 qOlSZ06 9029539 2056925 4643530 ? III !11 LEASE NO. IENHANCE9 RECOVERYI COHP.DATE 4 ~ STATUS PRODUCT JAN FER HAR ~~ SHANSON RIVER, HENLOCK SWANSON RIV UNIT 5]2-22 UNITOs]qg4 OIL ALASKA INDIVIDUAL HELL~ODUCTION APR MAY JUN JUl AUG AP1 155-10147-00 FOR 1986 SEP OCT NOV YEAR TOTAL CUM. 08/11/62 HTR 1GINJ GAS SWANSON RIV UNIT UNITOSIq94 OIL 516-27 APl 155-10154-00 875988 24017269 06/14/60 HTR 1GINJ GAS SWANSON RIV UNIT UNITOSIqq4 OIL 551-27 APl 155-10156-00 78552178 02/17/58 HTR 1GINJ GAS 282656 '-= ...... ARCO ALASKA OPERATOR 0IL TOTALS HATER 8,557,995 POOL, TOTALS GAS 7,041,527 7,852,406 8,187,502 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,596 8,115,868 8,569,449 8,595,451 8,667,789 7,511,775 95,601,665 SHANSON RIVER. HENLOCK 0IL HATER GAS 7,041,527 7,852,406 8,187,502 8,680,226 7,499,819 6,288,655 7,215,596 8,115,868 8,569,449 8,595,451 8,667,789 7,511,775. SHANSON RIVER 8,557,995 1,929,187,012 FIELD 95,601,665 TOTALS OIL HATER GAS 7,041,527 7,852,406 8,187,502 8,680,226 7,499,819 6,288,655 7,215,596 8,113,868 8,569,449 8,595,451 8,667,789 7,511,775 8,557,995 95,601,6 1 TABLE I Wells 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 Producti on 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 ~'343-33' ATTACHMENT E-I Injection Well Data Water Disposal. Avg. Wells Rate(BPD) SRU 31-33W 327/+ SRU 32-33W 651 sRu ~1-33w 125 sau 21-33w 2s05 scu ~3-/+w.; .... Max. Rate(BPD) /+500 /+500 ~500 /+500 ~500 Avg. Press(psi) 769 778 913 735 Shut In Max. Press(psi) 1000 1000 1000 1000 1000 Depth of , Inj.(ft.) 2100 2100 .2.~.s2 2.1.2_.0 3100 Depth of Well(ft.) 2~61 2520 3000 6660 Gas Injection Ave. Wells Rate(MCI;D) Max. Rate(MCFD) SCU 31-/+-2 39.,950 SCU 323-/+ 35,680 SCU 332-/+ 27,6/+0 (~m~ULi 3Q.I-/+ 37,6/+0 3/+ 1-8 30,300 '~5'C U 31'2-9 SCU 321-9 29,91$0 SCU 323-9~. ~ 35 ~ 920 SCU 31+3-33 0 SRU 332-15 0 SRU 312-22 0 SRU 31/+-27 0 SRU 331-2_7 t~ 0 /+5000 #5000 qS000 ~5000 ~5000 qS000 ~5000 /+5000 /+5000 /+5000 /+5000. ~5000 #5000 o,'/ 5075 5370 5095 5355 5160 5270 5155 5105 Shut In Shut In Shut In Shut In Shut In 5800 '5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 10291 1039~ 10~70 10226 10256 10183 1029/+ 10280 10695 11388 1075/+ 111#6 11520 10775 11119 10850 1081/+ 10785 107~5 10750 10995 11982 11000 11#3/+ 11620 ARCO Alaaka, Inc.~ Post Office L _ ^ 100360 Anchorage. Alaska 99510-0360 Telephone 907 265 6369 John C. Havard Engineering Manager Cook Inlet/New Ventures July 14, 1987 Mr. C. V. Chatterton Alaska Oil.& Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Re: Swanson River Unit: Gas Injection Well Production Casing Pressure Tests Dear Mr. Chatterton: Attached are seven (7) Well Service Reports documenting the results of the recent pressure tests conducted on Wells SCU 314-4, SCU 323-4, SCU 332-4, SCU 341-4, SCU 312-9, SCU 321-9, and SCU 323-9. The other active gas injection well, Well SCU 341-8, is currently loaded with kill weight fluid in anticipation of a late-September workover to repair a packer leak. Of the seven gas injection wells tested, only one (Well SCU 323-4) did not meet the criteria stated in Rule 6 of the AOGCC Area Injection Order No. 13. The remaining six wells held their calcu- lated test pressure (within 10%) for 30 minutes. The test pressure for each well was calculated to generate a differential pressure gradient across the casing of 0.25 psi/ft at the vertical depth of the uppermost packer. The surface pressures in Well SCU 323-4 have stabilized at acceptable levels (PC _+1500 psig, SC _+100 psig). We will be retesting this well for integrity in the near future. AOGCC and BLM representatives will be notified 24 hours in advance of this test, should they wish to be onsite. Until that time, we propose to continue injection into this well. if you need additional information, please contact H. F. Blacker at 263-4299. Very truly yours, J CH ;JWR:cI: 0004 Attachments cc: Mr. Joseph A. Dygas - Bureau of Land Management ARCO Alaska, Inc ,s a Subsidiary of AtlanticRichfieldCompan¥ Form 3~'60-5 .~Ndvember 1983) (Formerly 9--331) L,~'TED STATES 8um, z'r (Other Instrucf aa re DEPARTM~..r OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS O'N WELLS (Do not ume this form for proposals to drill or to deepen or plug back to n dltZerent reservoir. Use "APPLICATION FOR PERMIT--" for such prop~alt) Form approved. Budget Bureau No. 1004-0135 Expires_ AuEust 31, 1985 5. LEASE DBSlONA?ION AND IBIIAL NO. 6. Ir INDIAN, ALLO'A~BB Oit TItlES NAME 1. 7. UNIH AGIBEMENT NAME O'LWELL ~] GARwELL ~' OTHER Soldotna Creek Unit 2. NAMR OF OPERATOR 8. FAItM OR LEASTM NAMIt ARCO Alaska, Inc. 3. ADDRERB Or OPRRATOR 9. WILL NO. P.O. Bo× 100360, Anchorage, --~ 99510 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL (Report location clearly and tn accordance with any 8tare requirements.* See also space 17 below.) At surface Soldotna Creek Unit - 7 wells 15. ELEVATIONS (Show whether DF, aT, aR, et~) 14. PERMIT NO. Swanson Rivmr Fimld 11. 8B~., H., It., M., OIt BLE. Lifo Sec. 4, 9, T7N, R9W 12. ~UNTY OR P~ISHJ 18. ITATB Kenai Alaska 16. Check Appropriate Box To Indicate Nature ot Notice, Report, or Other Data NOTICB Or INTENTION TO: FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZR ABANDON* REPAIR WELL CHANGE PLANS (Other) X Pressure Test SOBSBQUBHH IIIsOIHO!: FBACTVRB TREATMENT ALTRRING CASING SHOOTING Oft ACIDIEING ABANDONMENTe (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) lT. 9ESCiHBZ PnOPOSED OR COMPLETED OPERATIONS (Clearly state all pertineut details, and give pertinent dates, including ~timat~ date of s~rUng any pcoposed work. If well is dir~ction~y drill~, give s~surf~e locations and measured and true vertic~ dept~ for all markers and ~nes pert~ nen~ ~ ~is wor~) * The AOGCC has issued Area Injection Order No. 13, applicable to Swanson River Field, effec- tive March 16, 1987. To comply with Rule No. 6 - Demonstration of Tubing/Casing Annulus Mechanical Integrity, ARCO Alaska, Inc. is planning on pressure testing the production casing annulus of each active gas injection well at Swanson River to a surface pressure sufficient to generate a differential pressure of 0.25 psi/ft between the uppermost packer and the formation. The wells included in the program are wells 314-4, 341-4, 312-9, 323-9, 321-9, 323-4, and 332-4. The attached procedures outline the steps that will be taken to conduct the test. The wells are currently being loaded with fluid in the production casing and surface casing annuli. The pressure testing is expected to occur in the last two weeks of June, 1987. RECEIVED 15. I hereby certify,that the foregoing is tr~e and correct TITLE Regional Engineer DA~ (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVA/,, XF Alq~: TITLE DATE *See Instructions on Reverm Side Title 18 U.S.C. Section 100l, 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 representations as to any matter within its jurisdiction. SCU 314-4 LOAD PRODUCTION AND SURFACE CASING AND PRESSURE TEST PRODUCTION CASING Loading PC: and SC Annulus 1. Record pressures on the tubing, production casing and surface casing. 2. Blow down PC' to 1000 psi, recording all pressures. 3. Blow down Sc, recording all pressures. . Shoot fluid levels for pump-in volumetrics. Estimated volumes from most recent fluid level data are noted below. . Load SC with lease water containing 10 gal/lO00 gal WT 676 corrosion inhibitor and a 5 bbl crude cap. Do not exceed 300 psi surface pressure during pump-in. Monitor all pressures. . Load PC with lease crude. Do not exceed 2500 psi during pump-in. Do not bleed PC below 1000 psi during pump-in. Pressure Testing) Production Casing Note: 24 hours prior to initiating pressure testing procedure, contact the Alaska Oil and Gas Conservation Commission at 279-1433 and the BLM at 267-1240, and inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. Note' During pressure tests of production casing, closely monitor PC/SC packoff to insure no communication to the surface casing. If any communica- tion is noted, cease pressure test and notify Engineering in town. 7. Pressure test PC/SC packoff to 3000 psi. . Pressure production casing to 2000 psi. Hold for five minutes, observ- ing pressures on tubing, production casing and surface casing. If initial pressure is already at or above 2000 psi, proceed to Step q. . If no significant pressure changes occur within five minutes (>50 psi), increase production casing pressure by five hundred psi. Hold pressure for five minutes. 10. Repeat Step 9 until a pressure of 3740 psi is reached. Hold pressure for 30 minutes, noting initial and final pressure on all strings. Vol umetri cs Fluid Level (4/17/87) Annular Capacity (bbls/ft) Estimated Fluid to sur. face (bbls) Surface Casing 510' .1070 55 Production Casing 146' .0264 4 DAILY PROGRESS OF WELL WORK Page I of 7._ For all W.L. work, perf. jobs, solvent jobs or other subsurface work other than drilling. Well no. $c0 31q-q Field: ~v/;,~S0:9 R~ec~ Date: /~¥ ~, t~{ Object: ~d~ ~c~j;,J ~.:o,:,~ 4~ ?~-~ ~,~': ~uf~ All contractors present during work ~-~v;~:d~ Work detail breakdown: Results by Company Representative , Contractor signature and Company (if detail prepared by Contractors) ce: Production Foreman -Area Engineer Well File - Original Company ReEr~entative Signature and Date DALLY PROGRESS OF WELL WORK Page Y- of ~- . - For all W.L. work, perf, jobs, solvent jobs or other subsurface work other than drilling. Well no. 5cu 5, q - fl Field: 5 cws ~ s~,-o ,e, ~ ~L. Date: 5- ~-8c/ Object: ~ All contractors present during work Work detail breakdown: Contractor signature and Company (if detail prepared by Contractors) Results by Company Representative ZoQ ~-~-,u ~,~v ~ r r~ - - ~ ' 2 O= /~dryoEGO '_~;2 Az~O Nl¢~ /~XE~.T,',,~ ,2~Tr /Oa,'o ~,20¢-, j'7¢/~, 6U,/~:c,,~(- 5~:'eJ ,~- T'~/~IE. ,,, ce: Production FOreman Area Engineer Well File - Original 3700 FrJ/~N: , Company Repre~e Signature and Date THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. °oo Ul::)o"rCA, Cz~mA We_..L.L a:: ged, 31.1-q 31q-q I / ! RECEIVED 8Y Illl Il I ~ /?' _,,'*, . ': .,.., .;-,, REMARKS ON OTHER SLOE, THIS SHE'ET ~ON U.S.A. INC. BOX 7.839 'ANCHORAGE, ALASKA 995!0 ASKA OIL ~,~A~~':/''''. -('COI~PA HY ~evron U.S.A. Inc. Box 7-839, Anchorage, AK 99510 TRANSMITTED WELL · L! ......................... ~CmT~ c~~ o,~,T ........ .,, , ,, . , .... ,,, ,, · ,,. ,,. ,,, . ~ . ,,, ,. ~ ... ~ ,,. , , . , mm ~ m II m m m m m I m , ~ 9.5¢ , SCHL~ C3ERGER WELL SERVICES 5000 GULF FREEWAY, P.O. BOX 2175 HOUSTON, TEXAS 77001, (713) 928-4000 PLEASE REPLY TO P.O. BOX 1001 KENAI, ALASKA 99611 May 7, 1984 Chevron USA, Inc. P. 0. Box 107839 Anchorage, AK 99510 Attention: Mr. Jim Logan Dear Jim: Attached is the drawing of the production logging string which was left in the Soldotna Creek Unit 314-4 on May 2, 1984. The sketch is hand dra~n and not to scale. The total length of the tool is 52.5 feet. Also, there was 612 feet of wireline left in the well. The wireline is .22 inches in diameter and weighs 9.6 lbs. per 100 feet. I hope this information will be sufficient for your well records. Yours very truly, SCHLUMBERGER OFFSHORE SERVICES Senior Field Engineer DK: ser A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION /o j. I! 1~ °° e.- I¢ t& o~ I ,'6 -i-c i{ -¢-' N~T-Y -' ;;," /o,,3 Tool Name Telemetry cartridge Telemetry housing Collar locator Hewlett Packard_ gauge Caliper Interface cartridge Interface housing Temperature tool Spinner 2-1/8" Weights (3 ~ $1444) Adapt er Adapter Adapter Adapt er Head Desi~nat ion ATC-CB 348 SHH-EB 191 CAL-UB 351 HMS-BA 141 TCS-C 832 PIC-EA 217 PIH-A 237 MTS-A 769 CFS-F 768 EQF-46 AH-38 AH-92 AH-94 AH-60 MH-22 Price $ 15,814 1,999 1,462 38,553 3,683 7,751 1,223 1,741 1,980 4,332 184 1,015 1,111 598 571 $ 82,,q,17, C. A. /HITE WIRE' LINE WELL ERVICE CO. P. O. BOX 156 ~ CASPER, WYOMING 82602 29315 COMPANY J~ i9 ~ I,,' ,"" ,~ ~ ADDRESS FIELD ~ ~ ~ ~ ~ ~' /'" · WELL g ~ ('J WELL PRESSURE WELL DEPTH CUSTOMER'S ORDER NO. COMPANY REPRESENTATIVE OPERATIONS ?/z,, - EQUIPMENT USED POWER UN,T W" 'e t; ,,, ," C~EW ,/'% ,~,~, ~. ~- ~'*,~' /.,~/.,'-~ ,,".s DALLY REPORT DATE OPERATION NO. HOURS AMOUNT ,, ~ ~,~ ~o~* ~ -~ ~/*~-,~ 1,~ ".-. MATERIAL SOLD ". --' ," 'QUANTITY · ~' ' ' DESCRIPTION REMARKS: . ~ .. · ~ . INVOICE NO. DATE AMOUNT, TOTAL SERVICE AND MATERIAL ACCEPTED: _ C. A. WHITE WIRE LINE WELL SERVICE.CO,',.'., · Page DALLY PROGRESS OF WE1,L V~:ORK For all W.L. work, pert', jobs, solvent jobs or other subsurface work other than drilling. Wellno. S'~LI 3/~-~ _Field:_~,~.~,- /~;~,~ Dale: ~--,F- ~ Object: of All eontraelors present during work Results by Company Represenlative ~on~etor signature and Company (if detail prepared by Contractors) Production Foreman Area Engineer Well File - Original Company Representative Signature and Date · ~, STATE OF ALASKA ~--,~, ALASKA O,L AND GAS CONSERVATION CO,..,qlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. ·Permit No. Chevron U.S.A. [nc. 3. Address 8. APl Number P.O. Box 7-839 50- 133-10104 4. Location of Well 680' E & 680' N of the S.W. corner, Section 4, T7N, R9W, S.M 5. Elevation in feet (indicate KB, DF, etc.) I 6 . Lease Designation a~nd Serial No. A-028997 12. 9. Unit or Lease Name Soldotna Creek Uni~ 10. Well Number SCU 314-4 11. Field and Pool Swanson River Heml oc k Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] '- Perforations [] Altering Casing [] . Stimulate [] Abandon [] Stimulation [~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull T,ubing [] 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). 1. Closed XA sleeves at 10,327', 10,409' and 10,506. 2. Shut i.n gas injection and acidized H-lO sand as follows' a) 30 bbl. (1260 gal.) 5% HC1 b) 15.95 bbl. (6700 gal.) 12-10 ultra mud acid c) 30 bbl. (1260 gal.) 5% HC1 3. Returned well to injection and opened XA sleeves at 10,327', 10,409' and 10,506'. *Work Performed July 26-28, 1982. AUG 2 ? ].982 AJ~aska Oil & Gas Cons, Commission Anchorage 14. I'hereby certify that the foreg~fl'h~)is true and correct to the best of my knowledge. Signed~..~,-~ . ~ Title Area Engineer The space below for Commission use'~ Date 8/16/82 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 (.,L AND GAS CONSERVATION CG,.,MISSION SUNDRY NOTICES AND REPORTS ON WELLS "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 7-839, Anchorage, Alaska 99510 50-133-10104 4. Location of Well 680' E and 680' N of SW corner of Section 4, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 160 K.B. 6. Lease Designation and Serial No. A-028997 9. Unit or Lease Name Swanson River Field 10. Well Number SCU 314-4 11. Field and Pool Swanson River Field Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (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.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering casing [] Abandonment [] Other 0 [] [] 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). Chevron plans to acidize wall SCU 314-4 as described in the attached program. Subsequent Work Reported m J U L 2 ~' Alaska 0il & Gas Cons. Commission ^nch0rage 14.' herebyceTyt~a~tforegoing 's true and correct to the best of my~c~knTledge. Signed AO .~__.~_//¢j...~_~ ~) ~//'~'/~' Title Operak. ions Super±ntendent Date . July 21t 1982 The space below for Commission use Conditions of Approval, if any: O~IG;tgAL SIGNED BY /ONNIE C~ SBiIII Approved by ..... ~,' ' COMMISSIONER Approved Copy Returned By Order of the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WELL: FIELD' ~ Wf? tI~P~/fWVEP- CHEVRON U,S.A. INC. WESTERN REGION ALASKA AREA WELLW~ ~DURE SUMMARY · · . . ,,. Loc.' 2E¢ TYPE WELL' TTN TYPE JOB ' _ _?TI~A[)I_I~ T/ON ORIGINAL SUMMARY OBJECTIVE ' SUPPLEMENTAL SUMMARY WELL DATA' K.B. - 1'7 CASING' , LINER ' T.D. II~'20 ZEE I~TF~C. IIED D~7~IL,~ , PBTD TUBING: 5~ PERFORATIONS: .... NOTES' PKR. 5 F 'C .~77'~ H ED PROGRAM RIG UP I~I~. LIP D~/.UbT_L T,c_~ T /_l~E-_< TD Ft FTEn ~--LIG t ./V~ VD/{?/H E H,eS. /:~"/. DETAILS ATTACHED I Distribution: -Original to Well File w.D. Seuer (3) Field Office(I) P ~re!x~rer (I) D.M, Wilson(I) Alaska Oil & Gas Cons. Commission /~ncHora,qe Date, , WELL: CHEVRON U.S.A. INC. WESTERN REGION ALASKA AREA WELL, WORK P~.C~RE ~UMMAR, Y · PROGRA_M [CON~NUED): PAGE o~ 2 mil , _.q77~A/Z. I~E .,<he_, . /A./JEC'7'/QtU /.4.~ 'LO',, £PZf O, ,FOP i 1, I _ _ , , , , u, 11 , ,, , i . , , -- -- JUL"2 ~ :t82 DETAILS ATTACHED Dlstrlbutlofl: 'C~lginal to Well File w.o. s<~, Field Offlce(I) Prep~ (I) D.M. Wilson(I) Abuku Oil & G~u (;uu~, Commission lknchora,qo . '.. ,~,~ · -..;..j.'.~_.'.- . ....--.. . .!~ .~ .. -.j . · : :::. ,,~ . -". :'. ." ,:'.- ~- . , ::.:.,..... ~;/--<~'"....: . · . ' · -~' 11 · .'~ " ..:'.. '..' .. ; . '..! . '" ' ' '" ~ ' ' ' :i' '' · .. ~i:.:;- " : ' ' ': '- ' I "" . f. · . . ,,,, · 4' ' f~. :; .:; LANDING MANDREL TO .KB 17' =' ~1'~:.*..'-.-~ ~ ... '......- . . . '.., . . ., · , ~, I1,1 , Il j, I , , I Iii · . -- e..t, ~1 ~ Z 5 ."02' ' ,. "3¥ EL/E ~ 2'/~'; EUE . lOP_Il ' 65' 'OTIS' 'XA' .SLEEVE ' 10215 -/" ICl' x g'~"' [LIE B~F-~ :'FH' PKR. IDZSD · OTiS FO.5 H 5 .I~iPPL£ IOL---~3 OTiS 'XA' SLEEVE ID3Z7 BAKER 'FH" PKI( 103b~ 7" ?_.fl* ' 2TM EUE- OTIS ?DS ~ 'S"~IPFLE .. 2' OTIS 'X/:I' 5LEEUE /' I . "FH" PKF~ .. '7" Z~l" 13/t[E/~:'FI~L~ PKR-Y,D TD " C..R MCO "D" ..CHAR. 5DE · IC/'G5 i I DBL'Yo ~ · flit & Gas (;OHS, Corn~nisstun HYDROFLUORIC ACID SAFETY PRECAUTIONS · · ALL CHEVRON U.S.A. INC. PERSONNEL MUST ABIDE BY THE FOLLOWING SAFETY PRECAUTIONS' · o NOTE: · These safety precautions have been adopted by 'Chevron U.S.A. Inc. and are recommended to the Service Companies. 2. 'Dowell, B. J. Service, and Halliburton sell hydrochloric - hydrofluoric acid mix for well stimulation. 2. All but the Halliburton Company call this mix "Mud Acid". The' Halliburton Company has a "Mud Acid" consisting of Hydrochloric Acid and surfactants and contains no Hydrofluoric Acid. Their Hydrofluoric - Hydrochloric Acid combination is known as "H. F. Acid". Be e The current trend is to increase HF acid concentrations from the 3% - 5% formerly used, to 10% - 15% in addition to the normal 10% to 15% hydrochloric acid. While these higher concentrations are more hazardous, the safety precautions outlined below apply to all mixes containing less than 20% HF. Special additional precautions should be added for concentrations above 20% HF. The acid is less dangerous after expending in the well but can still cause serious injury. HF acid mixtures will bur,~ the skin. Both HCL and HF acids can serevely damage eyes. HF acid fumes can cause eye damage, and the liquid HF can cause immediate blindness. SAFETY PRECAUTIONS '" The Production Foreman is to hold safety meetings with 'all personnel prior to start of the work and acquaint all..with these precautions and with the attached First Aid measures. e e Service Company people'may be required near the acid piping while pumping, but these should be kept to an absolute minimum. There is normally no reason for our Company personnel to get closer than fifty feet to the acid piping. An adequate supply of fresh water must be immediately available for emergencies and for washing tubing. Protective Equipment' (a) Eyes - Protective goggles shall be worn.by all personnel within fifty feet of equipment or lines containing HF acid. -Face shields should be used with goggles but are not adequate protection used alone. Face shields do not protect against acid vapors or splashing around edges of the shield. Alaska Area .June, 1982 .Page 1 of 3 o 5, 6, (b) Skin J'NormJl clothing is adequate protection from acid vapors. '~hing provides some immediate protection against liquid but should be ripped off and"the skin flooded with water if saturated with liquid acid. Wet or sweaty areas' will absorb HF vapors. 'F Attached to these safety precautions are the irst Aid measures drawn up by our Company doctors. IMPORTANT The attached are First Aid measures only. The patient must be rushed to a qualified physician immediately after administering First Aid by flushing with water for. a minimum of 20 minutes. The physician must be cailed'and advised of~che emergency and the type of chemical con- . tacted concurrently while administering First Aid. On wells which have had W-41 treatment, toxic arsine gas (AsH~) may be generated when contacted with HF acid. The Foreman is responsible for checking these wells with a DRAEGER detector as outlined in Chevron Practice No. 89. On wells which have some hydrogen sulfide production, additional amounts of this extremely dangerous gas may be released when acidizing. The Foreman is responsible for proper precautions and detection of H2S gas as outlined in Chevron Practice 77. · · Alaska Area .o ..June, 1982 Page 2 of 3 O. FIRST AID TREATMENT OF HYDROFLUORIC ACID INJURIES Contact With Skin 1. Put patient under Shower at once - remove contaminated clothing while under shower. Wash area 20 minutes. Inhalation 3. 4. 5. 6. Remove the patient to fresh air, free from drafts. Apply arti~ficial respiration, if necessary. Reassure the patient and discourage him from coughing. Keep patient warm, because he will be suffering from shock. Make patient rest. Take patient to emergency hospital. ContaCt With Eyes. le Irrigate eyes freely with clean Water for 15 to 20 minutes, holding eyelids apart during irrigation to insure contact of water with all of the tissues of the surface of the eyes and lids. NOTE' 1. 0 Take patient to a physician, preferably an eye specialist or emergency hospital. .. !MPORTANT " The above-are First Aid measUres only. The patient must be rushed to a qualified physician immediately after administering First Aid. In the Alaska Area the following doctors and/or hospitals have been contacted and are equipped for emergency treatment. SOLDOTNA/KENAI Paul G. Isaak, M. D. "Peninsula Medical Clinic i block off Kenai Spur Road. Soldotna, Alaska 262-4401 (8:00 a.m. until..5:OO'p.m.) weekdays only) 262-4404 or 262-4407 (after hours, weekends and holidays) Peter O. Hansen, M.D. Medical Center, Inc. Benco.Building Kenai Spur Road Kenai, Alaska 99611 283-4611 Alaska Area June, 1982 ~NCHORAGE Dale J. Trombley, M. D. 4001 Dale street Anchorage, Alaska 99504 (907) 276-0500 - Office (907) 272-5777 - Home Page 3 of 3 ...... -'-',~.~-, ,, / (~(,.,) --- ('~ ! ~ ._ . _. _ - ' IFIDT IFIE~I). DI6T~ICT: S~TE ~ ~ -~i:~YS "II. YE ' , ,~.?/~' ~,I _ ! . ~.,¢'/~.. / / I. ,a -~-t GONTI4AGTOR IOPffAATION AT REImOMT 11kE£ _ JMa"'d.,! ~4*fe~ -.~M,Z- J ,. d~.~/~. ,., ~ · REMARK~ -- ' i ii i il i i i, il i ilml , m mi - · ., . .... o~..~ ................. A.j~ ~d /M _ '/',f& a~_ /t). J.,EF ,., i mil, , i · mi i , i lUll I Il m i m____lll lmm i I __'7 i , i . i CHECK THIS BLOCK IF SUMMARY "CONTINUED ON BACK COMPLETION REPORT - REMEDL~2! WELL CHEVRON U.S.A. INC. AREA: Swanson River Field Kenai Peninsula Alaska LAND OFFICE: Anchorage PROPERTY: Swanson River Unit LEASE NO: A-028997 WELL NO: SCU 314-4 API NO: 50-133-10104 LOCATION AT SURFACE: 680' E & 680' N of the S. W. Cor.., Sec. 4, T7N, R9W, S.M. LOCATION AT TOTAL DEPTH: Same ELEVATION: 160' K.B. DATE: 4/82 T. L. PERRYMAN AREA SUPERVI $OR DRILLED BY: Brinkerhoff Signal Drilling Company, Rig #58 DATE COMMENCED REMEDIAL WORK: 10/11/81 DATE COMPLETED REMEDIAL WORK: 10/27/81 RETURNED TO INJECTION: 10/27/81 SUMMARY TOTAL DEPTH: 11,520' EFFECTIVE DEPTH: 10,850' CASING: 20" conductor cemented at 30' 13 3/8" cemented at 3005' 7" cemented at 11,040' PLUGS: 10,850' t £C£1V£D JUL i 4 1982 Alaska Oil & Gas Cons. C°mn~ission Anchorage 450' - 10,456' 10 670' - 10,674', PERFORATIONS: 10,318' - 10,333', 10, , , 10,291' - 10,297', 10,354' - 10,365', 10,464' - 10,545'. 10,302' - 10,306', 10,376' - 10,432', 10,588' - 10,655' LOGS: DUAL INDUCTION LATERLOG LONG SPACED SONIC LOG COMPENSATED FORMATION DENSITY LOG COMPENSATED NEUTRON FORMATION DENSITY LOG BOREHOLE COMPENSATED SONIC RECEIVED J U L i 4 ]982 Alaska Oil & Gas Cons. CommJssion Anchorage OCTOBER 10, 1981 Rigging up. Raised Derrick. OCTOBER 11, 1981 Continued Rigging up. Accepted rig at 6:00 p.m. OCTOBER 12, 1981 Mixed brine water (68 ppg). RU Dowell and lines to kill well, pumped 400 bbls. water no pressure on tbg or annulus. Turn flow to gas buster, well spurting gas and losing returns, now haVe +--1/4 to no returns at all, mix more brine water, pump 33 bbls down annulus had good returns. Circ w/100 bbls appear to be pulling in gas, pump down tbg w/50 bbls w/o returns, mix brine wtr w/polymers. OCTOBER 13, 1981 69 PCF Cont. mixing polymers in brine water. Killed well w/BW (400 bbls), gained full returns. Circ. 5 hrs, well flowing back. Circ. 1 1/2 hr., well still flowing. Brought wt. up to 9.2 ppg/69 pcf, circ, well dead no back flow. Installed back pressure valve, ND, Tree, NU BOPE. OCTOBER 14, 1981 Finished NU BOPE, had 200 psi on annulus, bled annulus down no flow. Tested pipe rams, blind rams, and choke lines and valves to 5000 psi held ok, tested hydril to 2500 held ok. Witness by USGS waived. OCTOBER 15, 1981 Removed~plug. Stabbed in Do-nut. Pulled 100,0009 over string weight-threads stripped on Sub-donut fell 17'. Stabbed Do-nut w/new sub. Pulled 120,000# over string weight and 74 rounds to try and release packer, unsuccessful. Rig ~p Dialog. Run freepoint couldn"t get below 2 7/8" tubing above top packer 'w/freepoint. RU and run dialog cutter. Cut 2 7/8 tubing. @ 10,888, Rigged down dialog. POH with 3 1/2" tubing. OCTOBER 16, 1981 69 PCF -- Finished POH w/3-1/2" tubing. Picked up fishing tools, and D.P. RIH. Circ. at 4900' due to bubbling gas. RIH. Circ. at 10,070' due to bubbling gas. OCTOBER 17, 1981 Raise mud wt. to 70 pcf. Screw down over fish w/overshot and jar on fish. POH (chain out). Lay down fish (287.44') retrieved; camco mm maudrell, 1 JT 2-7/8 EUE tubing, baker FH 7" x 2 7/8 packer, 1 JT 2 7/8 EUE tubing, Otis S nipple position #3, 4 JTS 2 7/8 EUE tubing camco mm maudrel, 1 JT 2 7/8 EUE tubing, 3/4 of brown He-16-1 7" x 2 7/8 packer (left 11" piece of packer loose in hole). Pick up fishing tools, BHA & RIH. Try and stab 1_1"~ ~%~h~ and screw into same. POH (chain out). No recover. RIH w/taperR~ L ]- 4 Gas Cons. Commission OCTOBER 18 1981 70 PCF RIH w/taper tap. Fishing. POH to 30 stands-circ bottoms up 2 times-no gas-POH- no fish. Picked up shorter taper tap & RIH-latch on fish. POH, circ. 2 BU @ 30 stds out. Finish POH. No recovery. Picked up modified spear and RIH. Picked up fish 6' and circ. 2 times bottoms up-no gas-POH. Well flowing @ 30 STDS out. Shut well in w/pipe rams. ISIDPP-450 psi ISICP-200 psi began weighting up mud for kill procedures. OCTOBER 19, 1981 72 PCF Finish weighting up mud to 72 PCF-SIDPP-500 psi SICP 450 at this point. SCR was established @ 9 SPM-175 psi. Circ. through Po-Boy Degasser. 2 min. of dry gas then a lot of mud was coming w/gas and being blown over crown. Shut well in again. Now SIDPP.1100 psi, SICP 3500 psi. Displaced mud in pit w/ligno weighted mud to 'raise mwt to 78.5 pcf. OCTOBER 20, 1981 Began killing well. Had wash out in tank setting. Shut well in. Had 740 psi SIDPP, and 3450 SICP. BRI. OCTOBER 21, 1981 90 PCF Built mud weight to 93 pcf (12.4ppg). ru Halliburton. Killed ~ell. Rig down Halliburton. Circ. through. Degasser-no returns. RI~ w/2 stands (195') of DP. Began circ. still losing mud-dropping wt to 87 pcf. Loss of 250 bbls. OCTOBER 22, 1981 78 PCF RIH very slow. Attempt to circ. w/86 pcf mud. No returns. Lowered mud wt. to 78 PCF. Reverse circulated and was able to get circ. this waF. OCTOBER 23, 1981 78 PCF Circulate out gas and balanced mud weight at 78 PCF. POH slowly. Circ. bottoms up @ 6 stands out-no flow-no gas cut mud. POH. Had 267' 10,371-10,638 'of fish. Found wire line tool at 10,601' in camco "D" Nipple. Pick up packer mill and DP. RIH. Mill out baker model D @ 10,565' in 5 1/2 hrs. Circulate bottoms up-gas cut mud-from 78 to 72. OCTOBER 24, 1981 79 PCF Circulate out gas cut mud. Raise mud weight to 79 PCF. No gas cut mud at this weight. POH slowly w/fish. Lost fish @ 1900'. POH check fishing tool. RIH. Got fish @ 1900'. POH. Lay down fish-pick up BHA. RIH ~/bit and CSG scrapper. Hit iron in bottom of hole at 10,784. Could push j~k to bottom. OCTOBER 25, 1981 78 PCF POH and lay down DP and BHA. Rig up casing crew. Hydrotestin~ 2 7/8" tubing and 3 1/2" tubing. R~[E~VED Al~sk~ Oil & Gas Cons. Commission Anchorage OCTOBER 26, 1981 79 PCF RIH w/ 3 1/2" and 2 7/8" tubing and landed at 10,663' with packers at 10,562', 10,435,' 10,364', and 10,250'. OCTOBER 27, 1981 Rig up GO International. Run Neutron logs for correlation. Space 3 1/2" tubing. Install Donut w/casaco plug and land tubing. Rig down GO Interna- tional. Nipple down BOp. Released rig at 6:00 p.m. OCTOBER 28, 1981 Finish nipple down BOP's. RE£EIYED J U L 1 ~ 1982 Alaska Oil & Ga,9 Cons. Commission Anchorage ALASK'~i STATE OF ALASKA ..-., ~;IL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORT ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator 7. Permit No. CHEVRON U.S.A. INC. 21-60 3. Address 8. APl Number P. O. Box 7-839, Anchorage, Alaska 99510 50-133-10104 4. Location of Well 680' E & 680' N from the S.W. Cor., Sec. 4, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 160' K.B. 6. Lease Designation and Serial No. A-028997 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 314-4 11. Field and Pool Swanson River Hemlock 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). The injection string and top packer of well'SC~ 314-4, Swanson River Field, were pulled and replaced as follows: 1. R. U. Brinkerhoff rig #58 and killed well with 68 p.c.f. KC1 Brine. 2. Removed X-mas tree and installed and tested Class III 5000 p.s.i.B.O.P.E. 3. Pulled 3%x2-7/8" injection string and packers at 10,159', 10,366', and 10,438'. 4. Milled out Baker model "D" packer at 10,565'. 5. Cleaned out with 6" bit to 10,784'. 6. Ran 2-7/8"x3~" injection string to 10,663' with packers at 10,562',10,435',~ 10,364' and 10,250'. ~ Removed B.O.P.E. and installed and tested 10,000~. p.s.i. ~. . Returned to injection. RECEIVED NOV ~ z, ],qB1 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that t, De~s true and correct to the best of my knowledge. Signe~~' ~.~' ~~/~i~~C~~ Titl~rea Operations Supt. The space below f~r ~ommission 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(-"'1.- AND GAS CONSERVATION C?'%MISSION % MONTHLY REPORT'OF DRILLING AND WORKOVER OPERATIONS' 1. Drilling well I~. Workover operation ;~] 2. Name of operator 7. Permit No. CHEVRON U. S . A . INC. 3. Address 8. APl Number P. O. BOX 7-839, ANCHORAGE, AK 99510 50-133-10104 4. Location of Well at surface 680' E & 680'N from S.W. Cor., Sec. 4, T7N, R9N, S.M. 5. Elevation in feet (indicate KB, DF, etC.) 6. Lease Designation and Serial No. !60' ~.;R- A-028997 9. Unit or Lease Name SOLDOTNA C~RV.V.~ 10. Well No. SCU- 3!~_-4 11. Field and Pool Swanson River Hemlock For the Month of. OCTOBER ,19 81 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced workover operations 10/11/81. Killed well with 68 P.C.F. Brine. Installed and tested class III 5000 P.S.I. BOPE. Pulled 3%" x 2 7/8" tubing and 2 7/8" x 7 packers at 10,159' 10,366' and 10,438'. Milled out model "D" packer at 10,565'. Cleaned'out to 10,784'. Landed 403 joints of 2-7/8" x 3%" tubing at 10,633' with packers at 10,250',10,364',10,435' and 10,562'. N.D. BOPE and installed 10,000 p.s.i. injection tree. Released Rig 10/27/81. 13. Casing or liner run and. quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run .16. DST data, perforatin§ data, shows of H2S, miscellaneous data NOV 1 0 198t Gas Cons, C0rnmrss[0r~ 17. I hereby~certify that theforego~ is true and correct to the best of my knowledge. NO'FE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ~, '7_1 _~ STATE OF ALASKA -~"~ ALASKA OIL AND GAS CONSERVATION C~,MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] ~ COMPLETED WELL [] OTHER [-I 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 3. Address P. O. Box 7-839, Anchorage, AK 99510 4. Location of Well Surface: 680' E and 680' N from SW corner of Section 4, T7N, R9W, SB&M. 5. Elevation in feet (indicate KB, DF, etc.) 160' KB 12. I 6 . Lease Designation and Serial No. A-028997 8. APl Number 50-- 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 314-4 11. Field and Pool Swanson River Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [-] Repair Well ~] Change Plans [] Repairs Made [] Other Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We propose to pull the injection string and replace the top packer as noted in the attached program. We anticipate this work to begin the second quarter of 1981' RECEIVED JAN2 2 1981 Alaska 0il & Gas Cons. Commission A~ch0raga 14. I hereby cet,~ that the for~egoing is true and correct to the best of my knowledge. Signed Title Area Eng±neer The space below for Commission use// Approved by Form 10-403 Rev. 7-1-80 Date 1~9/81 COMMISSIONER By Order of the Commission Date Apprehend Copy Returned t - Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate .. · PROPOSAL FOR"WELL OPERATIONS PR0-316-1 Fi eld · Swanson River Proper_tY and Well No.' Soldotna Creek Unit 314-4 Surface Location' 680' East and 680'North from the Southwest corner of Section 4, T7N, Rgw, SB&M. Total Depth: 11,520 feet. Plug_s: 10,850 feet.. Casing_~- 20" Conductor cemented at 30 feet. 13-3/8" cemented at 3,005 feet. 7" 23#, 26#, and 29# cemented at 11,040 feet. DV collar at 7,059 feet. Perforations' 4 - ½" holes per foot 10,318' - 10,333' 10,450' - 10,456' 10,670' - 10,674'. Tubing: See attached. Junk' Hone reported. 10,291' - 10,297' 10,354' - 10,365' 10,464' - 10,545' 10,302' - 10,306' 10,376' - 10,432' 10,588' - 10,655' Datum' 15' above ground level at original KB elevation of 160'. · BOPE Considerations' Gas injection well. A, Be Maximum anticipated formation pressure is 4500 psi in the Hemlock at 10,460'. A 68 pcf drilling fluid will overbalance formation pressure by 435 psi. Maximum possible surface pressure' 3500 psi. Care must be exercised to avoid swabbing the well when pulling injection string. C. Any kicks should be handled by normal procedures. All personnel should be made aware of these methods. The hole is to be kept full at all times. D. Blowout prevention equipment' Class III - 5000 psi for all work. RECEIVED JAN2 2 1981 ~aska Oil & Gas Cons. Commission Anchorage PROGRAM 1. Pull CEV at 10,126 feet. , Move in contract rig and kill well with 68 pcf KCl brine as directed by Production Foreman. 3. Install safety plug in do-nut, remove xmas tree. 4, Install and test Class III, 5000 psi BOPE, including 5000 psi blow and kill lines. Alaska Oil & Gas Conservation Commission and U.S.G.S. to witness test. Remove pl.ug. . Release packers Uppermost packer is Baker 2-7/8" x 7" 29# Model FH. at 10,159 feet. Remaining hydraulic packers are 2-7/8" x 7" 29# Brown HS-16-1 Models at 10,366 feet and 10,438 feet. e Pull 3½" x 2-7/8" injection string. RIH with packer mill. Mill and retrieve Baker Model "D" at 10,565 'feet. . · RIH with 6" bi..t and clean out to 10,850 feet or as deep as possible. e Make up hydraulic packers and jewelry on 2-7/8" tubing; run 2-7/8" x 3½" injection st.ring per supplementary program to be furnished. Hydrotest tubing to 6500 psi. 10. Se,t hydraulic packers. 11. Install plug in do-nut. Remove BOPE and install 10,000 psi injection tree. Test tree to 6500 psi with clean water. 12. Remove plug, release rig. 13. Backflow intervals sep'arately to clean up well. Return to injection in selected intervals per supplementary program. REC£1VEI) JAN2 2 1981 Naska 011 & Gas Cons. Commission Anchorage. · ' ' ' SC d '51 · ; ' ' ; °,',~ :'" ~ I .... ~;. . .~.' ,.,', ........ · , ,I '~ ' ' ' .: ........................... , . - ~ ,. % · L'"A'N~Ir,IG. MANDREL..~7 ;'r(.3.5 Landing Mandrel ......... · o..F,~ ,17:; ........... i .............................. ; ...... · ..... '. '. ~., . - .~ .. ~ o ~o~.o~',---~ .... 33,0o~ ~.wd~s' 3'/z''X_Over.~U~ Tu bin ~ ':. ~o,o:~2.~.a .... -~ r-~e~' x o,~' ................ '-~. ..... 1.1'3 ---i dr. 2}~" EUE Tubing ........ :.; ....... 31.51 I0, !13.73' :.-- :'v .... b,'-;k',C 0"" ,",'~ .',*' ' ' ' ;'.' ~c,';vr~l' ' 1~5.01 .-.'- 10,1£~4' ~ ...... ' .......... .:-~ ...... · I - · , .... :::~.,.:k,::r F'tt ¥"., :,: 2.~" Pc,.cker ................ ~" ' "dt 2~' !L'~ '" --' '] .... ,-I0'1S8.62'- ....... . S Dl' i :', . . · - . · . _--02~ . [t 06~ . . .~ u 18," '" i__,-io'32~.o~',. -- lU,o 5G.09~ . . 51.77 6,GEI .... ! "t'uc, i .... , ' .. ,31.82 ,~qii:-l)¢,.~ F'oslii,3:'~ ;"S . I,Gi - . . ,. ', ~ .. . . ,' . . . . · . . · .... .4 d,s" ,..~ E'UE Tubing ..124.41- . · : ......;.; .:~. ,,: ~'---C~MCO MM M~ndrel ............. .:<.,.. · 13. o6.' .. · "-'- '- ' - - - ' J dl. ~'74 Li.U{: J-ubinq ........ :.}.: ...... 8.9.72.' "'""~'" ' ': ~-::--w ...... .... : ~ I'S-'lJ~fl ?-;--.:___ ,~o.,.~,--,.'°'~'~":'-'-:~ ...... ,-"-'-""'_ ~,,.,....;, ? ~:;. ,~...~. _ ,., -,,,, ~ o~,~_ ~ ~.-.." ,,..:,,...,..,-:.. ....... . . ~.o4~ *. '-.-. . .j... "_ _7~ " ...... Pup .J? ;~Ya EUE TuL:irt¢ ...... :'.:.' ..... 10.02 "'"':':' '" : I' ' - .... :1 ~s, 7'----]-' · . " '. ' ' - a .=.~ ,_::- , }->~,'~,-~i,. ~: *',,.,,!-, :;~,.'~ ...,'" ,.. . ,: _ z__J ...... 10,58o.45_._i~ ...... ,. .... ¢ .-, ,N,..,,,,;:,, ; '~'s.~, ~C-:,,-. .............. , 1.56 ...... ;,7 :.? ! ,¢ 'C !~ ·,, - :.-" : _ Pup Jr. .-?a ~.o,_ ,t:ut,,9-. ...... ,..; ...... lO.OG ~-- .:----4o,5954¢.. [ · ~,:,, >-- CAMCO M M Mandrel ' 12.94 32' 10,'138.00' -- .... dt 2/~J" E UE -31.57 Tubing ....... '.'i ~ .'.. :.... . . · . · o. ,."~ r, .... ,.-~- 5 °9 · - - ._~~-IL_N_ 1~,o'4o' ', CCC,. 955,1"I.D. IS 7" 29 P 11,520' · ",".5 '~ : -: - ---:- .I J~o, C:~'a EUc.. lu,;,~,g..' ..... :..'; ...... 31.0 , u t u64' ' ~ .~. ' ~,'Z/" '1 ~ .... ) ' · ' ' ' - ~5" 10,552, 3'-- - [ ................. ' ..... " I ......... , ~ . ~:~;" ,:,; ..... ,,.,,,,;,. ~L..'..~.' __ ,. ~ ,.i '. a ':.' c ~ .... . ......... · ...... 51,G5 ...... ~. . ~ ' ' 'JANe2 i14r-.~;ll .... ,o,~.oo.--q5o;,~r Siop S.b ..., ............... 881 ... · - N ~o' ,o,.,I,co Baker= Sbdl Assem~Oll~'~8 ... 4.07 : ::~7 10,6~,2D'~~ "4 IX ti Ii_ z o; ....... ' ............................. 104( i \ · ~ ~0600 .o F~rm ~-331 (May 4. 14. ~'"'ITED STATES suBMzT I. ~'-"~,ZeAT,- (Other lnstru, .s on re DEPARTk.-~NT OF THE INTE~IO~ ~..~d~ . GEOLOGICAL SURVEY .... · SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. , Use "APPLICATION FOR PERMIT--" for such propotmle.) oIL WELL WELL OTHER NAME OF OPERATOR Standard 0il Company of California). WOI,' - Operator ADDRESS OF OPERATOR · · P. O. Box 7-839, Anchorage, Alaska LOCATION OF WELL (Report location clearly and in accordance 'with any State requirements.* See also space 17 below.) At surface -,", ' '' '/ '" 680' East and 680' North from Southwest corner.of Section 4, T. 7N.,.R. 9 W., S. B. & M. .- -' PERMIT NO. Form approved. Budget Bureau No, 42- §. Lmnism DeSIONATION AND S~IRIAL NO. A'0289.97 (J. IF' INDIAN,, ALLOTTEE OR TalES NAME Check Appropriate Box To Indicate' Nature of Notice, Report, or Other Data ...: i" NOTICE OF INTENTION TO: ' SUBSEQUENT REPORT' OF: ' ' TEST WATER SHUT-OFF PULL OR ALTER CASINO '~ WATER SHUT-OFF : :' . ~ RPIPAIRINO WEt'I, '":SHOOTING OH ACIDIZINU -'ABANDONMENTS'-- [ ' SII~T OR ACIDIZB - "~O J ~tec~Ott--'[~lvl REPAIR %VnLL CHANGE PLANS' (Other) 88 . (NOTE: Report results of muiti~le completion on-Well (Other) . . Com~letion or Recompletion Bereft and ~o~ form~} DESCnlBE I,~OrOSED OB CO~IPI, ETED OPERATIONS (Clearly state all pertinent details, nnd ~lve pertinent dates, Including, estimated date of'startin~ nnl' propose, work. If well is di~tion~y drHl~, .~lve subs~ace lo~tions !md measured and trl~e ~ertical. depth~ for. nil ma~ker~ nnd sones~:.perfl- . ,, _ _ . .... '. neat ~ ~ls work,) ' . .. ~-,..' . ~F 'c :" ....., . ... . - : ' . .'(. . -- , : .., . ' T.' - : .,.. -... ... .... -. .~ . _ ..: .. · ,· .. . '-, . . e, '_ '. ':~ . : .' ' -. '(.~... ' . . . ', ... ,; -. , . . .. ' . ., .. .;; ".. ~,. . . . -. . . . ~ . ~ -. ., -., ... for 'future gaS---.inJ~~~'1965' Initiated. gas inJecti~'n' ' ~'- Well converted, gell..redeSigUa,ed~~:~l/~~hanical:. ~;f- condiciOn-a~: per. :"..:']' :~' ' '" ..... L' " "'- .,..~./ .-.: ~, :',:-,,.:,,¢-" >'"~:..:.'.~, ,,'. r,j,. ,:~-'-'-~.?:'.~ ,,:.,.~: ..... ..' ,,..,',:., = ~ ~',... j .~, , .9'- (',, ' ::'} .,,::-" ~''''':''' ";"::' ' ' '~'" : '' ' :'~"~":" " ' :~,. ' :'?'":.'' ": :?V;--." ~ .",' "'.'>'.'.':'.:","../%", :.:~, .'. '" ..-'-". '..'.',' ':.""'' ' ' : '; :~ ';. · '",.'' ' ; .' · .' , .:- ~ .-~!":'-';~..-..' :"-/ .-'-:" :.:,,: ' '-- '' "' : - /1' -".," -.. ;':." ' ' " , · ~:, ; ::. ' f'~ '.." ; ' ,RECEI VED ' "" '' " :' '. , · ' "" " ..... " ' " ~' '~::: """'"" _"J "~'- , ..:}',- :L' ' :'" .... ':'~:" _ - -. < ',,;, · .. , . ~,~, , ..... · ,,'- ,. ~,, :. ~ ~'[., ' .: ;': - ., .. . .., , .... /',': .... ' ANCHORAGE "' " - : . . ~ : . ..- -,. . ... :.. -.' .7 . .'...,.- - ,-.L... - -: · . .-. ',~..'..-..... ,,/:-. ,_ : , ., -.. - . . ._-., - . .-- ..:.. ... .. .. . 18. I herebY~rr~t ' ~'~ TI~E. :District :Superintendent ' Da~n~l~2, -1966 ~der~ o~te ~ use) . . ~..,-' . .. .... ./., . ~ . :: :..__:' /::; L' ;~-*See'lns~uCtions;:: ,-,d;' .:::,°n Reve~e. Side · :"' :'. - . -- '- '/ "<'.:.:-:;:--,; "~ ,:.;,....'.,. ..1 ..... .;.,.: , . ,, Soldotna Creek" 9. WELL NO. '. ' ,.- ' ' Scu 14-4 - 10. FI~gLD AND POOh; OR WII, DCAT SwanSon River 11. ~EC., T., R., M.,' OR ELK. AND SUaVEY O!% AaEA 4- 7N-'9W- '.. S.B. & M. 12. ~ot?~y ou r~Rt~I!I 18.. STATE · enai 'BoP'ouch :l 'Alaska 15. ULBVATIONS (Show whether Dr, aT, OR, Late.) 160' KiB.- '"' 7. UNIT'AOREMMMNT NAME Soldotna Creek "' 8, FAR,~I OR LEASE NAME Furm P.- 7 - SUBMIT IN L.~A,ICATE* STATE OF ALASKA {Seeother,~- S~ I'UCtiOBS 011 reverse side,, OIL AND GAS CONSERVATION COMMITTEE i i i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* i n la. TYPE OF WELL: OH~WELL ' "GASwELL' ~ DRY ~ Other b, TYPE OF COMPLE~ON: NEW ~ WORK ~ DEEP- ~ PLCG ~ DIFF.~ W E L I, OV ER E N B AC K RESV a. Other ~ 2. NAME OF OPERATOR ~3. ADDRESS OF OPERATOR 4. LOC^TION OF WELL (Report location clearly and in accordance with any State requirements)* At surface At rap prod. interval reported below A~ total depth HOW ~Y* ROTARY TOOLS 22. PRODUCING !NTE~VAL(S), OF THIS COMPLETION--TOP, BOSOM, NAME (~ AND ~)* 2~. ThCPE ELECTRIC AND OTHEI{ LOGS RUN ~. API N~CAL CODE LEASE DESIGNATION A/qD SERI3kL NO. 7.IF INDIAN, A_I.,LOTTEEOR TRIBE NA_M_.E 8.UNIT,F~ OR LEASE NAME 9.WELL NO. 10. FIELD AND POOL, OR WILDC&T I1. SEC., T., R., M., (BOTTOM HOLE OI~1ECTIVE) 12. PHRa'ViIT NO. i E~EVATIONS ~DF, RKB, l{'r, GR, ~'~'PC)*ll7. ELEV, CASINGIIEAD INTERVALS DR[I,I,ED BY CABI,E TOOLS 23. %VAS DIRECTIONAL SUR, VEY MADE I 25. ' CASING REC~R~) (Report all strings set in Well) CASI34G SIZE WEIGHT, DEPTH SET (1VI~) HOLE SIZE 26. LINER RECORI) hS. PEI~ORATiONS OPV--~ TO PRODUC-YI'IO~ (InterVal, size and number) ii PI%ODUCTION CEMLNTING RECOILD A~/IOUNT PULLED SCi-[EEN (MD) S1,Z,E DEPI~ SET (MD) ~ PACKER SET (MD) . 29. ACID, Si!OT, ~';IA~I O'RE, C~',IENT SQUE2ZE, ETC. D~U~i 1NT~V.~ (MD) [AM. OUNr AND 1.2!ND OF MATEPAAL US~ DATE FIRST PrIODUCTION I FrI~ODUCT1ON MEi.[{O'D(Fiowii~g, kla5 lifL pumping--size and type of pump) I[V/ELL~nuL'ln)[J'FATU$ (Producing or 1 D*T, Or T,,T, ~EOU~S TEST~ ;' ']CIiOl{~ SiZE]TES'I~? l [PEOD'N PO.R OI~BBL. '%A~.] A I BLWA'I'E~L' ' ' ] GAs'OIL I~"~'IO" ~6~ ] ~'O PRESSURE iCAL~~ OI~BBL. TE~T WITNESSED BY .... ~'3.'I hereby certify that the foregoing and attached information is complete and correct a'S deterr~lned from all-av~'tlable r~curds SIGNED TITLE DATE *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in ether spaces on this form and in any attachments Items'~0, and 22:: If this well is completed for separatc prcduction from more than one interval zone (mulliple 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 interval 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 additional data pertinent to such interval. Item]6: "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 producmd. (See instruction for items 20 and 22 above). ,,, Y OF I~ORMATI'ON TESTS IN('LUI)IN(; INTE. RV^L TES'FED, PI:~EF-~UP.E DATA ~'~COVERI~ C)F OIL, GAS. 35. G~GIC WAT~ AND MUD NAME DATA,. AN*I?A&'H 'H~I~' ~~~s' Op ~tTIIO~OOY. poR. O~Y~ FRAC~R~. ~P~NT' ~:~ . AN'~ I~'ECTEI~ .S{{O~S OF OIL. G~S: O~ ~VA~ " .... 4 .., ..... ,., , ,., , Form 9-331 (May 1963) z"~! ITED STATES SUBMIT IN ?~ '~LICATE* (Other lnstru ,s on re- DEPARTI,....NT OF THE INTERIOR verse side) / GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--'* for such proposals.) OIL [] GAS ~] WELL WELL OTHER NAME OF OPERATOR Standard Oil Company of California, WOI, - Operator ADDRESS OP OPERATOR P. O. Box 7-839, Anchorage, Alaska LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 680' Eas: and 680' Notch from Southwest Corner of Section 4, T. TN., R. 9 W.~ SB~I 14. PERMIT NO. 15. ELrVATIONS (Show whether DP, ET, 0~, etc.) 160' K.B. Form approved. Budget Bur. eRu 5. LEASE DESIGNATION AND SERIAL NO. A-028997 6. IF INDIAN, ALLOTTEE OR TalBE NA.%IE 7. UNIT AGREEMENT NAME _So'i dona_Croak 8. FAR,~I Da LEASE NAME Soldot:na Creek WELL NO.' SCU 14-4 1-6.---~'IELD AND POOL, aa Wn~DCAT 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF II PULL OR ALTER CASINO ' ~.RA,CTURE TREAT MULTIPLE COMPI.ETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ,~:., ...ALTERING CASING SHOOTING OR ACIDIZINO 17,..: ABANDONMENT' (Other) Conversion .~o gas injection NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) .i 17. D~:SCR~nE PROPOSED OR COMPI,ETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including'estimated date of Starting any proposed work. If well is direction~ly drill~, give subsurface lo~tions and measnred and true vertical.: depths for all markers and zones perti- nent ~ ~is work,) * '.'~ :.~ : ~ f~ ':' J' !. ~'' ::; ~'~ "~ ~:-' V .~., ~' : :~,--.' 'j 0 Application to convert to gas injection, dated 7/16/65. Conversion to gas injection completed 9/7/65. Well re- turned to production 9/9/65 pendiug commencemen~ of gas injection. l{e: · 18. I hereby certify th%~;the foregoing is true and correct SIGNED TITLE District Superintendent ' ' ' ::' 10/ DATE.i; ' ' . (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, I~ ANY: TITLE *See Instructions on Reverse Side Form 9-331 (May 1963) /'~ITED STATES s,~.M,T ,. T 'ac.rE. (Other InstrueL j on re- DEPARTM,'NT OF THE INTERIOR ~erseside) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use 'APPLIGATION FOR PERMIT--" for such proposals.) 1, WET, I, WELL OTHER 2~ ..... OF ' ' NAME OPERATOR ..... Standar, d Oil Company of California; Western Operations: ln_¢, 8, ADDRESS OF OPI~RATOR P, O,_~ox 7-0_39. Anchorage. ~laska 99501 ~/--~,0~-~i~ ~-~k~,/, {~epor(ioca~n clearl~ add in accordance with any State requirements.* See also space 17 below.) At ~urface 680' East and 680' Horch ~rom Southwest Corner 14. PERMIT NO. J 15. E~VA~ONS (Show whether DF, ....... [ 160' ~ Form approved. Budget Bureau No. 42-R1424. 5. I,EAbJE I)ESIONATION AND amRIAL NO. A-028997 INDIAN, ALLOTTEE OR TS'iBm NAMM UNIT AGREEMENT NAMB S o_ld.o_tna._C r_~ek~ 8, FAnM OR I,EAaE NAME _ _So ].do r. ne_~reek_ 9. WELl, NO. SCU....14-4_ __ lO. FIELD AND POOl,, (IR WiI,I)(~AT Swanson_ ~_. 1Ltv e.K, 11. SEC., T., R., M., OR BLK. AND SURVmy OR AREA Kens ii Borou~h_.__A~ 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICB OF INTmNTIOH TO: TEaT WATER sHuT-oFF ~ PULL OR ALTER CASINO FRACTURE TREAT ]~ MULTIPLE COMPI,ETE SIIOOT OR ACII)IZE ABANDON* REPAIR WELL CIIANGE PLAN~ SUBSEQUENT RBPOBT OF: XVATER SHUT-OFF ~ REPAIRINO W~LL FRACTURE TBEATMI~NT AI,TERING CASING SHOOTING O~ ACIDIZINfl ABANDONMENT* (Other) (NOTE: Report results of multiple completion on' Well (Other) Convert to (las Injection Con~pletlon or Recompletion Report and Log for_re.__)_ I)ES,'RIBE PROPOSED OR CO.MPI,ETED OPERATIONS (Clearly state nil pertinent details, nnd give pertinent dates, lnchiding estlmatod date Of Starting any proposed work. If well is directionally drilled, give subsurface locations nnd lnensnred and trne vertical depths for fill nmrkers and sones pertl- nent to this Work.) * .. ~r ~ ' ~ .. .. 1. Move in, kill well, remove x-mas tree, install and test blowout prevention ..:, equipment. o 4, 5. 6. Remove BOPE and install 10,000# W.P. x-mas tree, Test x-mas tree and remove .rig. Pull tubing and run modified tubing with packers and accessories suitable for selective injection. , · Return well to production, Your Division will be notified upon co~nence~ent of injection.! R EC"E I V'E D · cert. that the foregoing is true and correct ~IGNED ~ TITLE c_ v_ c!~_~_~.n~_~_. APPROVED BY //~' /~ &~~l CONDITIONS 0F ~PPROVAL, IF' A~: /TITLE DIVI$1©N OF /x~ 8~NgHO_RAGE f · District_ S_u_pe. rtntendent _ ~AT~, ' 7116165~ Executive Secretary Alaska Oil & Gas Conservotion Committe5 *See Instructions on Reverse Side AREA: Kenai Peninsula, Cook Inlet Area, Alaska PROPERTY: Soldotna Creek Unit LAND OFFICE: Anchorage T~SE NO.: A-028997 ELEVATION: 160 ' K.B. DATE: April 2, 1963 WELL NO.: SCU 14-~ Section 4, Township 7 North, Range 9 West, Seward LOCATION: 680' East and 680' North from Southwest Corner of Projected Section 4, T. 7 N., R. 9 W., Seward B & M. K.B. is 15 ' above ground. C .~V~''C~ATTE~ON, District Superintendent CONTRACTOR: Santa Fe Drilling Company, Rig DATE CO~,~:~NCED R~I~ WO~: October 9, 1~62 DATE CO~. ~.~.[ R~.~DIAL WORK: October 13, 1962 s~ TOTAL DEPTH: 11,520' PLUGS: 11, 520 - 11, 430' 11, 385 - ll, 055 ' 11,055 - 10,850' CASING: 20" cemented at BO' 13 B/8" cemented at BO05' 7" cemented at 11,040' PERFORATIONS: As before. RECEIVE]) ~PR 16. _ lg63 Petroleum Branc.~ CGMP~RTION REPORT - PA~ INSTALLATION SOLDOTNA CREEK UNIT 14-4 Section ~ T.,, 7,,...N~-~ ,R.' 9 w... Seward B & s~ oil CO~A~ O~ CA~r~~ W;O.r, Page October ,9,,~. ,19,6~ Remedial work commenced at l:O0 P.M., Black Magic mud~ October 9, 1962. Rigged up and conditioned October 10, 19,62 Conditioned Black Magic mud. Displaced oil with 82~ Black Magic mud using Halliburton. Removed x-mas tree. Installed BOPE and pulled 2 7/8" tubing. Pulled 2 7/8" tubing. Ran 7" casing scraper. Circulated on bottom at 10,850' Pulled. Reran 2 7/8" tubing equipped with packer. 9ctober _.12.~,_ 1962 Ran 2 7/8" tubing. TUBING DETAIL K.B. to landing flange 17.35 Landing flange and nipple 1.67 328 joints 2 7/8" tubing 10105.17 Camco sleeve valve 3.08 i joint 2 7/8" tubing 31.89 Brown CC safety joint 1.08 Pup Joint 6.05 Pup joint 4.15 2 7/8" X 7" Brown ES-16-1 6.00 2 joints 2 7/8" tubing 60.52 Camco D nipple · 92 14 joints 2 7/8" tubing 428.85 Venturi shoe .66 tubing landed at 10, 66~'. 39 K.B. Depth 19.o~ ].o32.7.27 lo159.16 10160.24 10166.29 10170.44 10176.~ 10~36.96 10~37.88 10666.73 10667.39 Ail tubing is 2 7/8" 6..5~ N-80 EUE 8R Rg 2. Removed BOPE. 9c,tober 13, 1962 Reinstalled x-mas tree and tested with 4500 psi - OK. mud with oil using Halliburton. Flowed well. Rig released at 3:00 P~M., October lB' 1962. SR~:pb Displaced Black Magic Set packer at ~70~',--(~c~P)' Returned well to produ, ctio~l~ s. R. DWision o '~' AlaSka Dept. o~ ~ 0NF IDE NT _r AL Page 2. Revised 1-10-62 CASING: 20" Conduc%or..cementud a~' 30' 13 3/8" Casing .cemented at 3005' in 2 stages: 1st stage around shoe with 600 sacks. 2nd stage through DV @ 1500' with 1100 sacks. 7" Casing cemented at 11,040' in 2 stages: 1st stage around shoe with 650 sacks. 2nd stage through DV @ 7509' with 650 sacks. PERFORATION RECORD: 1. 5 - 2. 5- 3. 4- 5. 4- 7. 4- 9. 4- 10. 4- 11. 4- ~" jet holes, interval 10,195' - 10,196', 1' WSO ." " '~ " 10,688' - 10,689', 1' WSO ." " " per'foot, interval 10,674' - 10,670', 4' - 17 shots WSO "' " " " " " 10,655'- 10,588', 77' -309 shots "" " " " " 10,545'- 10,464 ' , 81' -325" "' " " " " " 10,456' - 10,450', 6' - 25 " ~" " " " " " 10,432~ - 10,376', 56' -225 " " " " " " " 10,354'.,- 10,365', I1' - 45 " " " " " " " 10,318' - 10,333' 15' 60 " " " " " " " 10,306 '°- 10,302', 4' - 17 " " " " " " " 10,297' - 10,291', 6' - 25 " WELL SURVEYS: 1. Schlumberger IES Log interval 3004' - 30' 2. Schlumberger Sonic Log interval 3009' - 30' 3. Schlumberger IES Log interval 10,306' - 3004' 4. Schlumberger IES Log· interval. 11,000 ' - 10,304 ' 5. Schlumberger Micro Log interval 11,000' - 3006' 6. Schlumberger Sonic Log interval 11,000' - 3006' 7. Schlumberger Dipmeter intervals 11,O00' - 9000 '; 6800 ' - 3800 ' 8. Schlumberger Temperature Survey 0 - 5960' 9. Schlumberger IES Log interval 11,518' - 11,040' 10. Schlumberger Sonic Log interval 11,516' - 11,040' 11. Schlumberger Micro Log interval 11,519' - 11,040' 12. Schlumberger Neutron-Collar Log interval 11,042' - 8962' . 520 13 Baroid Mud Log interval 550' - ti, ' DRILL STEM TESTS: 1. HFT #1 on interval 11,385' - 11,430' open hole 2. HOT #2 on perforated interval 10,195' - 10,196' (WSO) 3. HCT #3 on perforated interval 10,688' - 10,689' (WSO) 4. HOT #4 on perforated interval 10,670' - 10,674' (WSO) COMPLETION REPORT~ SOLDOTNA CREEK UNIT 14-4 STANDARD OIL' 00' OF CALIFORNIA' ~,O'I~', OPERATOR Page 3. June 4, 1960 Spudded in 12:O0 midnight June 3, 1960. Drilled 12~ hole 30' - 1967' 1937' drilled Mud logging equipment commenced operations. 79 pc f mud slurry weight 116~. CASING DETAIL~ Ail 74 joints or Total Above KoB. Landed at 3018' 13 3/8", 54#, J-55, 8-R, R-3 ST & C, equipped with Baker guide shoe, Baker Flex-flow float collar, and Halliburton DV Collar at 15OO'. 3018 ' !3' 3oo5' Drilled 12~' hole 1967'- 3005' 1038' drilled Ran Schlumberger IES Log, interval 3004' - 30', Sonic Aog interval 3009' - 30'. Opened 1~ hole to 17½" hole 30' - 540' 510' opened 79 pcf mud Opened 12~ hole to 17~ hole 540' - 3OO5' 2465' opened 85 pcf mud Cemented 13 3/8" casing at 3005' in two stages with 1700 sack of construction cement, using Halliburton Power Equipment. FIRST STAGE~ with 600 sacks around shoe. Used one top and one bottom rubber plug. Pumped 60 bbls. of water ahead. Good circulation. Average slurry weight 116#. SECOND STAGE~ with 1100 sacks through DV Collar at 1500'. Pumped 60 bbls. of water ahead. Good cement returns. Plug bumped with 1500 psi. Average COMPLETION REPORT $OLDOTNA UREEK UNIT 14-4 Section 4, T. 7 N..~R. 9 ~., Seward B & M ST~D~ ~i~CO' O~"cALIFOR~A,~' W.O~i? O~ERATOR Page 4. Tested casing head with 1000 psi., OK. Installed & tested BOPE with 1500 psi., OK. Drilled 12~ hole 3005' - 3674' 669' drilled J ,une . lO,, 196o Drilled 9 7/8" hole 3674' - 4105' 431' drilled Reamed tight spots as required during drilling operations. Drilled 9 7/8" hole 4105' - 10,291' 6186' drilled Changed to lime base mud, and built up mud weight. Drilled 9 7/8" hole 10,291' - 10,306' 76 pcf mud 78 pcf mud 81-100 pcf mud Found cement at 10,167. Recemented. Hung DP at 10,106. Mixed and pumped 133 sacks of const, cement treated with 3% H.R.C. retarder. Displaced with 139 bbls. drillfng fluid. 'comPie~e circulation. Pulled 10 stands and cond. mud. Mixed mice-rex lost '. circulation material with mud. 94 -'96 pcf mud July !3, 1960 Lost circulation at 10,306'. Ran Schlumberger 1ES Log, interval 10,306' - 3004'. Ran in with open end DP hung at 10,296'. Mixed and pumped in 125 sacks construction cement with 20 bbls. water ahead and followed with 6 bbls. water. Displaced with 142 bbls dfill~ fluid. Fluid dropped away in hole 30 stands off bottom. 96.5 pcf mud COMP~TI~ REPORT SOLDNOTNA CREEK UNIT lh-h Section ~, T. ? N., R 9 W., Seward B & M 'STANDARD-OIL' 'COMPA2~/~"0F CALIFOI~Ni-A' W"6~ii'" OPERATOR JulM 14, Ran in to clean out. of cement at 9995'. July 15, 1960 Drilled 9 7/8" hole 10,430' - 10,447' Cored 7 5/8" hole Core 10,447' - 10,477' CORE DESCRIPTI~: Core #l ext 8 3/4' Next ' 6 1/4' Next 2 3/4' Nex~ 3' Bottom 3' Broke circulation at 5000' and 9000'. Found top Cleaned out to 10,185', with no lost circulation. 17' drilled 30' cored 27' recovered SS M Gry $ & P FG SA Mic in Lams TI in Lams. Pred. Perm. Even TN Oil Stn Yel Gold Flsnt Good Pet. Odor. Sit ~tn M Grey V HD Mic Num Carb Incl Strks VFG SS W Mic Lams Occ Scat Pebs. SS M Gry S & P MG SA M Fri. V Perm Even Brn Oil Stn. Bri. Yel. Flsnt Strong Pet Odor Scat Small Pebs. S& Lt Gry S & P V C alc V Hd TI NOSF. SS M Gry S & P MG/CG Even Brn. Oil Stn. CGL W/Num Small Pebs Bri. Yel Flsnt Very Perm. No Recovery Opened 7 5/8" hole to 9 7/~" hole 10,447' - 10,477' 30' opened Drilled 9 7/8" hole 10,477' - 10,600' 123' drilled Cored 7 5/8" hole Core .~2 10,6oo' - 10,608' '8' cored 94} pcf mud 6' recovered ¢~LE?ION RAPORT $OLDOTNA CREEK UNIT 14-4 S~ctio~ ~., ..T.- 7 No, R 9 W,,...Seward B ~ M STANDARD OIL CO,~' OF CALIFORNIA,' W.O'i., 'OPERATOR Page 6. CORE DESCRIPTI~: Core #2 Top 6, Gry'Brn V/FRI SS Bottom 2' No Recovery ~ulY .17,..!~0 Opened 7 5/8" hole to 9 7/8" hole 10,6OO' - 10,608' Drilled 9 7/8" hole 10,608' - 10,677' 8' opened 69 ~' drilled D llled 9 7/8" hole 10,.677 - 10,950' 273' drilled . Drilled 9 7/8" hole 10,950' - 10,999' 49' drilled 96 pcf mud 96pcf mud 96 pcf mud 10,999' - 11,040' 41' drilled Conditional mud prep to run 7" casing. 96.5 pcf mud Cemented 7" casing at 11,040' in two stages with 1300 sacks of construction cement treated with 0.3% HR4 retarder, using Haliburton Power Equipment. Dri~tled 9 7/8" hole Ran Schlumberger IES Log interval 11,000' - 10,304', Micro Log interval 11,O00' - 3006', Sonic Log interval 11,000' - 3006'. Continuous Dipmeter interval 11,OOO' - 9000'; 6800' - 3800'. 96.5 pcf mud C(~,~LETI O~ REPORT $OLDOTNA CREEK UNIT 14-4 · Section 4, T, 7~, R 9 ~.~ Seward B & M ~. ~ ~ -. ~ · . .~ ~. ,, .. ~ .... ~ ~ · ~ ~ ~ ~ ~" ~ : ...... S~ANDARD OIL CO. OF CALIFORNIA, W. O ~ I., 6PEP, ITOR ~a~e 7. ReVised 1-10~62 FIRST STAGE: with 650 sacks around shoe. Used i top and i bottom rubber plug. Mixed cement in 40 min. and displaced ce~uent in 35 min. with rig pumps. Bumped plug with 1250 psi. Pumped 40 bbls. of water ahead. Good circulation throughout job. Average slurry weight ll6# pcf. (Pipe stuck on bottom after 30 min.) SECOND STAGE: with 650 sacks through DV collar at 7509'. Mixed cement in 35 mins. and displaced in 30 mina. using rig pumps. Closed DV collar with 2OOOpsi. Average slurry weight 116~ pcf. CASING DET&IL Top Next Next Next Next Next Next Next Next Next Bottom 312.56 feet 993.07 feet '3497.04 feet 1512.65 feet 1202.76 feet 2.50 feet 484.55 feet 1658.49 feet 7.58 feet 43. feet 1336.13 feet 29#~ 8o ~ 26# N 80 BT 23~ ~ 8o ~T 26# N 80 BT 29# N 80 BT DV collar (at 7509' ) 29# N 80 BT 26~ P 110 8 Round 29~ P 110 8 Round 26~ P 110 8 Round 29# P 110 8 Round Equipped with Baker differential fill-up shoe on bottom, Baker differential fill-up collar on top second joint, two centralizers on shoe joint, centralizers installed on each joint from 10,7OO' - 10,180'. Scratchers installed at ten foot intervals opposite following sections.. Total 11,O50' Above K.B. 10' Cemented at 1i~,~5~' 10,180' - 10,210' 10,270' - 10,3OO' 10,340' - 10,370' 10,440' .- 10,460' 10,540' - 10,590' 10,680' - 10,710' Ran Schlumberger Temperature Survey interval 0-5960' Found top of cement at 5960'. Installed and tested BOPE with 1505 psi. OX. July 24, 1960 Drilled out DV collar at .7509', float collar at 10,960', cement 10,960' - 11,O40'. Tested DV collar with 1800 psi for 30 min. OK. Checked shoe at 11~O40'. Drilled 6" hole 11,O40' - 11, O63' 23' drilled 97 pcf mud COMPLETIC~ REPORT $OLDOTNA CREEK UNIT 14-4 Section 4' T. 7 N., R. 9 W., Seward B& M ~TAI~iRD'"'bIL ~' OF cALiFO~IA' W'O:I, ;':OPERATqR Page 8. Drilled 6" hole 11,063' - 11,304' 241' drilled 9 -96 pcf mud Drilled 6" hole 11,304' - 11,315' 11' drilled Lost circulation at 11,315', pumped in 1OO bbls. no returns. Hung DP at 11,305', spotted %0 bbl. pill of lost circulation material in hole. Had returns but lost 50-60 bbls. per hr. Pulled out of hole. Hung drill pipe at 11,315'. Mixed & pumped in 70 sacks of construction cement treated with HR-4. Equalized with 49 bbls. of mud. Ran in found soft cement from 10,630' to 11,130', med. hard cement from 11,130' to bottom. No lost circulation. Drilled 6. hole 11,315' - 11,331' 16' drilled 91 ~cf mud July 29- 3o, .!96o Drilled 6" hole 11,331' - 11,468' 137' drilled 91-93 pcf mud Drilled 6" hole 11,468' - 11,%20' 52' drilled Conditioned mud for logs. Ran Schlumberger IES Log; interval 11,518' - 11,040', Sonic ~og interval 11,516' - 11,040', Micro Log interval 11,519' - 11,O40' and Neutron-Collar Log interval 11,042' . 8962'. Mud logging equipment released. 90-92 pcf mud August_ 1,_ 1960 Ran open end DP and hung at 11,515' Mixed and pumped in 60 sacks of construction cement treated with O.~ of HR-4 retarder. Mixed cement to 115# pcf slurry. 92 pcf mud2 C~MPLETION REPORT SOLDOTNA CREEK UNIT 14-4- Section 4, T. 7 N., R. 9 W., Seward B & N Co', c ZFo mZA'" w Ojf' OPEPLATO Page 9. Ran in found top of cement at 11,223'. Cleaned out medium hard cement to 11,330', hard cement from 11,330' to 11,430'. NFT ~1 on interval 11,385' - 11,430'. Tool assembled as follows: 33' of p~rf~rAted-~'~i, '2'"'ou~si~e BT r~cjrders, left hand joint, 2 side wall packers, safety joint, hydraulic jars, 2 inside BT recorders, and hydro- spring tester tool. 182' - 6" DC -i~2~ I.D., TC valve, on 11,179' of 2 7/8" DP. Used 3358' of water cushion. ~S~t .bottom packer _at 1!,385'. Opened tester at 4:17 a.m. fSr 29 min.i ~itiaI shUt'in pressure-, Opened TO valve at 4:46 a.m. for 4 min. flow period. Annulus fluid dropped after 3 min. Pulled packer loose at 4:%0 a.m. Medium blow increasing to strong during flow period. Attempted to reset tester at 4:58 a.m.; fluid dropped immediately. Pulled packer loose and started out of hole. Recovered net rise of 1841'. Ail muddy water cushion, grading to thick, heavy drilling fluid, slightly gas cut. Salinity of drilling fluid filtrate was 67.2 g/g which is the approx. salinity of drilling fluid. 91 pcf mud Au ust 3_, 196o Cement plug ~1 - Equalized ~0 sacks of construction _cement treated with '$'J.3%' H~ ~etarder, through 2 7/8" DP with 400' of 2~ aluminum tubing on bottom. Pipe hung at 11,385'. C~e_ment~ P!U~ .~2- Equalized 75 sacks of construction cement treated with 0.35 HP~h 're~L~der through 2 7/8" DP with 400" of 2~ aluminum tubing on bottom' Pipe hung at 11,055'. Ran in found top of cement at 10,752'. Cleaned out hard cement to 10,850'. Ran Haliburton retrievable retainer and tested at 7627' with 3000 psi., no loss. At 7495', pumped fluid away at 2 bbls. per min.. at 2400 psi. At 7425' - 3000 .psi- no loss. ~1-92 pcf mud u ust 5, ~ith 2 7/8" DP at 7204', set a Halliburton DM retainer. Broke down formation with 2600 psi. Pumped in 12 bbls. water followed by 100 sacks construction cement. Mixed to 120~ slurry followed by % bbls. water. Closed tool displaced with 30 bbls. mud for hesitated squeeze. Final pressure 4000 psi. Displaced 72 sacks out of DV ports. Left 25 sacks of cement in casing,' Dr~ied O~t-~ainer at 7204'. Found top cement 7287'. Drilled out soft cement to 7376', medium hard cement to 7516', Ran to 10,850', conditioned mud. Tested DV collar with 3000 psi for 1% min. OK. 94 pcf m~d CC~PLETION REPORT $~DOTNA CREEK UNIT 14-4 Section..4, T-_.~ 7 .N.,_..R. 9. W.~...Sewa. rd B_& M STANDARD'OIL'CO~: OF':CALIFO~NIA, W.O'I~, OPERATOR Page 10. A ~st 6, 1960 Ran Schlumberger Jet gun and perforated 5 - ~ holes at 10,195' - 10,196', using casing collars for reference. Hal,.burton W.S.O. Test on holes at 10,195' - 10,196'. Tool assembled as foll$w~ ~t~0 ~u~Sid~':'~ re6ord~rs'~'! perforated 'tail pipe, Junk pusher, hookwall packer, VR safety Joint, hydraulic Jars, two inside BT recorders, Hydrospring tester, 180' DC, TC valve. Used 2296' of water cushion. Set packer at 10,156'. Opened tool for 30 min. initial shut in pressure. Opened tool to surface for one hour flow period. ~" subsurface bean open 15 mins. No blow. 3/8" bean open 45 min. No blow. ~hut tool for one hour 20 min. final shut in pressure. Recovered 90' net rise. Ail thick drilling fluid. Salinity of filtrate tested 76.8 g/g. PRESSURE~ DA?A IH I$I IF FF FSI FH Inside BT 6690 126 1437 1437 1635 6890 Inside BT 6791 109 1524 1524 1614 6761 OutSide BT 6811 133 1460 1460 1661 6811 Outside BT 6749 111 1442 1442 1634 6749 WSO- OK Ran Schlumberger Jet gun and perforated 5 - ~ holes at 10,888' - 10,689' using casing collars for reference. 94 pcf mud August 7, 1960 Halliburton h~O on holes at 10,688'. r.!9,689'. Tool assembly as before. Set packer at 10,6.34.'. Opened tool for 45 min. Initial shut in pressure. opened tooi 'to- surface for one hour flow period, ~' subsurface bean open 15 min. No blow. 3/8" bean open 45 min. No blow. Shut tool in for one hour Final Shut in pressure. Recovered 30' net rise. Ail watery drilling fluid. Salinity of filtrate tested 38.4 g/g. Clock stopped on two BT record.Ps. ....... IH ISI IF FF FSI FH - . · ' .. ~ ,~ : : .,~.~"~ · Insid6 ~B~.. 7048 40 1344 1351 1418 6871 Outside BT 7079 45 1345 1360 1425 7079 W~O- OK Ran Schlumberger Jet gun and perf'd 4 - ~ holes per ft. interval 10,670' - 10,674'. COMPLETION REPORT SOLDOTNA CREEK UNIT 14~4 Section 4,. T. 7 N.,~. R. 9 .W..~ Seward B & M STANDARD OIL C'O. OF CA~iFO~IA, W.¢~jIj"', '0PERATO~ Page 11. Revised 1-10-62 Halliburton WSO Te..st .ion holes !o~.670.'., 1~.0~67~'. Tool assembly as before. 29'96' water cUShion. Set pa. cker at 10,632 '. Opened tool for 39 min. initial shu~t,,in pressure. Opened tool' to surface for one hr. and 26 min. flow test.~ subsurface bean open 19 min. No blow. 3/8" bean open for 22 min. No blow. Opened by pass for 2 min. Reopened tester, very weak blow to dead in 15 min. Opened by pass for 11 min. Reopened tool, faint blow. Closed tool for one hr. final shut in pressure. Recovered 60' net rise. Ail drilling fluid, salinity 48.6 g/g at tool. WSO - OK , PRESS~ DATA ~,1 IH IS I IF FF FSI FHS Inside recorder Inside recorder Outside recorder Outside recorder 6688 185 1410 1530 1706 6654 690P 189 1404 1501 1679 6724 6976 219 1434 1519 1702 6837 Clock stopped 94 pcf mud Au ust 8, 1960 Ran Schlumberger jet gun and perf'd 4 - ½" holes per foot interval 10,588' - 10,655', 77 ft. Gun stopped at 7430' on second run. Ran in and conditioned hole. Ran to 10,000 could not circulate, pulled to 9,910' circulated OK. Ran into 10,600 and circulated, singled to 10,700' and plugged bit. Pulled back to !0,211', circulated OK. 93 pcf mud August 9, _1960 Conditioned hole for production perforations. Ran Schlumberger Jet gun and perf'd 4 - ½" holes per foot interval 10,545''- 10,464' and 10,456' - 10,450'. Attempted to run jet gun and stopped at 7400', ran bit and cleam~d out to 10,750 ' · 96 pcf mud Aug~ust !0, 1960 Ran Schlumberger jet gun and perf'd 4 - ½" holes per foot intervals 10,432' - 10,376'; 10~365' - 10,354'; 10,333' - 10,318'; 10,306' - 10,302'; 10,297 ' - 10,291 ' · 91-93 pcf mud Augus$ 11, 1960 Cleaned out to 10,840'. Conditioned mud, laid down 2 7/8" DP. Ran 344 Joints of 2 7/8" tubing. Landed tubing at 10,606' Kelly bushing measurement with venturi shoe on bottom. 90-91 pcf mud ¢OMPLET~O~ REPORT SG4DOTNA CREEK UNIT 14-h STANDARD OIL CO, ~OF CALIFORNIA, 'W.-O'I.' O~ATO~ Page 12. Au~ust._.~2,13, 1960 Installed Xmas tree, Tested to 3500 psi, OK.- Circulated well in using Halliburton truck. Pumped 40 bbls. water down tubing followed by approximately 300 bbls. crude oil until clean annulus returns. Began pumping 2:45 p.m. Well flowing to clean up at 6:00 p.m. ~epre..s.e~t~tive f~ow rate:' 7:30 - 8: OO P.M. 730 B/D; 182 MCF/D 9/64" Bean, 1900 psi tubing pressure, 1360 psi casing presSUre. 10:30- !1:OO P.M. 1440 B/D 348 MCF/D 14/64" Bean, 1800 psi tubing pressure, 1310 psi casing pressure. Other rates not stable due to plugging. Flowed total of approximately 300 bbls. With 200 bbls. through trap meter. Shut in at 1:50 a.m. 8-13-60, with 1950 psi tubing pressure. Flow samples ~ested as..foll0ws: TIME WET TEMP. CORRECTED TOTAL WATER EMUL S & M GRAV. GRAV. CUT 7,3o PM 38.1 84 ~6.3 3.4 o.2 3.1 o~ 8,00 PM 38.2 85 36.3. 3.0 0.2 2.7 Oil 8:30 PM 38.3 84 36.5 2.8 0.2 2.5 Oil lO:3O P~ 38.2 81 36.6 11:OO PM 37.9 77 36.6 1.8 0.9 0.9 T 11:30 PM 37.7 89 35.6 4.4 1.6 2.0 0.8 12:00 PM 38.0 77 36.7 1.6 0.3 1.3 T 12,30 AM 38.5 83 36.8 1.5 0.5 1.0 T l:OO AM 39.0 89 36.8 1.4 0.6 0.8 T 1:30 AM 39.2 89 37.0 1.4 0.5 0.9 T Rig released 8~.~. AM~, .August 13, 1~0. COMPLETI(~ REPORT SOLDOTNA CREEK UNIT 14-4 STA~1D-ARD OIL 'CO, OF CALIFORNIA' W'O.i''~ oPERATOR Page 13. DIRECTIONAL SURVEY DATA 35o' - o° - 45' 771' - 0°- 30' 3005' - OO - 45~ 3674' - O°- 30' 4384' - 1O- 30' 5203' - 1° ',30' 5700' - 2°- O' 6124' - 10 - 45' 6667' - 2° - 30' 6935' - 2°- 15' 7147' - 2° - 45' 7242' - 2° - 15' 7435' - 2°- O' 7540' - 2°- O' 7780' - 1° - 45' 7960' - 2°- 20' 8086, - 2° - 15 8257' - 1° - 45' 8510' - 1°- O' 8700' - 1°- 30' 8983' - 1° - 9192' ' 0° - 45' 9351' - 10 - 45' 9585'-1°- o' 9817' - O° - 45' UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS State ........ _~A~_____az_.__k_a_. ............. Co~,nty ........ ~o~._ai_._P_en2ns!l~aField ..... SWarl$ afl .~ver .... The fo~lowin2' is a oorrect report of operatio~' and prod~ctio~ ('i?~(./a, dfn;! ,]z'i[li~ a'ad prod~ci;~2' welL,) for the mont, k of ..... ~tO~r ..................... 19._6Z .......... S~~. Creek U~g ............ .. ................................... ~h:or~e, _ ~a~ka .................. ?i~ned ............. J~e~t's titleD!q~riot._S~pe~o~nd~n~ .. 1~ OF ~ '.~O. ~ P~eJ~ecnn BABaE~ Or OIL (}RAVIT~ (!n ~ho~ands) ~ RKCO%'~I~I:D no'l~~, :., st:,: -) d,t. aw} ~,,..uh ~,l *~.-~ t ~ T~P. :(3) , Remedial Work. Remedial K/.1].~l well ~h Bl~k Mi Z 7/8" tqbing ~q~pp.d w ~o~d BO~ a~ i work co~mnced October 9, 1962o ~gic m~d~ Removed m-mas tree and robing. ~an casing scraper. ~th packer. Landed tubing at 106~? '. [led x-mas tree. Displaced mud with Se~ 9ackbr at 101?¢~'. Returned well to productio~. Rig released Obtober 13, Richfield Files t Mo H, Soyster D. Bruce - C. W. Perry R., R. Ritter roduc,kng 1962 o ,toy 8 1902 Petroleum Branch p~vi~ion o{ Mines and ~inermls AIo~ko Dept. ot Nmu~.~.~u~ Nebr.--There were ...................................... runs or sales of oil;, .............................................. M cu. ft. of gm sold; .............................................. runs or sales of gasoline during the month. (WriCo "no" where applicable.) No~..--Report on th~ fern ~ mq~r~ for each ~lendar month, regar~ess of the status of operations, and must bo filed in duplma~ with the superv~r by the 6th of the_succeeding month, unl~ otherw~e directed by the supervisor. PRODUCING DEPARTMENT TE/£PHONE BR. 7--6201 C. V. CHATTERTON D I~TRIC'r SUPERINTENDENT P. O. BOX 7-839 ° ANCHORAGE ° ALASKA Jan~aryl6, 1962 ~'Division of Mines and Minerals Alaska Department of Natural Resources P. O. Box 148 Anchorage, Alaska Dear Sir: Enclosed herewith are revised Pages 2, 7 and 11 of Completion Report for Soldotna Creek Unit Well 14-4. Very truly yours, C. V. CHATTERTON PRODUGING DEPARTMENT TELEPHONE: 47~01 J. T. CROCKER DISTRICT SUPERINTENDENT P. O. BOX 8 3 9 · A NC H O R A G E · A LA S KA December 2, 1~60 CO~DENTIAL ~. R o V. R~tz~hy Alas~ 0 & G Conservation Commission 329 Second Ave~e Anchorage, Alaska Dear Sir: Enclosed, herewith, is a copy of the Completion Report for Soldotna Creek Unit Well No. 14-4 (3) for your information and files. Very truly yours, STANDARD 0IL COMPANY OF CALIFORNIA Western Operations, Inc. J. T. CROOKER COMPLETION REPORT - NEW WELL STANDARD OIL COMPANY OF CALIFORNIA - WESTERN OPERATIONS, INC. - OPERATOR .~, ! ku. ,, , ,, , , , ,,, .,,: L,.,, ,, , , ' ,, ' ' " ''-" '' ' "' - .J -.' ---::~ AREA: Kenai Peninsula, Cook Inlet Area PROPERTY: Soldotna Creek Unit LAND OFFICE: Anchorage Lease No.: 028997 WELL NO.: LOCATI ON: 14r~ SEC. 4, T. 7N, R. 9W, Seward B& M _ 680' east and 680' north from southwest corner of projected Section 4 T. 7N, R. 9W., Seward B & M ELEVATION: 160' K. B.. DATE: November 17, 1960 ~. $$ 15' above ground. J. ~T./~KER,' Distridt Superintendent DRILLED B~: Coastal Drilling Company DATE COmmENCED DRILLING: June 4, 1960 DATE COMPLETED DRILLING: August 13, 1960 DATE OF INITIAL PRODUCTION: August 25, 1960 RECEIVED oEO PRODUC TI ON: Daily Average 394 Flowing Oil ......... ; 390 Gravity ........ 37.1° Water. ....... 4 TP ............. 1950 psi Gas.. ....... . 113 mcf Bean ........... 8/64" SUMMARY TOTAL DEPTH: 11,520' PLUGS: 11,520' - 11,430' - 11,385, - 11,o55, 11,055' - 10,850' PRODUCING DEPARTMENT T~L~PHON~ 4700! J. T. CROOKER DISTRICT SUPERINTENDENT P. O. BOX 8 3 9 · A N C H O R A G E · A LA S KA September 8, 1960 CONFIDENTIAL Mr. R. V. Murphy Alaska Oil & Gas Conservation Commission 329 Second Avenue, Anchorage ~ Alaska Dear Sir: Enclosed, herewith, are one field print and one sepia copy of the ComPosite Induction-Electrical Log for the Soldotna Creek Unit Well No. 14-4 (3) at recorded intervals as follows: Run No. 1 - 30 to 3,004 feet .Run No. 2 - 3,004 to 10,304 feet Run No. 3 - 10,304 to 11,000 feet Ru~ No. 4 - 1!,040 to 11,518 feet for your information and files. Very truly yours, STA~ OIL COMPANY OF CALIFORNIA Western Operations, Inc. Enc lo sure s J. T. CROOKER -./ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget ]]ureau Approval expires LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a correct report of operations arid prod~,ction (incl~dinff drilli~ff and prod~cin~ w~ls) for t~e month of ...... ~~ ...................... 19. ~, __~~..~~ ~ ................................. , ~ S O 0 L OF ~lu~d back~f~m ~,385~ to 10,850'. ~st~ casi~ and fo~d ;colOr l~~ at 7509'~ squeezed ~lea~ed out e~nt f~m ~ color Jet pe~'d. ~ ~" ~s pe~ foot 10,5~ ~10~302- lO,~~, 10,291- 10,297'. ~ 2 y/8" tubi~ at 10,606'. ~~lled~a~ ~s~d ~s T.~e~ ~l~ced ~~ fluid ~th oil. ~9~d ~ll for 3 h~ur and 15 ~nute - ~o~ at ~ of l~ B/D~ i (Iu4ert) Net ~ise Drilling Fluid Nor~. There were ........................ runs or sales of oil; .............................................. !~.i cu. ft. of gas sold; ............................................... runs or sales c£ gasoline duriug the month. (Write "n()" where ~pI)iicaL, h,.) Nors. Repor~ on th~s [orm is require4 for each ca!endac inot~th, re~rardies,~ of the staU~ et oi~act~ duplicate with the supcrvhor by th.c 6th of tho ~:u. ccccdi~g n~o~ h. u~css othec,.¥~e directed by thc ~upc~ (Ja~i~ry 1950) MONTHLY REPORT OF OPERATIONS LESSEE'S .... A~a~klk ................. &o~ty ..~.e_r~..~__~_.~;~__i__n._8_~.a. .... ~eld .~-~~ ....................................... T~e follo~ is a oorreo~ report of~Oper~io~s a~ prod~o~io~ (ino~dt~ d~ll~ a~d produoi~ for t~e Comp~ ..W~~~--~ ......... ................................ ~e ' ~ ! * .... _ none, ~.o c~7/8' fr°m` !0,:~.' to 1C,h~7'. Dr~led 9-'l[~ n~l.e +~ !b 608'_ i~Cov,:.~ 6' co~~eratiq o~ s~, ~en. ea ~-71b, h.ote t'~m ~::,16o8, to Lo'itt/'. ~ ~ .~g ~r~ i1~~ to ~-~ a~ 6,~CO' t~ 3~'4 ur~i~: y-Mo- '. / hole/from lO,~9~ t~ Zl,O40' c. 7" casing ~ ' cemeht an~ ar~~ ~" hole f~T,'~O to ~,5,0 ... ~S i.o~- from ii q~,~ to l],Oh~,~c ~g fr~,. 11,516' to · , ~',:~ ~-~1 ~J.~ ~-*~ I~ ~19~' to 1!.(~40'. ~d Neutron Mo L. Hill R. . ~iisbe~ File: EX~lor ion No~..--There were .......... '--: ............. k ....... ~.._ runs or sales of oil; .............................................. M cu. It. of gas sold; .......................................... '_._ runs or sales of~asoline during the month. (Write "no" where applicable.) NOTr.--Report 'on this form is required for each calendar month~-, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the sudceeding month, unless o~herwise directed by the supervisor. , " ,v ....... , n .~,,"¥'. Forsl} 9-3~1 ~ (Feb. 19,H) NOTICE OF NOTICE OF NOT ICi:' OF NOTICE OF NOTICE OF NO[ICE OF NOTICE OF (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY RECEIVE ' SUNDRY NOTICES AND REPORTS ON WELLS. INTENTION TO DF~iLI .................... ( . .~ SUBSEQUENT REPORT OF WATER SHUT-OFF, INTENTION TO CHAff;GE FI_ANS ~. ......... [ ....SUBSEQUENT REPORT OF SHOO/'ING OR ACID~ . iNTENT~ON TO TES? WATER SHUT:OFF. JJ SUBSEQUENT REPO~T OF ~LTER~NG CASING ~N]fNTION TO ~E-D~ILL OR REPAJ~ WELL .... J~ SUBSEQUENT REPOR'I Of RbD~ILLING OR REPAIR ......... J ,, INTENTION TO SHOot OR ACIOIZE~) ..... ] SUBSEQUENT REPORT OF ABANDONMENT INTENTION TO PULL OR ALT~R CA~ING _ ~ SUPPLEMENTARY WELL HISTORY '--- -' ': ? ..................... .... .............. iNDICATF ABO'. E~Y CH~CK M~RK NATtJ~[ C;F REPORT, NOTICE OR OTHER 'JUL e~ l/ ;ection and M~neral~ ~~x. I~"~ line and_ ~ ft. from Well No.. !.t~..1~, . is located/ I..:', ft. from {S ~ {Wi line of ...~~ ~ .... ~ ~. ........ 9_.W ........ ..~~ C~ ~ ........ ~ ~ _. _ The elevation of th(. ~above ~ca level is ~ ft. sec. _. ~ ..... DETAILS OF WORK lng p.~ints, and all other in~portar t proposed work'., ~. ~ on re~ultI ~ S~q~ ~1 eoa~lete.wll ia Aeepe~ bo~t~oa or a~n UNITED STATES DEPARTMENT-OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No, 42-R356.5. Approval expires 12-31-60. LESSEE'S MONTHLY REPORT OF OPERATIONS The followinff is a correct report of operations and production (ir~oh~din~ drillin~ and produein~ w~lls) for the mo~tl~ of ................... _______ Pko~e .................... ~A]~R]gL,q oF OIL SEC. AND TWP. Hot )4 UoSoO.8. - I I I GRAVITY (I~ thousands) OASOLINE WATER (If (If drillin~, d~vh: if ~but down, ~ECOVERED 110110, ~ StB~) da~ and r~ult of t~t for e~tent of ]~r~a lt. 8oym'~r (3) ~ 0 CO - Richard We . RECEIVED jUL 5 1960 Oil & Gas Section Division of 5.~,;nes and Minerals Alasl~a Dept. o[ Natural Resources NoT~..--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................... runs or sales of gasoline during t, he month. (Write "no" where applicable.) Nots.--Report on this £orm is required for each calendar month, regardless of the s~atus of operation~, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by tho supervisor. Form 9-329 16--25700-8 U. $. (,~';/RNMrNT P~INTINC 01FFICg (January 1950) (Feb. 195I) (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R358.4. Approval expires 12-31-60. Land O ffice~~; ....... Lease No. ~ ................. SUNDRY NOTICES AND REPORTS ON WELLS , NOTICE OF INTENTION TO DRILL .............................. L .... SUBSEQUENT REPORT OF WATER SHUT-OFF ....................... NOTICE OF INTENTION TO CHANGE PLANS ....................... --I ...... SUBSEQUENT REPORT OF SHOOTING OR ACIDIZING. I SUBSEQUENT REPORT Of ALTERING CASING ............................. NOTICE OF INTENTION TO TEST WATER SHU'I'-OFF ............. ! ...... NOTICE Of INTENTION TO RE-DRILL OR REPAIR WELL .................. SUBSEQUENT REPORT OF RE-DRILLING OR REPAIR ..................... NOTICE OF'INTENTION TO SHOOT OR ACIDIZE ................... ~ ....... SUBSEQUENT REPORT OF ABANDONMENT ............................... NOTICE OF INTENTION TO PULL OR ALTER CASING .............. ~ ...... SUPPLEMENTARY WELL HISTORY ......................................... NOTICE OF INTENTION TO ABANDON WELL ............................................................................................................. (INDICATE ABOVE BY CHECK MARK NATURE OF REPORT, NOTICE, OR OTHER DATA) Well No,~. ........... is locate~k ft. from:[ line ft. fro line of $ sec. ~ a'il~, - .... ~_~.~: ............... ~. The elevation of above sea level is ~_ ..... ft~ DETAILS OF WORK (State names of and expected depths to objective sands; show sizes, weights/and lengths of proposed casings; indicate mudding jobs, cement- ing points, and all other important proposed work) I understand that this plan of work must receive approval in writing by the Geological Eurvey before operations may be comme~c~el. C0mpany -a~-:~:~-~-~ ..... ;~_~__~ .................... Address ~' ~ ~ ~" . . APPLICATION FOR PERMIT TO DRILl., DEEPEN OR PLUG BACK APPLICATION TO DRILL ~ DEEPEN [] PLUG BACK [] NAMlV~ OF COMPANY OR OPERATOR DATE Address City State DESCRIPTION OF WELL AND LEASE Name of lease ~l~li W~ ~1~ ~J~.8~ ~--~l~ ~l~lV~'ell number IElevati0n (grOund) Well location (give footage from section lines) Section~township~ran~e or block & survey Field & reservoir (If wildcat, so s~ate) ~ County Distance, in miles, and direction from nearest town or post office Nearest distance from proposed location to property or lease line:. Proposed depth: Number of acres in lease: Distance from proposed location to nearest drilling. completed or applied--for ;veil on the same lease: Rot~ary or cable tools I Approx. date work will start Number of wells on lease, including this well, completed in or drilling to this reservoir: fee t 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 back, briefly describe work to be done, giving present producing zone and expected new producing zone) CERTIFICATE: I, the undersigned, state that I am the ~*~*.. of the (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 stated tharei~ qre true correct and complete to (.)ngm~! s[gne~ the best of my knowledge, g. ~, C~OOKER Signature Z* ~.'~ C~ Permit Number: Approved By: ~~,- D. D. Bguce. Petro]eum. Geolo~st. Notice: Be. i0r~ senmngjn m~s ~or~_oe sur~na~ you have given al~J~m~t~ ~t$~d~~eessary eorrespond- enqq ~ill ~us be ,a~ojae0.. ~ !klas.t~a De~t. o~ iNatural nesoumes See Instrue/ioh on Reverse Side of Form Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 ~0 MAY ~5 1960 Oil & Gas Section Division oF Mines and Minerals'~ ~ Dep~ o~ blatm~
