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162-002
) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Performed: Alter Casing 0 Change Approved Program 0 2. Operator Unocal Alaska Name: Repair Well U Pull TubingO Operat. ShutdownO Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 StratigraphicO StimulateU Other ~ Pool Correction WaiverO Time ExtensionO as of 12/1962 - Re-enter Suspended Well 0 5/1965 5. Permit to Drill Number: ExploratoryO 162-002 ServiceO 6. API Number: 50-133-10162-00-00 9. Well Name and Number: SRU 21-33WD (AKA SRU 221-33) 10. Field/Pool(s): Swanson River, Sterling Undf Gas 3. Address: P.O. Box 19-0247 Anchorage, AK. 99519-0247 7. KB Elevation (ft): 206' 8. Property Designation: Swanson River Field/Swanson River Unit 11. Present Well Condition Summary: Total Depth measured 3805 feet true vertical 3805 feet Effective Depth measured 3100 feet true vertical 3100 feet Casing Length Size MD Structural Conductor 33' 20" 33' Surface 1396' 95/8" 1396' Intermediate 1370' 7" 1370' Production 1779' 51/2" 3149' Liner Plugs (measured) Junk (measured) 3000' none TVD Burst Collapse 33' 1396' 1370' 3149' Perforation depth: Measured depth: ~766'- 2770',2862' - 286E True Vertical depth: !766'- 2770',2862' - 286E Tubing: (size, grade, and measured depth) 23/8" 4.7# N-80 surface to 2866' MD Packers and SSSV (type and measured depth) Brown HS-16-1 pkr @ 2mal,r.¡n HS-16-1 pkr @ 2820', 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: SC,ANNEf) FEB 0 2; 2.005 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 000 000 15. Well Class after proposed work: ExploratoryO Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 0 0 Tubing Pressure 0 0 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service 0 GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: Contact Larry Greenstein @ 263-7661 Printed Name Larry Greenstein Title Production Technician Signature 4 ¡? ~' Phone 263-7661 Date 2/1/2005 Form 10-404 Revised 0412004 ~ I{8ff}J7S ~/f !5SUbmit Original Only ) Greenstein, Larry P From: Sent: To: Subject: McMains, Stephen E -AOGCC Tuesday, January 18, 2005 10:27 AM Larry Greenstein Swanson River Wells Larry , The following wells require paper work to reflect the current pools the well is producing from at this time. The forms need to be back dated to when production started for each well in the current and correct pools. *The following wells have the pool number after the name that requires corrected paper work: * 160-018 50-133-10135-00-00 Swanson River 212-10 772550 162-006 50-133-10137 -00-00 Swanson River 211-15 772550 160-022 50-133-10138-00-00 Swanson River 12-15 772520 162-002 50-133-10162-00-00 Swanson River 21-33WD 772550 202-118 50-133-20515-00-00 Swanson River 213-10 772520 *The only paper work required is a Report of Sundry Well Operations (10-404) for each well with date started production. * Here are the current Field & Pool codes we have in RBDMS and currently use in Swanson River Field: 772036 SWANSON RIVER, UNDEFINED WDSP 772100 SWANSON RIVER, HEMLOCK Oil 772110 SWANSON RIVER, UNDEFINED Oil 772500 SWANSON RIVER, TYONEK UNDF GAS 772520 SWANSON RIVER, BELUGA UNDF GAS 772550 SW ANSON RIVER, STERLING UNDF GAS 772555 SWANSON RIVER, GAS STORAGE If you have any question please call me, thanks Steve 1 ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: OilD GasD Plugged 0 Abandoned ~ Suspended 0 WAGD 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJD WINJD WDSPLD No. of Completions Other Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., r~ 12. Permit to Drill Number: Union Oil Company of California Aband.: Aban1, 62-0002-0 ../ 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 Apri11,1962 50-133-10162-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 560' FSL, 2,110' FEL, Sec. 33, T8N, R9W, SM May 6,1962 SRU 21-33 WD Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): same nla 206' RKB above MSL Total Depth: 9. Plug Back Depth(MD+ TVD): Swanson River FieldlSterling same nla nla 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 344525 ft y- 2465919 ft Zone- 3,805' MD, 3,805' TVD Swanson River Unit TPI: x- nla y- nla Zone- 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- y- Zone- nla A-028399 18. Directional Survey: Yes 0 No -g 19. Water Depth, if Offshore: 20. Thickness of Permafrost: nla feet MSL nla 21. Logs Run: nla 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 0 33 0 33 yes 9-5/8" 40# N-80 0 1396 0 1396 13-3/4" 800 sx 7" 23# N-80 0 1374 0 1374 8-314" 600 sx 5-1/2" 17# N-80 1374 3149 1374 3149 8-3/4" 600 sx 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 2,108 nla 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED see schematic attached see attached schematic 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): nla Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: IGaS-Oil Ratio: Test Period ... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate ..... 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RECEIVED RBDMS 8FL nlOCT 1 1 ?nn~ OCT 0 7 2004 nD'~'f\'AL Alaska Oil & Gas Cons. Commissio Anchorage G P Form 10-407 Revised 12/2003 CONTINUED ON REVERSE 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach nla detailed supporting data as necessary. If no tests were conducted, state "None". nla RECE IVED OCT °7 2004 Alaska Oil & Gas Cons. Commls:ìicn Anchorage 30. List of Attachments: Daily summary and schematic. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler: 263-7649 Printed Name: Tim C. Brandenbura Title: Drilling Manager Signature: "-Z-:::-¿~ ,--;;;;;þ Phone: 263-7628 Date: 1 0/5/2004 ~/ -,// INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~ UNOCAL8 Swanson River Field Well SRU 21-33WD As Abandoned TD= 3805' PBTD= 2450' Straight Hole SRU 21-33WD AsAbandoned Size T e Wt 20" Conductor 9-Y'" SurfCs 7" Prod Csg 5-Y," Cas in Grade ID Tubin Btm Hole Cmt Cmt To 33' Yes Surf. 1,396' 13-%" 800 sx Surf 1374' 8-%" 600 sx 1500' 3149' CBL Surf 25 bbls Surf N-80 N-80 ITEM DETAIL NO. Depth Date Coments 1. TOC Surf to 177' 9/7/99 Lubricated 5 bbls of 15.8 ppg "G" cement into 7" x 9-5/8" annulus 2. TOC Surf to 193' 7/9/72 Top job performed at 193' wI 45 sacks cement to surface 3. TOC (íì¿ 680 8/25/99 CT CO to fish (íì¿ 1751 '. Bullhead 25 bbls of 15.8 ppg of"G" Neat 4. TOCI93't02,110' 7/7/72 Cemented tubing with 250 sacks cement 5. 1,751' Unknown Fish 6. 2,590' 7/6/72 Retainer with 140' of cement 7. 2,886' Two retainers 8. TOC @ 340' 5/29/04 Drilled/CO cmt to 680'. Perff/ 655'-675'. Sqz'd 65 sx (13 bbls). Final pressure, 1520 psi. 6/11104 Tag TOC (íì¿ 222' SLM wI 2-1/4" bailer. PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 655 675 6 5/04 Tbg. Punch, 13 bbls pumped 2120 2174 4.5 5/64 2194 2262 4.5 5/64 2280 2296 4.5 5/64 2350 2394 4.5 5/64 2402 2438 4.5 5/64 2766 2770 4.5 5/62 Abandoned 2862 2866 4.5 5/62 Abandoned 3060 3065 4.5 5/62 Abandoned GPS Coordinates: 6O-degrees 44.86N, 150-degrees 52.30W (89') REVISED: 10/5/2004 DRAWN BY: DED 5/18/04 . Travel to SRU, Sign in at the Production Office (Note:Conduct a SIMOPS meeting in AM with forward plans). SRU 21-33WD, This well does not have a tree cap installed on top of Demeo valves, It has a flange with a 2" bull plug. This flange will need to be replaced in order to drift the CT downhole tools. I suggest removing this flange, and replacing it with a raised face flange with a 3" LP outlet. Then install a 3" pin x pin with a 3" LP API ring groove flange looking up and install a 3" Gate Valve on top to test CT BOP. 5/19/04 SIMOPS meeting with Production, Discuss forward plans for SRU 21-33 WD. Utilize Production back-hoe to dig out around wellhead to have access to lower casing valves. Check 7" x 9 5/8" casing annulus valves both had cement to surface. Called Schlumberger (James fouras) to come out to do layout of pad, and go over Coil Tubing check list. Located Cement Blocks 4ea for Coil Tubing work. Located crossover from Demeo 3" x 3 1/8" 5M API. Located a 3 1/8" 5M Gate valve to utilize in place of the Demco(Will test Coil against this Valve). Went around to SRU 21-33 WD, SCU 23-27, SCU 42-04, and SCU 22-04 with Schlumberger (James Fouras) to obtain CTU layout drawings. Also, checked Coil Tubing equipment and went over check list. Spoke with Dennis Jackson (Swaco) about a 150 bbl tank with shakers.(Will follow up). 5/20/04 Attend Safety Meeting with the Production crews, Held SIMOPS meeting with Production. Discuss nippling down Demeo tree vavles, and installing a 3 1/8" 5M API valve. Nipple down Demeo tree valves(Cement was +/- 20' down) Install 3 18" 5M WKM API valve, and tested to 3,000 PSI. Called Dennis (Swaco) ordered 150 bbl tank with shakers, and 30 bbl cuttings tank. We will mix Xanvis or equivalent in the 150 bbl tank. Liner arrived at location, will have Peak hands in the AM to install. Schlumberger picked up BOP to bring to their shop to redress(Will be ready in the AM) Production will let us use their Vac Truck for pumping out cutting, and hauling water. Need to follow up with Baroid about mixing Xanvis. Sent water samples from Rig location to Schlumberger for Cement test for Rig work. Airport is sending out Generator to run Shakers. Should start spotting Coil equipment in the AM. Pollard wireline is on will call to gauge tubing with dummy guns. 5/21/04 Attend Safety meeting with the Production crews, Held SIMOPS meeting. Discuss use of forklift, and vac-truck. Meet with Peak crew, Held Safety Meeting and went over job operations of installing liner and layout for spotting Coil equipment. Laid out liner and timbers on 21-33 pad to spot Coil equipment. Held PJSM, Spot Coil equipment and Mud Tank with shaker system, Hook up lines to same. Note: The Coil Bits will not be in Anch. Until Monday. . . . Will finish hooking up Schlumberger line in the AM. Placed call to opssummaryforagencies.doc, 10/5/2004, page 1 AOGCC (Jim Regg) will not have anyone available to witness test on BOP ( I Will send Inspection Report) 5/22/04 Attend Safety Meeting with Production, Held SIMOPS on forward plans. Held meeting with Schlumberger on hooking up hard lines and hoses to unit and tanks. Hook up services lines, Install BOP, Clean Swaco tank and fill with water. Note: It seems that the alternator may be out on the Coil Power Unit. A Mechanic is coming out in the morning. 5/23/04 Attend Safety Meeting with Production, Held SIMOPS Meeting, Discuss forward plans. Held Meeting with Schlumberger, Continue hooking up lines and rigging up unit. Mechanic showed up, and it seems that the kill switch was not pulled out all the way. The power pack unit is running fine now. Power-pack up & running, Check hydraulics & function test equipment. Discover crack in reel. Called for a Peak welder in AM 5/24/04 Held Meeting and discuss forward plan. Welder arrives, Inspect reel, unload leads, and remove hard lines from reel. Welder makes weld on reel, connect hard lines back to reel. Prep reel to stab coil pipe. Dress coil for ball catcher. Will launch Hippo-Trip, Nerf Ball, and 1.0 drift ball in the AM. 5/25/04 Attend SIMOPS meeting with Production forward plans, Held PJSM with Schlumberger, Discuss rigging and testing safety issues. Stab injecting on well place Hippo Turbine, Nerf Ball in reel. Press up against reel valve, release & bring pump online @ 1.5 bpm. First Hippo through, Displace 10 more bbls. Some diesel came back from reel. RID Inj. Head, run down pipe to retrieve Hippo & nerfball, 2nd Hippo in reel, re-head up. Press up on reel/valve. Begin displacement of Hippo turbine @ 1.5 bpm. Reel Volume 21 bbls. RID Inj head to retrieve Hippo. Place drift ball (7/8") & nerfball in reel, Re-head & press up on reel valve.Release pressure and displace drift. ball. M!U Inj head, ready to function & test BOP. Test BOPE Low 300 psi - High 3,000 psi, Blinds, Shear, Slips, and Pipe. M!U set/slip connector. Pull test CT connector to 15k. Set head down, replace switch on #4. 5/26/04 Shut down for the night. Attended sim-op meeting with production. Held safety meeting with Schlumberger CT. PU injector head. Made up BHA consisting of motor and mill. "Stabbed injector head. Had a leak around the 3 1/2"" tubing at the top ofthe seal flange. Unstabbed injector head. Welded the 3 1/2"" tubing to the seal flange and tested to 1,000 psi. Stabbed injector head. Tested brake to 300/4,000 psi. TIH and tagged TOC @ 82'. opssummaryforagencies.doc, 10/5/2004, page 2 Milled cement @ 60'/hr ROP from 82' to 320'. Circulated 20 bbls. POOH. 3-1/2" tubing broke at seal flange while breaking lubricator. Secured BOP's. Pulled BHA out of riser and laid back injector head. ND BOPE and laid back same. Shut down Schlumberger for the night. Broke studs out of old seal flange. Located 7-1/16" 5M x 3-1/8" 5M DSA, NIU new seal flange. Will nipple up Coil on seal flange in the AM. Note: After the old seal flange was removed, inspect the tubing it is in very bad shape The 3 1/2" x 7" had cement all the way to the top ofthe tubing spool. 5/27/04 Shut down operation for the night. Held PJSM with Schlumberger on rigging up BOP. Service equipment. NU BOP on top of new seal flange, MU riser, BHA and injecting head. Shell test BOP to 4,000 psi, open gate valve, test new connection on top of tubing spool to 1,000 psi. RIH, break circ, tag cmt at 320'. Drilling cmt, 1.5 bpm, 60 gpm, 450 rpm, 200# torque, and at 2,300 psi. (free spin 1,900 psi) Drilling slowed down @ 345' stalled motor.Increase rate to 2.0 bpm,75 gpm, 500 rpm, 250# torque, and 3,700 psi (free spin 3,300 psi) still not drilling off. PU off bottom, eirc bottoms up, POOH with BHA. Inspect PDC bit, the bit looks good no wear or marks, Change out the motors. Test connection break, RIH tag at 345', break circ, Drilling ahead, 1.25 bpm,50 gpm, 375 rpm, 180# torque, and at 1,950 psi. (free spin 1,650 psi) Drilling from 345' to 408' 50' ROP, continue drilling, drilling slowed down, ROP 6' @ 408' to 430' 5/28/04 Shut down operation for the night. Held SIMOPS, Held PJSM with Schlumberger, and service equipment. MU BHA, Installed new motor with the same PDC bit. MU riser on BOP. Test to 3,000 psi. Open gate valve and RIH, Tagged at 430', Break circ, No fill, Drill f/ 430' - t/ 460, Drilling slowing down and not making much progress, POOH, Change out bits, removed the PDC and Installed a Carbide bit. MU riser, test connection. RIH, break eirc, No fill. Drill f/460' - t/680', drilling rate increased after changing out bits. Circ hole clean, POOH, RD, Stand back injection head. 5/29/04 No Operations Held PJSM, RU Slickline lubricator and equipment, and test to 1,500 psi. RIH with 2.75 gauge ring to 680', POOH. RIH with 2 1/2" x 20' dummy guns to 680', POOH. RD Slickline lubricator and equipment. (Move to 23-27) RU E-line (Schlumberger) lubricator and equipment, test to 1,500 psi. RIH with 2 1/2"x 20' guns (6 spt), CCL, and weight bars. Tag at 680', PU 5' and fire guns, prerforated 655' - 675' (pressure came up to 400 psi) POOH. Open needle valve bleed pressure to 0 psi, RD E- line lubricator and equipment. RU Cement Unit hard lines and test to 3,500 psi. Start pumping H2O for Injection rate. 1/2 bpm 1.5 bbls 380 psi, 1 bpm 2.5 bbls 1100 psi broke down to 800 psi, 2.5 bpm 3.5 bbls 1250 psi. shut down pumps. Start Cement job, 65 sks, 15.8 ppg, 1.16 yield, 8 bbls H2O, Total bbls pumped 13 bbls. Displaced with 3 bbls of water, (340' cement left in tubing) Final pressure 1520 psi. Close in well. Flush lines, clean tanks, RD Cement Unit.Rigging down Coil tubing unit. (Will test cement in 72hrs) opssummaryforagencies.doc, 10/5/2004, page 3 6/10/04 No operations. DS Pump truck arrived in field. RU to well. Pressure test surface iron to 2500 psi. Required a lot of rate to achieve this. Pump appeared to be bypassing fluid. RU hart recorder. Open well. Pressure up on well to 1500 psi. found adapter flange leaking. Fix same. re-pressure well to 1500 psi. Found 3-1/8" x 2" XO flange leaking. Attempts tighten flange failed. remove same. found XO flange ring grove badly corroded. attempts to remedied failed. Search field for replacement was disappointing. RD DS pump. Inspection of pump found all three rupture discs were sheared. 6/11/04 No operations Pollard arrived on location. PJSM. RU lubricator. Pressure tested same to 1500 psi. OK. RlH w/ 2-1/4" DD bailer to 222'. Tag solid. AOGCC Representative, Jeff Jones, called it good. POOH. RD Slickline. 8/5/04 No Activity. Got with Plant personnel got a excavation permit, check pressure on well head zero, casing zero dug up around well, cement on top of culvert. Took picture sent to Anchorage office. Unable to get transit to determine ground elevation above 20" conductor pipe. Conductor pipe had already been cut 3-1/2' to 4' below ground elevation of Pad. Need to determine Oringinal ground elevation, possibly can use a welder to cut casing and weld cap on conductor without having to use air hammer, crane and hydraulic cutter will be determine in the morning. 8/14/04 No activity Converse with Field Super on plan for day and yesterdays activity. Late SIMOP's with production Mobe equipment to pad location and tools. PJSM with Peak crew about excavation plan of cement with emphases on environmental issues related to clean or dirty cement and soils. Instructed crew to slope hole sides to get within compliance with safe excavation practices. I covered SPS- 7.5 (UNOCAL Excavation Procedure) with crew. Used excavator to slope excavation hole as required as this was easier (more cost effective) than using coffin box, soils were clean and no facility items in the way. Looked excavation over vary closely and all soils are clean down to the cement well cellar. Found two extra lines under grade. Jack Hammer and remove concrete from cellar bottom. Finish removal of cement from well cellar bottom. (Ready for environmental visit and evaluation coming Monday morning.) Picked up tools, Picked up cement chunks and loaded in field dump truck. Fence in excavation hole for safety. Plan forward is for Remediation Technologist to evaluate soils on Monday 8/22/04 opssummaryforagencies.doc, 10/5/2004, page 4 Spot equipment, have tail gate safety meeting and rig up WACHS Casing Cutoff Tool. Loader, Vac Truck and Excavator used onjob. Cut casing's and tubing with WACHS Cutoff Saw at 3' plus below average original ground level. Took about 5 hours of actual cutting time and two blades. At least 2 hours of time lost with learning how to use tool effectively and miner problems adjusting saw function. Lay down pipe and shut down. Cut looked good. 8/23/04 SIMOP's PTSM, line out crew Crew cleaned up equipment and put away that was used on last nights cut and staged equipment for top off of surface plug on tubing. Glue and run in hole 1 1/2" PVC pipe ( with bottom 10 footer caped and perforated with holes full length) to 202' RKB and set down on fill above wire line tag. Washed the last joint some and added another joint. Ended up with 229' RKB ofPVC in hole. Mixed up 80 Gallons of 15.8# G-neat cement. Pumped cement down PVC while taking PVC by Tubing annulus returns to surface. Had to mix and top off with PVC and annulus with 3.5 gallons more G-neat cement. Cleaned up equipment, hauled off materials. Shut down operations and sent 2 Peak hands home for a day. 8/25/04 Sim-ops mtg. with Production personnel @ Plant site. Welded 20" x 1/4" plate, w/1/4" weep hole drilled into top of plate to 20" conductor. Welded following infonnation on top of plate SRU 21-33 WD, 560 FSL 2110 FEL, SEC 33T 8N, R9 W SM. The GPS reading 60-degrees 44.86N, ISO-degrees 52.30W (89'). opssummaryforagencies.doc, 10/5/2004, page 5 Surface Abandonment Pictures for SRU 21-33WD Provided by Unocal September 3,2004 Cutting casing (MVC-013F.jpg) Cutting casing (MVC-014F.jpg) Cutting casing (MVC-O 18F .jpg) SRU 21-33WD P&A August 2004 Casing cut complete; all annuli cemented to surface (MVC-019F.jpg) Tubing cemented to surface with perforated PVC pipe (MVC-003F.jpg) Marker plate installed for SRU 21-33WD (MVC-452S.jpg) 2 SRU 21-33WD surface cement on tubing Subject: SRU 21-33WD surface cement on tubing From: "Lucas, Ken J" <lucask@unocal.com> Date: Mon, 23 Aug 2004 23:36:01 -0800 T o~l:~im.:.. ~~ lor@åk;blm.goy'jiin - regg@ådfuin.st*~l~k us. ~ ~ Ib7...-Üù7.- .... . Ran 1 1/2" PVC pipe in tubing to 229' RKB. Pumped 15.8# G-neat cement down PVC while taking returns up annulus of PVC and tubing. Toped off with same 15.8# G-neat cement. «MVC-OO3F.JPG» «MVC-O19F.JPG» Content-Description: MVC-OO3F.JPG Content-Type: image/jpeg Content-Encoding: base64 . __-.mm_- ..... -..-.-..---....._.._mm_.....--.--.-.. Content-Des ption: MVC-OI9F.JPG MVC-O19F.JPG Conte ype: image/jpeg ent-Encoding: base64 . .. --......-......-...._.__mm.._....... 1 of 1 R.tF~ ~t~? I () ~ q~I4-^""" e~ 8/24/2004 9:32 AM SRU 21-33 WD Abandonment Pictures of WACHS Cutting Operation. ?r D it- its, 2- Ci) 7.-- Subject: SRU 21-33 WD Abandonment Pictures of WACHS Cutting Operation. From: "Lucas, Ken J" <lucask@unocal.com> Date: Mon, 23 Aug 2004 09: 14:31 -0800 1r~~~ftïp~L~~':~~~~~þhnigov~jimJ~~~dmÍ1istate.~~,< .~>¡::::J'::':;;::~.!::: ""';:. . :"'<:{if~~" ',: ""',<: cq;: t~yl~~, :~~e, I}~ftylersl@Unocal.~m>, :IIHarness,..ijvàn" <eh~øss@unocal~é~m>' «MVC-018F.JPG» «MVC-013F.JPG» «MVC-O14F.JPG» «MVC-019F.JPG» Tim & Jim, my intentions today is to get 250' of PVC pipe today and RIH with it. I will put a cap on bottom and perforate the first joint full length. We will set it on bottom and pump 15.8# G-Neat cement down PVC taking returns up PVC by Tbg annulus. We will cut PVC at surface when fully displaced. I will send you more pictures. Steve & Evan, this operation has been waived as to witness by BlM & AOGCC. I will be sending everyone pictures of events. Content-Description: MVC-018F.JPG Content-Type: image/jpeg Content-Encoding: base64 . Content-Description: MVC-O13F.JPG : MVC-O13F.JPG Content-Type: image/jpeg . Content-Encoding: base64 ................................................................. . Content-Description: MVC-014F.JPG Content-Type: image/jpeg Content-Encoding: base64 Content-Description: MVC-019F.JPG Content-Type: image/jpeg Content-Encoding: base64 1 of 1 8/23/2004 2:04 PM ?&{1 ß{1AI~ Surface Abandonment Pictures for SRU 21-33WD Provided by Unocal August 23, 2004 Cutting casing (MVC-013F.jpg) ':.\'" . ~ ,'t ;.;ft . i . , '. " .-'; Cutting casing (MVC-014F.jpg) : ~ . ~ '. :,. ~'j,. ""'0...,...,1 '.,""'.~ 1lf;~,C','."". .Il' -" . " ,,', ' '.~. - ;.\l~' ~ ..."""~~',l'~"',..I,".....,.,", ""'-1, ',. .", ,"" ' " ..~, " " --""'. ' . ~j '~.:.'.. . Cutting casing (MVC-018F.jpg) SRU 21-33WD P&A August 2004 Casing cut complete; all annuli cemented to surface (MVC-019F.jpg) Tubing cemented to surface with perforated PVC pipe (MVC-003F.jpg) 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission . ~.IZ~(D4 TO: Jim Regg, 1<-ftl' P. I. Supervisor DATE: June 11,2004 FROM: Jeff Jones Petroleum Inspector SUBJECT: Plug & Abandonment Well SRU 21-33 WD Unocal PTO #1620020 Swanson River Field June 11, 2004: I traveled to Unocal's SRU 21-33 WO well location to witness the wire line tag of a cement abandonment plug. An approximately 300 pound weight bar and sample catcher assembly was run in the hole by Pollard wire line personnel and the top of cement was tagged at 222.5' MD. A sample returned indicated contaminated cement at this depth. The plug will also be pressure tested by the operator in the near future at the AOGCC's request. Summary: I witnessed the successful wire line tag of a cement abandonment plug placed in Unocal's well SRU 21-33 WO, in the Swanson River Field. Attachments: Well Bore Schematic, Completion Report (2) X Unclassified Classified /~ ~~ ~ UNOCALi) 1.:,,;:~~_tbg ~;';:!:l? !4~~~~:,~,~ ~~~~ ~~ .~; 1~'''''1 '-";II'~'\ t OJ ... ., .';."', ~"r~V, :", ~ ~~t~ji :~ 0 , ,~',. ;ji -.'" , !. ~ '7. ','. .-; ~)" ~I!.' I.,"~':~::!~! ~., ...~-~ \i5-~~ -~--:~~.a..:~1~~~ "~. ,:,~;,.....).t; ""',;7:"\" ~~ m ,~ ~'''''.#;.'~ .~:.'" ~ ~ ~~ ~~'!~"'A~ ':'~"".. .. '." ~~",.~)J ~~~ :~'" ~ 8] ~ . ."".... " I ..,. rr"" J ;"'I'~"'Ii .,.. ..,~ ~~ V -' . I,' '.~" "'<!'"r: .a ." , ;:¡"*., 't!...... . 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"". . .: , " TD= 3805' PBTD: :USO' Straigbt Hole SRU 21-33 WD Actual ~' )- /b22-~5 Swanson River Field \Vell # SClJ 21-33\\:'0 Actual Completion 12/20/72 CasinQ & Tub i ng Size Type \Vt Grade ID Top 8tm Hole Cmt Cmt Top 20" Conductor Surf 33' Yes Surf. 9-%" Surf Csg 40 N-80 8.835" Surf 1.396' 13-3/4" 800 sx Surf T Prod C sg 23 N-80 6.366" Surf 1374' 8-%" 600 sx 1500' 5.1"2" 17 4.892" 1374' 3149' CBL Tubin~ cemented in CSr wI 250sx toped wI 45 sx Surf 3.1/=" Bullhead cmt I 9.2 N-80 I 2.992 I Surf I 2108 þ\~~ 25 bbls Surf NO. Deprh Dare I. TOC Surf to 177' 9/7/99 2. TOC Surf to 193" 7/9/72 3. TOC @ 680 8/25/99 4. TOC 193' 102.110' 7/7/72 5. 1.751' 6 2.590' 7/6/72 7. "'fi':J ( TOC @ 340' 5/29/04 TOP 2120 2194 2280 2350 2402 2766 2862 3060 BT!\I 2174 2262 2296 2394 2438 2770 2866 3065 ITEI\' DETAIL lUml."nr.. Lubricated 5 bbls of 15.8 ppg '.G" cement into T x 9-5/8" annulus Top job performed at 193' wI 45 sacks cement to surface CT CO to fish I'fi.' 1751 '. Bullhead 25 bbls of 15.8 ppg. of "G" Neal Cemented tubing with 250 sacks cement Unknown Fish Retainer with 140' of cement Two retainers Drilled/CO cmt to 680'. Perf f/655'-67S', Sqz'd 65 sx (13 bbls). Final pressure, 1520 psi, PERFOR-\ TION DA T.-\ ZONE SPF DA TE COI\'11\IENTS 4.5 5/64 4.5 5/64 4.5 5/64 4.5 5/64 4,5 5/64 4.5 5/62 4.5 5/62 4.5 5/62 Abandoned Abandoned Abandoned REVISED: 6/11/2004 DRAWN BY: rCB I .. ., UNOCAL . Alaska Drilling DAILY - DRILLING' WORKOVER , COMPLETION REPORT WElL TYPE Injector FIEL.DiPROSPECT Swanson River Un/1 WElL lEASE AND NO. Swanson River RIG NAME AND TYPE AFE NO. UOCO INT AFE AMOUNT $ :263,037 162285 100.0% we SCR 21-33WD i CASING PROGRAM SIZE T.O,LI5HOE MD COHD SHOE TEST TYPE PROPOSED MDITVD LocatIon latJIong OBJECTNE lCT CMT DnIlOUt & Phase II P&A WTR DEPTH RT -MSL CURRENT MUD WEIGHT REPORT NO. DATE 5/29/04 PRESENT OPERATION (0500) I From To 0:00 6:00 6,0 6:00 7:00 1,0 7:00 8:00 1.0 8:00 8:30 0.5 8:30 10:30 20- 10:30 11:00 0.5 11:00 11:30 0.5 11:30 12:30 1,0 12:30 13:30 1,0 13:30 14:30 1.0 14:30 15:30 1.0 15:30 17:30 2,0 -- RT.ML BuII!.E ye BOP L FLEX JT RT-MNGR ~ MUDTYPE~ 12 I Dliys on wen 12.0 I I Days slncespud 12.0 I I Mobe Da~ I Rig Up Days HOURS DRILLING AVERAGE ROP Total Depltl PBTDITOF FOOTAGE DRILLED Hours Remartcs No Operations Held PJSM, RU Slick line lubricator and equipment. and test to 1,500 psi. RIH with 2,75 gauge ring to 680', POOH. RIH with 21/2" x 20' dummy guns to 680', POOH. RD Slickline lubricator and equipment. (Move to 23-27) ---. RU E-line (Schlumberger) lubricator and equipment. test to 1,500 psi. RIH with 2 1/2"x 20' guns (6 spf), CCl, and weight bars. Tag at 680', PU 5' and fire guns. prerforated 655' - 675' (pressure came up to 400 psi) POOH, Open needle valve bleed pressure to 0 psi, RD E-line lubricator and equipmenUMoved to 23-2?L-___- RU Cement Unit hard lines and test to 3,500 psi. Start pumping H2O for Injection rate. 1/2 bpm 1.5 bbls 380 psi, 1 bpm 2.5 bbls 1100 psi broke down to 800 psi, 2.5 bpm 3.5 bbls 1250 psi. shut down pumps. Start Cement job, 65 sks, 15,8 ppg, 1,16 yield, 8 bbls H2O, Total bbls pumped 13 bbls. Displaced with 3 bbls of water, (340' cement left in tubing) Final pressure 1520 psi. Close in well. Flush lines, clean tanks, RD Cement Unit.Rigg.!!lg down_C..Q!1 tubing unit. (Will test cement in 72hrs)_- -- ----------- -----. ----- ---_._- ----'.---' --.--- --- ------- -- ---- 17.5 TOTAL HRS, ¡COSTS DAILY INTANGIBLE $ 42,255 CUMULATIVE MUD COST $ DAILY TANGIBLE $ DAILY MUD COST $ I MUD PROPERTIES FILTRATE FIL TI!.RCAKE MW OIWR WPS GELS IOSEC HTHP8 2SÐ HTHP E.S. SOUDS CONTROL EQUIP 8HAKER 11 SHAKER IZ I I IBIT INFORMATION -- COST-TD-DATE $ DAILY COST $ YESTERDAY'S TOTAL ~ 166.841 42.255 124,585 VP EXCESS UME 3RPM SHAKER II/J SHAKER 1114 SHAKER IItI SHAKER III SHAKER ff1 SHAKER 18 I ~ I I I ~ I I I I I I OTHER 1 OTHER OTHER BIT NUMBER SIZE IIN, I Reamer Size I I :e:~) DAlLY HYDRAUUCS INFORMATION I Statu!' PUMP MAKE MODEL I I MoIor Bend SERIAL TFA DEPTH (FT, DISl TOTAL.. HRS WO£> RPM CONDITION NUMBER (II~SQ, FROM TO In, OB1. DRLG ROP IFPH, (KIPS, MTIRn' I 0 D L B G 0 R I I I I -1--- I I I I I I Dale Pulled I Sliding ROP (FPH, BU Revs 11.000) I I I I I Pilot On 0" P1 P2 81 82 Off 0" DAlLY DRILL STRING INFO BHA LENGTH A:~r:;S IDAlL Y HOLE CONDITIONS AVERAGE BACKGRD GAS MAX DRILLED GAS MAX TRIP GAS STRK EFF BBU PUMP GPM DCAV DPAV JET VEL HHP ~ PRESS #VALUE! #VALUEI tlVALUE! ~ALUEI #VALUE! BIT PRESS DROP IMP FORCE #VALUEI "VALUE I LINER SPM FT'LB TORQUE HOURS ON JARS ADDITIONAL INFORMATION BHAWGf BELOW JARS WOB 1000 LB ROfARY RPM HR~ SINCE INSPEC TION ON 8TM 0 OFF 81M 0 -- 0 unitS 0 unUs 0 unll5 ¡FOREMAN Marty Monn~_- -- 0 umts 0 unn~ SLACK OFF WCT ~(IOOOLB) ~ (1000 LBI _~11000LB) CONN GAS SIT GAS PICK UP WGT ROTATING WGT MIDNIGHT TO 0500 HRS TIME BREAKDOWN ------------_._------~ .--------- ----. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, . T}~1 ¡;12~04 P. I. Supervisor I DATE: June 11,2004 FROM: Jeff Jones Petroleum Inspector SUBJECT: Plug & Abandonment Well SRU 21-33 WD Unocal PTD #1620020 Swanson River Field June 11, 2004: I traveled to Unocal's SRU 21-33 WD well location to witness the wire line tag of a cement abandonment plug. An approximately 300 pound weight bar and sample catcher assembly was run in the hole by Pollard wire line personnel and the top of cement was tagged at 222.5' MD. A sample returned indicated contaminated cement at this depth. The plug will also be pressure tested by the operator in the near future at the AOGCC's request. Summary: I witnessed the successful wire line tag of a cement abandonment plug placed in Unocal's well SRU 21-33 WD, in the Swanson River Field. Attachments: Well Bore Schematic, Completion Report (2) X Unclassified Classified >- . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure nla 3-400 bblsldaily nla nla nla nla 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: oilD Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ 1. Operations Abandon W Performed: Alter Casing 0 Change Approved Program 0 2. Operator Name: 3. Address: Suspend U RepairWell 0 Pull Tubing 0 Union Oil Company of California PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 206' RKB S. Property Designation: Swanson River Field 11. Present Well Condition Summary: Total Depth measured 3,S05' feet true vertical 3,S05' feet Effective Depth measured nla feet true vertical nla feet Casing Length Size Structural Conductor 33 20" Surface 1396 9-5/S" Intermediate 1,374 7" Production 1,775 5-1/2" Liner Perforation depth: Measured depth: 2,120 to 3,065' True Vertical depth: 2,120 to 3,065' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2,120 to 3,065' Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl nla nla x Contact Steve Tyler 907-263-7649 Printed Name Philip J. Krueger Signature V~/ .þ;t~ Form 1'04 Revised 12/2003 Operation Shutdown U Plug Perforations 0 Perforat~ New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 Other U Perforate U Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: ~ ExploratoryO 62-eOO2-u /bP,oo-2..0 Service 0 6. API Number: 50-133-10162-00 9. Well Name and Number: SCU 21-33WD 10. Field/Pool(s): Swanson River FieldlSterling Plugs (measured) Junk (measured) 2,590' 1,751 MD TVD 33 33 1396 1396 1374 1374 3149 3149 Burst Collapse 916 psi 532 psi 397 psi 3,090 psi 3,S30 psi 6,2S0 psi RECEIVED APR 1 9 2004 3-1/2" Bullhead cmt, 9.2#, N-SO @ 2,108 Alaska Oil & Gas Cons. Commission Anchorage nla Bullhead 25 bbls of 15.S ppg "g" neat cmt, 700 psi Tubing Pressure 600-650 Ibs nla Service D GINJ D WINJ 0 WDSPL 0 Isund3N,~r ~r N; ;f ~O. Exempt: Title Drilling Manager Phone 907-276-7600 Date 4/7/2004 ORIGfNAL R8DMS BFL APR 2 0 2004 8/20/99 MIRU Dowell Coiled Tubing unit and Baker tanks. M/U adaptor spool and set BOP. RU circulating system and choke manifold.Displace lines and coil with water. Pressure test lines and BOPE to 350 psi. and 1750 psi. MU 2 1/4" grapple coil connector and pull test to 16K. Fuel equipment and secure for night. 8/21/99 M/U BHA #1 and Lubricator. Test tools and tubing without motor to 3500 psi. M/U motor and bit. Stab lubricator and test to 1750 psi. SITP = 0 psi. SICP = 130 PSI. Ream in hole w/ full returns at 75 gpm. And 3200 psi. CTP. Returns clean to slightly cloudy. Motor torque steady. Tag fish at 1751'. Set down and work fish at various weights. CTP to 4000 psi.and WOB to 5K. NO progress. POOH to 1650' and shut in at choke. Attempt injection with no displacement to 1500 psi. Broke down at 1500 psi. Established 1750 psi. at 2.2 bpm. Total injected volume 10.25 bbl. RIH and tag fish at 1752.5'. Work mill and weight with no movement offish. Shut-in and confirm well still open for injection. Inject total of 20 bbl. At 2.2 bpm and 1750 psi. POOH. Shut in well and LID bit. Bit "cored" w/ junk marks in center. Injection test 3 1/2' tubing: 960 psi. at 1.4 bpm.; 1290 psi, at 2.0 bpm.; 1450 psi. at 2.6 bpm.; 1700 psi at 3.0 bpm. RID and prepare to move to well 41- 33WD. Move to well 41-33WD 8/25/99 R/U to bullhead down tubing. SITP = Vac. SICP = 140 psi. in 7" x 9-5/8" annulus. Hold job safety meeting. Cement 3-1/2" tubing from surface to TD with 25 bbl class G cement mixed at 15.8 ppg. Established injection rate of 2.0 bpm at 1200 psi. Started mix at 14:53 started pumping downhole at 14:55. Finish cement and chase lines with 1 bbl water4 at 15:10; CIP at 15:10 with 700 psi. pumping pressure. Shut in tree. Wash out lines and change over to 7 x 9-5/8 annulus. Attempt to establish injection rate. Pumped 1.05 bbl and held 1550 psi. Bled to 1350 psi in 10 min. Attempt to inject. Pressure to 2600 psi. Bled to 1817 psi in 10 min. Confer with office and secure operation. Clean up cemnt unit and location. NOTE: will inspect Wellhead with S. Lawrence to evaluate options. 8/26/99 Inspect wellhead w/ S. Lawrernce SITP = Opsi. SICP = 140 psi. Rig Blowdown tank to 7" x 9-5/8 annulus and bleed to 0 psi. Recovered 3 gal. Dead oil and water. SI casing. SITP = 0 psi. CICP = 40 psi. Bleed casing down to blowdown tank. No fluid but blowing slight gas stream. Strap tank. Open tubing and SLM to top of fluid at 26' and top of cement at 76' SI tubing and continue casing blowdown. POINTS FOR CONSIDERATION and DISCUSSION: 1; The attempted injection pressure was held at 2000 psi. The wellhead is 3000 psi rated. 9-5/8 N-80 burst is 5750 7" N-80 collapse is 3830 psi. We can replace the casing head wing valves after blowing down the flow and try taking the injection pressure to 3000 psi. The risk is of casing failure due to corrosion wastage. 2; At 22:30 there was no flow. We can dress the wing valves an lubricate water to float out the antifreeze oil and then lubricate cement to float out the water, the shut in the outlet and inject cement until it locks up. Then shut in and hold until set. The risk is that the cement might channel or the volume might be inadequate. 9/4/99 Remove Scotch nipple and install 3000 psi ball valve on annulus, install 3000 psi ball outside of Rockwell plug valve, install guages in tbg, 7" X tbg, 7" X 9 5/8" annulus. Rig up triplex test pump. Pump @ 40 gals lease water into 7" X 9 5/8" annulus to fill and pressure up to 3000 psi. Hold for 30 minutes pressure bled to 1950 psi. Pressure up to 3000 psi, took 5 gals. Monitor pressure @ 11 :30 hrs 3000 psi 15:00 hrs 500 psi 17:00:hrs 450 psi 9-5-99 5:30 hrs 250 psi Will attempt to displace annulus fluid w/ N2 in the AM and possible lubricate cmt in. * Pressure was at 70 psi when we bled down at 0800 hrs to change annulus valves. Had bled down the previous night at 1700 hrs to 0 psi. 9/5/99 Rig up to equalize N2 into 7" X 9 5/8" annulus Equalize N2 into annulus in an attempt to push fluid level down. Initial pressure 2250 psi, bled to 1750 at 1800 hrs. 9/6/99 Keep N2 pressure from 8 bottles on 7" x 9 5/8" annulus. Pressure at 0700 hrs - 1450 psi 1330 hrs - 1300 psi shut in bottles 1700 hrs - 1200 psi 1800 hrs - 1150 psi 1815 hrs - 1650 psi open up 4 bottles (2250) 2030 hrs - 1600 psi 0530 hrs- 1350 psi (917199) * Dowell on the hook to pump cement today 9/7/99 Rig up Dowell cementing unit and bulk truck. Hold pre-job safety/operational meeting. Test lines to 3800 psi. 1300 psi (N2) on 7" X 9 5/8" annulus - Mix 3 bbls cement Bleed pressure to 1000 psi (N2), pump 2.25 bbls cement, pressure up to 3000 psi Bleed pressure to 1000 psi (all N2) , pump 1.00 bbl cement, pressure up to 3000 psi Bleed pressure to "0" psi (N2 and 10 gals cement),pump 1.5 bbls cement, pressure up to 3000 psi Pressure bled to 2500 psi, pump .2 bbls cement, pressure up to 3000 psi Pressure bled to 2500 psi, pump .2 bbls cement, pressure up to 3000 psi Pressure bled to 2500 psi, pump .2 bbls water, pressure up to 3000 psi CIP 13:35 - 5 bbls 15.8 ppg "G" - 177' cement in 7" X 9 5/8" annulus Shut csg valve in that Dowell was rigged up on. Rig down Dowell and monitor pressure Pressure 3000 psi 1100 psi 850 psi 800 psi 750 psi 700 psi 450 psi 9/11/99 Time 13:40 hrs 14:40 hrs 17:00 hrs 18:40 hrs 19:50 hrs 21 :00 hrs 05:00 hrs (9/8/99) Dig up cellar. RU and Hot Tap Annulus Valve (Cemented Open). Bore thru cement in valve to annulus. No pressure found in annulus. Well dead. Secure welhead. . .' w ~ UNOCALf) RKB to tbg Hog =16.5' ill TD=3805' PBTJ>aZ450' Straight Hole SRU 21-33 WD Actual NO. Depth 1. TOC Surf to 177' 2. TOC Surf to 193' 3. TOC @ Surf 4. /.... TOC-tW' to 2,110' 5i .1751' ') 6\ "Ù90;_.:>~ 7. '----2:gŠ6' TOP 2120 2194 2280 2350 2402 2766 2862 3060 BTM 2174 2262 2296 2394 2438 2770 2866 3065 Swanson River Field Well # SeD 21-33WD Actual Completion 12/20/72 13-0/4" Cmt Yes 800 sx 600 sx Cmt Top Surf. Surf 1500' CBL Casine, & Tubing Size Type Wt Grade ill Top Btm Hole 20" Conductor Surf 33' 9-%" SurfCsg 40 N-80 8.835" Surf 1,396' 7" Prod Csg 23 N 80 6.366" Surf 1374' 5-W' ~ - 4.892" 1374' 3149' Tubing cemented in cs~ wi 250sx toped wi 45 sx 3-W' Bullhead emt I 9.2 I N-80 I 2.992 I Surf I 2108 8-0/4" r Surf Surf ,¡ 25 bbls ITEM DETAIL Coments Lubricated 5 bbls of 15.8 ppg "0" cement into 7" x 9-5/8" annulus Top job perfonned at 193' w/45 sacks cement to surface CT CO to fish@ 1751'. Bullhead 25 bbls of 15.8 ppg of "0" Neat Cemented tubing with -250 sacks cement Unknown Fish Retainer with 140' ofeement Two retainers Date 9/7/99 7/9/72 8/25199 7/7/72 7/6/72 PERFORATION DATA ZONE SPF DATE COMMENTS 4.5 5/64 4.5 5/64 4.5 5/64 4.5 5/64 4.5 5/64 4.5 5/62 4.5 5/62 4.5 5/62 REVISED: 3/1912004 Abandoned Abandoned Abandoned DRAWN BY: TCB ~ STATE OF ALASKA ~ ALA--. .A OIL AND GAS CONSERVATION COMf'v",;jSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: ~ :- Abandon ~ Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99516 7. KB Elevation (ft): 1. Type of Request: 206' 8. Property Designation: Swanson River Unit 11. Total Depth MD (ft): 3,805' Casing Structural Total Depth TVD (ft): 3,805' Length Conductor Surface 33' 1,396' 1,374' 1775' Production Production Liner Perforation Depth MD (ft): 2,120' - 3,065' Packers and SSSV Type: nla Perforate U Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: ~ 62 0000 0 ,/' /62LlJ:IV 6. API Number: /' 50-133-10162-00 Suspend U Repairwell 0 Pull Tubing 0 Development Stratigraphic 0 0 Exploratory 0 Service 0 9. Well Name and Number: \N'~rr I I It L.VL ~ pr5 i-/6/1-- Annular Dispos. U Other 0 10. Field/Pools(s): SRU 21-33WD /' Swanson RiverlSterling PRESENT WELL CONDITION SUMMARY Effective De~th MD (ft): /Effective Dep~h TVD (ft): Size MD TVD PIU9S (measured): 2,450' Burst /JUnk (measured): 1,751' Collapse 20' 33' 33' 9-5/8" 1,396' 1,396' 916 psi 3,090 psi 7" 1374 1374 532 psi 3,830 psi 5-1/2" 3,149' 3,149' 397 psi 6,280 psi / Perforation Depth TVD (ft): 2,120' - 3,065' TUbing Size: TUbing Grade: 3-1/2" 9.2#, N-80 Packers and SSSV MD (ft): nla 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Philip J. Krueger Title Drilling Manager Phone Date - COMMISSION USE ONLY Signature ytc..'./ ~í> - 5/3/2004 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas 0 Plugged WAG D GINJ D WINJ Date: Contact TUbing MD (ft): 2,180' 0 Service 0 0 Abandoned 0 D WDSPL D Steve Tyler 907-263-7649 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: JOy.f () Plug Integrity D BOP Test 0 Location Clearance [!( RECEIVED RECEIvr- " ')nnll APR - 72004 Mechanical Integrity Test 0 Other: fllllSBFl APR 1 ~ zoo~ Form 10-403 Revised 12/2003 Alaska Oil & ba.. ';/'1." Anchor ¡;¡ BY ORDER OF COMMISSIONER THE COMMISSION -.. r- INSTRUCTIONS ON REVERSE L) t,. , c, . " . , i¡ Daœ ø g!,¥ "'\ I Submit iZup:ate . - r-'\ SCU 21-33WD Procedure 3/31/04 MIRU CTU, NU to WH, PT BOPE & CT. SDFN RI Drill out cmt to 1500'. POOH. SDFN RD CTU. MllSpot and RU Eline. Test BOPE's RIH Peforate Zone SDFN RD Eline Unit. Package for Demobe RU cementers. Pump 100 sx of G neat wI GasBlock. RD Cementers SDFN Utilize backhoe to dig 8' deep x 6' x 6' trench around well. SDFN Finish digging trench. Support same. SDFN Utilize crane & csg cutters. Cut tubulars off 5' below ground level SDFN Finish csg cut off's SDFN Weld marker plate on conductor. Back fill hole. r"\ RKB to tbg Hog =16.5' TD= 3805' PBTD= 2450' Straight Hole SRU 21-33 WD Actual Swanson River Field Well # SCD 21-33WD Actual Completion 12120/72 C a sing & Tub i n g Type Wt Grade ID Top Btm Hole Conductor Surf 33' SurfCsg 40 N-80 8.835" Surf 1,396' Prod Csg ~ N-80 6.366" Surf 1374' 5-v," 17 4.892" 1374' 3149' Tubing cemented in cs~ wI 250sx toped wI 45 sx 3-y," Bul1head cmt I 9.2 I N-80 I 2.992 I Surf I 2108 Size 20" 9-%" NO. Depth 1. TOC Surf to 177' 2. TOCSurfto193' 3. TOC @ Surf 4. TOC 193' t02,110' 5. 1,751' 6. 2,590' 7. 2,886' TOP 2120 2194 2280 2350 2402 2766 2862 3060 Date 917199 7/9/72 8/25/99 7/7/72 7/6/72 BTM 2174 2262 2296 2394 2438 2770 2866 3065 ITEM DETAIL Cmt Cmt Top Yes Surf. 800 sx Surf 600 sx 1500' CBl Surf 25 bbls Surf 13-%" 8_3;'" Cornents Lubricated 5 bbls of 15.8 ppg "G" cement into T' x 9-5/8" annulus Top job performed at 193' wi 45 sacks cement to surface CT CO to fish @ 1751 '. Bul1head 25 bbls of 15.8 ppg of"G" Neat Cemented tubing with 250 sacks cement Unknown Fish Retainer with 140' of cement Two retainers PERFORATION DATA ZONE SPF DATE COMMENTS 4.5 5/64 4.5 5/64 4.5 5/64 4.5 5/64 4.5 5/64 4.5 5/62 4.5 5/62 4.5 5/62 Abandoned Abandoned Abandoned REVISED: 3/31/2004 DRA WN BY: TCB / / RKB to tbg Hog =16.5' TD=3805' PBTD=2450' Straight Hole SRU 21-33 WD Proposed Swanson River Field Well # SCD 21-33WD Proposed Completion Cas & T u bi n g Top Btm Hole Cmt Yes 800 sx 600 sx Size Type 20" Conductor 9-W' SurfCs~ 40 N-80 8.835" T' Prod Csg 23 N-80 6.366" 5-y," 17 4.892" 1374' Tubing cemented i.n cs~ wI 250sx toped wI 45 sx 3-Y2" Bul1head cmt I 9.2 I N-80 I 2.992 I Wt Grade 13-%" 3149' 8-%" I 2108 25 bbls ITEM DETAIL ,NO. 1. 2. 3. 4. Depth 1350' to 1360' 1450' to 1460' 1350' to 1460' 16.5' to 22.5' Dejails Cmt Sqz holes Cmt Sqz holes 100 sx of"G" Neat wi GasBlock Csg strings cut 3' below original ground level wi abandonment plate welded on conductor. Then back fil1ed to pad level. Spotlfil1 cement in tbg. 5. 24.5' to 1500' . Proposed Procedure RU CTU. DriB cmt in tbg to 1500'. POOH. RD. /" RU Eline Rl perfsqz holes @ 1450' - 1460' and 1350' - 1360'. POOH RD. "".,P" Establish injection rates and pressures. Pump/s{~'-;~~ of cement around 9-5/8" shoe. Utilize backhoe to dig 8' deep x 6' x 6' hole around well. Tap 20" conductor to check for gas. RU OD csg cutter. Cut conductor 3' below original ground level. . . . . . Repeat same on 9-5/8",7" and 3-1/2" tbg. Top off with cement as needed Weld on abandonment plate. Take GPS reading. Back fill hole to pad level. . SPF 4.5 4.5 4.5 4.5 4.5 4.5 4.5 4.5 2120 2194 2280 2350 2402 2766 2862 3060 2174 2262 2296 2394 2438 2770 2866 3065 Abandoned Abandoned Abandoned REVISED: 3/31/2004 Cmt Top Surf. of"" Surf 1500' CBl Surf Surf DRAWN BY: TCB STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 [J-~OCAL , SWA_~SON RI~"ER FIELD -ONIT 051994 MARCH 2002 Name of Operator Field and Pool Month and Year of Injection i. 2. 3. 4. 5.~_ 6. TUBING PRESSURE CASING PRESSURE DAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION WELL APl NUMBER u~ FIELD DAYS 7. 8. 9. 10. 1~. i2. 113. 14. n & POOL ~ IN MAX AVERAGE MAX AVERAGE LIQUID GAS LIQUID GAS NO 50- ~ CODE ~ OPER PSlG PSIG PSIG PSIG (BBL) (MCF) (BBL) (MCF) iBRO 21-33~ 133-10162-00 5 7?2036 8 0 0 0 0 0 0 0 0 0 SI~O 31-33WD 133-20336-00 5 7720.36 9 31 1,3.00 945 0 0 3,440 0 106,629 0 SRO 32-33WD 133-20337-00 5 772036 9 31 800 721 840 '/99 3,73.0 0 3.3.5,015 0 R :.CEIVE APR 1 ? ~OOi A~ )i~&~Cmm. Cm~ ~ I hereby certify that the foregoing is true and correct to the best of my knowledge 15. Title ACCT. SUPERVISOR Date.12-APR-2002 TOTAL 221,644 o Form i0-406 Rev 07/27199 SCANNEC I~AR t 0 2DD3 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 UNOCAL SWANSON RIVER FIELD -UNIT 051994 FEBRUARY 2002 Name of Operator Field and Pool Month and Year of Injection 1. 2. 3. 4. 5.c- 6. TUBING PRESSURE CASING PRESSURE DAILY AVERAGE INJECTION ~ TOTAL MONTHLY INJECTION WELL APINUMBER ., FIELD.~ DAYS 7. 8. 9. 10. 11. t2. 13. 14. - & POOL ~ IN MAX AVERAGE MAX AVERAGE LIQUID GAS LIQUID GAS NO 50- ~ CODE 2 OPER PSIG PSIG PSIG PSIG (BBL) (MCF) (BBL) (MCF) SRU 21-33WD 133-10162-00 5 772036 8 0 0 0 0 0 0 0 0 0 SRU 31-33WD 133-20336-00 5 772036 9 28 1,000 924 0 0 3,289 0 92,091 0 SRO 32-33WD 133-20337-00 5 772036 9 28 760 712 900 787 3,207 0 89,802 0 I hereby certif)rthat the foregoing is true and correct to the best of my knowledge 15. Signed /~/~~ ~J~//~) Title ACCT. SUPERVISOR Date. 12-MAR- 2002 TOTAL 181,893 0 Form 10-406 Rev 07~27~99 ~CANNE~ [~R ~ 0 2003 Submit in Duplicate UNOCAL Swanson River Unit Well No. 21-33 W.D. Abandonment Operations Summary July 17, 1999 Attempt to inject down tubing. Pressured up to 1,750 psi. with no bleed off. August 21, 1999 RU 1-3/4" Coil. Clean out tubing. Found top of wireline fish at 1,752'. Unable to push down hole. Establish injection rate of 2.2bpm @ 1,752 psi. August 25, 1999 RU Dowell to cement tubing. Bullhead 25 bbls 15.8ppg Class G cement slurry at 2bpm/1,200 psi. Line up to pump into 9-5/8" surface x 7" production casing. Attempt to establish injection. Pumped 1.05 bbls. Pressured up to 1,550 psi. Bled to 1,305 psi in 10 min. Pressure up to 2,066 psi. Bled to 1,817 psi. Suspend operations. UNOCAL Swanson River Unit Well No. 21-33 W.D. Abandonment 9/3/99 Well SRU 21-33 WD 9-5/8" Surface x 7" Production Casing will not take fluid at an appreciable rate to allow for bullheading of cement into the annulus. Contingency: 1. Displace fluid in annulus with Nitrogen. 2. Shoot fluid level in annulus to verify that fluid level is below 150'. . Pump cement in annulus valve while bleeding gas from opposing annulus valve. Volume required to fill 150' feet in annulus - 4.23 bbls. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL Dan Williamson Drilling Manager Wednesday, July 28, 1999 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Re: Blair Wondzell Form 10-403 Swanson River Unit Well 21-33 WD Abandonment Dear Mr. Wondzell, On July 18, 1998, an attempt to establish injection down the tubing of SRU 21-33WD was made. The tubing was pressured to 1,750 psi with no bleedoff. The original intent had been to abandon the well by bullheading cement down the tubing. Since the tubing is obstructed the plan has been amended to include clean out the tubing with coil tubing until communication is established with the perfs, then to abandon as per the original procedure. There may be a wireline fish in the tubing string. If this fish is encountered, the amended plan has a contingencey for the recovery of the fish using slickline. Please find the enclosed amendment to the procedure for inclusion to the 10-403 previously submitted. If you have any questions, please contact Tim Brandenburg at 263-7657. Sincerely, Dan Williamson Drilling Manager RECEIVED .;,.,,_ o 0 1999 Alaska Oil & Gas Co~, Commissior) UNOCAL ) Swanson River Unit Well No. 21-33 WD Coil Tubing Clean Out Procedure I. MIRU 1. Mobilize 1-3/4" Coil to Swanson River. 2. RU injector, BOP's, and lubricator. . Pressure test all surface pressure lines to 4,500 psi. Fill coil with lease water. Function and pressure test BOP's as per Unocal Alaska specs. II. Clean Out Tubing . Measure up Grapple Type Coil Connector; pull test to 25K. 'Blue Lock Tite' all connections. . . - 2-1/4" Grapple type coil connector. - 2-1/8" Dual Check Valves - 2-1/8" Hydraulic Disconnect - 2-1/8" Motor - 2.70" Drag Bit I CEtVED ~U~ ~ 0 t.cj~,~ Stab injector. ~asl~a 0il & Gas Cons. C0mmissio~; Anchorage RIH cleaning out tubing to top of fish, T.D. or until communication is established. Note: There may be a wireline toolstring fish at 1,600' or deeper. If the fish should be encountered see contingency below. 7. Rig down coiled tubing. 8. Pump abandonment per procedure. Contingency for recovery of Wireline Toolstring Fish A. If milling progress is thwarted, POOH. Check for indications of milling on junk. B. RU slickline. C. RIH with Impression Block and attempt to determine the nature on the top of fish. The decision of what fishing assembly to run will need to be made based on the information gained from the I.B. run. D. Make fishing attempts with slickline. If the fish can be latched but not pulled with slickline, attempt to recover with coiled tubing. Unocal Corporation ~ P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL Dan Williamson Drilling Manager Friday, June 25, 1999 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn' Re: Commissioner Robed N. Christensen Form 10-403 Swanson River Unit Well 21-33 WD Abandonment Commissioner Christensen- Please find enclosed Form 10-403 for the abandonment of SRU 21-33 Water Disposal Well. In 1972 the well was converted to a monobore completion by cementing tubing in place thus eliminating any tubing by casing annulus. To abandon the well, Unocal intends to bullhead cement down the tubing into the perforations. A volume sufficent to fill the casing and the tubing to surface will be pumped to cement the well from effective T.D. to surface. Additionally, cement will be pumped down the Surface x Production (9-5/8" x 7") annulus. If you have any questions, please contact Tim Brandenburg at 263-7657. Sincerely, Dan Williamson Drilling Manager ~°/lo/'age' coee/s,/.o~ STATE OF ALASKA '-" ALASKA AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 206' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: X Swanson River Unit 4. Location of well at surface 8. Well number 560' FSL, 2,110' FEL, Sec. 33, T8N, R9W, SM SRU 21-33 WD At top of productive interval 9. Permit number Same 62-0002-0 At effective depth 10. APl number Same 50- 133-10162-00 At total depth 11. Field/Pool Same Swnason River Field / Sterling 12. Present well condition summary Total depth: measured 3,805' feet Plugs (measured) 2,889' D.C. Retainer true vertical 3,805' feet 2,886' Mod. "K" Bridge Plug 2,590' Cement Retainer w/140' Cement Effective depth: measured 2,590' feet Junk (measured) 1,600' MD true vertical 2,590' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 33' 20" 33' 33' Surface 1,396' 9-5~8" 800 sx 1,396' 1,396' Intermediate Production 3,149' 7" & 5-1/2" 600 sx 3,149' 3,149' Tubing 2,108' 3-112" 295 sx 2,108' 2,108' Perforation depth: measured 2,120'-2,174'; 2,149'-2,296'; 2,350'-2,394'; 2,402'-2,438' RECEIVED Abandoned 2,766'-2,770', 2,862'-2,866', 3,060'-3,065' true vertical Same Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80, EUE 8rd @ 2,108'; Tubing is Cemented to surface A~a~k;a 0il & Gas Cons. C0mmissi0r~ Packers and SSSV (type and measured depth) Anchorage 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 7/15/1999 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water Disposal Well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~~)V~/~ Dan Williamson Title: Drilling Manager Date: (~/~-~,~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity ~ BOP Test ~ Location clearance~ Mechanical Integrity Test Subsequent form required 10- ~'O"'~ ORIGINAL SIGNED'BY Approved by order of the Commissioner Robert N. C'hdstenson ..e~'~ Form 10-403 Rev 06/15/88 ~ SUBMIT IN TRIPLICATE UNOC,AL Swanson River Unit Well No. 21-33 W.D. Abandonment Preliminary Procedure Pump Abandonment Plug 1. Spot and rig up Dowell Cementing equipment at SRU 21-33 W. D. 2. Rig up hard lines to tree cap flange and to 7"x 9-5/8" annulus valve on casing spool. Pressure test surface line to 3,000 psi. 3. Batch mix cement abandonment plug· Capacities 5-1/2", 17# (4.892" I.D.) 3-1/2", 9.3# (2.992" I.D) 7"x 9-5/8" .0232 bbls/ft .0087 bbls/ft .0282 bbls/ft · 1305 cf/ft .04883 cf/ft · 1585 cf/ft Pump Schedule - 25 bbls cement slurry in tubing - 40 bbls cement slurry in 7" x 9-5/8" annulus 4. Pump 25 bbls cement slurry down Tubing. Shut in Master Valve. 5. Pump 40 bbls cement down 7" x 9-5/8" annulus. Shut in annulus valve. 6. Rig down Dowell equipment. Perform Plug Integrity Test , Perform Integrity test of plug by pressuring the tubing to 1,500 psi. Hold for 30 min. UNOCAL RKB to TBG Head = 16.5' A SIZE WT Swansoa River Field Well # SCU 21-33WD Proposed Abandonment CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 20" 9-5/8" 40# 7" 23# 5-1/2" 17# Surf 33' N-80 S8R Surf 1,396' N-80 BT Surf 1,374' N-80 L8R 1,374' 3,149' Tubing/Cmtd Liner: 3-1/2" 9.2 N-80 NO. Depth 1 193' 2 2,108' 3 1,600' 4 2,590' 5 2,886' BTC Surf 2,108' ITEM DETAIL Top job performed at 193' w/45 sacks cement to surface Cemented tubing with 250 sacks cement Unknown Fish Retainer with 140' of cement Two retainers ABANDONMENT DETAIL A 25 bbls. Cement bullheaded into tubing 40 bbls. Cement bullheaded into annulus Fill tagged at 2,101' 4/7/89 PBTD = 2450', TD = 3805' Straight Hole SRU 21-33 WD Proposed. DOC TOP 2120 2194 2280 2350 2402 2766 2862 3060 PERFORATION DATA BTM ZONE SPF DATE COMMENTS 2174 4.5 5/64 2262 4.5 5/64 2296 4.5 5/64 2394 4.5 5/64 2438 4.5 5/64 2770 4.5 5/62 2866 4.5 5/62 3065 4.5 5/62 Abandoned Abandoned Abandoned REVISED: 6/24/99 DRAWN BY: TAB Form ~160-5 (JUNE 1990) UNITED ,-~TES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WEllS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use 'APPMCATION FOR PERMIT-' for such proposals SUBMIT IN TRIFLICA TE 1. Type of Well Oil Gas [~ Well [~ Well [-] Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- 14 Wells Soldotna Creek Unit -- 7 Wells FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Seriel No. 6. If Indian, Niottee or Tribe Name 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8, Well Name and No. 9. APl Well No. 10. Field and Po<N, or Exploratory Area Swanson River Field 11. County or Padsh, State Kenai, Alaska TYPE OF SUBMISSION Notice of Intent [] Subsequent Report Final Abandonment Soldotna Creek Unit Swanson River Unit ~. j¢j SCU 21-8 ~ll SCU 34-9 ~:~') ~SRU 212-10 (Oi" ~SCU34-8 ~'~SCU41B-9 (,eO-~RU12-15 (e,,~.' i SCU 243-8~ ~U 14-3400-;~ ~SRU 14-15 ~ ~.,.-.~ O SRU °~ i-cI~SCU 13-9 [,.t~,~ . 41A-15 'd-107" I GO_t? SRU23-22 * High GOR well that may be produced intermittently ~ Change of Plans ~ New Construction [-] Non-Routine Fracturing I'-] Water Shut-Off r'-] Conversion to Injection ~ Dispose Water (Note: Report results o~ multiple conmpletion on Well Completion or ~mpletio~ Refxxt and Log form.) SRU23-27 SRU331-27OO I~at lS r::tVl O SRU 34-28 SRU 43-28 (pi-' ;~_ SRU 21-33W0 ~,~,-,~, APR 0 1 3996 SRU 24-33 ~ ~- "~ 14. I hereby cet'tify tt~i~ the foregoing is true and correct. t ...... //! I ' (This spa~e for Federal and'Sa~L.t~frme use) Dennis L. Groboske Petroleum Engineer Date 3/29/96 Approved by Conditions of approval, if any: Date T'~ie 18 U.S.C. SeclJon 1001, makes ira crime for any pemon knowingly and willfully to make to any deparlznent or agency of the United $late~ any talse, fictitious *See Instruction on Reverse Side Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 21 Wells Twelve Month Period: April 1, 1996 to March 31, 1997 Shut-in Wells under Evaluation for Rate Potential P&A Shallow Gas Potential and 'Hemlock Only' P&A Shut-in Wells during Field Blowdown Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 34-8 SCU 243-8 SCU 13-9 SCU 41B-9 SRU 21-33WD SRU 34-28 SRU 43-28 SRU 212-10 SRU 212-27 SRU 12-15 SRU 41A-15 SRU 23-27 SRU 331-27 SCU 14-34 7 Wells 2 Wells 5 Wells '*..~. h GOR well that may be produced intermittently - SCU 21-8 SCU 34-9' 2 Wells SRU 14-15 SRU 43A-15 SRU 14-22 SRU 23-22 SRU 24-33 5 Wells ATTACHMENT 2 SWANSON RIVER FIELD Wells with Temporarily Abandoned Status Change Removed from 1996 Temporarily Abandoned Status · SCU 34-4 Recompleted in Tyonek G1 and G2 zones · SCU 43A-4 Recompleted in Tyonek G1 and G2 zones · SCU 13-4 Workover to remove tubing fish. Currently producing from Hemlock · SCU 23B-3 Returned to full time production · SCU 314-3 Returned to full time production · SCU 43-9 Returned to full time production · SCU 23-15 Returned to full time production Additions to 1996 Temporar!ly Abandoned Status · SCU 13-9 Recompleted in Tyonek G2 zone Iow rate oil producer. APR 01 ~6 Um~cal North Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region March 31, 1994 Re: Mr. Joseph A. Dygas .... . Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 · 1994 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment I lists the proposed TA wells using the same-format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SRU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - '1 1994 Alaska Oil & Gas Cons. Commission Anchorage Mr. Joseph A. Dygas March 31, 1994 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. if you have any questions concerning this Sundry Notice, please call me at 263-7816. DLG:dma 7~~.Dennis L.' ~~rd~ske Petroleum Engineer Attachment cc: L.R. Dartez, Marathon Oil Company O. W. Johnston, Chairman, AOGCC Form 3160- 5 (JUNE 1990) UNITE ATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use 'APPMCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas I~ Well I~ Well r-I Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- - 19 wells Soldotna Creek Unit --- 11 wells FORM APPROVED Budget Bureau No. 1004-0135 Expirea: Mm'eh 31r 1993 5. Lea~e Deelgnation and ,%dal No. 6. If Indian, AJlottee or Tribe Name , o. 7. If Unit or CA, Agreement Deeignation Swanson River/ Soldotna Creek Units 8. Well Name and No. g. APl Well No. 10. Reid and Pool, or Exploratory Area Swanson River Field 11. County or Padsh, State Kenal, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION !~ Notice'of Intent r-i Subsequent Repo~ I-'1 Final Abandonment 1"'1 Abandonment r-1 Recompletion r-] Plugging Back r-! casing Repair I-1 Altering Casing [] Other Temporarily Abandon I-'] Change of Plans I'-] New Construction I-'1 Non-Routine Fracturing I'-1 Water Shut-Off I-'1 Conversion to Injection r-I Dispose Water Compiel~on or ~ Report and Log lmm.) As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1994 to March 31, 1995: Soldotna Creek Unit ~ ! SCU 13-4 SCU 341-8 <J I ': <JI * SCU 21A-4 SCU 13-9 " ~1 SCU 34-4 * SCU 34-9 I-elL., 5' 1 * SCU 43A-4 SCU 14-34 % I / -o/Z..* SCU 21-8 *High GOR wells that may be produced Intermittently. Swanson River Unit ~'~ SRU 212-10 .,-"SI:IU 14-22 $ I SRU 43-28 %~s~o ,~=lU 14-15//-:/~uRU 12-15 ~ I SRU 14A-33 ~/ SRU 23-15 ~1 SRU 23-22~'uSpSRU 24-33 ~us?SRU 34-15 ~1 SRU 23-27. '' SRU 32-33WD % I. SRU 41A-15Jr~SRU 212-27 SRU 21-33WD ~5~ SRU 43A-15G~ SRU 331-27 ~ uSf SRU 432-15 ~t SRU 34-28 (This space for Federal and ! te l e use) Apfxoved by TrUe Date Concitions o~ appro~ml, if any: RECEIVED APR - 1 1994 r~e 18 U.S.C. Section 1001, makes ita crime for any pemon knowingly and willfully to make to any departme~ ~ agency o~ the Unaed sa~f.~l,,~ns. C0mmissior, fraudulent statements or representations as to any matter within ils jurbcB=tion. *See Instruction on Reverse Side R, Ghorage Attachment No, I Swanson River Field Proposed Temporarily Abandoned Wells: Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for '1 Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A ']5-tSSCU 13-4 ux~--l~ SRU 212-10 ~-~[oSCU 34-4 (~-o5 SRU 23-15 [e~-3Z, SCU 341-8 ~.-~o SRU 41A-15 ~-'l SRU 34-28 (az.-¥{ SRU 14-22 ~ ~-~ SRU 43-28 eo-~.~ SRU 23-22 ~t0~t~ SRU 32-33WD al-55SRU 212-27 (~--b~ SCU 243-8 ~o-lqB SRU 331-27 (aT_- Z SRU 21-33WDa0-ZZ. SRU 12-15 b0-~&SCU 1 4-34 ~0-q~/SRU 23-27 SRU 14A-33 Shut-in Wells during Field Blowdown Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned b~-t,t SCU 21-8' CO-I~t, SRU 1 4-15 ~\~5 SCU 13-9 (~0-u~[ SRU 34-15 ~-~L~ SCU o34-9' SRU 43A- 15 ~q--~DSCU 23B-3' %°t-bb SRU 432-15 -~u<--5~ SCU 43A-4' -~-L-o~SRU 24-33 SCU 21A-4' 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells *High GOR wells that may be produced intermittently RECEIVED APR - 1 1994 Alaska Oil & Gas Cons. Commission Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Temporarily Abandoned Status., · SCU 12-15' Shut-in gas lift producer with casing communication. Evaluate for repair or abandonment. · SCU 21-33WD' Shut-in due to wireline fish in tubing. Workover candidate. Removed from 1994 Temporarily Abandoned Status · · SRU 24A-9: · SRU 21-3: · SRU 33-5: Returned to full time production after workover. Returned to full time production due commencement of Blowdown in field. Returned to full time production after workover. tO RECEIVED aPR - 1 1994 ~l~s~a uti & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA ~AND GAS CONSERVATION COI~'""~SION APPLICA, .ON FOR SUNDRY .tOVALS 1. Type of request: Abandon Stmpend m Operatlom shutdown Fie-enter euepended ~ Alter ea~Ingm Repak well Plugging ~ Time exlenelon Stimulate Change approved program __ Pull'tubing __ Valance __ Perforate __ OtherX_ 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 1 g6~47 Anchorage, Alaska 99619-6247 4. Location of well at sLrface 560' FNL, 2110' FWL, Sec. 33, TSN, R9W, SM At top of productive Interval Stlalght Hole At effective depth Straight Hole At total deplh . Straight Hole 5. Type of Well: Oev.k3pmem __ am~gr, ph~ SenSe X_ RE([EIV£D J u L - 8 199: Alaska Oil & Gas Cons. comtll'tss'to~ Anchorage 6. Datum elevation (DF or KB) 206' KB 7. Unit or Property name $'wanson RIv~ Unit 8. Well number SRU 21-33WD g. Permit number 10. APl number 50-133-10162-0 11. Field/Pool Swanson River/Sterling feet 12. Present well condition summary Total deplh: meas[xed 3805 true vertical 3805 Effective depth: measa'ed 2450 true vertical 2450 feet Plugs (measured) feet feet Junk (measured) feet 2450-2590, 2886-21~89, 3100-3162 ORIGINAL cas~g Leng~ Structural Conductor 33' Surface 1396' Intermediate Production 3805' Liner Perforation depth: Size ~mel Measured depth 20" Driven 33' 33' 9-5/8" 800ex 1396' 1396' 7' x 5-1/4" 600ex 3805' 3805' meas[xed 2120-2174, 2194-2262, 2280-~, 2350-2394, 2402-2438 true vertical 2120-2174, 2194-2262, 2280-2296, 2350-2394, 2402-2438 Tubing (size, grade, and measured depth) 3-1/2", N-aO, 9.2# (~ 2108' (tubing Is c, emenled to stzfac, e) Packers and SSSV (type and measured deplh) 13. Attachments Description summary of proposal w Detailed operatiorm programX__ BOP sketm _ 14. Estimated date for commencing operation !15. Statue of well classification aa: 16. If proposal was verbally approved / ~ ~ ~ ~ ~~ed Name of approver Date approved Service X (water disposal) 17. I herebyir~ehlifylhat tl~gqllng~ t_Oje/.~l, oorrect to the best of my knowledge. ~/ ' ' FOR COMMISSION USE ONLY conditions ol approval: NoUIy commission so represenlalive may witness Plug Integrity _ BOP Test__ Location clearance _ Mechanical Integrity Test_ Subsequent form requi'ed 10- qO Lf Original Signed By Appr .oved bY. theorder of the Commlssion David W. Johnston lApp royal No. ~pproved Copy Returned Commissioner Date ~ Form 10-403 Rev 06/15/88 SUBMIT Well SRU 21-33WD Mechanical Integrity Test July, 1993 Determine mechanical integrity of the well with oxygen activation 1o8 and verify that the well is not affecting the fresh water aquifer. Procedur~ Prior to lo_s~_'ng 1. RU slick line and tag fill with 2.8" gauge ring. 2. Notify AOC~C and BLM 24 hours prior to logging. Mechanical Inte?i _tv Test .6~11~_ : Ox~. _ en .4 ctivation Log_ Establish a stabilized injection rate into the well with a 550 psi injection pressure. 24 hours should be sufficient time for stabilization. Record injection rates and pressures during the survey. . RU E-line and pressure test lubricator. RIH w/GR/CCL/OA log. The O/A log should be configured to detect upward flow. 3. Tie in. 4. Cheek for upward flow at the following stations: Depth Reason 2098' 2060' 1760' 1715' 1620' 1470' 1265' End of tubing Above last logged injection sand In deepest confining layer Above deepest confining layer Potential USDW* Potential USDW* Potential USDW* * Underground source of drinking water. RECEIVED J U L - 8 1995 Alaska Oil & Gas Cons. Commission Anchorage . Make further stops to check for flow as deemed appropriate by on site Unocal representative. 6. POOH WELL NO. Z'.~'3- 2 7 SECTION MO. Z7 TRACT MO. ~ PROPOSED ~ PREL 1141NARY ~ F~ M~L WELL SURVEY Pro-312 COUNTY OF <::~¢/~,?o CiTY OF TOim~I~IP /J' ~ RANGE LOT MO. FIELD .~ 14. O.B. & 14. ELEVATIOM: 6ROUMO ~ ~. (~ CONCRETE 14AT DERRIC[ ,., & LTE~I ATE OR SU EVE YED LOC& T I Ol LOCAT 1 041 DES I ~JIAT I Ol LOCAT I O# COOEO I I ATE$ NOV E · , · NORTH ' . SKETCH OR RE14ARK$ , la _ga o/f !OV 1o,,92 '- .... ~ Gas 6u,..,,.s' AnChorage ~"°mmis~ion STATIOI IEAIIIt OlITUC[ SINE COlliE NONTN' ~UTN [AlT WEST _ C.C. DiV. ENG,E. FILE ~lll'l'll II I1.1.1. · DATE 7-..//,~/~/$ DATE klA INT. SUPT. D&TE PR0.312 (25C~;CD. I- 58) ARCO Alaska, Inc. Post Office Box !00360 Anchorage, Aiaska 995 i 9-0350 Telephone 907 263 4724 T S~ewart McCor~ . Engineering Manaqer Cook Inlet/New May 9, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Sundry ApprOval: Pump-In-Temperature Surveys SRU 21-33WD & SRU 31-33WD Swanson River Field Dear Mr. Chatterton: ARCO Alaska, Inc. requests approval to perform the attached pump-in-temperature surveys on SRU 21-33WD and on SRU 31-33WD to prove that current injection practices are not resulting in fractures that extend through confining zones enabling disposal water injectant to enter any fresh water strata. Such testing is warranted as recent data shows these wells to be injecting over parting pressure. The recommended surveys will make multiple temperature passes from 1200' to PBTD after injecting hot lease water into each well. The resulting data will define where the hot fluid travels when injection is over parting pressure. If there are any questions pertaining to this matter, please contact Carol Baker at 263-4643. Sincerely, T. S. MCCorkle TSM:CMB:ch:0015 Attachment RECEIVED JAN - 2 ~)92 Alaska 0il & Gas Cons. ~;ommission Anchorage CC: G. A. Graham A. 1~ Kukla UNOCAL CorporaUon Marathon Oil Company ARCO Alaska, Inc. ~s a $uDsldiary of AtlanticRict~helclCompany AR ~3 -,~ ',~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdOwn __ Re-enter suspended well __ Alter casing_ Repair we!! __ Plugging_ Time extension_ Stimulate_ Pump- i n Change acproved program __ Pull tubing __ Variance __ Perforate __ Other % Tamp. s u r vey 2. Name of Ooerator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, I nc. Development__ 206' KB +eet Exploratory __ 3. Aadress Stratigraphic __ 7. Unit or Property name P. O. Box 10036[,,~A'~'"~'[_,j].,.,~_ '1 .A.% r~c~m_]t,,_[ _ .~ -~ Service_.~ Swanson River Unit 4. Location of well at surface ..... "'"'"':¥~i,.., - 8. Well number 560' FNL, 2110' FWL, Sec. , Rgb/ SRU 21-33WD At top of productive interva -- ';¢ EC/IVED 9. Permit number Straight Hole .L'/ "8 At effective depth I~fo OOOK INLET/NEW YENTURE$ SRF ~ ,~ [~ ,/ .,. 10, APl number v.,fi, .]. } .~r].:.':;~ 50--133-10167-00 At total depth Gas Cons. Ccmmiss[0n 11. Field/Pool ., · i ~ . m ~' .?,4&~,~4~'~,(~ _~, , , Swanson River/Sterlin~ 12. Present well condition summary Total depth: measured 3805 ' feet Plugs(measured) 2450 - 2590' true vertical 3805 ' feet 2886 - 2889' 3100 - 3162' Effective depth: measured 2450 ' feet Junk (measured) true vertical feet 2617 - 2866 ' 2450' Casing Length Size Cemented Measured depth True vertical depth Conductor 33 ~ 20" to surface 0-33' 0-33 Surface 1396' 9-5/8" yes 0-1396' 0-1396' Production 3805 ' 7" X 5- 1/4" yes 0-3805 ' 0-3805 ' ~ (combination casing) Perforation depth: measured 2120 - 2174'; 2194 - 2262'; 2280 - 2296'; 2350 - 2394'; 2402 - 2438'. true vertical 2120 - 2174'; 2194 - 2262'; 2280 - 2296'; 2350 - 2394'; 2402 - 2438'. Tubing (size. grade, and measured depth) 3-1/2", N-80, 9.2# e 2108~ ~D; tbg is cemented to surface. Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal __ Detailed operations program X BOP sketch _~ RECEIVED 14. Estimated date for commencing operation 15. Status of well classification as: May, 1989 16. If proposal Was verbally approved Oil __ Gas __SuspeJ del - 2 Name of approver Date approved Service Water D i 5/~J~l0il & Gas Cons, Commissioa 17. I hereby certify th at the foregoing is true and correct to the best of my knowledge. · ......... Signed ~,~--/.-¢.~~ TitleCOok Inlet Engineering Mgr. Date _~'/c]/~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness i Approval No. Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- /,'/'; Commissioner Date ~-"-- Approved by order of the Commissioner "" Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ~.~'"~. ~ 'e STATE OF ALASKA ~ AI.A,~KA OIL AND GAS CONSERVATION COMMI$51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ~ ' Perf;3rate'w Pump- i n Pull tubing _... Alter casing _.... Repair well __. Pull tubing m Other ~ 2. Name of Operator 5.'~ype of Well: ARCO A I aska, I nc. Development ~ Exploratory ~ 3. Address Stratigraphic ~ P. O. Box 100360 Anchorage, AK 99510 Service)~. 4. Location of well at .sudace 560' FNL, 2110' At-top of productive interval Straight hole At effective depth FWL, Sec. 33, T8N, R9W, SB&M At total depth 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical ,,, Temperature Survey 6. l~atum elevation (DF or KB) .... 206 ' KB 7. Unit or Property name Swanson River Unit 8. Well number SRU 21-33WD 9. 'l~ermit number/approval number 10. APInumber 50-- 133-1016~-00 11. Field'/Pool Swanson River/Sterling ! 3805 feet Plugs(measured) 2450-2590' 3805 feet 2886-2889' 3100-3162' feel Junk(measured) 2450 feet 2617-2866' 2450 Casing Length Conductor 33 ' Sudace 1,396 ' Production 3, 1 ~J9 ' Size Cemented Measured depth 20" to surface 0-33 ' 9-5/8" yes O- 1,396' ~2" yes 0-3,149' 7" x 5-1~ (combination casing)' True vertical depth 0-33' 0-1,396' 0-3,149' Pedor~onde~h: measured 2120-2174'; 2194-2262'; 2280-2296'; 2350-2394'; 2402-2438' true vertical 217_ 0-2174'; Tubing (size, grade, and measured dePth) 3-1/2" N-80 9 2~I 0 2108' MC',; , , · Packers and SSSV (type and measured depth) 2194-2262'; 2280-2296'; 2350-2394'; 2402-2438' 13. Stimulation or cement squeeze summary Intervals treated (measured) tubing is cemented to surface· Treatment description including volumes used and final pressure RECEIVED JAN 0 2 1992 Naska 0il & 6as Cons. Commission Anchorage feet 14. Representative Daily AveraCe Production or Injection Data OiI,Bbi Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1200 56 580 Subsequent to operation 1200 54 15. Attacl~ments 16. Status of well classification as: Copies of logs and Surveys run Daily Report of Well Operations X Oil ..._ Gas 17. I hereby certify that the foregoing is true anct correct to the best of my knowledge. Form lO-aO~ Sorvic~ T~eCook Inlet Engineering Manager 610 Wat~ Disposal Date ~.~/~ ~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Results of ~mp-In Temperature Survey of ~g~r~nson River Field Dear Mr. Chatterton: 'This is to submit the results of the pump-in temperature survey (PITS) that was performed on SRU 21-33WD on October 12, 1989. The test was done to prove that current injection practices (below parting pressure) are not resulting in fractures that extend through confining zones enabling disposal water inJectant to enter any fresh water strata. The pump-in temperature survey was obtained in accordance with the submitted sundry, as previously approved by your office. The results prove that this well is injecting up to -2070' MD, which is 370' below the legal injection cut-off depth of 1700' (see attached Survey). If you have any questions concerning this matter, please contact Stacy Strickland at 263-4914. Sincerely, T. S. McCorkle TSM:SLS:ch:0014 Attachment cc' S.W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company RECEIVED Alaska Oil & Gas Cons. Oommlssion Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlantlCRichflelclCompany AR3B--6279 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering August 14, 1991 Mr. L. Smith Alaska Off and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Revised Submittal of Subsequent Reports for SRU 21-33WD and SRU 41-33WD. Dear Mr. Smith: Please find the attached revised submittal of the Subsequent Reports on the subject wells. These reports were recently sent to your office on August 8, however, that submittal erroneously included the form used by the Bureau of Land Management in lieu of the applicable AOGCC document. We sincerely regret any inconvenience that this oversight may have caused you or your staff. The remaining information of the documentation previously submitted was accurate. Copies of the logs for the well work will be forthcoming when the final prints are available. If you require any further information in this regard, please do not hesitate to call Jim Zernell at 263-4107 Sincerely, T. Wellman TW:JTZ:czm: 0118 Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED Oil &/las Cons. C0mmisslen ~mchorage' ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO NsORIGINAL 1. Type of Request: Operation Shutdown Pull tubing . Stimulate Plugging Alter casing Repair well Perforate ~ Pull tubing Other MIT 2. Name of Operator ARCO Alaska. Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 560' FNL, 2110' FWL, Sec.33, T8N, Rgw, SB&M At top of productive interval Straight Hole At effective depth 5. Type of Well: Development Exploratory Stratigraphic Service At total depth 6. Datum elevation (DF or KB) 17g' KB feet 7. Unit or Property name Swanson River Unit 8. Well number SRU 21-33WD 9. Permit number/approval number 10. APl number 50- 133- 10162-00 11. Field/Pool Swanson River-Sterl inq 12. Present well condition summary Total Depth: measured true vertical 3,805' feet 3,805' feet Plugs (measured) 2,450-2,590', 2,886-2,889' 3, 100-3, 162' MD Effective depth: measured 2,450' feet true vertical 2,450' feet Junk (measured) 2,617-2,866' MD Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Current: Length Size Cemented Measured depth True vertical depth 33' 20" Driven 33' MD 33' TVD 1396' 9-5/8" 800 sx 1,396' MD 1,396' TVD Current: Tubing (size, grade, and measured depth) 3,1/2", N-80, 9.2~ @ 2,108' MD; tubing is cemented to surface. Packers and SSSV (type and measured depth) 3,805' 7"X 5-1/4" 600 SX 3,805' MD 3,805' TVD (combination casing) measured 2, 120'-2, 174'; 2,194'-2,262'; 2,280'-2,296'; 2,350'-2,394'; 2,402'-2,438' MD true vertical 2, 120'-2,174'; 2, 194'-2,262'; 2,280'-2,296'; 2,350'-2,394'; 2,402'-2,438' TVD RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A AUG 1 5 1991 Alaska.Oil a Gas Cons. Commissien Rnchorage 14. Prior to well operation Subsequent to operation ReDresel~tative Daily Average Production or I niection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 58O 58O Tubing Pressure 500 500 15. Attachments Copies of Logs and Surveys run~ Daily Report of Well Operations ~ 16. Status of well classification as: Oil __ Gas Suspended ~ Service .. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 Title Cook Inlet Re,cjional Engineer SUBMIT IN DUPLICATE WATER FLOW ADVISOR SRU 21-33 WD -Company Field Logging Date Processing Date Reference - ARCOALASKA INC. - SWANSON RIVER UNIT - JUNE 23, 1991 - JULY21, 1991 - 74656 Mechanical Integrity Test Water Injection Disposal Well Schlumberger Well Services Alaska Division Computing Center 500 West International Airport Road Anchorage, Alaska 99518 907/562-2654 AUG 1 2 1991 ~Anchorage ARCO ALASKA, INC. Swanson River Unit SRU 21-33 WD Production Logs 23-Jun-gl INTERPRETATION SUMMARY WATER INJECTION DISPOSAL WELL This suite of production logs was run to determine the mechanical integrity of well, SRU 21-33 WD. This well has 3 1/2 inch tubing cemented to surface inside a 5 1/2 inch liner that is tied back to a 7 inch liner inside 9 5/8 inch surface casing. The depth of the casings are: 3 1/2 ~-- 2108 feet, 5 1/2 inch --- 3149 feet, and 9 5/8 --o 1396 feet. The 5 1/2 inch casing is plugged back to 2450 feet. The 5 1/2 inch casing is perforated from 2120 to 2438 feet in five intervals. The depths of interest are: Lowest Accessible Depth* Above Top of Injection Sand In Deepest Confining Layer Above Deepest Confining Layer Deepest Potential USDW** 2098 Feet 2060 Feet 1760 Feet 1715 Feet 1620 Feet *Schlumberger depth, 6/23/91, was 2084 feet. **Underground source of drinking water. The Water Flow Log (WFL) was run to determine if any water is flowing behind the casing strings in the upward direction and potentially contaminating the underground drinking water zones. To determine this, the Water Flow Log was set at various depths in the well and the oxygen in the water surrounding the neutron generator is activated. This includes the water on the outside of the casing strings. This changes the oxygen to nitrogen, which radioactively decays back to oxygen and at the same time gives off gamma rays. If the activated water is flowing up the well, its gamma rays will be detected at gamma ray detectors spaced 1, 2, and 15 feet above the neutron generator. If the activated water is not flowing up the well, its gamma rays will not be detected by the gamma ray detectors, and therefore, no water flow will be detected. Stations reading were taken at the following depths with the wfl tool to determine if there is water flowing in the upward direction. DEPTH RESULTS 1065.0 No Water Flow 1165.0 No Water Flow 1265.0 No Water Flow 1360.0 No Water Flow 1470.0 No Water Flow 1620.0 No Water Flow 1715.0 No Water Flow 1760.0 No Water Flow 1980.0 No Water Flow 2060.0 2077.5 Detected Detected Detected Detected Detected Detected Detected Detected Detected No Water Flow Detected Water Flow Detected;Water Injection into Sand was Approved ARCO ALASKA, INC. Swanson River Unit SRL~ 21-33 WD Production Logs 23-Jun-91 No water flow was detected with the WFL Log. This was also confirmed by the temperature survey that was logged. The temperature survey was performed as follows: the SOLID RED LINE is the base temperature log before the 300 barrels of water at 46 DEGF was pumped into the well, the LONG DASHED BLUE LINE is the temperature log run immediately after injecting 300 barrels of water at 46 DEGF, the DASHED GREEN LINE is the temperature log run 2.5 hours after injection of cold water had stopped, and the DOTTED BLUE LINE is the temperature log run 5.0 hours after injection of cold water had stopped. The warming up of the wellbore after the injection of cold water indicates no "heat sinks" above 2065. CONCLUSION --- There is no injected water flowing up the well behind casing above 2065 feet. The composite of the logs run on SRU 21-33 WD is presented on the facing page. The depths and gamma ray are presented in track one. Also in track one, the depths that the WFL measurements were taken at are presented as SHORT RED SPIKES. Solid Red Curve Long Dashed Blue curve Dotted Blue Curve Presented in track two are the time lapse temperature logs. Base log before cold water was injected into the well. Log immediately after injecting cold water. Log run six hours after cold water injection. The pressure was recorded simultaneously with each temperature log pass. All logs were recorded going down the well. GRi99i .20, (GAP!) ~ ¡ l 100 - "" ¥Æ 400 ,,~ 500 .~ þ 1t :; ~ !ii' .~ ~ -, " ~ p t 1100 ;1 ~ ~ 1200 i , 1300 1400 . 1700 1800 1900 2100 60, 'q¡#í\\'W -,%WP ARCO ALASKA !NC" SRU .33WD,SR JUNE 23,i99i (74656) TIME LAPSE TEMPERATURE , , " , ¡ , I ' : >=u I ¡=II I I' I ' If, I , ) ~-\ H+- \ , ) ;: l I " J I / i \ \\, I J ~~. , rh- i¡: þ\ ~ I - - - ,,' ,,!A' - t - Jt 'P - ~ :II"" ,k, I l' I , , , 0 , ¡ I" :, I : , I , \. , \ \ I-', \ i \ I \ \ \ ; ) l \ \ \ I I I I I I.n":- (DEGF) \ ( ? I j I """" , I \ {" \ \, "\ I " I ',. I 'Ii. I \, I \.: I \: 1 / I J I , I :' '\ ',- i \', I ; ': , ¡ : i' , \. " J ",J"" " I : I" I I, , 1 ~ I ( (f (" (I "', ",// 1 ,,- -'-"--- ,--~-----------,,----------~-- TIME LAPSE PFŒSSURE I 100 0,0 (PSI) ß\ 'I" \ \ i , , j \; '. ,\ \ ~ \ I \ - \ ,\ \ .~ 4\ \ IT, I, \ , I \i' ~ \ I \ I - I \ \, \ \ \ \ \ I" I \' I I " j '\ \ \ \ \ I I '\ =;=t \ I \ ,'i;, '. ~ I;, \ ~ 'I" I " i I \ ~"', , í , ". i500 I I I I - ,- - I -, I j - ,- ,- ._, "/, ARCO ALASKA, INC. Swanson River Unit SRU 21-33 WD Production Logs 23-Jun-91 WELL: SRU 21-33 WD Water Flow Log Summary DEPTH ACTIVATION CYCLES FIFTEEN FT TWO FT ONE FT BURST TIME ~TACKED DETECTOR DETECTOR DETECTOR SECONDS VELOCITY VELOCITY VELOCITY FPM FPM FPM 1065.0 10 9 0.0 0.0 0.0 1165.0 10 18 0.0 0.0 0.0 1265.0 10 9 0.0 0.0 0.0 1360.0 10 9 0.0 0.0 0.0 1470.0 10 20 0.0 0.0 0.0 1620.0 2 10 0.0 0.0 0.0 1715.0 2 9 0.0 0.0 0.0 1715.0 10 14 0.0 0.0 0.0 1760.0 10 10 0.0 0.0 0.0 1760.0 2 9 0.0 0.0 0.0 1760.0 10 9 0.0 0.0 0.0 1980.0 10 10 0.0 0.0 0.0 2060.0 2 9 0.0 0.0 0.0 2060.0 10 9 0.0 0.0 0.0 2077.5 2 9 0.0 8.5 0.0 2077.5 10 9 0.0 5.2 0.0 Activation time is how long the neutron generator is turned on. The activation time will be either two seconds or ten seconds in duration. Cycles stacked - each measurement at a given depth is the summarization of several single measurements. A single measurement is an activation burst time of two or ten seconds, followed by a sixty second measurement time. This cycle is repeated several times, usually six to ten times, to reduce the statistics in the measurement. There are three detectors spaced 1, 2, and 15 feet above the neutron generator to detect if there is any activated water flowing by these detectors. The reason for several detectors is due to the different velocities - high and low. The high velocities, up to 230 FPM, are measured by the 15 foot detector, while the low velocities, 1 FPM, are measured by the 1 and 2 foot detectors. ARCO ALASKA, INC. Swanson River Unit SRU 21-33 WD Production Logs 23-Jun-91 WATER FLOW LOG EXAMPLES 300.000 240.000 180.000 CPS/CYCLE 1~0.000 60,0000 0.0 T I M E < :!: E C ) FILE i I I I ])ETECTI3F,: = FAF,: T[IT-F' Depth 2077.5 Water Flow Detected Flow Velocity = 5.2 Ft./Minute 400.000 320.000 240.000 CPS/CYCLE 160.000 80.0000 0.0 T I I'IE,:i :!:E¢:) i I i FILE I'tUI,1]E:ER DATA AO~!UI RED DETECTEIR: FAF,: T:I:~T-F' Depth 1760.0 No Water Flow Detected Flow Velocity -- 0.0 Ft./Minute ) , 1396i "'. ell I t' ' : t' · ' llOe*_ i it'''* ,2619~1' · ~ e. IT~e / ~ il' ' ~~x, ~9, ~ ~' ~mG v~ T~ · ~6~?.2~, ~X! -! ~ ~~ · ~.~ . :1~i / ( ~o~ 3 ~ ~. ~ "~" ~ ]o~. ) I /~ 1~040, ~ ' " /' )~ 3100.~' -- TOP ~ ~' . i ~~--31~' ! CASING · TUBING DET~ · . ~-- ~' ! . SECTION , l/~,, ~ ~.~. ~., !~ ' ' ' ~~~ ' - Form ~160--5 ~November 1983) (Formerly 9--331) UNI ) STATES s.smT IN ~zz-, ~' (Other instrue~ons r~ DEPARTMENI' OF THE INTERIOR ,--~,) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not tine this form for proposals to drill or to deepen or plug back to a di~erent reservoir. V/se "APPLICATION FOR PERMIT--" for such proposals.) O,'..,~L [] OAEWELL E~ OT.ER X Water Disposal 2. NAME OF OPERATOR ARCO Alaska, Inc. 3. ADDRE88 O~ OPERATOR P.O. Box 100360 Anchoraoe. AK. 99510 4. LOC&TION OF WELL (Report location clearly aff~d ih accordance with any State requlrements.* See also space 17 below.) At surface 560' FNL, 2110' FWL, Sec. 33, T8N, R9W, SB&M 14. PERMIT NO. 2-62 15. ELV'VATION8 (Show whether Dr, ItT, as. etc.) 206 ' KB 16. Form approved. Budget Bureau No. 1004-0135 Expires_ August 31, 1985 5. LEAIB DEmlOMATION AND OBalAL NO. 6. xr INDIAN, ALLO~BB aa TIIBB NAME 7. UNIT AOEBEMBNT NAME S. wan~on R I ver Un it 9. WELL HO. SRI_I ? !-33WD Swanson River/Sterlinq 11. SI~., T., I., Ii., OI ~Z~. s~rD aUIVB! OI ~IIA Sec. 33, T8N, R9W, SB&M -12. ~OU~TY Oa P~tmHJ 18. STATE K~n~l I Alaska Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPI,ETE SrtOOT os ACZDZZB ABANOON* REPAIR WELL CHANGE PLANS (Other) (Other) MI T (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 17. o~:scainF, i'ROPOSEO oR COMPLETED OPERATION-~. (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface loc~tions and measured and [rue vertical depths for all markers and ~ones perti- nent to this work.) * ARCO Alaska, Inc. on 6/22/91 successfully completed a Mechanical Integrlty Test on SRU 21-33WD. Please see the attached for test results. REC[;\/ED AUG 1 1991 /tJasJ~ Oil & 6as Cons. Commissien ;tnchorage 18. I hereby certify that the foregoing is true and correct (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATI~ '*See Indvuctions on Reve,se Side Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. j-UN-25-~ 91 05: ~9 I D: SWANSON R I VIER ARCO Alaska, Inc. 6ul~ldiary of Atlantic Richfield Company WELL CONTRACTOR TEL NO: 2651383 #948 P02 WELL SERVICE REPORT I'P'BDT t FIELD :' DISTRICT- STATE IDAYS .... 1- f~.~,v.~_,v' ~~e ~/_~-_~ ...... IOPERATION AT REPORT TIME [DAT~ !_7:go -/7:,~o I D: bwgN$ON RI VER TEL NO:~Sla~J REMARKS CONTINUED; DESCRIPTION DAILY ACCUM', .... ~, TOTAL OTIS " ' ...... SCHLUMB'ERGER Wozr~ 7"D . ~,-~-~'~ ] ' ,," .._ ' , " ,,,," DRESSER. ATLAS - .... DOWELL ..... "HALLIBURTON ........ "ARCTIC COIL TUBII~G ......... ~ i ,, , i . , ,, , ,, ,_ , FRACMASTER Bi J. HUGHES Roustabouts 6ieael ........... · .. i_ _ · i Methanol Supervision ' Pre-Job ,Safety-- Mee!Ing , '" _ , ......... ' ,,, ' , ' , AFE ii , ,i , ii i. .- , , ,, TOTAL FIELD ESTIMA~'E .......... ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering June 17, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached are the revised procedures for conducting a mechanical integrity test on SRU 21-33WD and SRU 41-33WD. These procedures would replace those submitted with our Sundry requests dated May 29, 1991. The revised procedures call for the substitution of an oxygen activation (OA) type log in place of the RA tracer log specified in the area injection order. Use of the OA log to detect leaks and channels has now been approved by the EPA. We believe oxygen activation to be a superior technique to the RA tracer log and propose that it be formally added as an approved procedure to the Swanson River Field Area Injection Order Number 13, Rule Number 6. Additionally, AAI requests that Temperature Logs and Noise Logs be added under Rule #6 of the AIO. The use of these tools for Mechanical Integrity Testing has also been recognized by the EPA (Re: Federal Register Notice - Volume 56, Number 2, Section II). If you have any questions on this matter, please contact Jim Zernell , at 263-4107. Sincerely, T. Wellman ~~~ Regional Engineer TW:JKW:czm:0071a Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Compa~!¥ Co.or or CEiVED ARCO Alaska. Inc. is a Subsidiary n! atma~,,~ ~;~=~a~ ~ ....... ~ 4. Check for upward flow at the following stations (depths from 10-12-89 temperature log). De-pth 2098' 2060' 1 760' 1715' 1620' ' 1470' 1265' Reason Lowest accessible depth Above last logged injection sand In deepest confining layer Above deepest confining layer Potential USDW. Potential USDW Potential USDW . Underground source of drinking water. 5. Make further stops to check for flow as deemed appropriate by on site engineer. "'., " 6. POOH. Prepare for PITS. REGflVED ~' UUNl81991 " '. .~~ßqsCo/1J.9/1nml~r__." , . ~,~~~ · Prior to Pump-itl Temperature Surveu_ {PITS) 1. Shut-in well for at least 12 hours. 2. Assure that 300 bbls of (-45°F) lease water is on location. NOTE · Do not use produced water (too warm). · (PITS) 3. RU E-line. Pressure test lubricator. . RIH w/ CCL/temp tool (CCL on top). to PBTB. Do not exceed 30 fpm. Record temperatures from surface 5. Tie-in. Re-log the bottom 200' to verify repeatability. Set tool at 200' _ . 6. RU pump truck and pressure test lines. Pump 300 bbls lease water at 550 psi injection pressure. RD pump truck. 7. Log down to Obstruction (2098' WLM) at 30 fPm recording temperature data. .- -. 8. POOH to 200' at 30 fpm~ .~ -' 9. Repeat steps 7 & 8, as needed. Make at least 3 down passes, 1 hour apart. 10. POOH. RD E-line. 11. Return well to service. . ,ITM · 193.00. * .o · 1396t':' ' *'" ' ' , ' ' 67 ';~s. ~,., 9.2~ ~-a~Bu'r~ss ~. ~2108.~" ~ SH~ ~ ~ T~~ ' . .. ii'"'.'' ' '" ' '' t I~'~ ' ' ' · "- ~ '-.,-. " .' ' :" .-.:':.' -;"'~ I I'=" - · .' :" .' '.' ; .... ':' - -' ' · ' ~ " · ' '-.'"";" ' ~': ' '"-:~ 'i' '-...' '- ' ' . -'" .. - ' ' ' ';':~ . ..: izzts - . . · . ;'._." . . ii""'-.'. · !! · :. . u~,,~.VE~ ~ . ,' . .... . ~~u ' . " I - 'i1411 ' ' ' ' ' . .~~~.m' ~. TO~ ~~ ~ ' ; ~,'J~2~.m' , =,~ ~== JUN 18 ~uu~ I ~1 ..2~*~'~ ' - .. · .. . ·-.r ~:ttt. "I~ .31m' CASING S TUBING ~4~ 3162' '. ~i SECTION 33 T. 8N,R.9~S~ .. ~, · · ' · 12~-~ Ii I i i ~ i i II i L I I I I III ~ . . . ~~~ ~" .:.. _ .&~ 0 Il f G I N A L o,. o. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend_ Operation Shutdown __ Re-enter suspended well __ Alter casing_ Repair well _ Plugging_ Time extension _ Stimulate ___ Change approved program __ Pull tubing __ Variance _ 2. Name of Operator ~ 5. Type of Well: I Development ~ ARCO Alaska. Inc. Exploratory _ 206' KB I~. Address I Stratigra phic ~,,V~.~ 7. Unit or Property name 41 O. Box 100360, Anchorage, AK 99510, ~ S,,er~ice Swanson River Unit Location of well at surface i ECE D 8. Well number 560' FNL, 2110' FWL, Sec. 33, T8N, R9W, SB&M SRU 21-33WD At top of productive interval 9. Permit number Straight Hole MAY '1 t991 At effective depth Alaska 0il & Gas Cons. C0mmissi( At total depth Anchorage 12. Perforate __ Other X ( M I T) 6. Datum elevation (DF or KB) rllO. APl number 50-133-101 62-00 11. Field/Pool Swanson River/Sterling Present well condition summery Total Depth: measured .3,805 feet Plugs (measured) 2,450-2,590', 2,886-2,889' true vertical 3,805 feet 3,100-3,162' MD Effective depth: measured 2,450 feet Junk (measured) 2,617-2,866' MD true vertical 2,4 5 0 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 33' 2 0" Driven 33' MD 33' TVD Surface 1,396' 9-5/8" 800 sx 1,396' MD 1,396' TVD Intermediate Production 3,,805' 7" x 5-1/4" 600 sx 3,805' MD 3,805' TVD Uner (combination casing) Perforation depth: measured feet Current: 2,120-2,174'; 2,194'-2,262'; 2,280'-2,296'; 2,350'-2,394'; 2,402'-2,438' MD true vertical Current: 2,120-2,174'; 2,194'-2,262'; 2,280'-2,296'; 2,350'-2,394'; 2,402'-2,438' TVD Tubing (size, grade, and measured depth 3-1/2", N-80, 9.2# @ 2108' MD; tbg is cemented to surface. Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: June. 1991 I Oil __ Gas Suspended 16. If proposal was verbally approved Name of approver Date approved Service X (Water Disposal) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Plug integrity B. BgP Test Mechanical Integrity Test Approved by the order of the Commission Signed ~f.~~~ Title Cook Inlet Regional Encjr. FOR ~MISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Location clearance Subsequent form require 10- ORIGINAL SIGNED BY --.~--Co~missioner Date IApproval No. ~.. I ~/-/~ 3 Date Form 10-403 Rev 5/03/89 LONNIE C. SMITH SUBMIT IN TRIPLICATE Well SRU 21-33WD MIT & ~ SR 245 - Revised Determine mechanical integrity of the well with oxygen activation log (MIT) and verify that the well is not affecting the fresh water aquifer. Current Status SRU 21-33 WD is on injection. Minimum Restriction: 3-1/2' tubing. Last Tag' 2085' WLM (10-12-89) Pressures: T P 610 psi .... .. _~- · PC 45 psi- . ._....~ . .SC 0 psi Procedure ' ' - · Prior to Locloino "1. RU slickltne and tag fill with 2.8" . gauge ring. 2. Contact'Anchorage Office to Verify Sundry Approval and notify the S/ate and BLM 24 hours prior to the MIT. 3. Tie-in log is Temperature Log 10-12-89. · M¢¢honical Inte_orit~_ Test (MIT~: Ox!l__oen Activation Loo 1. Establish a stabilized 'injection rate 'into the well with a 550 psi injection pressure. 24 hours should be sufficient time for stabilization. Record injection rates and pressures during the survey. .2. RU E-line and pressure test lubricator. RIH w/GR/CCL/OA log. The O/A log should be configured to detect upward flow. 3. Tie in GR. Log from the tubing, obstruction to 1000' MD. Verify repeatability. , ~ -\ti\.;U AlaSka, tnc.(,' ..) luDIIG11fY of At ¡t tIO RICh... CGmØIftJ PBCT (' WELL SERVICE REPORT well. 07:DO - 1£)', \.C- \0'1) - ,,') ~~ ö to:'!.o - 10 '.A~ IO~4~ ~ l&t\ 30 t4:'!>O - It..: ~ð 1 t. ~ 30 - Z. \ : '2. :-, '"t. u- tJ';> ¿;~~L\J~~~l...t:~. K\l.. ù~ :T,)ðt k~\. "- rV\.\",,- ~oo + h'b\ ~ f)ç ~. ~ rf~ ~r- \.....L ?~~~ ~e...;;' \ECa. r Ld(\..Q, LA.Tð(') ~ \O(:)ö t''-- \ - 0 \L. . Q \ ~ -rù \? 1'\ (') , I ^~ DðuJÙ ~ ~l) ç:~M. ?øu.~-Q. ~~~ù. lDð9-\.t. ð U ,Ç\.1LÙ ~~~rl.tot;.\f.) ~~~Jt.AT~ t2. ~ I LDCð ~I.L.'...) ~.,.. ~ð ç:p'M. .0 ~~\''''2\t'''t\tH.) fðu..fÞ~08.L.- W\. ~ . L()~Co~h "-~~~~ - OY:. 'T}1;.\1"F:.Lf'1,? 1t=\ L~ ~ ~'~I&"\,' ~~ \\~ \ ~J /r} A,.IJ!J.!J. Ln/.. %='~ Øf/ß9 I~~(-"'~\) ~ðð \h\\ l""'t.C" ~ ß s: ~r-'\.'~- A.'::!. Ç"o\'~Q~ ~ .. '-""'..."""""'.."---- ----"- ¡:~ 1.,:\ ? 530 - ...,. /E"HECK THIS BLOCK IF SUMMARY CONTINUED ON BACK =- IT~ OF IChl.Fïëï.~r~i" m"HrMÎÌdV.L knoltršieñ.d71A.æe~1~Æ!7:~'.': 0CT-~.4-'1~ ~:Sc. D:SWI:I~ R~LE]~ I~MARI~ CONTINUED:. CA~:~ OTto D~E~Ef~ATLA$ ~we~;.~- ~ -_. HALMBURTON ARGTI~ GOIL TUBING ,m FRACMASTER 8. J. HUGHES RoustaOouto MMI~anot OEaCRI~ION DALLY m~ ACGUM. TOTAL .. TOTAL IqaLO EIllMAll t 4'7° ~' br-;,--,,... ~ io~; Z4 - h,- 5Z. '~ hr' o.,Ckr p~,~p-' ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures O.'iGINAL August 17, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Sundry Approval: Pump-In-Temperature Survey SRU 21-33WD Swanson River Field Dear Mr. Chatterton: ARCO Alaska, Inc. requests approval to perform the attached pump-in-temperature survey on SRU 21-33WD to prove that current injection practices are not resulting in fractures that extend through confining zones enabling disposal water injectant to enter any fresh water strata. Such testing is warranted as the previous pump-in-temperature survey on 5/19/89 indicated that the injection interval was within ten feet of our upper injection limit while injecting above parting pressure. Subsequently, operating conditions were changed to maintain injection below parting pressure. The recommended surveys will make multiple temperature passes from 1200' to PBTD after injecting cold lease water into each well. The resulting data will define where the cold fluid travels when injection is under parting pressure. If there are any questions pertaining to this matter, please contact Stacy Strickland at 263-4914. Sincerely, TSM:SLS:ch:0005 Attachment CC: S. W. Ohnimus ,a~ R. Kukla UNOCAL Corporation Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany AR3B--6279 · · - ~'~ STATE OF ALASKA ~----,~ . A_ ~KA OIL AND GAS CONSERVATION COMr lION ~ APPLICATION FOR SUNDRY APPROVALS" R IN A l 1. Typb of Request: Abandon__ Suspend__ Operation shutdown __ Re-entersuspendedwellmPumD- i n temperature Alter casing ~ Repair welt w Plugging __ Time extension m Stimulate __ rv Change approved program m Pull tubing m Variance __ Perforate m Other ~ S U rve y 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 9951O 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 560' FNL, 2110' FWL, Sec. 33, T8N, R9W, SB&M At top of productive interval Straight Hole At effective depth At total depth 6. Datum elevation (DF or KB) 206' KB feet 7. Unit or Property name Swanson River Unit 8. Well number SRU 21-33WD 9. Permit number 10. APInumber 50-- 133-101~00 11. Field/Pool Swanson River/Sterling 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production Perforation depth: 3805 feet Plugs (measured) 3805 feet 2450 feet Junk (measured) 2450 feet 2450 - 2590' 2886 - 2889' 3100 - 3162' 2617 - 2866' Length Size Cemented Measured depth True vertical depth 33' 20" To surface 0-33' 0-33' 1,396' 9-5/8" Yes 0-1,396' 0-1,396' 3,149' 7" x 5-1/[" Yes 0-3,149' (combination casing) measured 2120-2174'; 2194-2262'; 2280-2296'; 2350-2394'; 2402-2438' truevertical 2120-2174'; 2194-2262'; 2280-2296'; 2350-2394'; 2402-2438' is cemented to surface. Tubing (size. grade, and measured depth) 3-1/2", N-80, 9.2# e 2108' MD; tubing Packers and SSSV (type and measured depth) 0-3,149' 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation August, 1989 Date approved 15. Status of well classification as: 16. If proposal was verbally approved Oil ~ Name of approver Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,gne £ ~ ~/c~~. Gas ~ Suspended __ Water Disposal Title Cook Inlet Engineering ManagerDate FOR COMMISSION USE ONLY Conditions of approval: NOtify Commission so representative may Witness Plug integrity ~ BOP Test __ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- ORIGINAL SIGNED B'~ LONNIE C. SMITH Approved by order of the Commissioner Commissioner Approval N q,'~ ~:~z./ .. Approved Copy Returned Date FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Pump-In-Temperature-Survey SRU 21-33WD SR 71 Objective: To determine how far up water injection extends in this well while injection is maintained below parting pressure. Well Data,: Completion Perforations: Last PBTD tag: Current Pressures: Est. Parting Pres · 3-1/2", 9.24/ N-80 tbg; cmt'd from shoe (2108' MD) to surface 238' Total; Top Most @ 2120' MD, bottom @ 2438' MD Obstruction @ 2101' WLM (4/7/89) 500 psi tbg. inj. pres.; PC is cemented 610 psi surface injection pressure Note: Verify that Sundry approval has been obtained and that well has been injecting below parting pressure (570 psi injection pressure or 1200 BWPD) for at least one week prior to performing this temperature survey. = ~, Procedure: . . SI well for at least 24 hours. -~ ~:. i:i :-~; (i~:,~: i; ~',; Hold safety meeting, Assure that at least 300 Bbls of cold (-50°F) 3°/6 NaC1 brine is on location. 3. RU E-line. Pressure test lubricator to 1000 psi. . RIH with CCL/temp tools (CCL on top). Record temperatures from 1200' MD to the tbg obstruction (2101' WLM). Do not exceed a 30 fpm line speed below 1200' MD. 5. Tie-in. . Re-log bottom 200' at 30 fpm to verify temp tool repeatability (down run). POOH to 1200' MD. . RU pump truck and tie into tbg. Pressure test lines to 1000 psi. Pump at least 300 Bbls of cold brine (N50°F) at under 570 psi surface injection pressure. SI well. 8. Log down to obstruction at 30 fpm recording temperature data. 9. POOH to 1200' MD at 30 fpm. 10. Repeat steps 8 and 9, as needed, to determine the intervals which receive water injection (these areas will be colder than surrounding intervals). A minimum of 3 hourly passes will be required. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6OO1-A Pump- In-Tem perature- Survey SRU 21-33WD SR 71 - Page Two 11. 12. POOH. RDMO. Return well to injection. ARCO Alaska Inc. Is a subsidiary of Atlantic Richfield Company AR3B-6OO1-A iii i · iii $ RU 21-3,3'. CASING 5 TUBING DETAIL SECTION ~3 T. 8N.,R.gW. · ' 12..30-'72 :.?~/;-' _ _ i I__: - _ ........ o - · -... I,...._~l~e.,i ~ -,,..I~1....- . .. · ...' . E-Line BOPE's . Grease Head/ Hydraulic Packoff Lubricator Extension 'Manual Rams Swab Valve Double Maste~ Valves Wellhead r~ ARCO Alaska,"lnc. f Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures May 9, 1989 Mr. C. V. Chatterton, Chairman Alaska Off & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Sund .ry Approval: Pump-In-Temperature Surveys a -aaw ~s~ Field Dear Mr. Chatterton: ARCO Alaska, Inc. requests approval to perform the attached pump-in-temperature surveys on SRU 21-33WD and on SRU 31-33WD to prove that current injection practices are not resulting in fractures that extend through confining zones enabling disposal water injectant to enter any fresh water strata. Such testing is warranted as recent data shows these wells to be injecting over parting pressure. The recommended surveys will make multiple temperature passes from 1200' to PBTD after injecting hot lease water into each well. The resulting data will define where the hot fluid travels when injection is over parting pressure. If there are any questions pertaining to this matter, please contact Carol Baker at 263-4643. Sincerely, T. S. McCorkle TSM:CMB:ch:0015 Attachment RECEIVED CC: G. A. Graham A. R. Kukla UNOCAL Corporation Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 /~" STATE OF ALASKA ALA...,,,A OIL AND GAS CONSERVATION COMMIS,~. ~N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Alter casing __ Change approved program Pull tubing Operation shutdown g Re-enter suspended well __ Plugging ~ Time extension ~ Stimulate __ Variance ~ Perforate ~ Other SusPend ~ Repair well 2. Name~Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK Sec. 33, 4. Location of well at surface 560' FNL, 2110' FWL, At top of productive interval Straight Hole At effective depth At total depth 12. Present well condition summary Total depth: measured true vertical 5. TyPe of Well: Development Exploratory. Stratigraphic 951 Service Effective depth: measured true vertical Casing Conductor Surface Length 1396 ' T8N, R9W REC[IVED MAY 1 i .Oil & Gas Cons~ 3805 ' feet Plugs (measured) 3805 ' feet Pump-in ~ Junk(measured) 2450' ~et 2450' Size Cemen~d Temp. survey 6. Datum elevation(DForKB) 206' KB feet UnitorPropertyname Swanson River Unit 8. Wellnumber SRU 21-33WD 9. Permit number 10. APt number 50--133- 1016~.;,00 11. Field/Pool Swanson River/Sterlin 2450 - 2590' 2886 - 2889' 3100 - 3162' 2617 - 2866' Measured depth 20" to surface 0-33' 9-5/8" yes 0-1396' True vertical depth 0-33' 0-1396' Production Perforation depth: 3805' measured 2120 - 2174'; true vertical 7" x 5-1/4" yes 0-3805' (combination casing) 2194 - 2262'; 2280 - 2296'; 2350 - 2394'; 2402 2194 - 2262'; 2280 - 2296'; 2350 - 2394'; 2402 tbg is cemented to surface. 2120 - 2174'; ~bing(siz~gmde, and measumddepth) 3-1/2", N-80, 9.2# @ 2108' MD; PackersandSSSV(typeandmeasumddeCh) 0-3805' - 2438'. - 2438'. 13. Attachments Description summary of propoSal Detailed operations program X BOP sketch _.~ 14. Estimated date for commencing oPeration 115. Status of well classification as: May, 1989. 16. If proposal was verbally approved Name of approver Date approved Service Water Di sposa I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'/.-¢, ~~ TitleCOok I n let Engi neet ing Mgr. FOR COMMISSION usE ONLY Oil __ Gas ~ Suspended Date i Approval No. COPY Mechanical Integrity Test __ SubSequent form required 10- ,~c~.- Conditions of approval: NOtify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Approved by order of the Commissioner Commissioner Date ,,~ Form 10-403 Rev 06/15188 SUBMIT IN TRIPLICATE Pump-In-Temperature-Survey SRU 21-33WD SR 41 Objective: To determine how far up water injection extends in this well while injection is maintained over parting pressure. Well Dat~,.: Completion 3-1/2", 9.2# N-80 tbg; cmt'd from shoe (2108' MD) to surface Perforations: 238' Total; Top Most @ 2120' MD, bottom @ 2438' MD Last PBTD tag: Obstruction @ 2101' WLM (4/7/89) Current Pressures: =800 psi tbg. inj. pres.; PC is cement~,d Est. Parting Pres.: 610 psi surface injection pressure Procedure: MAY 1 1 t9~9 . . SI well for at least 24 hours. Alaska,0il .& Gas ,,~,t Anch0ra~e ' . . Hold safety meeting. Assure that at least 300 Bbls o~ heated (150 F+) lease water is on location. (A steamer can be used to heat the fluid). 3. RU E-line. Pressure test lubricator to 1000 psi. . RIH with CCL/temp tools (CCL on top). Record temperatures from 1200' MD to the tbg obstruction (2101' WLM). Do not exceed a 30 fpm line speed below 1200' MD. 5. Tie-in. , Re-log bottom 200' at 30 fpm to verify temp tool repeatability (down run). POOH to 1200' MD. , , RU pump truck and tie into tbg. Pressure test lines to 1000 psi. Pump at least 300 Bbls of heated lease water (150'F+) at over 700 psi surface injection pres. SI well. Log down to obstruction at 30 fpm recording temperature data. 9. POOH to 1200' MD at 30 fpm. 10. Repeat steps 8 and 9, as needed, to determine the intervals which receive water injection (these areas will be warmer than surrounding intervals). A minimum of 3 hourly passes will be required. 1 1. POOH. RDMO. 12. Return well to injection. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6OO1-A M EMORAN DOM State of Alaska TO: Logic C Smith ~ DATE: March 30, 1988 Co~i~sioner roLE NO: A. BEW. 90 TELEPHONE NO: THRU: SUBJECT.' Analysis of Radioactive Tracer/Spinner Surveys Well SRU 21-33WD Swanson River Field FROM: Blair E Wondzell Sr Petroleum Engineer After reading my March 23, 1988 memo regarding the running of these surveys in SRU'21-.33 WD, you asked me to analyze the Radioactive Tracer Survey (RTS). In that memo I stated that "It]he Spinner log indicated similar velocity throughout the tubing string." On March 30, 1988 I met with-Dresser Atlas personnel, Jerome Moe (St Sales Engineer) and Robert Brown (St Log Analyst), and analyzed the subject surveys. The results are as follows: e The RTS was made by taking velocity shots at various depths, the shallowest at 500' and the deepest at 2050'. (Shots at 2058' were for flow behind pipe determinations). The 3 velocity readings at 500' showed velocities similar to those recorded at 2050' (3 readings),- therefore, there are no significant leaks indicated in the tubing. 2. Velocity shots 1, 2, & 3 were made to check for fluid flowing upward behind pipe above 2058'. No radioactive material was detected after the radioactive slug went downward past the detectors; therefore, flow upward outside the tubing was not indicated. As reported in my earlier memo, same topic, the spinner survey covered the interval from 2010' to 50' and indicated no significant leaks. In consideration of the above survey results, I recommend that we accept these data as demonstrating mechanical integrity in well SRU 21-33 WD. 02-001A (Rev. 8/85),:; ARCO ALASKA, INC. Cook Inlet/ltew Ventures Engineering TRAIISI. IITTAL CO14PANY: ~~ ~_ ~-~ DATE: = ..~_ ---,:~ ~ -~ J~ FROM: ~. ,.~". ~~ - CO ,lPAN¥: WELL llAI,1E:: ....... ~/-,) '),~,/~ ~ ~_ Transmitted herewith are the follov~ing: PLEASE t~0TE- BL -- Blueline, S = Sepia, F -- Film, T = Tape, PC - Photocopy , Receipt Acknowledgment: D~.r~.~orago Return Receipt to; ARCO Alaska, Inc. AT.TN: Judy Boegler ATO- Po~{ Office Box 100360 Anchorage, AK 99510 /MEMORA.N DdM State of Alaska AI2%SKA OIL ~2~D GAS CONSERVATION COMMISSION TO: Lonnie C Stair.hr: Commissioner DATE: March 23, 1988 FILENO: A.BEW.89 TELEPHONE NO: THRU: SUBJECT: Radioactive Tracer/ Spinner Surveys Well SRU 21-33 WD Swanson River Field FROM: Blair E Wondzell Sr Petroleum Engineer In response to your March 21, 1988 request, I have listed below the relevant facts concerning the subject surveys run on 2/25/88 in the Swanson River well SKU 21-33 WD. Well SRU 21-33 WD was drilled to 3805' in 1962, and was completed with a 5%"x7" tapered casing string cemented at 3149'. Sterling zone gas was produced through perforations at intervals 2766-2770', 2862-2866', and 3060-3065'. In October of 1964 the well was recompleted as a sterling gas producer and disposal well.4%,A retainer was set at 2889' The casing was perforated with HPF at intervals 2120 to ~-438' for disposal. Tubing was run to 2866' with packers at 2628' and 2820'. A 10' pup joint was run for an injection string. In 1972 the well was again reworked. The tubing was cut at 2617' and a cement retainer was set at 2590' and capped with 30 sacks of class "G" cement. A string of 3%" buttress tubing was run to 2091' and cemented inside the 5%"x7" with 250 sacks of cement around the shoe and 45 sacks down the annulus. A March 3, 1986 letter from Robert S Burd (EPA) to J L Weaver (Chevron) stated that Chevron's plan to demonstrate mechanical integrity in SRU 21-33 WD had been discussed with and agreed to by AOGCC and BLM. (The type of test was not stated.) Burd further stated: "Please be advised, however, that EPA regulations at 40 CFR 146.8(d) require that these tests be approved as 'alternative mechanical integrity tests' in order to meet the mechanical integrity testing requirements in 40 CFR 146.23(b)(3). Upon receipt of the test results, we will evaluate the data for approval as an 'alternate' method. Please provide us copies of the logs and complete descriptions of the testing procedures at your earliest convenience." 02-001A (Rev. 8~85) LCS from BEW March 24, 1988 Page 2 Published in the Federal Register of December 10, 1987, the EPA approved Radioactive Tracer Surveys (RTS) as an alternative mechanical integrity test (MIT), stating.' "...the RTS is apProved as an alternative mechanical integrity test under the conditions and limitations described herein and in FRL-3260-8 effective December 10, 1987." (Two types of RTSs were considered -- the timed run method was approved~ the velocity shot method was disapproved.) ARCO took over the operation of the Swanson River Field effective October 1, 1986. Via a 10-403 dated 11/18/87 (approval #7-906), ARCO proposed to demonstrate mechanical integrity in SRU 21-33 WD by setting a "DD" wi,re line bridge plug in the 3¥' tubing in the joint above the casing shoe at 210~'~ This was ok'd by Wondzell and approved by Barnwell on 11/19/87. (Note: 9-5/8" surface casing shoe at 1396', 7"x5~" cross-over is at 1377'.) On February 14, 1988 a plug was run and set in SRU 21-33 WD at 2090' WLM. The tubing did not pressure up. ARCO stated that "It]he plug had dropped out of the tubing tail because it could not latch securely in the tubing due to scale deposits." ARCO's 403 states that on February 22, 1988 Mike Minder gave verbal approval to test SRU 21-33 WD for mechanical integrity by using RA tracer and sp~nner surveys. Mike did not specify the type of RA tracer. Mike also waived the State's right to witness the logging. A spinner and RA tracer surveys were run on February 25, 1988. A field copy of the surveys was received on March 15, 1988, and was handed to Mike. The logging company stated "It]he Sinker bar did not reach the tubing tail but was stopped by an obstruction @ 2087'" about where the "DD" wire line plug had been set. The spinner log indicates similar velocity throughout the tubing string. I have not analyzed the radioactive tracer survey, but it is definitely of the velocity shot type which has been disapproved by the EPA. If you have any questions, I will be glad to discuss them with you. ARCO Alaska, Inc. Post Office Box Anchorage. Alaska 995t0-0360 Telephone 907 263 4?24 March 11, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached is the Application and Subsequent Report of the RA Tracer Survey on the SRU2!r33~, This survey was run to comply with UIC Rule No. 6 to test tubing- production casing integrity. Verbal approval was given on 2/22/88 to run the survey after attempts to set a tubing plug were unsuccessful. It was agreed to send the two reports together after the logs were run. The RA tracer and continuous spinner verify the integrity of the tubing-production casing annulus. If you have any questions on this matter, please contact Mary Eck at 263-4214. Sincerely, C~ tS':~.~.~ Joiner DS~:~E:ch:~3 Attachments cc: J. Dygas, Bureau of Land Management (Information Only) STATE OF ALASKA '""%, ALAS,,,4 OIL AND GAS CONSERVATION COMr,,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ' 5. Datum elevation(DF or KB) ARCO Alaska, Inc. feet 3. Address 6. UnitorProperty name Post Office Box 100360 Anchorage, AK 99510 Swanson River Unit 4. Location of well at surface Sec. 33, T8N, R9W, S.B.&M At top of productive interval At effective depth At total depth 7. Well number SRU 21-33WD 8, Permit number 9. APl number 50-- 133-1016~-00 10. Pool Stl-er I i nq 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: SEE ATTACHED SCHEMATIC feet Plugs (measured) feet Tubing (size, grade and measured depth) Length Size Packers and SSSV (type and measured depth) feet Junk (measured) feet Cemented Measured depth True Vertical depth 12.Attachments Description summary of proposal ~ Detailed operations program ~ W-el ! sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved Name ofapprover Mike Hinder Date approved 2/22/88 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ,5.~~,,~._._ Title Mqr., Cook In let Engineer Commission Use Only Date ~/////~/~ .... Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMI~ Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test I-!. Location clearanceI Approved Copy Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate 21-33 WD Injection Profile Determine the integrity of the tubing string. Procedure: 1. Put the well on injection 12-24 hours prior to rigging up E-line. 2. MIRU E-line unit. 3. Make a tie-in nm with a GR/CCL and tag fill. Attempt to locate the tubing tail with the CCI.,. Note: Last tag 2100'WLM 2-16-88. 4. MU & RIH with a 2-1/8" continuous spinner and 1-11/16" RA tracer tool. 1 Make a spinner pass from the fill level to surface. Consult with the logging engineer and the field engineer to determine the logging .speed. Repeat the spinner pass at different logging speeds at the discretion of the field engineer. 6. Position the RA ejector inside the tubing as dose to the tubing tail as possible and eject RA tracer shots. Look for channeling up and around the tubing tail. . Make a series of RA tracer shots over the interval from approximately 1720' to 1820' and look for a possible tubing leak. Start the ~ shots in the lower part of the interval and work up to avoid contaminating the upper part of the interval with RA tracer. Note: This interval showed a significant anomaly on the Gearhart spinner log dated 7-28-80. Adjust the interval to be inspected at the discretion of the field engineer based on the results of the spinner. 8. Make additional spinner passes or RA tracer shots at the discretion of the field engineer. 9. RDMO E-line unit. FEB-2.8-' 88 ~3:42 67 .t~. ~%. ..! ; 9,2j N-.~OUTTP, F.,SS TBG. · . 2617,21t -- 28'(,6.4/. e "-'"-2¢'~,5.00t -J.~J:). '*}:" C.T. BRIDC..,S ?LUG 28&9.00~ D.C. 129.4,1' O~ 2.&" ?1~. V/ BO'~O:,I ~ 3022./.1~ --Jl.~X; 249' 0.? 2~" TU~ING %~ITH TOP O 2617,21' ~d i~O~O:.! ~ 2866,/J,: ( TOP CF FLail L~. ]~0:,~ "¢Cn SAFL'T~ JO~]T, ) 'fop CASING TUBING OETAII. SECTION STATE oF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS , 1. Operations performed: Operation shutdown [] Alter Casing [] Other ~ 2. Name of Operator " ' ARCO Alaska, Inc. 3. Address Post Office Box 100360 Anchorage, AK 4. Location of well at surface Sec. 33, TSN, Rgw, SB&M At top of productive interval At effective depth At total depth 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Stimulate [] Plugging [] Perforate ;"],, Pull tubing 99510 5. Datum elevation (DF or KB) 6. Unit or Property name Swanson River Unit 7. Well number SRU 21-33WD '8. ,~pproval number 9. APl' number ~ 50-- 133-1016~[~0,0 10. POOl Stet I lng Feet' Tubing (size, grade and measured depth) SEE ATTACHED SCHEMATIC feet Plugs (measured) feet feet Junk (measured) feet Size Cemented Measured depth True Vertical depth Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative DailY Averag~ Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well OPerations [] Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 " Title Mgr.,,,C°°k Inlet,Engineering Date in uuplicate~ PRESSURE TEST SRU 21-33WD The AOGCC has issued Area Injection Order No. 13, applicable to Swanson River Field, effective March 16, 1987. In order to comply with Rule No. 6 (the demonstration of mechanical integrity in the tubing/production casing annulus) procedures to set a tubing plug and pressure test to 1500 psi in the SRU 21-33WD and SRU 41-33WD were approved by the AOGCC on November 19, 1987. On December 24, 1987, wireline tools became stuck in the SRU 41-33WD due to scale/asphaltene restrictions while preparing the well for the pressure test. Several attempts to recover the tools were unsuccessful. The tubing had not been pressure tested before the wireline tools were lost. The decision was made to move onto the SRU 21-33WD and remm to the SRU 41-33WD later. On February 6, 1988, the master valve and wing valve were replaced on the SRU 21-33WD. The well was treated with xylene on February 9, 1988 to clear the tubing. On February 14, 1988, a plug was mn in the hole and set at 2090' WLM. However the tubing did not pressure up because the plug did not hold. The plug had dropped out of the tubing tail because it could not latch securely in the tubing due to scale deposits. Since the EPA approved RA tracer surveys as a valid method for testing tubing/production casing integrity, Mr. Mike Minder gave verbal approval to test the SRU 21-33WD in this manner on February 22, 1988. He also waived the State's right to witness the logging. A spinner and RA tracer survey was run on February 25, 1988. Both tools indicated no flow behind the tubing and production casing. A field copy of the log is attached and final copies will be sent when available. Fishing operations will begin again this month on the SRU 41-33WD. - 193.00~- r" ..- ,~r J Jl'~' o. · a~-';'~7o' 2108'c0~' , · · ?.174' · ., i?. 2~96' I ~40Z' 206' 189.5' -- 7" x 3~J' /,h%:ULUS CEM. - . - 67 JTS. 3~-", 9.2// t,'-SO BUTrltESS TBG. -SILOS O~ ~' TUBnm · ~:-:1 _ 2599.00 ' · CEI.E2~'I' I~T/'JI~R, [~ :~600' j i..o,,. I o I ,,-2617.21t -~ and BOTTOM '~ 28660 .g4! . . om~ m,0,,., I ( TOP iF FISH IS B,~Oh'N "CC" $,%FETX JO]lIT. ; °l:-~--~....-~-----2SF;6.00' i:!OD. "K" C.I. ~.RIDGE PLUG . · ,. ~ ./,~,---, ~oo.oo, 33 W '~~.~~./..~ ~¢o,, c~S~Ne ~ ~U,~N~ O~T,~ ' ~ · T.D. 1 ,.-...0- 72 . · b SWANSON RIVER WELL SRU 312-22 SRU 314-27 ~ SRU 331-27 ~ S~CU 323-4 ..SCU 332-4 ~ SCU 341-4 ~ SCU 341-8 ~ SCU 312-9 , SCU 321-9 ~ SCU 323-9 -SRU 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-in Shut-i n Injecting Injecting Injecting Shut-in Injecting Injecting Injecting Shut-in GRU13/2c RECEIVED FE 2S ..... Alaska Oil & Gas Con~. Commission Anohora~/8 STATE OF ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION SOUTHCENTRAL REGIONAL OFFICE 437 "E" STREET, SUITE 200 ANCHORAGE, ALASKA 99501 J.L. Weaver Chevron U.S.A. Inc. P.O. Box 107839 Anchorage, Alaska 99510 PERMIT NO. 8523-DB028 DATE ISSUED: February 6, 1986 This permit is issued to Chevron U.S.A., Inc., for the injection of a maximum of 420,000 gal/day of produced water and drilling and completion fluids to a depth of 2,100 feet or greater below the surface of the ground. This activity will be located at well SRU 221-33 WD at the Swanson River Oil Field, Sec. 33, T8N, R9W, S.M. This permit is subject to the conditions contained in Appendices A and B, which are incorPorated herein by reference. This permit is issued under provisions of Alaska Statutes 46.03, the Alaska Administrative Code as amended or revised, and other applicable State laws and regulations. This permit is effective on issuance and expires January 1, 1990. terminated or modified in accordance with AS 46.03.120. It may be RECEI '" ;;; Alaska Oil & Gas Cons. PERMIT NO. 8523-DB028 Page 1 of 4 APPENDIX A SPECIFIC CONDITIONS A. Application Compliance The Permittee shall comply with all parts of their permit application dated February 23, 1981 and the renewal request dated October 8, 1985, except as speci.fied otherwise in this permit. B. Site Operation The discharge shall be to a depth of at least 2,100 feet below the surface of the ground, unless authorized by a permit modifi- cation issued by the Regional Supervisor of the Alaska Department of Environmental Conservation. 2. The discharge shall not exceed 420,000 gal/day. 3. The maximum injection pmessure at the wellhead shall not exceed 1,000 psia. The discharge shall be limnited to those wastes directly related to drilling and production activities. This includes produced water, drilling and completion fluids and dilution water. Other waste, including substances pursuant to the Toxic Substance Control Act, and the Resource Conservation and Recovery Act are not authorized to be discharged. 5. The injection well must have and maintain mechanical integrity. Should leaks in the casing, or the waste entering areas other than what is authorized by this permit be detected, the permittee shall cease injection immediately and take the necessary remedial steps to stop this violation. Injection will not begin until adequate repairs are complete and the Department authorizes start-up in writing. The waste shall be collected and injected without loss of spillage onto the surface of the grounds. Permittee shall comply with the U.I.C. permit issued by the U.S. Environmental Protection Agency. PERMIT NO. 8523-DB028 Page 2 of 4 C. Monitoring and Reporting 1. Hazardous Wastes The Permittee shall test all materials that are suspected of being hazardous and exclude them from injection under Sec. B.4. 2. Produced Water The Permittee shall conduct a produced water to be injected. requi red: representati've chemical The following chemical analysis of analysis are Sodium Carbonate Potassium Bicarbonate Magnesium pH Iron Sulfate Calcium Total Dissolved Solids Chloride This analysis shall be conducted annually and the results shall be submitted to the Department's Southcentral Regional Office and the Kenai District Office by January 31 of each year during the term of this permit. Following a review of two of these reports, the De- partment may modify this r~uirement. Drilling Fluids ':. The Permittee shall conduct a composite, representative chemical analysis of the drilling fluids to be injected from each new well and workover that utilized a mu'd system which has not previously been sampled. The following chemical analysis are required: Sodium Carbonate Arsenic Potassium Bicarbonate Barium Magnesium pH Cadmium Iron Sulfate Chromium Calcium Total Dissolved Solids Cyanide Chloride Lead Nitrate This analysis shall be submitted to the Department's Southcentral Regional Office and the Kenai District Office within 30 days of sampling during the term of this permit. Following a review of two of these reports, the Department may modify this requirement. The analysis required in Part C.1. - 3., shall be performed in accord- ance with Standard Methods for the Examination of Water and Wastewater (American Public Health Assoc.) RECEi' A nchor'ag¢~ PERMIT NO. 8523-DB028 Page 3 of 4 5. Injection Log The Permittee shall maintain a log which will contain the date of receipt and source of waste received, volume from each source, com- position of the waste, the dates of injection, and surface pressures at the beginning and end of each injection activity or daily,which- ever occurs first. This log shall also include a summary of the re- sults of the monitoring {as required in Part C. 2. & 3.), the depth of injection, maintenance activities, and any unusual complications. A copy of this log will be submitted to the Department's Southcentral Regional Office and the Kenai District Office on an annual basis. The log shall be submitted by January 31 of each year during -the term of this permit. The log must be available for inspection at the site. 6. Injection Depth Any changes in injection depths other than as authorized in this permit, requires the written approval in the form of a permit modi- fication from the Southcentral Regional Supervisor. 7. Noncompliance Notification If for any reason the Permittee does not comply with or will be un- able to comply with any limitaMon specified in this appendix, the Permittee shall report the noncompliance to the Kenai District Office within 24 hours, by telephone, telegraph, or in the absence of both, by mail. This notification does not relieve the permittee of any civil or criminal penalties for noncompliance. For purposes of this permit, non-compliance is defined as: a. Discharging waste other than authorized. b. Operating the injection well with a leak in the casing, as identified by pressure monitoring. c. Causing discharges to surface waters and lands, and to fresh water aquifers. d. Injection into a formation and depth other than as authorized in this permit, or as may be amended by the Regional Supervisor. e. Violating any conditions of this permit. 8. U.I.C. Reporting All reports required in the U.I.C. Permit shall be submitted to this Department as well. PERMIT NO. 8523-DB028 Page 4 of 4 e All reporting required in this section shall be submitted to: Alaska Department of Environmental Conservation Kenai District Office P.O. Box 1207 Soldotna, AK 99669 Phone (907) 262-5210 Alaska Department of Environmental Conservation Southcentral Regional Office 497 E Street, Suite 200 Anchorage, AK 99501 Phone (907) 274-2533 RECEJV' Anchorage PERMIT NO. 8523-DB028 Page i of 2 APPENDIX B GENERAL CONDITIONS A. Access and Inspection The Department's representatives shall be allowed access to the Permittee's facilities to conduct scheduled or unscheduled inspections or tests to determine compliance with this permit and State laws and regulations. B. Availability of Records Except for information relating to secret processes or methods of manu- facture, all records and reports submitted in accordance with the terms of this permit shall be available for public inspection at the Southcentral Regional Office of the Alaska Department of Environmental Conservation at 437 "E" Street, Suite 200, Anchorage, Alaska. C. Civil and Criminal Liability Nothing in this permit shall be construed to relieve the Permittee from civil or criminal penalties for noncompliance, whether or not such noncom- pliance is due to factors beyond his control, including but not limited to accidents, equipment breakdowns, or labor disputes. D. Property Rights The issuance of this permit does not convey any property rights in either real or personal property, or any other privileges; nor does it authorize any damage to private property or any invasion of personal rights, nor any infringements of federal, State, or local laws and regulations. E. Severability The provisions of this permit are severable and, if any provision of this permit or the application of any provision of this permit to any circum- stances is held invalid, the application of such provision to other circumstances and the remainder of this permit shall not be affected thereby. Notwithstanding the above, in the event such invalidation materially alters the scope or conditions of this permit, the Department shall have the right, at its sole option, to terminate the permit. PERMIT NO. 8523-DB028 Page 2 of 2 F. State Laws Nothing in this permit shall be construed to preclude the institution of any legal action or relieve the Permittee from any responsibilities, liabilities, or penalties established pursuant to any applicabble State law or regulation. G. Adverse Impacts The Permittee shall take all necessary means to minimize any adverse impact to the receiving waters or lands resulting from noncompliance with any limitations specified in this permit, including such additional monitoring as necessary to determine the nature and impact of the noncomplying discharge. The Permittee is required to undertake cleanup activities in the event of any adverse impact resulting from noncom- pliance. He Modifications or Changes Anticipated facility expansion, production increases or process modifi- cation resulting in changes to operation will be reported to the Depart- ment, at least 30 days prio~ to the implementation of such changes. I. Permit Availability The Permittee shall retain a copy of this permit at the disposal facility. J. Transfers Should operation of the facility be contracted or a change in contractors be made, the new contractor shall be notified of the existence of the permit and its conditions. A copy of the written notification shall be forwarded to the Regional Supervisor of the Department's Southcentral Regional Office, 437 "E" Street, Suite 200, Anchorage, Alaska 99501 (274-2533). K. Renewal Application for a renewal of this permit will be treated in the same manner as the initial application, except that public notice or hearing will not be provided for applications for renewal. ADplication for renewal must be made no later than 30 days before the expiration of the permit. L. Cultural & Paleontological Resources Should cultural or paleontological resources be discovered as a result of this activity, work that would disturb such resources must be stopped. The Office of History and Archaeology, Division of Parks and Outdoor Recreation, Department of Natural Resources, shall be notified immediately (762-4108). ..-..-.. STATE OF ALASKA ,--., ° A[ ".A OIL AND GAS CONSERVATION C~ ~ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension f-i Change approved program [] Plugging [] Stimulate [] Pull tubing .r-] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. feet 3. Address 6. Unit or Property name Post Office Box 100360 Anchorage, AK 99510 Swanson River Unit 4. Location of well at surface Sec. 33, T8N, R9W, S.B.&M At top of productive interval At effective depth At total depth 7. Well number SRU 21-33WD, SRU 41 - 33WD 8. Permit number 9. APl number 133-10162-00, 50-- 133- 10167-00 10. Pool · Ster l lng 11. Present well condition summary Total depth: measured true vertical See attached sl=hematics feet Plugs (measured) feet Effective depth: measured true vertical feet · Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth RECEIVED True Vertical depth Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) NOV 1 9 1981 Alaska 0il & Gas Cons. C0mmissl0n Anchorage 12.Attachments Description summary of proposal I-I Detailed operations program ~ We,~l sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed -d~, ~.,~.'~.._... Title Manager, Cook Inlet Engineering Date /////~/~"7 · · Commission Use Only conditions of approval Notify commission so representative may witness I Approval No. '7 [] Plug Integrity [] BOP Test [] Location clearanceI -- 7' Approved Copy Returned .~ ~ ='C'o~rn~;;i0ner Form 10-403 Rev 12-1-85 by order of the commission Oats !,/!'/'/~ 7 Submit in triplicate ~ PRESSURE TEST SRU 21-33WD AND SRU 41-33WD The AOGCC has issued Area Injection Order No. 13, applicable to Swanson River Field, effective March 16, 1987. In order to comply with Rule No.6 (the demonstration of mechanical integrity in the tubing/production casing annulus) a tubing plug will be set in the SRU 21-33WD and SRU 41-33WD and tested to 1500 psi. The attached procedures outline the steps that will be taken to conduct the test. The pressure testing is expected to be completed by the end of December, 1987. R~U.\"tn NO\! 1. 9 \~\b 7 Gomm\ss\on . ' Gas cons. A\as\(a Q\\ &. l\ncnorage SRU 21-33WD Pressure Test Production Casing Via Tubing PROCEDURE 1. Record pressmes on Ihe tubing and surface casing. The production casing is blinded. 2. Blow down the SC, recording all pw. ssm~ 3. Shoot fluid level in the SC for pump-in volumetrics (8/5/87: FL-2$' at 30 psi; annular volume=0.0282 bbl0ft). . Load the SC with lease warn' containing 10 gal/1000 gal WT 676 con, sion inlu'bitor and a $ bbl crude cap. If fluid level is the same then less than 1 bbl of lease crude is required to fill the SC. Do not exceed 300 psi surface Ine,s.mre during pump-in. Monitor ali plessures. NOTE: 48 hours prior to initiating pressure w. sting procedure, contact the AOG(X: 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 F~eld Area Injection Order No. 13. NOTE: During pressure tests of the tubing, closely monitor PC/SC packoff to insure no communication to the surface casing. If any communication is noted, cease pressure test and notify Anchorase. 5. Pressure test PC/SC packoff to 3000 psi. 6. RU slicidine unit. PT lubricator to 2000 psi. RIH with gauge ring and tng bottom. 7. RXH with 'DD' bridge plug and set in joint above the casing shoe at 2108'. , Install two pen reconier to monitor the tubing and SC during the test. Pressure tubing to 1500 psi Hold for 30 mlnut~S, BOring JnitJ~ ~ final presStU~ on SC and tubing. If the pressure bleeds off then reset the plug in another tbg joint to verify if it holds. Rew, st. 9. POOH with 'DD" bridge plug. If pressure test was successful then return to injection. · 193,00e - 1396' ':'' ' . ' .. ....................... 67 ',]'tS, .,t,~" ~ 9,2~ l~-a3 BU:ilF.,SS · - Ge ~ ..... ' I ~2108.~,' SH~ ~ ~ T~G ' .' ' ' . .' . ' " ' - ,. ' . ." " ' · - '. -. . · · . . . . '- , · " · . . · '1 ~ n~O:.t · 2S~5.~ . / ( TO~ ~ FSZZ ~. ~,~= "CC" ~T~ ~0=~. ) . 129,41, ~ ~, ~, ~/E~O:.I e 3022.~1' ~~~~~-~,oo.~, -,o~ ~ =~ S R U 21-3: 31m' CASING ~ TUBING DET 3162 _ s~CT,O. ~ T. ~_ n ~ct . · 12~-~ ;'.-: ARCO Alaska, In~/~''~ Post Office ..,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering September 2, 1987 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell- This letter is to inform you of the naming convention for the Swanson River water disposal Wells. We will be using these names in future correspondence and notices. The monthly injection report will be reissued from March, 1987 to include information on the disposal wells as you requested through Mr. Ronzio. Well Name API Number Old Name SRU 21-33WD 133-10162 SRU 221-33 SRU 41-33WD 133-10167 SRU 31-33WD 133-20336 SRU 32-33WD 133-10164 SCU 43-4 WD 133-10111 SCU 243-4 If you have any questions, please give me a call at 263-4299. H. F. Blacker Regional Engineer HFB'MLE:ch'O034 cc- Joseph A. Dygas, Bureau of Land Management D. Gann/J. Renfrow SRF J. D. Hales ATO 704 R. H. Larson KI W. M. Peirce ATO 1390 E. A. Raleigh ATO 700 G. S. Ronzio ATO 2020 T. Wellman ATO 1396 RECEIVED SEP o 9 / Naska Oil & G~s Cons. Commls81o~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 SWANSON RIVER FIELD - UNIT 051950 09-Sep-87 August 1987 I Name of Operator Fi eld and Pool Month and Year of Injection ll. WELL NO. 514-4 525-4 352-4 541-4 541-8 512-9 1412-10 521-9 143-4WD 2. APl NUMBERIS. C14. FIELDIS. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION I 50- I LI & F'OOL I IN I I I I l I Al CODE I OPER 16. MAXI7. AVERAGEI8. MAXIg. AVERAGEI10. LIQUID Ill. GAS I 15. LIQUID I 14. GAS I I SI I I PSIG I PSIO I PSIG I PSIG I (BBL) I (MCF) l___SI I I ...... l I ...... l I l 155-10104-00 IG I 7721A0 I .SA 15,450 I 4,958 15,500 I 2,559 I I 59,259 15.5-10106-00 IG I 772100 I 0 I 0 I 0 I 0 .I 0 I I 0 155-10107-00 IG I 772100 I 50 15,500 I 5~005 11,040 I 656 I I .51,652 155-10109-00 IG I 772100 I 50 :5,550 I 5,141 12,860 I 2,.576' I I .57,120 1.55-10120-00 I G I 772100 I 0 I 0 I 0 I 0 I 0 I I 0 155-10125-00 IG I 772100 I .50 15,.550 J '4,945 ll,240 I 1,109 .l I 40,48.5 1.55-10126-00 IO I 772100 I 50 15,.500 I 4,928 12,600 I 2~.568 I I .55,148 155-101&8-00 lO I 772100 I 0 I 0 I 0 I 0 I 0 I I 0 155-20206-00 tG I 772100 I 0 I 0 I 0 I 0 I 0 I I 0 1.5.5-10125-00 :~ I 772100 I 50 15,450 I 4,991 ;1,960 I 1,815 I I 25,706 15.5-10111-00 ID I 7720.56 I 0 'I '0 I 0 I 0 I 0 ~ 0 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- 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 l 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 I I I I I I I I I I I I I I I I I I I I I 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 1 ~ 177~ 165 C) 948,955 1,115,609 0 I ~214~475 I , 054 ~ 428 I 0 1 I 0 1 I 771,182 0 I I I I I I I I l I I I I I l I I I I I ' ; , I l I l I I l l I ....... ' I I I I I l ...... I I I I II here~y certify that the foregoing is true and correct to the best of my knowledge 115. I I I I I l lSignedl -It'/, ~.. ,. 2~Z~~' I I -9:.-,~-, : : I I l I I I I ITitle /¢! ./'.,c ix-"i-'J z~(~c'~, Date ~ 7 ITOTAL I 0 I 6~279,814 I I I Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION.REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051994 Field and Pool August 1987 Month and Year of Injection 11. WELLI2. API NUMBERIS. CI4. FIELDI5. DAYSI TUBING PRESSURE I CASING PRESSURE |DAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION ~ NO. | 50- I LI & POOL I IN I I I I I l___SI ........ 1312-22 1133-10147-00 IG I 772100 ~514-27 1153-10154-00 IG ,I 772100 ~551-27 ~153-1015&-00 IG I 772100 1432-15 ~153-10141,00 IG I 772100 121-55WDI155-101&2-O0 ID I 77203& 151-33WDI153-2053&-O0 ID I 77205& I52-35WDI.153-101&4-O0 ID I 77205& 141-33WD1153-10167-00 ID I 772056 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I : : : Al CODE I OPER 16. MAXI7. AVERAGEI8. MAXIg. AVERAGEIIO. LIQUID Ill. GAS (BBL) I PSIG I PSIG I PSIG I PSIG I I I ...... I I I I I I I I I I I I t I I I 875 I 734 I I I 2,675 820 I 746 I 0 I 0 I 2,770 875 I 759 I 0 I 0 I 2,071 850 I 751 I I I 145 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 I I I ' I I I I ' I I I I ' I I I I I I I ' I l ...... I I 29 .50 30 (MCF) , II hereby certify that the foregoing is .true and correct to the best of my knowledge , I I I Si gned I I I ITitle I Form 10~05 Rev. 12-1-85 Date ~ /~ ~-~/~ 7 INSTRUCTIONS ON REVERSE SIDE 115. I I I : I ITOTAL I 15. LIQUID I 14. GAS (BBL) I (MCF) I 1 77,581 80,518 62,119 4,352 224,570 Submit in Duplicate PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY UNIT S-11 UNIT S-14 UNIT T-1 UNIT T-7 UNIT U-3 UNIT UNIT U-5 UNIT U-9 UNIT U-lO UNIT X-6 UNIT X-11 UNIT X-23 UNIT X-24 bNIT X-26 UNIT Y-3 UNIT Y-5 UNIT Y-6 UNIT Y-7 UNIT Y-11RD BAY UNIT Y-18 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL SWANSON RIVER, HEMLOCK OIL POOL ARCO ALASKA INC SOLDOTNA CK UNIT 314-~ SOLDOTNA CK UNIT 323-4 SOLDOTNA CK UNIT 332-~ SOLDOTNA CK UNIT 341-4 ' SOLDOTNA CK UNIT 341-8 SOLDOTNA CK UNIT 312-9 SOLDOTNA CK UNIT 321-9 SOLDOTNA CK UNIT 323-9 ............ SOLDOTNA CK UNIT 412-10 SOLDOTNA CK UNIT 343-33 UNIT OR LEASE TOTAL 264,425 174,467 380,162 602,357 31 515,072 31 264,751 31 183,322 31 2~4,173 31 29~,661 31 149,980 31 173,54~ 31 262,057 31 282,344 31 76,492 31 49,131 31 84,323 31 22,223 31 43,679 31 306,429 31 14,519,526~ 39,536,156 84,~5,002 39,536,156 88,810,140 SOLDOTNA CREEK UNIT SHUT-IN SHUT-IN 1,148,650 31 1,080,598 31 871,402 31 1,090,6.70 31 153,799 6 1,2h6,967 30 749,378 31 1,089,518 31 7,q30,982 6:975:0~0 7,115,160 1,2~1,472 2,275,7al 2,727,957 2,791,~76 2,551,632 1,790,980 1,767,557 6,174,166 5,618,096 3,530,3~2 5,273,083 3,169,181 3,9~2,403 1,968,753 2,653,q03 102,640 597,32~ 6,~09,296 1,388,876 294,7~2,9'15 233,327,280 207,759,3b0 231,764,932 218,694,647 304,044,302 33,033,842 170,911,513 111,/413,676 - - ENHANCED RECOVERY - - WELL NAME AND NUMBER ARCO ALASKA INC SWANSON RIV UNIT 331-27 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL TRADING BAY, MIDDLE KENAI C OIL POOL UNION OIL CO CF CALIFORNIA ADL-18731 TRADING BAY ST. A-5RD-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-18731 TRADING BAY ST A-5RD-Z TRADING BAY ST A-19 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL ALASKA INDIVIDUAL WELL PRODUCTION FOR MARCH, 1987 OIL(BBL) WTR(BBL) GAS(MCF) DAYS b't4ANSON RIVER UNIT SHUT-IN 7,k30,982 7,#30,98Z SHUT- I N SHUT- I N I '- '- ' SHUT- I N ! ~ // SHUT- I N ,. · / ,.; · SHUT- I N ' SHUT- I N CUM. OIL CUM. WATER ~13,934 15,582,616 h,~98,822 6,267,061 7,3~8,68~ 21,618,136 CUM. GAS 28,263,659 TABLE I Wells under Evaluation for Rate Potenti al 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 Uti 1 i ty 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown , 43A-15 314-27 331-27 ~'~343-33 ATTACHMENT Injection Well Data Water Disposal. Avg. Wells Rate(BPD) SRU 31-33W 327/+ SRU 32-33W 651 SRU/+1-33W 125 SRU 21-33W 2805 scu/+3-/+w.; .... Max. Rate(BPD) /+500 /+500 /+500 /+500 /+500 AVg. Press(psi) 769 778 913 735 Shut In Max. Press(psi) 1000 lO00 lO00 1000 1000 Depth of mj.(~t.) 2100 2100 3100 Depth of Well(ft.) 2/+61 2520 3000 6660 Gas Injection Ave. Wells Rate(MCFD) Max. Rate(MCFD) SCU 31#-2 39,950 SCU 323-/+ 35,680 SCU 332-/+ 27,6/+0 3t~ l-t~ 37,6/+0 !U 3/+1-8 30,300 :U 31'2-9 /+/+, 000 SCU 321-9 29,9/+0 scU 323-9j ~ 35,920 SCU 3/+3=33 0 SRU 332=15 0 SRU 3t2-22 0 SRU 31/+-27 0 SRU 331-2~7 ~ 0 /+5000 /+5000 /+5000 ~5000 /+5000 /+5000 /+5000 /+5000 /+5000 /+5000 /+5000. /+5000 /+5000 5075 5370 5095 5355 5160 5270 5155 5105 Shut In Shut In Shut In Shut In Shut In 6 7 4 z. 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 1080/+ 11520 10775 11119 10850 1081# 10785 107/+5 10750 10995 11982 11000 11620 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051~4 Fi eld and Pool December 1986 Month and Year of Injection 151.2-22 -~514-27 ~i:~i! ~ ~51-27 '~:~ 452-1 I I · I II. WELL~2. API NUMBERIS. C~4. FIELDI5. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION I NO. 50- I LI & POOL I IN I I I I SI I I___SI I 155-10147-00 I G I 772100 I - 155-10154-00 I G I 772100 I - 155-10156-00 I G I 772100 I - 155-10141-00 I G I 772100 I - Al CODE I OPER 16. MAXIT. AVERAGEI8. MAXI~. AVERAGEIIO. LIQUID Ill. GAS PSIG PSIG (BBL) I (MCF) I PSIG I I PSIG 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 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 II hereby certif~ that the forego~:ng is true and correct to the best of my knowledge //,/ /~ ~ .. Supervise, New Ventures ~ompl~ance and ~evenue I Title Date __~ ...... Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I15. TOTAL I I 15. LIQUID I 14. GAS I ; i I I 0 I 0 I Submit in Duplicate I (BBL) I (MCF) 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 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051950 Field and F'ool December 1986 Month and Year of Injection ~1. WELL~2. API NUMBER:5. CI4. 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 Al CODE ~ OPER 16. MAX~7. AVERAGE18. MAX~9. AVERAGEIIO. LIQUID ~11. GAS ~ 15. LIQUID ~ 14. GAS I ! ~ SI I I PSI8 I. PSIG I PSIG I PSIB ~ (BBL) : (MCF) I (BBL) ~ (MCF) 514-4 1155-1,0104-00 525-4 1155-10106-00 552-4 1155-10107-00 541-4 i155-10109-00 541-8 1155-10120-00 512-9 1525-9 1545-55 1412-10 521-9 I l___SI I I ...... I I ...... I I I I I I 772100 I 50 15,500 I 5,015 12,500 I 1,560 I I 52,501 I I 975,018 I I 772100 I 15,650 I 5,278 15~250 I 1,976 I I 29~526 I I 885,785 I I 772100 I 50 15,500 I 5~071 I 700 I 594 I I 24,058 I I 721,155 I I 772100 I 50 15,550 I 5,157 11~200 I 849 I I 29~951 I I 898~524 I 772100 I 50 15,500 I · 4,882 11,400 I 1~548 I I 25,121 I I 695,626 I 155-10125-00 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 155-10126-00 IG I 772100 I 17 15,200 I 5~140 11,600 I 1~588 I I 25,550 I I 450,602 I 155-10168-00 IG I 772100 I 0 I 0 I 0 I 0 I 0 I I 0 I I 0 I 155-20206-00 IG I 772100 I 0 I 0 I 0 I 0 I 0 I I 0 I I 0 155-10125-00 IG I 772100 I 50 15,540 I 5,150 11.,600 I 1,089 I I 20,970 I I ~29~091 I I I I I I ~ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I . I 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 ~. ~' ~ ~ ~l l I I I I I I I I I I~?,l''~ -- ~ ~ I I ,p~_~.~._, | II hereby certify that thee foregoing is true and correct to the best of my knowledge 18i gnId . I s Co P , pliance and Revenue ITitle Date ........ I Form 10-405 Rev, 12-1-85 INSTRUCTIONS ON REVERSE SIDE 115. I I I I I I ITOTAL I I I I I I 0 I 6~288~655 I I I Submit in Duplicate 'h LEASE NO. JENHANCED REC0VERYJ COHP.DATE + + STATUS PRODUCT JAN FEB NAR ALASKA INDIVIDUAL WELL'~ODUCTION FOR 1986 APR MAY JUN JUl. AUG . SEP OCT NOV BFC YEAR TllTAL CUM ~~m~ SWANSON RIVER, HEMLOCK ARCO ALASKA IN'C SDL~OTNA CK UNTT ~14-~ API UN]T051950 O]L '08/15/60 HTR 1GINJ GAS 1055857 1026590 1189909 1165806 1228646 1211657 1257286 1288552 1505704 1125075 1022955 975018 15808655 291785545 SOLDOTNA CK UNiT 223-6 APT UNIT051950 0IL 06/01/61 HTR GINJ GAS 926806 895795 1014489 1021515 1095847 1095954 1110742 1160265 1165222 9868~7 950909 885785 12505942 25016877~ Sn[DDTNA CK UNIT 3~-~ AP[ UNIT051950 0IL 06/05/60 HTR 1GINJ OAS 729520 694699 694'207 768554 848986 808659 855755 906429 908925 775879 755048 721155 9465572 20555481b" SDLnnTNA £~ UNTT . ~1-~ APT ] RR-~ fl].nq-nn UNIT051950 0IL 05/21/60 HTR 1GINJ OAS 964182 959897 1105310 1004702 1191650 1125455 1151894 1167267 1142665 989567 1047597 898524 12728466 228845715 SntBnTNA CE UNTT ~I-R APl UNIT051950 0IL' 07/14/61 HTR 1GINJ GAS 772050 721011 855765 795562 858795 851801 877466 885419 861454 802085 790782 695626 9761772 217114264 UNIT051950 0IL 10/09/60 HTR 1GINJ GAS 1150860 1105246 1275468 1219454 1266462 1242821 1268188 1518592 1512222 1120415 1159677 105.4878 14454281 5007845~5 5~LO~TNA C[ UNTT 3~1-9 AP! UNIT051950 0IL 07/19/61 HTR 1G[NJ GAS 787999 770786 941516 857121 859651 824009 859794 852454 865441 701058 657884 629091 9546564 51111755 SnLOOTNA CE UNIT 323-9 APT UNIT051950 0IL 07/17/61 HTR 1GINJ OAS 868162 887705 1057404 1002092 1041454 1027008 1054526 1105448 1110180 1002927 967125 450602 11552455 168145955 SOLOBTNA CK UNIT 412-10 APT AP1 133-101~8-00 15888, ,) 111415676 4018206 9029539 2056925 4645550 UNIT051950 OIL 06/11/72 HTR · 1NINJ GAS SOLBOTNA CK UNIT UNIT051950 0IL 03/08/61 HTR ' 1GINJ GAS -.. SHANSON R[V UNIT UNIT051994 0IL 10/26/59 HTR · 1GINJ GAS SWANSON R[V UNIT UNIT051994 OIL 0~/04/61 HTR 1GINJ GAS AP1 133-10161-00 36-15 APl 133-10142-00 II! !!! LEASE NO. IENHANCE9 RECOVERYI C0HP.DATE ~ STATUS PRODUCT JAN FER MAR ~~ SHANSON RIVER, HEMLOCK SHANSON RIV UNIT 312-22 API UNITOSiqg4 OIL ALASKA INDIVIDUAL HELL~ODUCTION FOR 1986 'APR HAY JUN JUl AUG SEP 133-101~7-00 YEAR OCT NOV DEC TrlTAL CUM. 08/11/62 HTR ZGINJ GAS SWANSON RIV UNIT UNIT05]gg4 0][ 314-27 API 133-10154-00 873988 24017269 06/14/60 HTR 1GINJ GAS SWANSON RIV UNIT UN]TOSIg9~ OIL 331-27 API 133-10156-00 78332178 02/17/58 HTR 1GINJ GAS ARCO ALASKA ]NC OPERATOR TOTALS Oil HATER 8,337,995 POOL TOTALS GAS 7,041,527 7,832,406 8,187,502 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,596 8,115,868 8,$69,449 8,393,451 8,667,789 7,311,775 93,601,665 SHANSON RIVER. HEMLOCK OIL HATER 8,337,995 FIELD GAS 7,041,527 7,832,q06 8,187,502 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,596 8,113,868 8,369,449 8,393,451 8,667,789 7,311,775 93,601,663 SWANSON RIVER TOTALS OIL HATER 8,337,995 GAS 7,041,527 7,852,406 8,187,502 8,680,226 7,499,819 6,288,655 1,929,187,'01" 7,215,596 8,113,868 8,369,449 8,393,451 8,667,789 7,511,775 95,601,665 ,~ REPLY TO ATTN OF: ~/S 409 U.S. _NVIRONMENTAL PROTECTION AG,.,~ICY REGION 10' 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 ~AR ~ {986 J. L. Weaver Area Operations Superintendent Chevron U.S.A., Inc. P.O. Box 107839 Anchorage, Alaska 99510 Dear Mr. Weaver: Thank you for your letter of February 4, 1986, which discussed your plans to demonstrate mechanical integrity for injection wells SRU 41-33 WD and SRU 21-33 WD, Swanson River Field. ~ We have discussed your proposed tests with both AOGCC and BLM representatives, and we are in agreement that the tests should adequately demonstrate mechanical integrity. Please be advised, however, that EPA .. regulations at 40 CFR 146.8(d) require that these tests be approved as "alternative mechanical integrity tests" in order to meet the mechanical integrity testing requirements in 40 CFR 146.23(b)(3). Upon receipt of the .. test results, we will evaluate the data for approval as an "alternate" method. Please provide us copies of the logs and complete descriptions of the testing procedures at your earliest convenience. Sincerely, cc: v~c.v. Chatterton, AOGCC Joe Dygas, BLM irector~ Water Division r¡,~\.. /J-t-.~ . / /). ~/? t,-'i \:,.: . 0 ~ fZ?' ,( <. f I' (I" /'~~~. "-~ . I I ~) " .~ '1 f '. /-/ . DEPT. :...{l //""/ÿ'~'1 j;V [' ',"/' +;,.¿'ll,~~ PLACE: ?,'¡'}/ !i~'rJ¿'; /1/ .(7('//y A TI' : J/(~,. ~~~;)} J¿ø~ i/ .~~ ~"(,7' , ; DATE / /// ,,;;.,/rl/ ,'-'?:: - ,1 &- -.....:. ..' R - rgJr' _ \.... . . F - X'- Œ7- Che\lrtl1 ~ '~®' . c.HEVRON U.S.A. ~ . TR.^..NSMITTAri ACKNOWLEDGEMENT OF RECEIPT 01:'~ MATERIAL .. - .. ,~ I~')J ,: >.') / //:://-'L .., THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE (iJ ¡/f . f..3f(;K a1~..' ~3š ". ? /;' ' ,/ ;1 'I <)" -/];-33 .-¥/J"//Z¿1¿-râ(í.'( U¡L.jt¡l r't,N} /: J ~ . 1 _ /" " /)..' / '] r ': / ,f <L" ", (·f.. l;f7?"1'/',d...~ ;;L~d." I / .-l:2:Jž¢c'¿4~~2///~;¿;',1~/"· - - -'- ¡¿~/I ,,¢. <'i'/(._?Nf' 1;~ ¡;;'ær/ 1d/~~7 )s/s:tL (> )Ñ~d jJfZ':~ (,'£¿4Î/:/ ð~:r/¿j~¿ --= - -- IÞ~¡/:# fI-;:') . ~~1ð-¿-:7'?()¥!/( ~ -~? tAr;> ;;) J;rf";,?,ZfL~/;'j (-;' ~I~(/Æ/I,~~~?r -- æ, ~/f/ /7/77 II Ci,.'~ ~)~ -- --- -- -- -- " . -- -- -- -- ... ~- ---- '\/f-r' D [ r C t " i" ~ ; ~ \. L>", !..! ',' ., . ,/' -- .:.-- ., : :. ,", ," :If~(:n , I, ; 1"1 f" V ..~"':'"'''' r-', '.) '.1 -' -r-- ,-- ~\asl~3. Uli Ù 0ì.'~ ~j F\nc:~¡::r2º3 ! ,;\~;~"t~t~~-:: -- - --- ....-..-. ---- -- ......-..- --- --- ---- .;,~:;i1~/:!føA:v,~~- -. BY (~~~:~~í¿{~!~~~4~ pr..~^Q)'·<: ('HI f'lTI-Je'C cine YUIC c\...IC"'T.'" '~ ~ ........ ...--..l:' t, ('" \; ~ I 1\ --y, ~"t'!.' r"\ I-'re'hi P.- 7 SUBMIT IN DU,. 2ATE* · . STATE OF ALASKA (so,, other st ructions on rever,~e side) OIL AND GAS CONSERVATION COMMITTEE I ~ III IIII I I WELl_ COMPLETION OR RECOMPLETiON REPORT AND LOG* la. TYPE OF WELL: oil, [--3 w ELL b. TYPE OF COMPLETION: V.' E L I. OVER EN I I I WELL Dna' Other Waste Water D|sposa] , 2. NAME OF OPERATOR Chevron U.S.A. Inc. 3. ADDRESS OF OPERATOR P. O. Box 7-839 4. LOC~T~OX O¥ WELL (Report location clearly and in accordance with any State requiremet~ts)* At su~ 560~ south and 2110' East of N,W. Cot. of Sec. 33, T8N, R9W SB&M At top prod. interval reported below same At total depth same ~.?25-80 J 6-30-80 206'KB 18. TOTAL DEPTH, Nm & TVD ~9. PLUG, B~CK MD & TVD~. ~ 1VrULT~LE CO1VLPL., J 21. 3805'~MD 3805' TVD J24501 MD 2450' TVDJ aow~. ~ .O~R~Too~ =~PRODUCING !NT~iRVALCS>, OFT HIS COMPT_JgTION--TOP, BOTTOM, NAME (1VIDANDq[~fD)' Top 2~20' MD 2~20' YVD~ BOt. 2438' MD 2438' YVD 8. UNIT,FA-Fq2Vi OR LF.,kSE NAME Swanson River 9. WELL NO. SRU221-~qWJ 10. FLELD A,NI~ ~OOL, OR WIL,DCA. T Swanson River 11. SEC., T., R., M., (BOTTOM HOLE OI~MECTIVE) Sec. 33, T8N, R9W SB&M 12. PE'H,MIT N'O. 2-62 E~EVATIONS tDF, RKB, RT, GR, ~C)* il7. ELEV. CASiNGtiEA. D ! . J 190'Gr. INTERVALS DRILLED BY CAUt,E TOOLS 23. WAS DIRECTIONAL SURVEY MADE 1 24. TYPE ELECTRIC AND OTHEI{ LOGS RUN II~, II ~ ,I -- III i il I i Ill ¢~$~ATG ~ORD (Report ~H strings set i:z w~'~D 20" ' 'J' 33' '" [' J' Driven None ' 9-5/8'l 40 ' . J 1396I ' J 13 3/4't 800 sacks None ~' &~5½I' 23 & 17 ' I 31491 ' ] 8 3/4""J 6oo s'~cks 'None ' 3j½jlj I ~ 9' 3 J J 2108,j j IJ IIII l ' 2095 sacks i None , I' I . I · I I ! II 111 lJ I I I 28. PERFORATIONS OP~--iNT TO PRODUCTION' (interval, size and number) 29 'ACID St,OT F;~z~"[O'Rw CF.Z',II:NT SQUrvZ.~ ETC 20-2174' 2194'-2296', 2350-2394' and 2402"-2438' x Eight ½,1 jet holes per foot I IIII I I II 30. PRODUCTION DFa-a2~Ii 1NTEI-~V.~L (MD) JAM, OUN£ Z~ND I'LiND OF MA3. E~,UAL, USED Per6s 2120' to ~2..~5 bbls of 12.~ HCL and 3% 2438' IHF with 900# of DiVerting ,lAgent in stag~,s ,' ', DA'rE FIRST Pf~ODUCTION [ FP~0DUCTION NEll{O!) (Flowii)g, gas lifL pumping--size and type o£ pump) JVv'ELL STATUS (Producing or .7_-2-87 /[ Injecting Waste Water .' ._ " i . WSPOS~XUON or ~as (Sold, used lorluet, vented, etc.) 32. LIST OF ATTACHMENTS 33. I herebycertify that the fo~nt)ttache..d information is complete~)~[i/~ as determined from alUavailablc records storm) R. W. HAGEjE 'f/(~ ,~,~~ Area Engineer ~?~: _~,. ii m *(See JnstructioEand Spaces For Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report e~d tog or~ all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attach,merits. Items 20, and 22:: If this well is completed for separate prcduction from more than one inlerval zone (multiple completion), so state in item 20, and in item 22 show the plcJuc~:~0 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 produce~, show- ing the ac~Jitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ 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 inlerval to be separately produced. (See instruction for items 20 and 22 above). ~tY OF' FORMATION TESTS 1NCLU[)IN(; INTERVal., TESTED. PRESSURE DATA. ~ ~C~VERI~ OF OIL'. GAS. 35. G~GIC MARK~ WAT~ AND MUD I ,, , ,, Form 10-403 REV. 1-10-73 t~ Submit "1 ntentions" in Triplicate , ~ & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OIL r-1 GAS B OTHER WELL~ ~ WELL, 2. NAME OF OPERATOR CHEVRON U,S,A. INC, 3. ADDRESS OF OPERATOR P. O. Box 7-8}P 4. LOCATION OF WELL At surface Waste water disposal Anchoraqe, AK 99510 560' south and 2110' east of N. W. corner of section 33, T8N, R9W SB&M 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 206' KB SHOOT OR ACIDIZE REPAIR WELL (Other) 14. CheCk Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE ABANDON* CHANGE PLANS 5. APl NUMERICAL CODE 50-133-10162 6, LEASE DESIGNATION AND SERIAL NO. A-028399 7. IF INDIAN, ALLO-i:~EE OR TRIBE NAME 8, UNIT, FARM OR LEASE NAME SWANSON RIVER UNIT 9. WELL NO. SRU 221-33 WI 10. FIELD AND POOL, OR WILDCAT SWANSON RIVER 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) ,~sec. 33~ T8N, R9W SB&M 12. PERMIT NO. 2-62 )ort,*Or Other Data SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. 1. Move in snubbing unit with 10000 psi BOPE equipment and 3000 psi stripper. 2. Clean out to 2450' using lease produced water· · Reperforate 5-½" casing with four ½ jet holes per foot from 2438-2402', 2394-2350', 2296-2280' 2262-2194" and 2174'2120' 4. Acidize perforations with 10000 gallons of 12-3 HCL-HF 5. Return well to water disposal. · A tracer survey will be run within 90 days after completion of this work. Follow-up tracer surveys will be run on a semi-annual basis as lo. ng as this well is injecting. (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: ARFA FN~INEER DATE COMMISSIONER TITLE BY ORDER OF DATE See Instructions On Reverse Side ' CbMPANY'~' J"ANDA R D LOCAT~ON'~ LA.'~KA SAMPLE SOURCE ~QNE :".~:.::'~ ...... '""IL,., B/D ' WATER 8/O GAS MCF/D OIL GRAVITY ·METHOD '' .~_.AMPLE DATE 9/!0/~4' ' "-~ORT DATE 9 / 2. 5 / 6 4 LABORATORY NO. 3 0 9- 6/-, IN- 8, b 6 SAMPLED BY ' ANALYST R C LOEB RADICALS ... __ PARTS PER MILLION SnU l U:.! II93.4 C4LCI Ut'4 ' . 98.2 NA.'.;t~E 3 1UH - ' 76.9 ,' · SULFAFI: .' C~iLOR I L)E .~ 866.3 - , CA:~Bm:A rE ' · o. BI CAKk~U~ArE · - TOIAL E~UI VALENT SALT-= '2'i5.0 ..'. CtlLI'IRINII'Y = L79~-72 HYDROGEN SULFIDE ABSEN[ _ REACTING VALUE REACTING VAL~JE EQUIV. PER MILLION P~RCENT 56.Z6 .... 4.1.68 4.90 · 3°63 6.33 - 4°69 · 0.06 0.04 · .. 5Z.64 ' 39.00 OD OD 14.79 , . '10.96 134.97 · i00;00 · G/G, RESiSTIVIIY =' 1.450 OHH-NETER AT SPECIFIC'GRAVITY =1.0045e PH = 7.91 .e CtlARC;L U SIGNED-R YAMADA, · CH'I+Br APPROVEi:/: ~ E F ! E 13 E · ! 'DMsion of 0tl and Gas Conservation: Anchorage . · . I=IGI 1/ ~ELL FILE · ' ' " ' ' "- - -' '- ' -,~': ' '*' i~..'~ . · . -. -. : · .:- ... , _. -... . . ,*, '* . ...... · . . . '.. , ,.' ·,,- : : , , --~.. .' - - .- - - ' - '..' ' _' -. , o- - -." - . . .'. · . I . ,, ; ,e~o: ., . , '-- -- . .......... ': ., e' .. '. '. -,. ~.:- , .- ..- -~ -. '- -.'- ;-;-.'.~:- .:.,-~--,-.'*-..';';~-'~.:~.;-:;~?.*.".'-,'-;..';..,:~.~' ".. :...". ;..-'.' ..,:; '.;i':- . 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LiI'' lC L/~BO!~ATORY · ' , IICL, IST SECt JAN 2B 1977 '-- · La Habra, California WASTE WATER ANALYSIS SWANSON RIVER, ALASKA Project B0, 28~6 April 15, 1989 SRF1 Cations - Mg/Liter Sodium Potassium Ammonium Calcium Magnesium Barium Iron 5200 '5800 ;4600 100 95 ~ z~O 35 · 27;40 1610 ;4010 .105 85 105 ~5 60 25 ..2.1 2.6 1.5 Anions - Mg/Liter ' Sulfate Chloride Hydroxide Carbonate Bicarbonate Borate .Iodide Silica 25 12840 0 0 .... ~..-'. ..... --~; :,~ 930 ;tO " 65 .-. · Organics (DiethYleth~er)Mg/Llter " Salinity as Salt Mg/Liter TOtal Dissolved Solids Mg/Liter Suspended Solids Mg/Liter Turbidity-Equivalent Mg/Liter as Kaolinite Suspension Specific Gravity - @60°F Resistivity Ohm-Cm ~75°F Freezing Point °F Viscosity C'Poise @ 72.7°F pH 21,170 22,140 '~-~ 36' 125 1.o19 29.5 29. ;46 0.955 6.40 Trace 50 11770 14180 0 0 o 0 915 825 35 3O lO. 15 ~o ~o 39 ;46 19,400 23,370 20,460 24,000 23' . 6 82 1.o18 31.2 29.30 0.996 6.26 55 1.02O 26.8 29.57 z.oo3 6.75 The three water samples were d~signated as follows: SRF1 - Discharge of water injection pump from waste water pit. SRF2' Discharge from sou waste water line into pit. SRF3 - Discharge from SRU waste water line into pit, , RECEIVED ',JAN 3 8 1977 Division of 011 and Gas Conservation Anohorage FIGURE 2 Form P--3' REV. 9-30-69 Submit "Intentions"'in Triplicate & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATIO, N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (DO not use this form for proposals to drill or to deepen Use "APP-LICATION'Fo~ ~'ER~i'I)-L~' 'for sUch 'p~o~osal~J . OILwE,~L ~ GAS WELL [~ OT.ER Waste Water Disposal Well 2.NAME OF OPERATOR Standard 0il Company' of California, W0I 3.ADDRESS OF OPERATOR P.O. Box 7-839, Anchora~e~,~ Alaska 99510 4.LOCATION OF WELL At surface 560' South and 2110' East of the NW corner of Section 33, T8N, R9W, SB&M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 206 ' KB 14. Check Appropriate Box To I,ndi'cate Niature of NOtice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI,ETE sHooT OR AC,DZZE I J *BA~DON* REPAIR WELL CHANOE PLANS I Other) 5. AP1 NUM.ERIC~ CODE 8. LEASE DESIGNATION AND SERIAL NO. A-028399 7. IF INDIA.N, ALLO'i-rI~E OR TRIBE NAME 8. UNIT, FAPu'VI OR LF.,ASE NAME Swanson River 9. WI~LL NO. ,, ~gU 221-3~ 10. FI. ELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOI.~ OBJECTIVE) Sec 33, TSN, R9W, SB&M 12. PERMIT lifO. ~ort, or Other Data EUBBEQUENT REPORT OF: WATER SHUT-OFF REPAIBINO WELL FRACTURE TREATMENT ALTERINO CASINO SHOOTING OR ACIDIZINO ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. 1. Killed well with 90 pcf mud on 6/17/72· 2. Installed and tested 3,000 psi BOPE. 3. Cut and recovered tubing at 2617'. 4. Set cement retainer at 2590'. 5. Layed 30 sack class "~i cement plug on top of retainer. 6. Ran'3½'' N-80 Buttress inner string to 2091'. · 10. - Cemented inner string with 250 sacks of Cement. Ran inside 3½" buttress and drilled sho6~ at 2018' and cement to 2110'. Cemented down annulus at 193' with 45 sacks class "G" cement. Cement to surface at 8:30 A.M., 7/9/72. Released rig at 10:00 A.M., 7/9/72. TITLE Dist· Superintendent DATEAURUSt //, 1972 (ThlB space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side REV. 9-30-67 & "Subsequent Reports" in Duplicate OIL AND GAS COMMITTEE SUNI~Y NOTICES AND RF.~OR?$ ON W[I..i,~ (DO not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. A-028399 OILwELL ~. OAS -I" '.e-"~F©L "~ WELL r~ OT~EB And Wast:e Water Disposal Well . '2. NAME OF OPERATOR "8. UNIT, FA-H1VI OR LF-d%SE ,A/VIE --3 OEOL '~ ADDREsSStandardoF OPERATOR0il' Company of California; W0I .I 9. gwans°nw~L ~o. River Unit I DRAFT I . ?, O, Bo× 7-839 Anchorage, Alaska 99510 SP, U 221-33 --~ii~---'~ At surface Swanson River CONFER: 560' South & 2,110' East of the NW corner of Sec 33, o~JEcrzvm T8N, R9W, S B & M. Sec 33, T8N, R9W, SB & M , . 13. ELEVATIONS (Show whether DF. RT. GR. etc. 12. PER1VIIT 1~O. I 206 ' KB I Clteck Appropriate Box To I~ndicate 'N~ature of NIotlce, Report, or Other 'Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF II PULL OR ALTER CASINO I I FRACTURE TREAT I--I MULTIPLE COMPI.ETE SHOOT OR ACIDIZ]] II ABANDONS REPAIR %'.'ELL CHANCE PLANS ~UBIEQUENT REPOR'~OF; FRACTURE TREATMENT XLTERIN0 CASINO SHOOTING OB ACIDIZlNG ABANDONMENTS (Other) (NOTE: Report results of multiple completion on Well tOther) Completion or Recompletion Report and L,',og form.) "~5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an~' proposed work. We propose to change the Sundry Notice dated 5/31/72 & approved by your office on 5)/~.1/7~ to the following: . 2. 3. 4. 5. 6. 7. 8. NOTE: Kill well w/ 78-80 pcf mud. Install & test 3,000 psi BOPE. Cut & recover tubing to 2,57-.2'. Perforate 5" casing at 2,570' +. Set a cement retainer at 2,565T & squeeze w/ 50-100 sacks. Spot cement above retainer to 2,450'. Cement 3 1/2" Buttress inner string at 2,110'. Recomplete well as a single zone-water injector only. Verbally approved per telephone discussion 0. K ' 6/5/72. 16. I hereby c~y ghat :.ghs f~$oing ts true and correct (Tht~ spa~/for - z:- TITLE District Superintendent State office use~9 - CO~DZT~-O~S O~ a~l'~O~,~ ANT: '--~9' See 1,nstrucflons On Reverse Side Approved Copy Returned '"' % ,t~ · DER J F~rrn P--3 S~brnit "intentions" in ~pli~ ~V. 9-~9 & "Su~que~t Repo~s" m Dupli~te C~ STATE O,F A~KA ~ ~'~ SUNNY NOTICES AND REPORTS ON W~ use "~CA~ON 'YO~' ~'~'~" ~or ~ucb 'p~osa~0 S~a~da~d 05~ Compaq7 o~ Ca~o~a, ~0~ S~a~o~ ~$~e~ ~'3 gEOL 3. ADD~SS O~ O~O~ 9. ~ ~O. ~t~-~e~ 560' south and 2,110 ' east of ~ corner Swanson River of Section 33, T8N, R9W, SB & M. u. sEC..omEn:w) ~', ~"~" mowo~ Sec. 33, T8N, R9W, SB & M. 13. ELEVATIONS (Show 14. 206' KB Check Appropriate Box To Indi'cate N, ature of N~ti'ce, Re NOTIC]~ OF INTENTION TO: ~ort, or Other I)nte l SUBSEQUENT REPORT OF: FRACTURE TREATMENT j--J ABANDONMENT ' ' Z TEST WATER SHUT-OFF ! PULL OR ALTER CASING X WATER 8HUT-OFF REPAIRING WELL SHOOT OR ACIDIZE -- ABANDONe _X__ SHOOTING OR ACIDIZING nEpAIR WELL I ~ CHANOE PLANS_:1 ,,I,i (Other) CNOTE: Report results of multiple completion on Well ~OtherRecomplete as a single zone for w~ter inject~m~letton or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting an)' proposed work. Propose to abandon the "B" zone gas sands, cement an inner string of casing and return well to waste water disposal capability per the following steps: 1. Kill well with 78-80 pcf mud. 2. Install and test 3,000 psi BOPE. 3. Cut and recover tubing and packers. 4. Clean out to top of plug at 3,100' or as deep as possible. 5. Equalize cement plug from cleaned out depth to near 2,600' 6. Run 3 1/2" Buttress inner string to 2,110'. 7. Cement inner string with 230 sacks of cement. 8. Recomplete well as a single zone-water injector only. DIVISION OF OIL AND 16. I hereby cert~j;~h~t ~8 he, fqre~oi,~s-true &nd correct SIGNED CW V. CHATTERTON (This lpace/J~or State office ~ ~ TITLE ?Z?LEC'~I~,I, 0~ ~e~ole~ EnRineer See Jnstrucflons On Reverse Side ..~0pr0ved Copy, ~turned F'urm P.- 7 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE i i WELL cOMPLETION OR' RECOMPLETION REPORT AND LOG* b. TYPE: OF' COMPLETION: WELI, OVER EN BACK nEsvm Other, __ 2. NAME OF OPERATOR SUBMIT IN D~CATE* (Seo other In- sl ructioBs on reverse side) 3. ADDRESS OF OPERATOR 4. LOC~TIO.~ Or WrLL -(-Report location clearly and in accordance with any State requirements)* At surface At top prod. interval reported below At total depth 13. DA:TE SPUDDED- [i4~ I~2~,~I .T.D~ REJ~Ct-IED -[ i5. DATE 'CO,iVIP SUSP' O:R .ABAND. 18. TOTAL DEPTH, MD & TVD[19. PLUG, B3%CK MD & TVD~20. IF 1VfULTIPLE COIViPL., 21. ~ / I-IOW iVIA/NIY* ROTARY TOOLS 22~ PRODUCING INTERVAL(S), OF TH/S COMPLETIO~--TOI:', BOTTOM, NA1V/E (1VfD AND TVD)' API NUlV[EILICAL CODE LEASE DESiGNATiON AND SERIAL NO. IF INDIA2q, Ai,LOTTEE OR TRIBE MA/ViE UNIT,FA/R/Vi OR LEASE NAME 9. WELL NO. ,, 10. FIEL,D A2qD POOL, OR WILDC&T 11. SEC., T., R., M., (BOTTOM HOLE OBJECWIVE) 12. PIL"Itg/IIT N'O. I ELEVATIONS (DF, RKB, RT, GR, ETC)* 117. ELEV. CASINGHEAD INTERVALS DRILLED BY CABI.E TOOLS 23. WAS DIRECTIONAL SURVEY MADE I 24. T%~PE ELECTRIC AND OTHER LOGS-RUN CASING RECORD (Report all strings set in well) CASI~G SIZE WEIGHT, ~O DEPTH SET (MI)) HOLE SIZE ] 26. LINER R/EC Oil.I) 28-. PERFORATIONS OPF2N TO PRODUC'i~ON (interval, size and nurnber) 30. : Pt~ODUCTION DATE FIRST PI%ODUCTION Il PRODUCTION: ME'I:I-IO'D (Flowing, gas lif~, pumping--size and type of pump~ CEMLNTING RECOILD i i 27. TUBING RES OFJ3 SCi[EEN IMD) SIZE DEPTH SET (MD) 29. ACID. Si!OT. FiiAC~[ GEE, CEd,lENT SQUE.'E'z-~2, D~i iNT~V.~ (MD) ~ AMOUNt Z~D }21ND OF, MAI'EY~AL,,US~ %~ELL STATUS (.Producing or snui-ln) DATE OF TEST, FLO%V, TUBINCr ~l. DISPOSITION OF HOURS TESTED '[CHOXE SIZE ']PROD'N POl% CA~12q~ PRESSURE [CALC12-L,ATED OIL--BBL. ~AS (Sold,. used ]'~r ]uet, vented, etc.) AMOUNT PULLED 32. LIST OF ATTACHMENTS ~ PACKER SET (MD) oIL-BBL. G.a_S---iVICF. %VA'I'EFt~BBL. [ GAS-OIL II.%TIO i W/kTER~IBBL. GAS--~vICF. [ OIL GRAVITY-AP1 (CORR.) I 1, 1 ITEST WITNESSED BY "~'3. I hereby certify that the foregoing and attached information is complete and correct as determined from alU~vallable records SIGNED '~J)C9 'ff' 6 6¥. C'6 H TITLE DATE *(See Instructions and Spaces [or Additional Data on Reverse Side) It- q-71 INSTRUCTIONS General: This form is designed for submitting a complete aad correct well completion report and Io9 all ~'ypes of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (whe~'e not o;herwise shown) for depth measure- merits given in ether spaces on this form and in any att,~ch:r~er'~ts Items :20, and 2:2:: If this well is completed for separatc prcduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~cJuc~:9 interval, or ~nfervals, 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 separately produced, show- ing the additional data pertinent to such interval. Item:2&: ",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 produc*d. (See instruction for items 20 and 22 above). ltY OP POI~MATION T~'I'.~ INCLUI)IN(; INq'ERVAD TESTED. PHEFxSURE DATA ~ ~COVERI~ OF OIL GAS. 35. G~GIC MARK~ WAT~ AND MUD AN~ [IE'I'EC~'EI) StlOWS OP OIL, GAS OR ORIGINAL COMPLETION REPORT - CONVERSION TO DUAL COMPLBTION STANDARD.OIL CO..MPANY OF, CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR ~ . . : ~ ~ _ ,, _ ,, _-: - ,, _ ~ ~ ~ ,, _ AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage Lease No.: A-028399 PROPERTY: Swanson River WELL NO.: SRU 221-33 SEC. 33 T. 8 N., R. 9 W., Seward B & M. LOCATION: Surface: 560' south and 2110' east from northwest corner Section 33. ELEVATION: 206' K.B. DATE: November 6, 1964 CONTRACTOR: Santa Fe Drilling Company, Rig #35. DATE COMMENCED REMEDIAL WORK: October 5, 1964 DATE COMPLETED REMEDIAL WORK: October 21, 1964 SUMMARY TOTAL DEPTH: 3805' PLUGS: 3100' - 3150' 3150' ~ 3162' Mod. D.C. retainer at 2889' Mod. "K" C.I. bridge plug at 2886' JUNK: 129' of tubing fish. Top at 2893' CASING: 20" cemented at 33'. 9 5/8" cemented at 1396'. 7" x 5~" combination casing cemented at 3149'. RECEIVED Iq OV 1 g 19 4 DIVISION OF MINES ,% MINERAL5 ANCHORAGE J. B. Hundley, Jr. R~COMPI~ION DATA (RMMMDIAL WORK) Swanson River Unit ~PPl-33, Alaska A. F.E. No. P-59!8 U.S.L. Anchorage-OP8399 WORK STARTED: WORK COMPLETED: October 5, 1964 October 21, 1964 WORK PERFORMED BY: Santa Fe Drilling Co. (Standard Oil Co.-Operator) K.B. ELEVATION: 206 ' NATURE OF WORK DONE: Shallow sands perforated & well recompleted as combination gas & water injection well. TOTAL DEPTH: 3805' Plugged 3162-3100' Bridge Plugs 2889' & 2886' CASING RECORD: 20" Conductor set at 33' 9-5/8" 40~ N-80 casing cemented at 1396' 7" 5½" 7" x 5½" 23~ & 17~ N-80 casing cemented at 31k9', x - X-Over at 1369'. Perforated 3065-3060' , 2866-2862' , 2770- 2766' 2438-2402' 2394-2350' 2296-2280' 2262-2194' 2174-2120' with 4 - ½" jet holes per foot. "DC" retainer with bridging plug at 2889' Model "K" bridge plug at 2886' , · Fish 2893-3o26' (32' x 2-3/8" tubing, Brown 5½" HS-16-1 Packer, 31' x 2-3/8" tubing, Camco "D" Nipple, 62' x 2-3/8" tubing, Venturi shoe). PRODUCTION: 12-12-64' 1934 MCF/D, 32/_64" bn., 820~/Pkr., 24 hr. prod. 12-13-64' 1934 MCF/D, 32/64" bn., 820~/Pkr., 24 hr. prod. 12-14-64' 1934 MCF/D, 32/64'' bn., 820~/Pkr., 24 hr. prod. * Well on test. Should be on production prior to end of December. REMARKS: 'Standard felt it was essential to recomplete this well as a combination water injection and gas well due to the rapidly rising Water cut in the field. The perforated intervals between 2120-2438' will be used for water injection down t-he "~' annulus, while the intervals between 2766-2866' will produce gas through the tubing. Approximately eleven days were lost due to fishing operations. Development Engineering Alaska District December 21, 1964 (mlc) R. L. Murray ? t 1 / / COMPLETION REPORT CONVERSION TO DUAL COMPLETION SWANSON RIVER UNIT 221-33 S_ .e_c_t!on _3_.3,_T.- 8 N., R. 9 W. ~ Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, W. O, I. - OPERATOR Page 2 PERFORATIONS: 4-~" holes/foot 2766' - 2770' 4'~" holes/foot 2862' - 2866' 4-'~" holes/foot 3060' - 3065' (Plugged Off) NEW ' PERFORA~'IONS: 4-~" hOles/foot 2120'-2174', 2194'-2262', 2280'-2296', 2350 '- 2394 ' and 2402 ' - 2438 ' WELL SURVEYS: None SWANSON RIVER UNIT 221-33 Section 33,_T 8..~.~. R. 9 W', Seward B .&. ~ STANDARD OIL COMPANY OF CALIFORNIA, W.O.I. ' ~PERATOR Page 3 October 5, 1964 Killed well with 78# mud. Installed Cosas¢o plug, removed x-mas tree and installed Class III BOPE. Tested with 2000-2000 psi. Removed Cosasco plug. Pulled and laid down42 joints (1293') 2 3/8" heater string. Rotated production string and rotated same free at safety joint at 2738'. Circulated. 'October 6,_ !9.6.4 Pulled and recovered 88 joints (2715') 2 3/8" tubing, Camco Sleeve valve, Brown 54" x 2 3/8" Hydraulic packer and top half of Brown Safety joint. Ran 2 3/8" tubing with Brown retrieving tool and attempted to free balance of tubing. Unable to rotate packer free. Worked string. Circulated and attempted to free fish. Circulated freely. Unable to work free. Backed off at safety joint at 2738'. Circulated and pulled out. Ran 4 1/8" wash pipe on 2 3/8" tubing. Worked over fish and washed 2738'-2862'. Had 8' sand bridge 2824'-2832', otherwise washed freely. October 7, 1964 October 8, 1964 Washed and worked pipe? Pulled wash pipe and ran in open ended. Circulated. RE(r Ran Bowen outside cutter and cut tubing at 2834'. October 9, 1964 DIVISION o~ M~F41-~ ', '4 NkRAL$ - ANCHORAGI: Recovered lower half of Brown Safety joint and 2 3/8" tubing totaling 95.55'. Ran mill shoe on 4 1/8" wash pipe and washed and milled on mandrel at 2907'. Milled 10" them pulled dull Ran 4" Bowen socket and ungaged fish at 2834'. Unable to release packer at 2972'. Hit one stroke with jars and socket released and dropped fish to bottom, with top of fish at 2866'~ Redressed socket, engaged fish and worked up to 2789'. Pulled socket. October ,_1,0,, 1964 Ran mill shoe on 4 1/8" wash pipe and milled on mandrel at 2853'. Milled 4' to 2857'. October 1,!, 196~4 While milling on mandrel, tubing torqued up, and backed off at 832'. Attempted to screw into Collar. Negative result. Ran 4 3/8" socket with 3 1/8" catcher. Retrieved 2 3/8" tubing, drill collars, wash pipe and shoe. Ran new shoes and washed over mandrel 2857'-2860'. Used 3 shoes. SWANSON RIVER UNIT 221-33 Section 33, T. 8 N. R 9 W. Seward B &.M STANDARD OIL COMPANY OF CALIFORNIA, W.O.I. - 0'PERATOR Page 4 October 12, :1964 Washed over mandrel to 2861' and washed to 2891'. Pulled and found part of fish wedged in wash pipe. Recovered 2 joints tubing, 4' pup and Camco mandrel. Top of fish at 2861'. Conditioned hole with 4 3/4" bit to top of fish. Ran wash pipe and new washover shoe. Unable to wash over fish below 2885'. Circulated and pulied out. October 13, 1964 Ran 4 3/4!' O.D. Servco concave mill and milled on fish 2861'-2871'. Ran 4 3/4" O,,D, Servco concave mill and milled on fish 2871'-2873'. Pulled dull mill. Ran mill shoe on 4 1/8" wash. pipe and milled and washed over fish 2887' - 2889'. October 15, 1964 Ran mill shoe on 4 1/8" wash pipe. Re-washed 2873'-2889' and milled and washed to 2891'. Pulled out and found pieces of mandrel wedged in wash pipe. Ran Bowen Flat Bottom Tungsten Carbide mill shoe on 4 1/8" wash pipe. Milled and washed 2887'-2891'.. Ran Bowen 4 3/8" Saw Tooth shoe and washed 2891'-2895'. Ran outside cutter. Unable to shear pin. Pulled. Ran Bowen Flat Bottom Tungsten Carbide mill shoe and milled to 2909'. ~Oct..o~ber 16., 1964 Ran outside cutter on 4 1/8" wash pipe. Unable to get over collar at 2892'. Ran Bowen-Itco socket with 2 3/8" grapple. Worked fish. Negative result. Pulled. Ran Bowen Tungsten Carbide mill wash over shoe with throat built to 2 3/4" and O. ~ ground smooth. Washed and milled over tubing collar 2892'-2893'. Ran Bowen 4 1/8" socket with 2 1/8" catchers for 2 3/8" tubing. Worked fish. Recovered 18.50' of tubing including ~ of milled down tubing collar. Ran 5~" Baker scraper and scraped hole 1381'-2650'. SWANSON RIVER UNIT 221-33 S...ect. i~on 33,.....T. 8 N.,l R.. 9. W.~ Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, W.OoI. -'OPERATOR Page 5 October 16~.19.64 - Continued TuBing Fish Left in Hole 1 joint 2 3/8" tubing Brown 5~" x 2 3/8" HS-16-1 packer 1 joint 2 3/8" tubing Camco D. Nipple 2 joints 2 3/8" tubing Venturi Shoe 30.50' 3.95' 31.24' .93' 62.21' .58' 129.41' October 17, 1964 Scraped to 2893' and tagged top of fish. Circulated. Ran and set Halliburton Model D.C. cement retainer at 2889', Pressure checked for break down. Took 1½ barrel mud at 3650 psi, then held pressure to 4000 psi. Set plug in re- tainer and circulated. Set Baker Model "K" Cast Iron Bridge plug at 2886'. Set Baker Model "C" Retrievable Bridge plug at 2600'. Pressure tested plug with 2000 psi. - OK. Capped bridge plug with one sack of sand. October 18, 1964 Ran Schlumberger Carrier gun and jet perforated 5%" casing with 4 - ~" holes per foot 2438-2402', 2394-2350', 2296-2280', 2262-2194', and 2174'2120'. Lost 21 port h~le covers from gun #12 while perforating interval 2194-2209'. Gun #13 pulled tight at 2206'. Fluid did not drop druing perforating. Ran 5~" casing scraper and scraped perforations 2120-2438'. Conditioned hole and pulled out. Ran 4" O.D. K&G magnet on Schlumberger wireline. Recovered metal cuttings and approximately 9 covers in 9 trips. October 19,. 19.64 Ran retrieving tool to 2595' and washed sand down to 2600'. Engaged bridge plug and attempted to shove plug down hole. Unsuccessful. Moved plug 10' up hole. Unlatched from plug and pulled out. Ran shortened washover shoe on 2 3/8" tubing with jars and bumper sub and attempted to move plug down hole. Unsuccessful. Ran retrieving tool, engaged and worked bridge plug out of hole. Ran casing scraper and scraped hole to 2870'. Pulled to 2810' and circulated. Pulled. SWANSON RIVER UNIT 221-33 Sec_t~on .33,..T. Lo8 ..N..., ..R.......9 N-.,. Se.ward,. B.. &..M . STANDARD OiL COMPANY OF CALIFORNIA, W.O.I. - opE'R~OR Page 6 Oc.t.obe~. 20,.L!.96.4 Ran open ended tubing to 2860' and circulated. Ran new 2 3/8" tubing for production string. TUBING DETAIL K.B. to landing flange Landing flange 82 joints 2 3/8" tubing Camco MMMandrel Assembly with CEV 1 joint 2 3/8" tubing Brown CC Safety joint 1 pup joint 2 3/8" tubing Brown 5%" x 2 3/8" HS-16-1 packer 1 joint 2 3/8" tubing Otis "S" Nipple (Position 1) 1 joint 2 3/8" tubing Brown Expansion joint 1 joint 2 3/8" tubing Camco MMMandrel Assembly 2 joints 2 3/8" tubing Brown CC Safety joint 1 pup joint 2 3/8".tubing Brown 5%" x 2 3/8" HS-16-1 packer 1 joint 2 3/8" tubing Camco "D" Nipple 1 pup joint 2 3/8" tubing Venturi shoe KoB. Depth 16.50' .50' 17.00' 2,554.88' 2,571.88' 14.13' 2,586,01' 31.20' 2,617~21' .95' 2,618.16' 10.09' 2,628.25' 3.94' 2,632.19' 31.12' 2,663.31' 1.53' 2,664.84' 31.80' 2,696.64' 3.78' 2,700.42' 31.53' 2,731.95' 13.97' 2.745.92' 62.90' 2,808.82' .95' 2,809.77' 10.09' 2,819.86' 3.93' 2,823.79' 31.02' 2,853.81' .95' 2,855.76' 10.09' 2,865.85' .59' 2~.866.44' Tubing Landed at 2,866.44' Ran one pup joint = 6.06' for injection tubing. NOTE Ail tubing is 2 3/8", 4.7#, N-80, 8 Rd, Rg. 3. Removed BOPE and installed dual x-mas tree. Tested secondary packing to 4000 psi End tree to 7000 psi. October 21, 1964 Displaced mud with diesel by circulating down annulus and out tubing. Set packers at 2628' and 2820'. Pressured annulus to 1000 psi with water. Formation took fluid freely through perforations 2120-2438' at 7200B/D rate thus assuring injectivity. Used Halliburton equipment. Rig released at 11:00 P.M. 10/21/64 S. R. HANSEN J. B. Hundley,· Jr.. COMPLE~ION DATA (NEW WELL) Swanson River Unit ~221-33, Alaska A. F.E. No. P-3739 U.S.L. Anchorage-028399 DRILLING STARTED: April 22, 1962 DRILLING CCMPLE~ED: April 26, 1962 DRILLED BY: Reading & Bates Drilling Co. (Standard Oil Co.-operator) WELL COMPLETED: May 6, 1962 Ko B.~ ELEVATION: 206 ' TOTAL DEPTH: 3805 ' Plugged 3162-3100 ' CAS RNG RECORD: 20" Conductor set at 33' 9-5/8"_4C~ N-80 casing cemented, at 1396' 7" x 53" 23~ and 17~ N-80 casing cemented at 3149'. 7" x 5½" crossover at 1369' Perforated 3065-3060' 2866-2862' 2770-2766' with four !.. jet holes per' foot. 2 JUNK: None PRODUCTION: 12-6-62:*1935 MCF/~D, 29/~64" Surf. Bn., 9/_64" SS Bn., 705~/.pkr. 24 hours. 9/64" sS Bm., 9oo / pZr.' 12-7-62: 2632 MCF/D',29/64" S~rf. Bm., 9/64" SS Bm. 700~/pkr.' 24 hours. 12-8-62: 1820 MCF/D, 29/64" Surf. Bm., , , 24 hours. 12'9-62: 2861 MCF/D, 29/64" Surf. Bn., 9/64" SS Bm., 800~/pkr. ~ 24 hours. *Reported producing water anA sand, but no amount obtainable. This well was drilled to further develop the shallow gas sands on the west flank of the Swanson River Unit. Well stood shut in until required as gag source for SCU gas injection project. Development Engineering Alaska District March 20, 1963 (jh) R. L. Murray COMPLETION REPORT SWANSON RIVER UNIT 221-33 8~ANDARD OIL COMPA~ OF CALIFOItNIA~ W.O.I. - O?FZRA~R pERFORATIONS: holes/foot 2862' 2866' holes/foot 3060' 3065 ' Page 2. WELL SURVEYS: 1. Schlumberger Induction-Electrical log, interval 31' - 3807' 2. Schlumberger Sonic Log, interval 31' - 3804' 3- Schlumberger Continuous Dipmeter, interval 1395' - 380~' Schlumberger Microlog-Caliper, interVal 1395' - 3154' 5. Schlumberger Cement Bond log, interval 1500' - 3092' 6. Schlumberger Neutron Collar log, interval 1600' - 3098' 7. Baroid Daily Mudlog, interval 3030' - 3805' DRILL STEM TESTS: HCT ~1 3060' - 3065' HCT ~2 2766' - 2770' HCT ~3 2862' - 2866' COMP~TION REPORT SWANSON RIVER UNIT 221-33 Section 33, ~T... 8 N,,.. R- .9. W,_, Sewa. rd B & M STANDARD OIL COMPANY OF CALIFORNIA, W.O.I. ' ~ OPERATO~ Page 3. April .22, 1962 Spudded at 4: 00 A.M. Drilled lB 3/4" hole to 1168' 76 - 78 pcf mud Apr, i% ,23, 1962 Drilled 13 3/4" hole to 1400' and 8 3/4" hole to 1500'. Ran Schlumberger Induction-Electrical log and Sonic log. April 2.4, 1962 __ Ran 9 5/8" casing. CEMENTING DETAIL: Cemented 9 5/8" casing at 1396' with 80D sacks of cement. Pumped 50 bbls. of water ahead, mixed cement in 25 mins. using Halliburton truck, displaced in 9 mins. using rig pumps. Average slurry weight ll6~ - llT~. Bumped plug with 1600 psi. Full circulation. Cement in place at 5:35 A.M. 4-2~-62. Hookload weight of casing before cementing ~8,000~ ~fter cementing 'before landing casing CASING DETAIL: 35 joints or Below K.B. 1376.94' 9 5/8", 40~, SSR, N-80, equipped with Baker shoe and float collar. Cemented at 1396.08 ' Installed B.O.P.E. and tested with 2000 psi. O.K. Located top of cement at 1351' · i ri! 1962 Drilled out float collar~ cement and shoe. Drilled 8 3/4" hole to 3670'. Baroid Mud_logging Unit installed at 3030'. 73 - 77 pcf mud April 26, 1962 Drilled 8 3/4" hole to 3805' T.D. Ran' Schlumberger Induction-Electrical log, Sonic log and Continuous Dipmeter. Unable to run Micro log. 78 - 79 pcf mud April 27~ . 1,962 Cemented plugs as follows: Plug ~l - Cemented at 3162' with 120 sacks cement. Top of plug not located. Plug ~2 - Cemented at 2838' with 100 sacks cement. Top of plug not located. Plug ~3 - Cemented at 1~88' across shoe of surface pipe with 150 sacks cement. located top of plug at llSO' and drilled cement to 1350'. 80 p cf mud COMPLETION REPORT SWANSON RIVER UNIT 221-33 Secti0. n .53 T. 8 N., ..R:....9.....W., .Seward B. & M STANDARD OIL COMPANY OF CALIFORNIA~ W.O.I. - OPERATOR Page April 28,.... 1962. Drilled cement and cleaned out to 2720'. 72 - 75 pcf mud Apr~il 29, 1962 Drilled cement and cleaned out to 3150'. Ran Microlog-Oaliper. Ran 7" X 5½" combination Casing string. CEMENTING DETAIL: Cemented 7" X 512'' casing at 3149' with 600 sacks of cement. Pumped 50 bbls. of water ahead, mixed cement in 20 mAns. using Halliburton truck, displaced in 15 mAns. using rig pumps. Average slurry, weight ll6~. Full circulation. Cement in place at 1:20 A.M. Hookload weight of casing before cementing 60,000~ after cementing before .land/ng casing 65,000~. CASING DETAIL: 34 joints or 1374,83' 7", 23~, BT N-80 ~ 3~ 7~.e,~- X-Over sub 1.70' _ 41 joints or 1775 89' ~!,, 17~ L 8 R, N-80 ~ ~ ~ ~' Float Collar 1.50' Shoe 1.60 ' Total 3155.52 ' Above K.B. 6. - Landed at 3~49.52' (Casing equipped with l0 centralizers and 35 scratchers.) Circulated. Cut off casing. Installed B.O.P.E. and tested with ~000 - 3500~, O.K. Ran 7" casing scraper to 1350'. Pulled. Ran 4 5/8" bit and 5½" casing scraper. Located top of cement at 2715'. Drilled out cement to 3100'. Ran Cement Bond log and Neutron Collar log. Shot 4 ½" holes/foot 3060' - 3065'. HCT ~l on 4 ½" holes/foot 3060' - 3065,,-,,C Tool Assembly: 2 outside BT record~rs, 3' of 2 7/8" perf'd, tail pipe, type 4½" Hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydro sp ring tester, plus dual closed in valve. Ran on 3008' of 2 7/8" drill pipe. Used no water cushion. Set packer at 3030'~ with 16' of tail to 3046'. Opened tester at 6:15 P.M. for 3 min. pressure release. Shut in tester at 6:18 P.M. for 30 min. ISI pressure period. Opened tool to surface at 6:48 P.M. for 82 min. flow test. Shut in tool at 8:10 P.M. for 65 min. FSI pressure. Pulled packer CO~PLE~XON P~moa~ SWANSON RIVER UNIT 221-33 Section...33 T%8 .N:~ R. 9 W...~ Sew..ar.d B & M STANDARD OIL COMPANY OF CALIFORNIA, W.O.I.' ' OpERAT0~ Page 5. May 2, 1962 COntin~e__d loose at 9:15 P.M. Pulled 8000~ over weight of pipe. Gas to surface immed- iately. - Flared at stack. Turned to prover (½" orifice) at 7:00 P.M. - Too much pressure. Mud spray with gas to surface at 7:03 P.M. Mud spray with gas and water spray at 7:10 P.M. SpraY cleaned up by 7:15 P.M. and turned to prover. 5/8" subsurface and ½" surface bean. Rates as follows: Orifice ~ Time Press. Coeff. T. em~. MCF/D TbS. . 7:15 to 7:25 52-55 657.5 46° 2560 l" surface 1.1. ~W 7: 30 68 657.5 45° 3110 CloSed in at 7:40 to tighten chicksan. Reopened 7:42 P.M. 1" 7: 40 - 7: 50 100-120 406.7 44° 3150 3/4" 7:55 - 8:10 225-232 224.9 46© 3170 3oo 2oo~ 21o~ No recovery - tools dry. Final Pressure data: Depth Gauge IH ISI IF FF FSI FH Top Inside 3015' 1716 1279 558 640 1274 1631 Bottom Inside 3020' 1698 1276 569 654 1272 1638 Top Outside 3038' 1714 1277 579/610 530/687 1272 1646 Bottom Outside 3042' 1713 1281 584/611 537/691 1276 1650 Conclusion: Tools functioned O.K. Dry gas test. Ran bit and 5½" casing scraper. Circulated at 3100'. . 69-77 pcf mud Ma , 196 , Set HOWCO plug at 3000'. Shot 4 ½" holes/foot 2766' - 277o'. HCT ~ on 4 ½" holes/ft. 2766' - 2770' (4'). Tool Assembly: 2 outside BT recorders, 3' of 2 7/8" perf'd, tail pipe, "C" type Hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester~ plus dual closed in valve. Ran on 2706' of 2 7/8" drill pipe. Used no water cushion. Set packer at 2729', with 16' of tail to 2745'. Opened tester at 10:55 A.M. for 3 min. pressure release. Strong blow of gas to surface. Shut in tester at 10:58 A.M. for 30 min. ISI pressure period. Opened tool to surface at 11:28 A.M. for 5 hours and 17 min. flow test. Shut in tool at 4:47 P.M. for 45 min. FSI pressure. Pulled packer loose at 5:32 P.M. with lO, O00~ over weight of pipe. 5/8" subsurface bean on all flow periods. Mud to surface 11:35 to 11:45. COMPLETION REPORT SWANSON RIVER UNIT 221-33 Section 33 T. 8 N', R...9 W-a. Seward B & M $_TANDARD OIL COMPANY OF CALIFORNIA, W.O.I. - OPERATOR Page 6. Surface Bean Orifice Time Press. Coeff. 32/64" l~" 11:45-12:00 92-96 657.5 Some spurts of water 12:04 to 12:09. 32/64" 1~" 12:OO-12:30 100~ 657.5 Took gas Sample at 12:15 P.M. 48/64" mi" 64/64" ~,, 12:30-1:10 120-122~ 657.5 ~ 1:10 -1:45 128~ 657.5 Changed to 16/64" surface bean and 3/4 orifice. 16/64" 3/4" 1:45- 4:45 58~ 224.9 Shut in at 4:47 for 45 min. FSI. Pulled loose at 5:32 P.M., no recovery - tools dry. Temp. ~ MCF/D rate 470-35° 7oo~ 340-35° 7oo~ 3~°-44° 43°-45° 42°-38° 4110-4180 4360-4380 5o80-5~2o 538o 970-814 average 940 Final Pressure Data: Depth Gauge IH ISI IF FF FSI FH Top Inside 2714' Bottom Inside 2719' Top Outside 2736' Bottom Outside 2741' 1658 1152 957 1144 llSO 1642 1693 1152 974 1147 1155 1648 1672 1153 1004 llS1 1153 1659 1685 1158 1045 Zl52 1156 1668 Conclusion: Ran bit and 5~" casing scraper to 2950'. Circulated. Shot 4 ~ TM holes/foot 2862' - 2866'. HCT ~3 on holes at 2862 - 2866 (4')'. Tool Assembly: 2 outside BT recorders~ 3' of 2 7/8" perf'd, tail pipe, "C" type hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydro sp ring tester~ plus dual closed in valve. Ran on 2796' of 2 7/8" drill pipe. Used no water cushion. Set packer at 2824', with 16' of tail to 2840'. Opened tester at 6:43 A.M. for 6 min. pressure release. Shut in tester at 6:49 A.M. for 46 min. ISI pressure period. Opened tool to surface at 7:35 A.M. for 6 hrs. and 3 min. flow test. Shut in tool at 1:38 P.M. for 30 min. FSI pressure. Pulled packer loose at 2:08 P.M. 5/8 subsurface choke. 16/64 surface choke at 7:35 A.M. Mud and spray to surface at 7:40 A.M. Shut in froze up steamed head and line. Opened on 24/64 at 8:00 A.M. to stack spray of water in gas flare. Turned to prover at 8:20 A.M. Valve to stack froze. Shut in to thaw out with steam at 8:38 A.M. Reopened at 8:43 on 64/64" choke. Turned to prover at 8:45 P.M. Surface Orifice Time Press. Temp. Tbg. MCF/D -64/6~" "l~L'~ 8:45-10:30 110-122 45°'46° ~00 psi 4600 to 5140 Changed to a 24/64" choke at 10:35 24/64 17' : . 10 35-1:35 72 280-25° 1000 psi 3320 Closed in at 1:~8 P.M. for FSI. Pulled loose at 2:09 P.M. with 10,000~ over weight of pipe. COMPLETION REPORT SWANSON RIVER UNIT 221-33 SectiOn 33 T' 8 N.~ R. 9 W.~ Se.ward B & M STANDARD OIL COMPANY OF CALIFORNIA, W.O.I. - OPERATOR Page 7. Pressure Data: Depth Gauge IH ISI IF FF FSI FH Top Inside 2816' 1732 ll91 853 ll08 1189 1634 Bottom Inside 2820' 1726 1180 856 ll06 1182 1627 Top Outside 2831' 1727 1196 956 1138 1195 1696 Bottom Outside 2836' 1742 1196 953 1139 1196 1706 Conclusion: Tools functioned O.K. Gas dry after 9:00 A.M. Ran 4 5/8" bit and 5~" casing scraper. Drilled out plug at 3000'. Cleaned out to 3100'. May 5, 1962 Ran 2 3/8" tubing. TUBING DETAIL: 1. Production String. K. B. to landing head Landing flange assembly 86 joints 2 3/8", 4.7~, N-80, 8R EUE tubing Camco Sleeve Valve 1 joint 2 3/8", 4~17~, N-80, 8 R, EUE tubing Brown HS-16-1, 5½' packer i joint 2 3/8" (as above) Brown CC safety joint 5 joints 2 3/8" (as above) Camco MM mandrel 2 joints 2 3/8" (as above) Brown HS-16-1, 5½" packer I joint 2 3/8" (as above) Camco D nipple 2 joints 2 3/8" (as above) Venturi Shoe (K.B. depth) 15.80' · 75' 16.55' 2651.53' 2668.08' 2.70' 2670.78' 31.56' 2702.34' 3.95' 2706.29' 31.57' 2737.86' · 9~' 2738.80' 155.36' 2894.16' 13.18' 2907.34' 60.99' 2968.33' 3.95' 2972.28' .31.24' 3003.52' · 93' 3oo4.45' 62.21' 3066.66' · 58' 3067.24' Tubing landed at 3067.24 ' 2. q.irculat.i,ag' String. K.B. to landing head Landing flange assembly 42 joints 2 3/8", 4.7~, N-80, 8R- EUE 2 3/8" thin collar 15.80' .75' 1292.56' .40' Landed at 1309.51' May. 6, 1962 Installed X-mas tree. Displaced mud with oil. Set packers at 2706' and 2972'. Rig released at 3:45 P.M. May 6, 1962. COMPLETION REPORT SWANSO~ RIVF,~ U~T ~2L~3 STANDARD OIL CO~A~"'6F ~CA~Fb~'w.o. I. - OPEneR Page 8. DEVIATION DATA Depth 1500' 2908' 3805 ' Degrees 0° 30' 0° ~5' 0° 30' Form ~9-33,1 (May '1963) UMUTED STATES s~B~iT D~PAR~M': T Of THE iNTERIOR 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.) 1. OIL --[~ ~AS ~J OTHER Dual 'temple Cio~_ WELL WELL NAME OF OPERATOR Standard Oil_Company of California.. Wester~ Operations.. Inc. ~. A~onEss oF O~ER~TO~ R. O. Box 7-839 Anchor~e~ Alaska 4. LOCATION OF WELL (Report location elearly"an~ in accordance with any State requirements.* See also space 17 below.) At surface 560' South and 2110' East from the Northwest Corner of Section 33 14. PERMIT NO. 15. ELEVATIONS (Show whether DF. aT, GR, etc.) 206' K. B. Form approved. Budget Bureau No. 42-R1424. O, LEASE DESlU~ATION ,AND IlBRIAL NO, 6. IF INDIAN, AI, LOTTEE OJt TRIBE NAME '/ · · 7. UNIT AGREEMENT NAME Swanson_Riva. r_ 8. FARM OR LEASE NAME __S~anson 9. w~ ~o. ..... ~ 1,~33 10. FIELD AND POOL~ OR WILD~&T Svanson ~iver ll. SEO., T,, R., a., OR BLK. AND SURVEY OR AREA Section 33, T 8 N, R 9 W Seward B & M 12. COUNTY OB PARISHI 18,:STATE Kenai .Penin.[ , Alaska .... 16. Check Appropriate Box To Indicate Nature oF Notice, Report, or Other Data NOTICE OF INTENTION TO: . TEST WATER SHUT-OFF I I PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SItOOT OR ACIDIZE ABANDONs REPAIR WELL CHA.NOn PLANS (Other) SUBSEQUENT REPORT OF '- ' ' WATER SHUT-OFF REPAIRING WELl, FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZING ARANDONMENT$ (Other) Dual Completion. (NOTE: Report results of multiple completion on W'ell C.mpletion or R~eompletlon Relmrt nn~ Lo~ 17. DES¢'ItlnI,: I'ROI'OSED OR CO.~[I'I,ETED OPERATIONS (Clearly Stltte all imrtln.nt details, nmi give pertinent dates, inclndlng estimated date of starting any proposed work. If well is dJrectionaily drilled, give subsurface locati.ns nnd measured ~tnd trite vertical depths for all markers and zones perti- nent to this work.) * ' 1. Rigged up and killed well with 78 pcf clay base mud. 2. Recovered 2 3/8" tubing to 2893' leaving 129' of tubing and packer Junk in hole from 2893' -3022' . 3. Set CI retainer at 2889' and attempted to get break'down to squeeze off lower zone. Could not get breakdown at 4000 psi. Dropped bridging bar. 4. Set CI bridge plug at '2886''to abandon hole below that depth. ' 5. Perforated intervals 2120'-2174', 2194'-2262', 2280'-2296', 2350'-2394' and 2402'-2438' in 5~" casing with 4-%" JHPF. 6. Removed BOP and installed dual x-mas tree. 7. Ran 2 3/8" tubing equipped with packers and hung same at 2866'. Also ran one (1) 6' pup joint for injection tubing. 8. Displaced mud with oil and set packers at 2628' and 2820'. 9. Tested for injectivity through perf's 2120-2438' by pressuring annulus t° 1000 psi and formation took fluid freely at 7200 B/D rate. Well dually recompleted and rig released at 11:00 PM October 21, 1964, 10. 18. I hereby ce~F/f'yj:~/~oTxC~o~n~-ts J;rhe an~d~orrect SIGNED ( .,;:/" ~ ~/'f~¢' ~fZ~%] ~I~LE District Superintendent (This space for Feder~ or S~te o~ u~) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: DATE __ TITLE *See Instructions on Reverse Side November/~ 1964 Budget Bureau No. 42-R866.6. /~"~,. ~ .-.~,~ Approval expire~ 12-81-60. UNITED STATES ~.o omc~ ..~~9~._. ...... . ....... DEPARTMENT OF THE INTERIOR ~ .u..~. ..... ~~ ........... GEOLOGICAL SURVEY u m~... ~.~.~.~.~.9~.. ~ ~.... ~.~... MONTHLY R[PORT OF OPERAT[ONS Tl~e foHowiz~E is a correc~ repor~ of operaHoz~s and prodz~ctioz~ (i~cl~di~E d~lli~E a~d prod~ci~E wells) for tke mon~]~ of ...................... .Q~9~ ...... 19..~.~ ............................................................................. ~Ee~'s address ...~__.~:.._~_.~2~ .................................. Com. a~ S~A~' O[L CO. 0F CALrF~ W.0.[. - ,..' .... 7"-~'v"?":'75'7'~-"5)"~~..~ __ .....~7~?./. i'"'~-' .......... .................. .............................. ..... ..... ~o~ .................. _~.~~..Zz~ ................................. ~e~'s ~i~ 9~-~t~--~er~n~ende~ ......... SEC. AND 7, GALLONS 0F BARltEL~ O~ ~._ __ ~AR O T ~_ t~O. ~_x ~ASOLIN~ W~T~R (~ (If ddHi~, d~: If ~hut ~wn, ~t of , , .... - , ,~ ..... ~ ~ ........ 33 8N 9W SWANSON ~.I~R- ~IT 221-3~ R~edial work. Conversi~m ~o du~l comple :ton (Dry Gas 'Weil.- W~.ter E[sposal) ~:o~ended work Oc :ober 5, 1964. Killed w~ll wigh 78~ mud, Installed BOPE and pulled tubing Cc 2893'. DIVISIC~N OF MINES & MtblE~ of 4 joia,tS 2 3/8" 'tu~tn~;,, ~ron Packer, ~amco D Nipple ~,~O~3E and Vent~.r~ Shoe. Set r,~tainer at 2889' md tested for .. break dO~'n. Pumped away 1% barrel drilli'.~g fluid at 3650 psi, then held pres. mrs to 4000 psi. Set C.I. Bridge P]u~ at 2886'. S,~t Retrievable Br'tdge Plug at 2600'. . , ' Sho~ 4 - ~" holes/foot 2~,38'-240~' 2394-'.~350' 2296-2280' 2262-219Z ' and 2174-2120 . Retrieved Bri,~ge Plug at 2600'. Ran 2. 3/~ " Production Tu],ing to 2866' T~[btng equipped wit] Packers ~t 2628' and 2821 '. Ran a 10: pul) Jotn~ for injec- tion strJ ng. . ~' R~c~f~eld.- C. W. R. R. RJ Un~cn - R!. A. Lyon · . Mare~thon · L. P. Fo~,~e Fll~s - P~coducing .... . .. ~ .... , , , , ,, , , ,, , NoTre.---There were ...................................... · runs or sales of oil; ............................................. M ou. ft. of gee sold; ............................................. rums or sales of gmsoline during the month. (Write "no" where applicable.) NOT~.--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' succeeding month, unless otherwise directed by the supervisor. .f Farm 9-~31 · (May 1968) UF~T'ED STATES SUBMIT IN (Other instruetto, on re- DEPARTML ._£ OF THE INTERIOR ye,Reside) GEO'~LOG iCAL 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.) si,. ,AS [] 2~" NAME OF OPERATOR Standard 0il Company. of Cal, ifornia, W. O. I. 8:J ADD.SS OF OPit~S P. 0. Box 7-839 Anchorage, Alaska LOCATION OF WELL (Report location clearly and in accordance with any 8tats requirements.* See also space 1T below.) At surface -. 560' & 2110' E from the 1~/ Corner Section 33 PERMIT NO. 4m '15. ELEVATIONS (Show whether DF, RT, OR, eta.) 206* 16. Form approved, Budget Bureau No. 4~-R1424. §. LEASE DESIONATION AND SItRIAL NO. '6." Ie;i~'~i~, AL~X~TTItm o~ :,alee ~-. l.l *f .9'*' - ,..-, .t ..~ T. "": .... ~. UNIT A~RBEMMN~; NAil[. . 8. FARM 0R LBAS~.NAMB.. ~.~ . } 7_ ,./' ,: ..~ .; SWansOn River .'Unit 9. WELL NO;: .' [ '~ 221 '33 ~ '''= ~' ~; . 10. FlgL~~ A~'D PO~, OB Swanson River ":~ 11. SmC~, T., it., M., OR BLse 'fJURVItT OR AnitA-' '. .... Sec,. g3'; 12. COUNTY~ · Sit PARlSHJ% 18;'.'% .~ HTATIt., Kenai peni~i'. Ch~ck Appropriate Box To Indicate Nature of Notice, Report, or Other Data NO~ICB OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs ' REPAIR WItLL CHANGE PLAN8 (Other) SUBSEOUENT Rm~'0RT'0F: WATER SHUT-OFF I J ;.' [ "REPAIRING WELL' FRACTURE TREATMENTJ~] ... '. '.~TERING C*~ISO[" SHOOTING OR ACIDIZINO (Other) No~: Report results of multi~e 'comple~n ow, Well ompletion or Reeompletion ~ " ' ' ' ' ANCHO~GE. · ' (This spa~ for F~er~ or 8~te offi~ u~) .......... . ' TITLE · See Jns~uctions on Reverie Side 17. Di~SCRIn~ PnoI'OSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including/estimated dflt'~ of..starting any proposed work. If well is directionally drilled, give subsurface Iocatisns and measured and true verticar:.dept.h.s for all ma_tReKs: and' z~0nes peril- - ~. ~ ,- ~ , ~y' ,.? it) nent to .this work.) * · :j ~ "':". ~ ,,' .~ ;':, .' j 0 21'. PuKillll we11Tubingwith, mud~ .remove x-mas tree~ install & test Bop.. 3° Place bridge plug near ~000.~ .4. to exclude perforated intervall. 3060~0:6~,.. 4, Perforate intervals 2120-2176', 2194-2262' , 2280-2296*, 2350-2394~ and ,~ ~: =~ ~ ¢. 2~02-2~38' with ~our .(4) ~" JeC hqles per foot for injection a~ .~ ,~., .~ ~-~;.~ 5. Re,un ~ubins equipped Vi~h packers ~o isolate perfforaC~d ~as ~rod~ei~ ~ ~: .~ ~ ' in~ervals 2766-2770' and 2862-2866' and provide for vaNCe radar ~dLi~oSal into annulus. "; c ': "' 7. 6. aemove ~op, inaeall aha ~x~ x-ma~ ~ree and' displace mua wi~ 'o~'l/. 7. ~ke inJectivity teac of perforations in annulus with water; . 8, Return well to production-as a sha11~ gas producer through the ~'$u~!n~ a waste wate~ disposal Vel1 in~'th~ annulus. ~,~ Confimi~ phone conversation be~een aoo~h-SoysJer '9/~9/~ ~ ~nd BoOth Yonder Ihs 9/29/~)L. = -. v · . ~, ..-, APPROVED BY ,, , CONDITIONS OF APPRi~VAL, l~. ANY.: · .[ PRODUCING DEPARTMENT TELEPHONE BR. 7--6201 C. V. CHATTERTON DISTRICT SUPERINTENDENT / P. O. BOX 7-839 ° ANCHORAGE ° ALASKA December 13, 1962 Mr. T. Ro Marshall State Department of Natural Resources Department of the Interior Petroleum Branch 329 Second Avenue Anchorage, Alaska RECEIVED OEC 14 1962 Petroleum Bra~ch Division of Mines c~:' Aiaska Dept. of Nc~i*J,c,, "CONFIDENT IAL" Gentlemen: We emclose herewith the following information and well data for yeur files and informatiom: Completien Report Yeurs very truly, C. V. CHATTERTON "RECEIVED aEC 14 .1.962 COMPLETION REPORT - NEW WELL Petroleum Branch Division of Mines ~nd Minerals Alaska Dei~t. of Natural Resources OIL CO:t~A~ OF ,CAL~.FORNIA.~ ,,N~S.~ OPF. dtAT.IONB~,,. ZNC, -_..0PERA~R AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage Lease No.: A-028399 PROPERTY: Swanson River ~% ~.. ~"0 . ~$$- I O,~ ~- WELL N0.: SRU 221-33 SEC. 33 T. 8 N., R. 9 W., Seward B & M. LOCATION: Surface: 560' south and 2110' east from northwest corner Section 33- ELEVATION: 206' K.B. DATE: December ll, 1962 K.B, is 16.5' .a. boYe ground. ,..-"" . / /- ..,':.' 4---.~M.. _ ~ / //...: ! -,,v~, /., /,'" ( /,~ / ./ ., /',. ..//'..,. : ./~.,?/~./' .,. z~&} ~ '/,./ .... , .,,,..._~,;,.. .,...':.,,.--(:; .... ;- , / ..,;,z':_._ b% V." CHATTERTON, District Supt. "' DRILLED BY: Reading & Bates Drilling Company, Rig ~6. DATE COMMENCED DRILLING: April 22, 1962. DATE COMPLETED DRILLING: May 6, 1962. DATE OF INITIAL PRODUCTION: None. Shut in gas well. SUMMARY TOTAL DEPTH: 3805' PLUGS: 3100' - 3150' 3150' - 3162' JUNK: None CASING: 20" cemented at 33'. 9 5/8" cemented at 1396' with 800 sacks cement. 7" X 5~" combination casing cemented at 3149' with 600 sacks cement. 1st Min. 2nd Min. Flow Time ~ 82 Date ~-. Number ~ - Closed in 1st Min. 2nd Min. Kind Halliburton Press. Time ~ ~ of Job ..~Zi~.~L~--.---.---- District Office · , Pressure Field Corrected Tester , ~ Witness Blanked Drilling Depth Off Contractor ~ -'--"-- Top Gauge 30~ Ft. ~O. BT. Hour Top P.R.D. No~' ~)78 ~2 ~_!_~k .~~eYo~::~ -- Packer Initial Hydr° Total Bottom Mud Pre?_.re ]-6~0 ' ~?~t~ De~.L _'~] ('~l Packer Initial Closed Interval Formation in Pres. ~2~0 · 1279 Te~ '~O~"A (~ Tested '. ' ' - - - Casing ~To.,, Initial I t~ casing or F,ow 2 . .o,. Size ? #. P.rf,. Bot. _ Final ! ~ Surface Bottom Flow pre., 6c;¢ . 2 61!n Choke AdJ, Choke ~/8" · ,.'n. - L~NaTN Final CloSed Size & Kind ii Drill Collars _ Above Tester in Pres.' 126 ~ ~ ~?)! Drill Pipe 2. ?/8 ~yd, 'Final Hydro Mud Mud ~.d P~_--_:~,e l~;l'n ~ ~3~ Weight 78 Vi'co'itY )~2 -- Con. ~.ge' 3020 Ft. Do - ,. BT, H~r Dep~s Depth o~ P~.D. No. ~~ ~k Mea. From ~ Te~er Valve F,. ~PE AMOUNT O ' De~h Back Initial Hydro Ft. Pres. Valve Ft. · i. p;~. ~2 70 - ],276 R.~o~-~;~ - F., o~ ,., ~ · Initial I . ~ Final ! .. Final CIo.d in 'Prfl. ~8 ~ ~ ~ ~2. R~G~G~ Feet of Final Hyd~ Oil Water Mud P~=. ~ ~R~ ~ ~ A.P.I. ~GVi~ S~c. Gmvi~ ~ Bbnk. d ~, SurfaCe ~00 -- ~ p,i Dep~ ~ Grav;~ Press.re ., Bot. Gauge ~O~8 Ft. ~ n .... -- A.M. ' ~ Tool BT. H~r Tool ~: ~ ~ P.~ CIo~d ~: ~ ~ P'~' P.R.D. No. ORD. ) 2 Cl~k Initial Hydro MudPm. ]7~. ~9~, Remarks ~OO~ O~~ ~O~ ~ ~ ~~ ~ ~O~. InitialCIo~d ~O~G~ ~O~ G ~0 ~U~G ~~G~ ~O~ in P~S.' ~2~ ~ .... Initial I ~ ~OO~ ~G-O~ ~ ~ ~O ~G S~OG ~~~ ' Final I ~ ~~ ~O ~O~ ~ ~O~G~ ~O~ ~0 ~ F~o~ ~,~. R~n ~ ~B7 ' FinalCbNd G ~ ~~ ~ ~O~ ~ ~~. in Pres. ~. ~ ~ Final Hydro' ~U~ ~o MudPms. ~ ." ~ ~ ~ FORMATION TEST DATA Ticket Flew Time .3. 5 hrs. 17 Date ~-3-62 Numhr., 318971 - S Closed in 1st Mi~. 2nd Min. Kind Halliburton Press. Time 90 4~ of Job Prod ,t, est' ,,District ..Anchorage Pressure Field Office Ren~dings C:orroeted Tester Ed Onstott wimm O. Gilbert ,, , , , , , , . ,.. . , Depth Blanked Drilling Top 'Gauge , 2714 Ft. n.0 BT. Hour Top P.R.D. .... .o. ?78 , 1'2 . .... Pe'ker , 7.29' Initial Hydro. Total Bottom Mud Pr.s. uro 1680 . 1658 Dept. 3000' PP.D_ Packer - Initial C:losed - i5 Inte.al Formation i. Pres. 1155 ~ 1 2 · Tested - Tested - - ~ ..... I.itbl i * Ca,i.g ~Top 2766 , , Casing or 5~"' 17 # Perfs. ~Bo,. ~7~0 Flow Pro.. 955' 2 957. Hole Size ..... . ........... Final , ,, I * Surface Bottom F,ew Pre,. 1130 2 '11~4 Choke Ad~. Choke ,5/8" I.D. - LENGTH Final Closed ' Size G' Kind · Drill Collars in Pres.* ~L155 11~O Drill Pipe 2 ,7/8" ,, , , 'Final Hydro Mud Mud, MudPr.ess,.uro .~,6.~ ,1642 , , ,Weight 83 1/2 ¥iscosity 60 Depth , Blanked Temperature Can. Gauge' 2719 Ft. no off , , oF Actual , BT~ Hour Depths Depth of P.R.D. Ho. C~7 ~ 12 · Clack . Mea. From., ~4~ ].~¥. b,.llshiri~ Tester Waive 270~ · ' 'tYPE '" AMOUNT - - initial Hydro ' ~ud P,,. 1710 16~3 ¢,,,hio. ,,None~ , ,. Pre,. ¥,i~, Initial Closed ..i,n. Pres. 1140 11%2 Recovered None Feet of ......... Initial I * Floweros. 9~0 ' " 2 9.7)-[, Recovered Feetof , Finai ' ' i FI,ow Pr.. ~30 ~ ' ~1)~ ? in 'Pres. Final Hydro Oil Water Depth Blanked Gas SurfeCe . Bot. Gauge 2735 F,. Yes. o, Gra~i~/ Pre:su. re ~00 - BT. 'Hour Tool ' ~k Tool. A.ta. p.R.D. Ho. 782 ' . ..12 , Initial Hydro · Mud Pres. 1710 . 1672 .. ~emerks Tool opened f.or a 3 minute fix et. f,.low: Init/el Closed i. Pres. .. 1160. 1153 Rots, ted for a 30 .m%,n, ute initial clos.ed in pr.es.s.ur, e.~ Initial I Flow Pro,. 1070 " ..2 i'0'.~ Tool re-opened with st_rang blow of Kas to the Final 1 Flow Pres. 1.!45 2 11~1 ' ". surface ..imm.e. distely Final Closed in Pres. 1160 11~ , , c]~osed in · Final Hydro A4ud Pres. 1660 ...... 16~9 *Unable. to read ' . ..... FORMATION,, TEST DATA ................ i_;. ,., .... -' ,, ' '~,.'. ~.d" ~..' ¢,esed ,'n Kind Halliburton .P.~e..s.,s. Time , 46 , . .. . 30, of Job .. Prod, test. District, Pressure Field Office Readings Corrected Tester l~,d Onstott ,Witn ,e,.sf. Depth Blanked Drilling Top Gauge 2816 ~Ft. ZIO Off Contractor Rf~adin~,~ ~B~r~ ~n(~ BT. . Hour Top P.R.D. No. 97 8. · 12" Clock Elevation . Packer , , , , Initial HYdro ]'76~ ~. 1~2 Total Bottom Mu,d. P.r, essure, ..... . ............ Depth ., ~1OO~,, Packer ,.,,o, ¢,o.d ~ ~]: To.~ - T.,od in Pres. 1].~ 1 , Interval Formation ...... , ..... Initial I Casing or Casing ~Top Fie? Pre,. _ '?~ ~' ~.~ .. .ale Si. ~½ ~?~ ..... Perf.. Final I Surface ' Bottom .... · ,. , Flow pres. '].~L].~ 2,,, 1108 ,, Choke ~dJ. Choke .... Final Closed · Size ~ Kind Drill Collars in Pres.' , 11~ 11~ Drill Pipe ~ 7/~ }~C] Above Tester , . ~ ....... !,, ~ , _ ......... Final Hydro' 17~ ' ,~34' i Mud Mud Mu,.d. Prelsu~ ,, . Weight ~? . , , Visco,?ity ,,..kod Tom..o,.ro ' C ~00 ., ~,. Cen.DepthGauge ~820, , ?, ,' Ft. , ......... PAC) Off .FAetual & Length 'OD BT, Hour Depths Depth of P.R.D. No. 9~9 -, '12 Clock . Mea. F,r,om - ~]~_v b. ~b~ ~_m Teste..r Valy.e r~p~ A.OUNV Depth Back MudlnitiaIpres.Hydr° 172~.. 1726. CUshion ~ O,T~. Ft. Pres. Valve Initial Cl°sed 116~ 1~80 ,,Recovered ,,, Fie, Pres. 860 2 8.~6 R~o,red Fe,~ of FI.o~ Pr.. ' ~:~0~ . . ~ '~:~0~" ........... R~eve~d F.~ of Final Cio,ed 11~ 1182 Rec.oyered Feet in Pres.. \ ........ Final Hydro · '1 Oil Water ~ud Pre,. '~ 16~3 ..... 1627 A.P.I. Grey!fy Sp, c. Grevi.~/ Depth· Blanked Gas Surface Bot. Gouge 2831 Fi. ~-es off Gr,avlty .... Pressure BT. . Hour Tool A~ Tool P.R.D. Ho. 982 12~ ~ Clock Opened 6S48.~ P.kA. Closed .111 i ii illi ii1( i i ~ I Initial Hydro MudPres. 17'3~ 1727 Remarks ~'OO1 eT)cried fop - Initial Cloaed · . inPres. , ,,.1,1,?0 ,, 11~)6, '~].o5ed izl T)z'essl~z-e.. ~'oo~ re-o.T-~r~t-] Initial I FiowPros. 9~O 2 ~6 ~tronK blow T~-itH .... ~a.~ to t]a~ Final I FlowPree. ]._~3~ :2 ].13~ .... .. . ~l~trned to Final Closed .in pres. ]?70 : ~L].~)~ ~ook 8 30 m:i.lqT]te firml c~l O~lc] MudFinal Hydro Pres. .1700- 16~, . , ......... tiN iTE O STATES 9EPARTMENT OF THE INTERIOR GEOLOSICAL SURVEY LESSEE'S MONTHLY ';-~EPORT OF ~°'?RATIONS _Alaska Uot~nt~ ..Kenai .Peninsula _ ~'i'ch.~ Sw~scn ~ver ~f,~ ~ . - . ~'clls)/b; ih.c ~:ton/h ~,/' .~y . . ;:: 62, SW~SO~ ~ver Unit ......... 5T~RD 0~L C0. ~ uddr,~:.~' P. Oo B~ 7-839 - _. Co,~;,,~,~i Wes~ ~erations, I~.. .................... Anchorage ~ Alaska C, V. CHATTERTON ......................... BR._7-6201 ,./~fc..t'~ ti~:l,. -District-Superinte~-- ' ~'EIL ' :)~Y~ { Tik"":.' ' )~' ' ~L ';'t.'. i:i. l)Y ~;A~ ~ (~ L;.,,~ A ',F }iA;;h,.:L~t ~,i' :'&,. . ? .~.',~m~:ui .......... ~;n (hCus~'h.{~) ~ R:a.b~ :~:]' ' ~: :~', ~.,, :',,'"z ~ 8N ~ Drilled out cement 2o 31~~. R~ CBL and NCL 3100' - 1~0'o Shot h - ~. hol~s/foot 3~O' - 3~'. Rs. ~CT ~"1 on perf'~ ~t 3060' - 3~'. Set pac~e~ at 3030~.~ 30 mine. ISI. ~ened ~ool for 82 ~ fl~ test. 'Flied d~7 ~as at 3170 t,DF/D r.teo 5/8" sub~face ~d[3/h" ,surface bean. 65 ~ns. FSIo P~ess~es 173~' psi, ISI i285 gsi, ~ 630~ psi, ~ :680 psi, ~I 1285 psi ~ 1710 psio Set ~llable ~idEe plug at ~000'. Shot ~ - ~}' holes/foot 2766' - 2770". Set pa~ker at 2729'. 30 ~ns. ISI ~ened tool for ~ hr. 17 ~. fl~' testo :Flied dry; gas at 5!20]MCF/b rate. 5/8" sub- surface bean. ]/4" surface be~n~ Tubing Dressure 450~ psi. Ch~ed to '~" surface bean. ~.~ed at 940 MCF/D rste. T.P. 1050~ psi. 45 ~ns. ~I. ~essures: E 1710 nsi, ISI 1160 nsi, F 1070 p~, ~ L~4~ pcf., Fsz 1~6o, F~ 1~0. , : Shot 4 - ~-" holes/foot 2862' -i 2866'. '.R~ HCT ~3 on ~rforated inter- v~. 2~2' - 28~~, Set packer'~ at 2824'~ 46 ~.ns. IS I. Sened for 6 hfs. ~ ~ns. fl~ test. ~ 5/8" su~surfsce bean, ~/S" s~face bean. ~bing p~essnre 1000 psi. Flied drM gas at 3320 M~/D rateo Press~es: .E 1735 psi, ISI 11~0 psi, ~ 940 ps~, FF 11~5 psi, FSI 1170~ psi & ~ 1700 psio ~ ~ Drilled out bridge plug at 30~'. Cleaned out to 31~o Ran 2 3/8" tub~g (production string) to ~067' wi~h two Br~ HS-16-1. packers at 2~70' ~d 2704' ~d C~ ~~z~ ~alve at ~894~. R~ 2 3/8" tub~ (circulating string) to'lBlO~. 'Set pack~rso Displaced ~d / cc: U.S.G.S~ - M. H. So,stet Ohio -George Sowards Alaska 0 & G C C - D. D. B~ce~ U~lon - H. Ltan ' Rich~ieE- C. 'W. Perry, ~. R.~ ~tter Files: Producing, Land NWl SE No'rE.--Thcre were .......... runs or sales of oil; ...............................................M cu. ft. of gas sold; ............................................... runs or sales of gasoline during the month. (Write "no" where applicable.) NoTE.~Report on 'chis form is required for each calendar men[h, regardless of the stat.,s of upera[ions, and mus~ bo filed in duphcate with the supervisor by the 6th of the-succeeding niunth, unless otherwise dire,?c(] l.,y the rut)crv/sot. Fora 9-3~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS S~.,:~:,.: .... A. la~_ka ........... co~ty .... K_ena! Peninsula.. J,'~e/d... Swanson River COMPf~NY OF P. O. Box 7-839 ............ Comp,~ny ~Weste~n~e~ti~ns, Inc~ Anchorage, Alaska ........... ,,¢n,~ ~ Cf ii,. District ~rintendent %~ .... (]UL'[lfiS).',~'.''..,',.'",.'; ....... .... ....... ' f tf, g.oli., ..... .... SpudGed Apr~ 29, 1~2. Dried 13 3/4" hol~ O - 14OO' Dri~ed 8 3/4" hole 14OO' - 1500'. ~'~-~ & Sonic logs 1501' - ~1'. ~ and cemented 9 5/8' casi~ at 1~96' with 8OO s~cks cement, L~ated t~ of cement at 1352'. Drilled out sh~ at ~396'. Dri~ed 8 3/4" hole;1500' - 3805', T.D. R~ ~-~, Sonic log ~ ~M 3805 - 1396". Micro~ tools wo~d not 33 funeMOno : Cemented Plug ~.1 at 3162' with plug! at 2840'. Cemented Plug Did net locate top ~f plug. shoe cf surface casing with 151 plug! at 1150' o and test wello ~EO sacks cementL Located top of !~'at 2838' with 100 sacks cement. ~ented Plug #3 aS 1488' across sacks cement¢ Docated top of Decipion made l to drill out Dlugs, cement casing co: Drilled out cement ~nd cleaned 7" xi5½" combinatiom casing st: cememt at 2715 - Alaska O & O CiC - D* Do Bruce Richfield- C. I~/. Pe~ry, R. R. Ohio!- George ~oward~ Unio~ - H. Lia~ Files: Producing Land i out hole to 3150~. Ran and cemented ;ing at ]149'. L~cated top of ,, Ritter t Petroleum ~ranch Dlvlst;n of Ahines. andattainetals Alaska! Dept. of Natur Resources NoTE.~There were ....................................... runs or sales of oil; ...............................................M cu. ft. of gas sold; ............................................... runs or sales of gasoline during the mouth. (Write "no" where applicable.) NoTH.~Iieport on this form is required for each calendar month, regardless of the stain~ of operations, and mu~t bc filed duphca~e wkh thc supervisor by thc 6th of the succeedina mom, h, unless otherwi.~,.? dircct~zd by the SUlmrvi~or. Form I...." ..., ..= .. 111,,1\1 ..' ...' 'iii.. III. .'~IICIIJ F/¡J I- '~,',,>¡"f- .I""~.'.''-''" .-"", '~"" ,,_.", ""', fIJI!II#,~ ..... ~.-'t, "-\J: " ",' , - 101'._". ... ~~." "," .""t.1 ,"', ' , ',' tJJ _.- ....II "',, ,,-.'" ,.. :--'.-*--'.-- ..,,','.',;~,'" """"" ',..,',,' " '1flf,JfIII'/IIJV". .. .~, ,," .."."... ','111' '~'_., .'~~',.. r ..118..'''. ..I :<::z I - ~:) c g tV 1l/''/ S v..; t,. ~I ~;." ¡,\ f? ¡ J co .' /;Ja,\,' t ,rVtl. ST4~l.C-ìl~ nil ./ eCL (,1- Co; 1,'-{(j(Vl,é.) APPLICATION FOR PERMIT TO DRill, DEEPEN OR PLUG BACK APPLICA TIO~ TO DRILL ex DEEPEN 0 PLUG BACK 0 NAMF: OF COMPANY OR OPERATOR DATE s~ OIL CCIIPAU01 CA.L'IFORIQ:A, Wenem o,ust1ona, IDa. , Address City P. Q. ... 7-839 Aao1r1'88l .re81817 2, 1962 State .'!I"~ DESCRIPTION OF WELL AND LEASE ..---.--.-. ~--------- Name of lease Fie1d & reservoir (If wildca.t, so state) I County "." au ~------~~t_-~U1t1a ----'----'----"------"-'-------------- - ,S~ ....,. l1e14 Distance, in miles, and direction from nearest.to'Yn or post office .AøroxIateJ¥ l' ~1e. DOnia otSter~A1a'" Nearest distance from propoRed location to property or lease line: - .,~"..., ,._~..'... ..n.__.._n_..,..-----.'-,---- Distance from proposed location to nearest drilling-, completed or applied-for well on the same lease: - feet ... feet I Rot",y 0' cable ~ I A1>P,"X';~ w;: 't~._-----_._--- Number of ,veIls on lease, including this well. completed in or drilling to this reservoir: Proposed depth', -.---------!_-.------ Numher of acres in lease: 1tIO aen. ft... Wen ---------'~"-".."__R____"__.._--'''''~..''.'''~_._-'-~.,_.~- . --- -,., ...-.-- .,"'..n_,_"_~,,-.'"_M'."._..".,,-"~.__."--- If lease, purchased with one or more wells drilled, from whom purchased: :';ame Address .'.. .--_..._,,-,--------~._.,',~_._-_."~."~--_..._._- "_._-_._~"""".'-'_."-_.'---_".'_.R_'__'~'-.-.'-'-'---,,~..._._-_._-_."_._._._-,._~, ~-- '-------'._~'---'-- M.'M."'.---'----~"----"---'--~--""._--~._- Status of bond ...' nfll;be4. -.-----,,----... _._~,-_.,.._-_.-..~ -..,--~"_._-~-~-_._---- Remarks: (If this is an application to deepen or plug back, briefly describe work to he done, giving present producing zone and expected new produëing zone) . ... p(-;..~:.t()~('.'~",~ :ì'~ I;"~ ~'; ~~ L: L~ ~'i~::;:,~$ '''--'.----'''''-'''-'''............"""""........--- CERTIFICATE: I, the undersigned, state that I am theþt..:t.~.Of the ~~IA (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 therein are true, correct and complete to the best of my knowledge. Or~ginaI signed Signature ::::alN::~'".,'..." '1wr~ ;S~21962~J"^ ~ Approved By, R'J'illr,)jv, "t't;¡. "l1gr V - ( Division of l'dnes & Itinerals Notice: Before sending in this form be sure that you have gIVen all information requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Effective October 1, 1958 I Form No. P-1 Authorized by Order No.1 GPO øe 20"0 BYO~~Z- ~~:~~.. . Title .D1~~~c' Supe~1~~_J.a.~_~.~!!~ ____.._____________..-~,._.. ..--__..______~_________ _"___~_·~__.____·~~<_T-· "_______ Ancho e Alaaka ./' . '-"'d~"' ' ......... c. . _.__.__."_....._u Company __S~ O~ ~____~~ WIS~._~ItATIOHS, lIte. Address __Of!· o!_.~x 7 ~~, I "nderatand that this plan of work.rnust reçelv. approval in writin. by the Geological [;urvey beforf' opera lions may he commenced. surtace. Ðrill to 1SOO', 10" .. ~nt 9 5/8t1 cae1Da in Qne .tap to Inst.all and tea't øJ&øs XII Blowout PreveD't1on lquipment. Test below 8ãoe ot .urt&<:e ca..ins. ~~CðÞ1&J^,A 'T/OÞ/ Drill ahead to 3100', Joe and ce.nt 5in~ 1n8 in one stases Ietab11eh requ1__ water shut-ofts. ßelect1.,.q Je't pertoptt.e and 1;ea't saa4ø as nee.s_%')'. RIm 2 3/8" w1J1nS aD4 QOIqpl.ete.. ' (State name. of an.-fexpe<:led depths toob;'ct¡;'. .ands; .how size., weights. and length. of proposed ca.in1(8, indicate .nuddin. job... ",,,n.nt- inllpolnh, and all other important propoaed work) -The elevation of the ~~ J above sea level is 11j ft. a:pproxiately. DETAILS OF WORK l:....;li\{t· or '!'I'f ;-¡I¡.ry\ (Fíl'l,lì Xena1 Peninsula (('utwtv "I ~ut,, ¡; sí~;;ì - , ~n R1ver Alaska. .____.__J~ry 2 ",,_ ._.0 19~2 , '. . .&»Proa1a1iel7, N 1 . Ii . 'W ell No~RU 221-33 1S located I 660. ft. from. l S ¡ lme and. 1980 ft. from '- \v lme of sec. 33- _.wt ProJ. Sec. 33. ___ T. S B. R. 9 w. ._. Sew.rt B ~ M U·'¡' :;d' aId :S,'( :\1),) !Twp,) (kJUI¡;I» \ 'Inídnm) (INDICATE ABOVE BY CHECK MARK NATURE OF REPORT. N01 ICE. OR 01HER PAT" .~ J SUBSEQUENT REPORT OF WATER SHUT-OFF, SUBSEQUENT REPORT OF SHOOTING OR ACIDIllNG SUBSEQUENT REPORT OF ALTERING "SING : SUBSEQUENT REPORT OF RE-[JRILLlNG OR RU....IH SUBSEQUENT HEPORT Of ABANOONMFNT SUPPl EMENTARY WRL HISTORY NotiCE OF INTENTION TO DRILL NOTICE OF INTENTION TO CHANGE PLANS.. NOTICE OF INTENTION TO TEST WATER SHUT-QFF__ NOTICE OF INTENTION TO RE·DRILL OR REPAIR WELl. NOTICE OF INTENTION TO SHOOT OR ACIDIZE.___d_. NOTICE Of INTENTION TO PULL OR AlTER CASING. _ . NOTICE OF INTENTION TO ABANDON WELL__ SUNDRY NOT1CES AND REPORTS ON WELLS Unit a_MOn a1~r _ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY x·I Anchozaae 028399 Lea.. No. (SVWHIT IN JR1PLICATF) Land OfT;. .. :¡"orul S-331 u. (Febf'~9,íJ) "<--v Blldg&: !H.t-'¡111 ,'".4:.' Inf''',4 \PIJr<n u! ,~x!jjrl"~ L',~ ;1\ ~ ........' \J -f 1. 2. 3· 14.. 5. 6. 7. r .j ~-:.; .. .. NOTICE The following well logs and oversized documents have been placed in offsite storage. If you would like to view the original documents, please contact the AOGCC librarian. AOGCC 3/4/2005 ¡SÇHWM<jÉ~~E~:: '[1:...:< ,':. {/,:":',,,,\,',:' <., -;-:- ,-,," ":-::- . " .., ", , 1,:,,;( ... . .' ,......[< COMPÀWl 'STANDARD" 0 ì ß;;"( ',. : Oth'èr' jµniey~ .... i'¡, ..' 1/:",'::\,''', " '.' "'. ".' ,I, , ".. ,[",'.."::,,. 'f':" 'I, I, , , .."¡ì:"'..";:.:. "'\,i;, . 11',;'1, .',.' ~I""" .' II ' , , , , ';' ,<,,' ',," " ";",' ',:>': ~I:":"::':" OF eAt If;ORNJA" """,,:,:<MI_ _r:OM'.... ',' .1.'; :; t:~;~V".,\:t,·Š~jl:~~ (~' :ï,' .,' %, >" QiL. '<,."",' ",':" 22l,>" ,'jl ,3,' '3,'" "";;"",'" , . "', ':".>":', '.'. ':::;;1;1";::':, ' '.' 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