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Home My WebLink About160-027 STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION Rt= CE\VED WELL COMPLETION OR RECOMPLETION REPORT AND L6~ "nnA SuspendedD WAGD 1b. Well Class: UL I 1 " '-UU 20AAC 25.110 ~ Development 0 [xplor¡:~or,/-'r. nission Other e - - "'eDli~ ~Iaska .&rat,gråPI~~c"ð;/'O" 5. Date Comp., Susp., or 12."l5"ermit to Drill Numbet\".# I W Aband.: 9/4/04 60-0027 JO¡-l~; 6. Date Spudded: 13. API Number: nla 50-133-10167-00 7. Date TD Reached: 14. Well Name and Number: nla SRU 41-33WD 8. KB Elevation (ft): 15. Field/Pool(s): 179' above MSL 9. Plug Back Depth(MD+ TVD): 2,990' - 3,000' 10. Total Depth (MD + TVD): 3,000'/3,000' 11. Depth Where SSSV Set: nla 19. Water Depth, if Offshore: nla feet MSL 1 a. Well Status: OilD Abandone~~ 20AAC 25.105 No. of Completions Gas U Plugged U GINJD WINJ - WDSPLD 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 4a. Location of Well (Governmental Section): Surface: 960' FNL, 1,320' FEL, Sec. 323, T8N, R9W, SM Top of Productive Horizon: Total Depth: 4b. Location of Well (State Base Plane Coordinates): Surface: x- 346,404 y- 2,465,561 TPI: Total Depth: 18. Directional Survey: Yes 0 No 0 21. Logs Run: nla 22. CASING WT. PER GRADE FT. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM HOLE SIZE 0 2~ 0 2~ 0 325' 0 325' 0 3,000' 0 3,000' 20" 13-3/8" 5-112" 54.5# 17,20# 17-1/2" 8-314" J-55 N-80, J-55 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): see schematic attached 24. SIZE 3-1/2" SRU 41-33WD 16. Property Designation: Swanson River FieldlSterling 17. Land Use Permit: A-028399 20. Thickness of Permafrost: nla CEMENTING RECORD AMOUNT PULLED surface calc 426 SX, surface calc wI 30% 2,036' calc wI 30% TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 2,859' nla 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT AND KIND OF MATERIAL USED see schematic attached for detail 26. Date First Production: nla abandoned Date of Test: Hours Tested: PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): n/a Production for Oil-Bbl: Test Period ... Calculated Oil-Bbl: 24-Hour Rate ... Gas-MCF: Water-Bbl: Flow Tubing Press. Casing Press: Gas-MCF: Water-Bbl: Choke Size: GaS-Oil Ratio: Oil Gravity - API (corr): 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". nla U K I b , t~ A L /\ ~ . ~ CONTINUED ON REVERSE ~ Form 10-407 Revised 12/2003 ~ ~ Q'- 28. GEOLOGIC MARKERS 29. FORMATION TESTS . NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". nla 30. List of Attachments: daily summary, 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: ?~ t"'~ ~ Phone: 907-276-7600 Date: 10/7/2004 ¿:/ 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 I njection, 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 # SCU 41-33WD As Abandoned on 09/04/04 11>= 3017' Straight Hole Cas in Tubin Size T e Wt Grade ID Btm Cmt Cmt To 20" Conductor 23' Yes Surf. 13-%" SurfCsg 54.5 J-55 Surf 325' 17-Yz" 276 sx Surf Calculated 5-Y>" 4.892" Surf 53 5-Yz" 4.778" 53' 338' Surf 5-Y>" 4.892" 338' 1174' 426 sx Calculated wi 30% 5-Y>" Prod Csg 1174' 1176' 8-Y¡' 5-Y>" 1176' 2932' 2036' 5-Y>" 2932' 3017' 300 sx Calculated wi 30% Surf 2.5 bbls 25' ITEM DETAIL NO. DeDth Date Coments 1. 3017' to?? 8/71 Cemented 3-Yz" tbg in place. Did not get cmt to surf. Unknown TOC. Visually confirmed TOC in PC x SC annulus is (â¡ surface on 8/26/99. 2. 670' 8/71 Csg Leak. Attempt (5) cement sqz's at 50 sx ea. For a total of250 sx.. still had cse: leak. 3. 344' to? 9/2000 Rotten, corroded, scaled up tbg. 4. 25' to 344' 9/2000 2.5 bbls of 15.8 "G" Neat Cement Plue: BRIEF HISTORY Dat 8/60 8/71 72 to 95 10/96 10/97 8199 9/2000 PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 2000 2001 WSO 5.5 8/60 WSO OK 2305 2306 WSO 5.5 8/60 WSO OK 2707 2708 WSO 5.5 8/60 WSO OK 2882 2926 4.5 8/60 & 10171 2940 2978 4.5 10/71 GPS Readings 60 degrees 44.72 N, 150.51 degree 67 W 89' SRU 41-33WD REVISED: 10/6/04 DRAWN BY: ded 8/15/04 SIMOPs with production and construction. PTSM with Peak crewMoved Vac truck, roustabout field truck and air compressor onto location. Got excavation permit. Pulled bull rail and general junk away from work location. Made sure injection line was still isolated and bleed down. Pulled injection line for well head back to flanges that where sub grade and off pad. Blinded flow line below grade and took pictures of same line in relation to well head.Laid pit liner down for excavated soils. Laid pit liner down for concrete. Started stripping 6" to 8" of dirty soils from top of a monopore concrete slab. Found it imposable to separate dirty stringers of materials from soils. Piled all materials on same pit liner. Encountered a 4" old flow line stubbed up through pad just below 8" of dirt. Found one old conduit in soil above concrete also.Dug around slab and found footers under two sides. We also found an old utility sump beside pad. (Took pictures) Took Jack hammer and broke up slab around wellhead and old flow line stub. Used excavator and pulled concrete slab up in chucks, cleaned as well as possible and stacked on pit liner. Hand picked concrete chunks from site.Dug soils from between footers and found them to be 4' high X 8" thick walls with footer. The plan now is to use them as coffin box walls. Placed all soils on pit liner as that are suspected of being contaminated soils. Stopped digging at wall footer (hole is 5' deep now) and squared & cleaned up hole. Got welder to start making spreader pipe supports for top of footers (This will make concrete walls into safe coffin box to work in without excavating larger hole ).Bermed in soil pile. Cleaned up work area and spotted equipment around hole for the night. Laid spreader bars across walls and need to bolt them in place when we get materials in hand. Sent excavator operator to town and shut Peak roustabout down for night. Took pictures of progress.All pictures have been emailed to town and saved to well file. 8/16/04 Cleaned area up some at SRU 21-33 WD. Worked on SRU 41-33 WD site. Cleaned of surface casing for cut. Fenced area around hole. Installed spreader bars on footers. Worked on field triplex test pump so that we could use it as we got call from town to pressure test Tbg again. Testing went as follows We filled 25' void in Tbg to surface and put night cap back on. Pressured Tbg up several times to 1500 psig and found pressure would fall back to 1000 psig with in a 5 minutes repeatedly. Noticed a small weep of water out of cement between 5 1/2" casing and 13 3/8" casing. Got Barton recorder hooked up to tubing and pressured Tbg up to 1500 psig one more time and recorded results. The pressure falls within 5 minutes from 1500 psig to 800 psig. From there it took two hours to fall from 800 psig to 400 psig. Seven hours later at 03 :00 hrs I found the well with 300 psig still on the tubing. The 31/2" by 5 1/2" annulus has been zero psig through out test. The cement in 5 1/2" X 13 3/8" annulus has weeped water through out test.Note:Scott Thorsell (Remediation Technologist with UNOCAL) came out today to look over excavation sites at 21-33 WD and 41-33 WD. He made his field notes on condition of soils & cement and also of facility piping unearthed in dig's. We spend several hours talking to Kenai Peninsula Borough Landfill personnel, Anchorage Sand and Gravel and he and Bob Shipley conversed with ADEC on findings. We found out that Anchorage Sand and Gravel will not take or concrete unless it is broke down into less than 2" size materials. The borough land fill personnel said that they would take the cement as long as it was as clean as the pit liner we send them at the end of each rig program. ADEC contact has indicated that we could back fill holes with materials excavated from holes. 8/21/04 SIMOP's with construction, production & rig.PTSM with PeakPeak crew cleaned first load of concrete for hauling to land fill tomorrow. Picked up rocks, smoothed out ground and laid pit liner in bell hole around SRU 21-33 WD wellhead. Banded pit liner to surface conductor to seal for cutting. Got permits and had welder cut cement monolithic pad collar away from 5 1/2" production casing and hanger on SRU 41-33 WD so that we could investigate the surface casing leak. Tubing is fluid backed with 1 psig (looks like Xylene or solvent has migrated to top of water column). 5 1/2" X 3 1/2" annulus still has no pressure and has a pad of same light hydrocarbon ends standing on surface. Cleaned 5 1/2" casing hanger and stub that's above surface casing. Inspected same and found hanger and 5 1/2" pipe looks good. Cleaned concrete and found a quarter segment to be wet as water is weeping up through it vary slowly (this is with 1 psi on tubing and 0 psi on annulus).Opened annulus 2" ball valve and attempted to get cement top tag with string and stiff wire (it appears as cement top is just at the ports off hanger). Could not pull tree cap until bleeding off l' of Xylene, solvent, lights ends off tubing. The only valve on wellhead is a total piece of junk. Decided to pull and change incase of future work. Hot bolt and pull swab on wellhead to replace with another valve. Found the existing 3" 900# raised face valve was made up with a garlock gasket only to a 3" 900# RTJ flange and the face is eat up. Looked for 3" 900# RTJ valve in field with no luck. Resourced a HalfRTJ ring gasket and installed it as ring grove is in fair condition on flange on well head. Put garlock gasket between halfRTJ ring gasket and new valve raised face.Attempted to test new tree valve and found night cap leaking. Upon inspection found ring grove for gasket cracked out. Found 3" 9000# test flange and put on new valve to test on. Tested new valve to 2000# (OK). Opened valve and pressured Tbg up to 1500#. Well is bleeding off pressure down hole a little faster than before. Pressured back up to 1500# a couple of times and after 10 minutes started to see flow up surface csg by production casing annulus cement. During the pressure testing the 3 1/2" by 5 1/2" production annulus has no pressure and has not had any fluid level rise.It appears that the surface section of 5 1/2" and hanger is good. That the leak up surface casing cement is from depth as flow show is delayed 10 to 15 minutes after pressuring up tubing. Known: the 3 1/2" Tbg is compromised around 344' depth. The shoe on the surface casing is at 325'. There is (some) good cement in the 3 1/2" X 5 1/2" production casing between surface and bad tubing as we do not see flow up it (where did the hydrocarbons come from found on top ofthe production casing the first day?).Note: Ifwe do high pressure work or put loads on the well head in future practice caution. This well head has been cracked on the tubing above hanger flange and ginger bread repaired. Consideration of changing valve to RTJ flange before high pressure pumping. 9/1/04 Opened well had tubing 25-psi got methanol returns. Moved in and spotted Cement equipment, had welder to fabricate slip plate for tubing and bell nipple to put on top of Master valve to catch returns in drums. Bled off pressure methanol & H2O, gauged to TOC 130'.Mixed and pumped 1.3-barrels cement mixed with prop-net got back 1.75- barrel fluid no cement Prop-screen plugging up pump majority of prop on top cement unable to pump. Shutdown after cement pumped no cement returns. Isolated well to let cement heal overnight. 9/2/04 No ActivitySims-Op meeting with Plant personnel. Opened well no pressure, made gauge run tagged TOC 47'. Pressured up to 1,800-psi, I-hour 1,750-psi looked good. Mixed and pump .750 bbls. Cement to 15.8-PPG + got cement returns shutdown washed up equipment, secured well moved to SCR 33-08 Well. 9/3/04 Moved in dug down around well preparing well for mechanical cut Moved equipement away from well and installed liner to Conductor. Plans are to cut the 20", 13"?, 5-112", & the 3-112" tubing. 9/4/04 No ActivitySim-Ops meeting with PlantAOGCC representative on location approved cement job, top all casing w/cement welded cap on as specified. Filled cellar with dirt cleaned up location, hauled equipment to PS yard. Covered up 21-33 cellar with dirt picked up old casing spool. Both 41-33 and 21-33 projects complete. See below comments. Surveyed ground elevation around well, 5.6-112' , made cut 4' below ground elevation.GPS Readings 60 degrees 44.72 N, 150.51 degree 67 W 89' 9/5/04 Cut wellhead off 9/7/04 Rest crewGrade and clean pads. Clean and package concrete for shipment. Clean equipment and De-Mobe from field. In general cleaning up after P&A work, G&I work and Kuukpik rig. Stagner departed field for Star Pad in AM & Lazenby departed field for HV Pad by days end.Rest crew 2004-0904]&A_SRU- 41-33_1g.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, P. I. Supervisor DATE: September 5, 2004 THRU: FROM: Lou Grimaldi, Petroleum Inspector SUBJECT: Plug and Abandonment SRU 41-33 PTD #161-003 Swanson River Unit Swanson River Field Saturday. September 4. 2004: I witnessed P & A procedures on Unocal's well SRU 41-33 in the Swanson River Field. I arrived to witness the cutoff of the casing, There was good cement to surface on the conductor, 13" x 5 % cement level was down at -2',5 % x 3 % down at -16' and the 3 % tubing was full of good cement. Danny Macdonald (Unocal) flushed the voids with fresh water and started preparing to cement the voids I left location at this time. Sunday. September 5. 2004: I returned today to find all strings filled with good cement. The plate was welded on and dunnage placed over the top. There is still an abandoned flow line stub in the cellar area that will have to be dealt with. Attachments: SRU 41-33 cemented stub.JPG SRU 41-33 marker plate.JPG SRU 41-33 flow line.jpg NON-CONFIDENTIAL Cc; Tim Lawlor (BLM) 2004-0904]&A_SRU- 41-33_lg.doc 10f2 2004-0904]&A_SRU- 41-33_lg.doc Swanson River Unit 41-33 (Unocal) Surface Abandonment Inspection Photos from AOGCC Inspector Lou Grimaldi September 4, 2004 SRU 41-33 cemented casing stub SRU 41-33 marker plate SRU 41-33 flowline 2004-0904]&A_SRU- 41-33_lg.doc 2 of2 \I-l f.::1 It"" T ( ......', ¿..u>"'<r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL v.J6~ 20 AAC 25.280 Abandon.!.d'" Suspend U Operational shutdown U Alter casing 0 Repair well 0 Plug Perforations 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 2. Operator Name: 4. Current Well Class: Union Oil Company of California Development 0 3. Address: Stratigraphic D PO Box 196247, Anchorage, AK 99516 7. KB Elevation (ft): 179' above MSL ~.,-- " 1. Type of Request: Perforate U Waiver U Annular Dispos. U WfJr Stimulate D Time Extension 0 Other ~ Re-enter Suspended Well D l.ccJiCl^- CJlr.t"':lfo\.e..Q. 5. Permit to Drill Number: Exploratory D .ßO-962T I It>o - 0 l7 Service D 6. API Number: 50-133-10167-00/ ¡J6 ~ Casing Structural Conductor Total Depth TVD (ft): 3,000' Length 9. Well Name and Number: SRU 41-33WD /' 10. Field/Pools(s): Swanson River Field/Sterling PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): IEffective Depth TVD (ft): 2,881' 2,881' Size MD TVD IPIUgS (measured): 2,990-3,000 MD Burst Junk (measured): 2,897' - 2,990' MD Collapse 8. Property Designation: Swanson River Field 11. Total Depth MD (ft): 3000' Production Liner 23' 20" 23' 23' 325' 13-3/8" 325' 325' 3,000' 5-1/2" 3,000' 3,000' 853 1130 Surface Intermediate 273 4910 Perforation Depth MD (ft): 2,882 to 2,978' Packers and SSSV Type: I Perforation Depth TVD (ft): 2,882 to 2,978' n/a ITUbing Size: 3-1/2" ITUbing Grade: N-80 Packers and SSSV MD (ft): ITUbing MD (ft): 2,875' n/a 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Date: 13. Well Class after proposed work: Exploratory D Development 0 & 15. Well Status after proposed work: 6/1 004 Oil D Gas D Plugged WAG D GINJ D WINJ Service 0 D Abandoned 0 D WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Philip J. Krueger Title Drilling Manager Signature \...~..:. / þ~ Ph(~ne 907-276-7600 Date / (. I COMMISSION USE ONLY Contact Steve Tyler 907-263-7649 4/8/2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30 4. Î 3:) /' Approved by: 4- fIII1I" 9fL Location Clearance ¡if RECE\VED ~PR 1 9 2004 ro ~\<}:;\on c!~ & Gaß C,ons. .... " ~\8tl¡,~' J\{\t(\ma~e COMMISSIONER :=:,ON Daæ ~ f 1 INSTRUCTIONS ON REVERSE 0 R t G \ N A L Submit in Duplicate 0 Plug Integrity D BOP Test 0 Mechanical Integrity Test Other: ~t\- --- " SRU 41-33WD Proposed Abandonment /' . Utilize backhoe to dig 6' 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. ToÞoffwith cement as needed / . Weld on abandonment plate. Take GPS reading. Back fill hole to pad level. RKB to tbg Hog =10.31' [I] ~ TD= 3017' Straight Hole SRU 41-33 WD Aband 9-18-2000 Size 20" 13-:%" 5-;/;," 5-;1;," 5-;1;," 5-;1;," 5-'1:," Type Conductor Surf Csg Prod Csg Wt Casing Grade m & Tubing Top Bim Surf 28' 54.5 J-55 Surf 17 J-55 4.892" Surf 20 N-80 4.778" 53' 17 N-80 4.892" 338' DV Collar 1174' 20 I N-80 I 4.778" 1176' 17 J-55 I 4892" 2932' 325' 53 338' 1174' 1176' 2932' 3011' Tubing cemented in csg w/160sx 3-'1:," Bullhead emt I 9.2 I N-80 I 2.992 NO, Del!tÞ 1. 30 IT to ')') 2. 670' 3. 344' to ') 4. 25' to 344' Date 8/60 8/71 72 to 95 10/96 10/97 8/99 9/2000 ~Ome!HS Cemented 3-;1;," tbg in place. Did not get emt to surf Unknown Visually confirmed TOC in PC x SC annulus is @ surface'ón Attempt (5) cement sqz's at 50 sx ea. For a total of250 sx.. leak. I Surf I 2859 ITEM DETAIL Date 8/71 8/71 on Hole Cmt Cmt Top Yes Surf 276 sx Surf Calculated Surf 426 sx Calculated w. 30% 2036' 300 sx Calculated w. 30<~':< Surf 2.5 bbls 25' 9/2000 9/2000 scaled up tbg. of 15.8 "G" Neat Cement Plug 17-Y;' 8-Y';' CQ.~!!li Drilled and completed as a water injector. WO Retrieved parted tbg. Three fishing trips. Failed to sqz csg leak @ 670' after (5) attempts. 250 sx sqz'd. Cmt 3-1/2" tbg in wcll w/ 160 sx. No returns at surfàce. LIH 21' of paired formed wire ¡j-om strip gun. 5 CT CO and approximately 15 acid jobs over this time period CT CO to 2881'. Could not get deeper. Perform acid job. CT CO. could not get deeper than 193'. Acid job to restore injection. CT CO to 406'. No fU!1her progress. No Joy on SL bailing attempts. Dump bailed 20% IICL. No Joy in establishing communication w/ interval. Lubricated 30 gals of20% HCI down tbg had same results- CT CO milled to 401'. RI w/ nozzle to 344'. No further progress. Circulate/spot 2.5 bbls of 15-8 ppg Cmt plug inplace t/344 to 25'. 2000 2305 2707 2882 2940 BRIEF HISTORY PERFORATION DATA 2001 2306 2708 2926 2978 WSO WSO WSO 55 5.5 5.5 4.5 4.5 8/60 8/60 8/60 8/60 & 10/71 10/71 WSO OK WSO OK WSO OK REVISED: 3/9/2004 DRAWN BY: SLT STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Servic~ Well OIL: GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 399-110 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 133-10167-00 4. Location of well at surface 9. Unit or Lease Name 960' FNL, 1,320 FEL, Sec. 33, T8N, R9W, SB & M Swanson River Unit At Top Producing Interval 10. Well Number Straight Hole SRU 41-33 WD At Total Depth 11. Field and Pool SAME 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Swanson River Field/Sterling Pool 179' KBI A-28997 22.. Typo Electric or Other Logs Run None Ran 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD, CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD [ AMOUNT PULLED 20' 0 23' To surf 0 ,,, 13-3/8" 54.50# J-55 0 325' 17-1/2' 272 sx 0 5-1/2' 17-20# N-80 / K-55 0 3000' 8-1/2' 726 sx 0 3-1/2 9.2 N-80 0 2875 4.8' 300 sx 0 , 24. Perforations open to Production (MEN-'rVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET IMD). PACKER SET (MD) Measured 2882- 2926' 2940 - 2978' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & 'KIND OF MATERIAL USED TVD Same 344 - 25' 12 a~ Class 'G' Mixed to 15.6 ppg . , 2.5 bble of slurry placed Inside of 3-1/2" tubing 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Water injector Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD => Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (¢orr) Press. 24-HOUR RATE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED MAR 1 ~ gggll ~.1~ Oil & ~ ~, , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , 31. LIST OF A'I-I'ACHMENTS Wellbore schematic, Summary of Daily Operations 7 Title Drillincl Manaee, Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more lhan one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for lhis well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-4o7 UNOCAL ) RKB to TBG Head = 15' Tree connection: TC-3 Uni-bolt Hole in Casing 670' ,,SIZE WT Swanson River Field Well # SRU 41-33WD Abandonment CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 20" Surf 13-3/8" 54.5 J-55 Surf 5-1/2" 170 J-55 Surf 5-1/2" 20g N-80 33' 5-1/2" 17# N-80 318' DV tool 1153' 5-1/2" 20g N-80 1155' 5-1/2" 17# 3[-55 2911' Tubing/Cmtd Liner: 3-1/2" 9.2 N-80 Surf Lowest jt saw tooth on bottom, no collar 23' 325' 33' 318' 1153' 1155' 2911' 3000' 2875' ITEM DETAIL NO. Depth Item 1 670 2 2875 3 2990 Casing Hole sqzd w/300 sx in 9/71 Unable to seal Tubing tail, circ 160 sx cmt and displaced with 25 bbls Rathole filled with sand prior to cmt job, cleaned out to 2990' with 2-15/16" bit in 10/71 after cement job thru tubing. A ABANDONMENT DETAIL 344-25' 2.5 bbls Cement 15.5 ppg into tubing Cleaned out with Coiled tubing to and step mill on motor to 401'. Ran in hole to cement and could not work past 344'. Placed cement with coiled tubing from 344' to 25'. Pressured up to 1500 psi and pressure dropped to 1350 in 10 minutes. TOP PERFORATION DATA BTM ZONE SPF DATE COMMENTS 2882 2926 2 10/71 2940 2978 2 10/71 PBTD = 2990', TD = 3000' Straight Hole SRU 41-33 WD Propl DRAWN BY: TAB SRU 33-41 Description of Activities Abandonment Summary September 16, 2000 PJSM on moving Coil Tbg Unit and support equipment. Load coil equipment on trailers, move equipment from well SRU 14-15 to well SRU 41-33. Spot in and set coil tbg unit around wellhead. Spot in and set batch mixer and cmt pump. Rig up surface lines. Spot and set in choke manifold and displacement tank. M/U XO flange on top of tree. M/U coil BOP stack on top of tree. Hook up service lines to water tank. Stab 1.5" coil into injector head. Clean location. SRU 14-15 after rig move. SDFN September 17, 2000 Install 2-1/8" Baker external connector, attempt to pressure test, leaks, change connector, leaks during pressure test, install 3rd connector, pressure test to 3000 psi, ok. Pull test coil to I6k. M/U BHA, Pressure test BHA to 3000 psi, ok. M/U injector head and lubricator. Test BOPE. Install leg extensions, Make up extra chains to stiffen up for stability, Open well to coil, 0 tbg pressure, Attempt to run in hole with coil, tag up on master valve, work valve, coil will not pass thru tree. Call out Steve Lawrence to insure proper turns on opening valve, getting 13 turns on top Rockwell valve, 10 turns on Demco valve, Work both valves, Mill tagging up inside flow-tee above master valve. Call out Baker to bring out smaller size mills, Pump down coil annulus in attempt to pump away scale, cannot RIH past flow-tee. Set back injector head, inspect mill, marks on OD and face of mill. M/U step mill, 1.65" to 2.27" OD. RIH, tag up @ 396', mill to 401', pump sweeps, attempt to mill. deeper, with no progress. Attempt to inject and pressure up to 1750 psi and held for 10 min, bled down to 1350 psi. Pull out of hold and change BHA. Make up roll on connector and ported wash down nozzle. M/U injector head to BOP. September 18, 2000 RIH with nozzle tag up at 344', attempt to work past 344', no progress. Batch mix cement. Pump 2.5 bbls 15.8 ppg cmt, pump 5 bbls water, pump 10 bbls 2 ppb biozan and borax, displace to end of coil tubing. Pull up 70 fpm while displacing cement at 1:1 basis. POOH to 25'. Cement plug place from 344' to 25'. CIP @ 01:20 hrs. Applied 1500 psi squeeze pressure, hold for 10 min, pressure bled down to 1350 psi. Circulate until fluid cleaned up (20 bbls). POOH with coil tubing. Secure tree, Bled down lubricator and injector head, set back injector. RDMO coil tubing unit, blow down coiled tubing and lines with nitrogen. ScblllnlbllP ' Coiled Tubing Service Report ebalUUmm'eG'- -~.. ..... ---[-~.o=.ea u.pl). [ h,~,i,,.o-... ] I Kenal, AK I 9/16/00 SWANSON RIV UNIT 41-33WD ~"tl°a "I e~'-~--" W.aMD ' "]'WeliT~ ' Field FormeUelt Name/Type sw^.so..IvE. D,.y e.. one 0 '! 0in ! o. i 0,,.,, --Coun~ ~' ' Sbt~/PTo~inm -"--'---" --------' '~-~'-- - T''BH~'~ i ~14~-r Perl Prel element · n Mil 0'FI 0'F I · 0 psi/fl AK .. - ?,-1 ....... ,. I,,~ ....... ~. ...... ...: ..... ~e' o.,.~ ['ort a.,,d~, v., ~*~_j~.~~r~._-~,L~.~~~ Disposal Land i~pm, It sm. In ..~ we~gb~ ibm. ' o~;~homZo.. ' w., c,a. ' I w., Typ~' -----" ' ~'----- ' T '9--0 . ! ! /i m i OldI Other 0 0 : 0 ..,. ~ , ........ ~.'-~,, P'-'~mary Treating Fluid 3 Fluid ~lr'GosltY Fluid Denrdt~ . ~ ...... '~ *~ Sllcl<waterI O cp lb/gal ~ptt~, mm. in : We~bt, in Cr~, Thing C,T Reel' ll~ i ct:Still1, ID ] CT Sitt~l. ' '! CTTlflakn' 0 ' 0 '0 1500438 5053 1.5 in 0.11 in -'"~'---- ---"~--~0 ' ' SelM(:eUne Jel)'i'ype Top, It BoRom. R ~"~o, dShatl Tetnllntm'vil Coiled Tubing CT Well Clean-Out MU. Alle~vee Tul)lng I.s~uf. I ..~. x,,o.d ,,,. r,-.-m WeqHoad Connection 0 0 ~ ~' O O tI m. m i Il 1750 psi 0 psi RX35 5K 0 0 0 I 0 S'"'%.,M~len~' .... 0 i 0 0 I-- 0 0 in Provide 1.5" Coiled Tubing Unit ~nd ~upport equipment t= c)een out tubin~ T'--~* C~.--'--'~--' ~~n* P~*~--~--- a~ per custome~ requ,,,,t. C-ileal Tubing 0 bbl Seal Bore · ' TUbing'VoL Ca~lng~ok-- Ann-'~'mV~ ' Ol~HoleVol 0 bbl 0 bbl, 0 bM 0bbi I g/~./oo ~:oo:OOAM I O/16/00S:00:~PM BadTubing ' I 402fl ~ 2.8131n L L .... · .... · ...................... -"--- .- ..... ~, .' ....... ' :: ;c';?"~*,';~:'.- - '-;;;-' ' I ~. '-~ .... '~':':~':':'~':';-':¥~::: :.: :?" ~' :" :::'~'~' 6:o0 0 On Looation .. B., 10 0 Safety Me,ting , I' 8:30 .. 0 Reck & Move Equipment .. '14i~ o Start CTU Rig up , la:OO ......... o BOP's on well 19:00 ' 0 ' Off I. oeation __ 0:20 343 124 0 1.3 0 0 2900 0 Tag Something 8:00 0 Safety Meeting . ,., . .. .... ~6:20 ..... 0 MU tool.trine . ,, · .... . . . '~:'~'~' 1600~ 0 ~ull Tees Connecter ill iii ~:¢0 0 MI./BHA ~O1_1~1~ .... 6 3~(~0 Pressur. teat BHA 10:25 ..... O ....... Connector Leaking .... .. 10:28 , , 0 ... Change out con.hector .. 10:4b 15000 O Pull Tees Connecter , , , 10:R6 0 3000 Pressure test BHA 11 -'o0 ' --': ' 0 ' Connector I.o,,akinO 11:10 .... 0 Cut ooil ' ., 11:40 16000 0 Pull Teat ne'W Conn6=tar . 11:45 " . 0 3000 "ressure toes BHA . ._ 11:60 "' 0 " ~ood Teat on BHA Sop 1m.2000 VV~.~ v~.O. SR Page SWANSON RIV U~iT ~ ~ .... 1. 1 ............ .....-:x~.~ ......... . .... · ....... ~ ...... '--.~ 12:00 0 ~0 2~0 _,BOP--.Testing- _ 1'~':00 -' 6' 0 w O O 0 0 0 .., '~ Op.n welIIRIH 13:05 , O ,B HQGo thru tree .... q~:30' . 0 , , Wait °n Bokor mole 'i'~:2U . 0 , . 1700 Wor~o ...... ,,, , i 16:30 0 doge thru tree . 'i8:40 - ' , . 0 Inst~ StepmJll i ~8:50 ' O On well ..... 18:66 ...G 2000 2~0 ~rosnr. T~K StaGk 19:00 ' 0 0 0 0 0 ' "0 0 0 Open welIIRIH .~ _ 10:10 3~ O~ O ' 1.~' O' 0 3700 ' 0 Wt. Cheek 1'9:1S 3~ 3~ 0 1'.3' '0 '" O ' 3~0 ' '0 ~.g,endstailmotor 19:25 3~7.6 1~ " , O,. 1.3S ..... 0 '0 ~0 0 Tag w~otor work , - ,i i 19:35 399' ' 100 O .~.,35 0 0 .,3~ . 0 H.rd Millin~~ 20:10 4o1' 3~ 0 1.35 0 0 3~0 0 Slow Mimng ~%:~5 401 "' 450 0 1:35 O ' O .... ~3 'O , .Stnl Slow milling 21:15 401 450 0 0.3 0 0 17~0 0 In~ion T.~I . 21:~' 401 " 45O ~ ~.3 o - 0 ceos " 0 Pump sweep 22:15 ~ 450' 0 1.3 0 0 3~0 0 POOH . .. 22:35 .... 0 ' out of Hol. . ~'~0 ' ' ' 0 Drain 22;45 0 ', Irish; Cement noz=o~",, 23:45 " ~ ' On weft 0:05 .... 0 ~ O O 0 -'0 0 " ,0 O~en well;IH O:50 ~'42 !~ 0 1,3 0 0 3925 0 NoGo past .. '~, ,. 1:00 ..... 342 1 ~ O 1,3 ' 0 0 ~0 0 Sta~ cement · , ,,, 1:10 342 125 O 1.2 0 O ~00 0 Start Biozan 1:20 342 0 0 ' 0.5 0 0 750 ' 0 ~UH la~ng 1:25 25 ~ O '"1.3 O ' 0 3~ 0 Stop ~pump 1:3~ ~ 0 - 0 0 0 0 0 1~0 Pres~r, ,. ~.., , -. . .., 1:45 25 5o 0 1.3 0 2o 3~0 0 Circulate 20 bbis. 2:10 ' 25 50 ' O' I 0 0 2~o 0 POOH · 2:16 o Out of Hole , . . . ,, 2:20 0 IRig ~=k Injector ., ,..-- · ,_ 3;00 0 Off ~oation 10:30 0 On Loaa~on , , ,, , ,, 10:40 [ .0 Safety Meeting .... 11~00 - 0 ' Ri~ up N2 1 ~ :OS ......... 0 ' . Rig ~own C~ . 17=00 ......... " ' '- 0 , ' ,?f L;=ation SRU 41-33 WD P & A /~'~, ~ Subject: SRU 41-33 WD P & A Date: Mon, 21 Aug 2000 10:42:01 -0700 t(,o (~ --O~ ~ From: "Davis, LD" <lddavis@unocal.com> To: '"tom_maunder@admin.state.ak. us'" <tom_maunder@admin.state.ak. us> Tom, Per our conversation last week on the P & A of well SRU 41-33 WD. In 1999, Coiled tubing was run in the well. The coiled tubing worked a motor and mill down to 406'. No additional progress was made. An agreement was made to P & A as deep as possible. What we plan is to run a smaller coiled tubing in the well (1-1/2" vs. 1-3/4") and a 2.25" mill. Last years mill was 2.7". We hope to be able to work through the bridge at 406'. Ifwe can not work through the bridge. The well will be P & A'd from that point. If we do get deeper then the well will be P & A'd as deep as possible. From the deepest point the well will be filled with cement to about 20' below the surface. If you have any questions please contact me. Regards, LD Davis Alaska Drilling Ops. Office no.: 907-263-7679 ,~L'" Cell no.: 907-250-2711 1 of 1 8/21/00 9:46 AM UNOCAL Swanson River Unit Well No. 41-33 W.D. Abandonment 9/3/99 Re- establish injection 1. RU injection pump. 2. Attempt to inject I bbl. 20% HCL. Note: If successful at re-establishing injection, bullhead tubing with cement as per approved program. Contingency (If injection cannot be re-established) 1. Run 1" work string as deep as possible. 2. Pump abandonment plug through work string. Plug will extend from deepest point achieved to surface. UNOCAL Swanson River Unit Well No. 41-33 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 scale out of tubing to 406'. Unable to work deeper. Suspect parted tubing. Establish injection rate of 1.4bpm @ 1,600 psi. August 26, 1999 RU Dowell to cement tubing. Pressured up to 1,725 psi with no bleed off. August 28, 1999 RU Slickline. Could not get 1.75" swedge below 101'. Run 1.5" swedge. Work through obstruction, run to 225'. Unable to work deeper. Run 1" Spear on 1-1/4" tool string to 225'. Could not work Deeper. August 31, 1999 RU slickline. Run 10 ea. Dump bailer runs to spot 20% HCI at 101' and at 225'. bailer to 283'. Toolstring stuck at 101' Work September 1, 1999 Attempt injection. Pressure to 1,700 psi. Bled from 1,700 psi to 1050 psi in 10 min. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager Monday, June 21, 1999 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Swanson River Unit Well 41-33 WD APl No. 50-133-10167 10-403 Abandonment Dear Mr. Christensen: Please find enclosed in triplicate Form 10-403 for the abandonment of SRU 41-33 Water Disposal Well. In a 1971 workover attemts were made to repair a hole in the 5-1/2" production casing. After unsucessful efforts to repair the leak with cement squeezes, 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. If you have any questions, please contact Tim Brandenburg at 263-7657. Dan Williamson Drilling Manager RECEIVED J UN 2 4 1999 Alaska 011 & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL 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: 179' 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 960' FNL, 1,320' FEL, Sec. 33, T8N, R9VV, SM SRU 41-33 WD At top of productive interval 9. Permit number Same 60-0027 At effective depth 10. APl number Same 50- 133-10167-00 At total depth 11. Field/Pool Same Swnason River Field / Sterling 12. Present well condition summary Total depth: measured 3,000' feet Plugs (measured) 2,990-3,000' MD true vertical 3,000' feet Effective depth: measured 2,881' feet Junk (measured) 2,897'-2,990' MD true vertical 2,881' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 23' 20" 23' 23' Surface 325' 13-3/8" 272 sx 325' 325' Intermediate Production 3,000' 5-1/2" 726 sx 3,000' 3,000' Tubing 2,875' 3-1/2" 300 sx 2,875' 2,875' Perforation depth: truemeasuredvertical 2,882'-2,926';2,940'-2,978'Same ORIG,/IVAL RECEIVED Tubing (size, grade, and measured depth) JUt~J 2 41999 3-1/2", 9.3#, N-80, EUE 8rd @ 2,875'; Tubing is Cemented to surface Packers and SSSV (type and measured depth) il~a~ka 0ii & Gas Cons. C0mmissio~ Anchorage 13. Attachements Description summary of proposal: × Detailed operations program: × 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 here~rtify that t ~f~. oing is true and correct to the best of my knowledge.~/~ ~~'~n ~/~f¢~ Signe Williamson Title: Drilling Manager Date: , FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represent~ive may witnessIIAppr°val No._ _ .,,, _~/(~:~?.,~_~/ Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- /'~7 -- Approved by order of the Commissioner Robert N. Christenson ~,<~_ . ., missioner Date Form 10-403 Rev 06/15/88 ;'~ i~~ ~Commissioner SUBMIT IN TRIPLICATE UNOCAL Swanson River Unit Well No. 41-33 W.D. Abandonment Preliminary Procedure Pump Abandonment Plug 1. Spot and rig up Dowell Cementing equipment at SRU 41-33 W. D. 2. Rig up hard lines to tree cap flange. 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) 5-1/2" x 3-1/2" .0232 bbls/ft .0087 bbls/ft .0113 bbls/ft · 1305 cf/ft .04883 cf/ft .0637 cf/ft Pump Schedule - 28 bbls cement slurry 4. Commence pumping 28 bbls slurry. Shut in Master Valve. 5. Rig down Dowell equipment. Perform Plug Integrity Test 6. Perform Integrity test of plug by pressuring the tubing to 1,500 psi. Hold for 30 min. RECEIVED jUN 24 1999 Naska 0il & Gas Cons. commissior~ Anchorage UNOCAL ) RKB to TBG Head = 15' Tree connection: TC-3 Uni-bolt Hole in Casing 670' SIZE WT Swanson River Field Well # SCU 41-33WD Actual Completion 9/71 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 20" Surf 13-3/8" 54.5 J-55 Surf 5-1/2" 17# J-55 Surf 5-1/2" 200 N-80 33' 5-1/2" 17# N-80 318' DV tool 1153' 5-1/2" 200 N-80 1155' 5-1/2" 17# J-55 2911' Tubing/Cmtd Liner: 3-1/2" 9.2 N-80 Surf Lowest jt saw tooth on bottom, no collar 23' 325' 33' 318' 1153' 1155' 2911' 3000' 2875' ITEM DETAIL NO. Depth Item 1 670 2 2875 3 2990 Casing Hole sqzd w/300 sx in 9/71 Unable to seal Tubing tail, circ 160 sx cmt and displaced with 25 bbls Rathole filled with sand prior to cmt job, cleaned out to 2990' with 2-15/16" bit in 10/71 after cement job thru tubing. Fill at 2881' PBTD = 2990', TD = 3000' Straight Hole TOP 2882 2940 PERFORATION DATA BTM ZONE SPF DATE COMMENTS 2926 2 10/71 2978 2 10/71 Scu 41-33 WD Actual. DOC UNOCAL ) RKB to TBG Head = 15' Tree connection: TC-3 Uni-bolt Hole in Casing 670' A SIZE WT Swanson River Field Well # SCU 41.33WD Proposed Abandonment CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 20" Surf 13-3/8" 54.5 J-55 Surf 5-1/2" 17# J-55 Surf 5-1/2" 20g N-80 33' 5-1/2" 17# N-80 318' DV tool 1153' 5-1/2" 20g N-80 1155' 5-1/2" 17# J-55 2911' Tubing/Cmtd Liner: 3-1/2" 9.2 N-80 Surf Lowest jt saw tooth on bottom, no collar 23' 325' 33' 318' 1153' 1155' 2911' 3000' 2875' ITEM DETAIL NO. Depth Item 1 670 2 2875 3 2990 Casing Hole sqzd w/300 sx in 9/71 Unable to seal Tubing tail, circ 160 sx cmt and displaced with 25 bbls Rathole filled with sand prior to cmt job, cleaned out to 2990' with 2-15/16" bit in 10/71 after cement job thru tubing. ABANDONMENT DETAIL A 28 bbls. Cement bullheaded imo tubing/perfs CT cleanout to 2881' CTM 10/27/96 PBTD = 2990', TD = 3000' Straight Hole TOP 2882 2940 PERFORATION DATA BTM ZONE SPF DATE COMMENTS 2926 2 10/71 2978 2 10/71 Scu 41-33 WD Prop.DOC 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: Blair Wondzell ~a~ 0il & Gas C0~s. C0m~o~ Aach0ra~e Dear Mr. Wondzell, Subject: Swanson River Unit Well 41-33 WD APl No. 50-133-10167 10-403 Abandonment On July 17, 1998, an attempt to establish injection down the tubing of SRU 41-33WD 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. 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. 2,~cerely, Dan Williamson Drilling Manager UNOCAL Swanson River Unit Well No. 41-33 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 Tire' 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 5. Stab injector. 6. RIH cleaning out tubing to T.D. or until communication is established. 7. Rig down coiled tubing. 8. Pump abandonment per procedure. RECEIVED Alaska 0ii & Gas Cons. O0mm~ssi0v, Anchorage 00T-21-98 NED 14'. 43 ~. u ~ Larry P. Greenstein Production Technician UNOCFtL R$$ET GRS GRP ~'RX NO, unocal Alaska Resources 909 West 9Ih Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7§61 Fax (907) 263-7874 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 UNOCALe October 21, 1998 Dear Blair, This note is to confirm your verbal approval regarding the Unocal testing of a scale removal tool in SRU 41-33 WD at the Swanson River Field. The tool is designed to work on slickline using injected water as the driver for the scale removal. Since the MIT for 41-33 WD expired at the end of September, Unocal contacted you regarding using this well as a test case for this tool. It is possible that this testing could take up to two days to complete during which, off and on, we would need to inject water into this wellbore. We appreciate your quick verbal approval and wanted to follow up with a written confirmation/concurrence. Sincerely, ~. ~re:nste,/~ Production Tech Concurrence Line: ~0hx~, ~,~~. ~ · ~T~ir Wond~ll p Date: JRN-U~-~8 'ltlU 14:415 UHUIJRL -'~ STATE OF ALASKA ALASKA .O~L AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS F, UE. 1. Type of Req'u~{!'" Abandon: ......... Suspend; '" Operation shutdown: ...... R~:'ent&'r'suspende~i''well: ........ Alter casing.--' Repalr'--'~ell: Plugging; Time extension: 8timulaT. Change approved'~rogram: Pull tu'"'~tng:,,._ Varlan""--~: Perfor~(ei- .. Other: 'X"- (MIT Waver) ~ i 1 1,11 ~ ,, 1' : ' 2~Name of °pe~'aior ....... 5. Type of'~'ell': 6. Datum elevation (DF or KB) UNOCAL Development: RKB: 179' feet 3. Address Exploretory:~ 7. Unit or Property name Stratigraphic: P.O, Box 196247 Anchorage, AK 99519 - 6247 Service: T Swanson River Unit 4. LoCati0n'~f wett at surface ............................ 8. Well numbm: ............ 960' FNL, 1320' FEL, Sec 33, TSN, R9W, SB & M SRU 41-33 WD At top of productive interval 9, Permit number Straight Hole (~.0 '" 0, ,.Z. ,? At effective depth ' 10. APl number 50-133-10...~.67-00. .... At total depth 11. Field/Pool Swanson River / Sterling..~ . . '12. Present weii"~ondi[ion sum~l~ ................ Total depth: measured 3000' feet Plugs (measured) 2990'-3000' true vertical 3000' feet Effective depth: measured 2897' feet Junk (measured) 2897'-2990' true vertical 2897' feet Casing Length Size Cemented Measured depth True vertical ciepttl Structural Conductor 23' 20" 23' 23' Surface 325' 13-3/8" 272 sx 325' 325' Intermediate Production 3000' 5-1/2" 726 sx 3000' 3000' Liner 2875' 3-1/2" 300 sx 2875' 2875' Perforation depth: measured 2882'-2926', 2940'-2978' true vertical 2882'-2926', 2940'-2978' Tubing (size, grade, and measured depth) 3-1/2", N-80 ~} 2875'; tubing is cemented to surface Packers and $88V (type and measured depth) 13. Attachements "'Desc~ripi'i~'~l summary of Proposal: X Detailed operations program: BOP sketch: _ 14. EstimMed c~'~ for comm~n.cing operation' ........ 15. Status of well classification as: ......................... Prior to October of 1998 16. If proposal welt v~:baily approved: "' . Oil: Gas: Suspended: Name of approver Date approved Service: Water Disposal i,,' ~/ FOR COMMISSION USE ONLY , Plug integrity ...... BOP Test. ~. Location clearanceI ~'~/'~i' ....... Mechanical Integrity Test Subsequent form required 10- Form 10-403 Rev 06It 5/88 Approvea Copy Returned __lh l I I -- RECEIVED SUBMIT IN TRIPLICATE JAN - 8 1998 Alaslm Oil & Gas Cons. Commissm ORI$IN Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, AK 99501-3192 ph: (907) 279-1433 fax: (907) 276-7542 TELECOPY TRANSMITTAL Number of pages including cover sheet: If you do not receive fax in its entirety, please call (907) 279-1433 immediately. MESSAGE: slh: 11/96 ' JRN-UU-9U 'rHU lb:bU Unocal Alaska Resources 909 West 9th Avenue, P.O. Box 196247 Anchor~je, Alaska 99519.6247 Telephone (907) 263-7861 Fax (907) 263-7874 UNOCAL ) 1", U I Larry P. Greensteln Production Technician January 8, 1998 Mr. Blair Wondzell AK Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Application for Sundry Approval for SRU 41-33 WD Mechanical integrity Test Waver Dear Mr. Wondzell: Attached Is an Application for Sundry Approval for a Mechanical Integrity Test Waver on SRU 41-33 WD. This MIT Waver is being requested due to the following well conditions: 1 ) the well is plugged sufficiently to interfere with any type of logging, see attached WSRs. 2) the well is scheduled to be replaced by a newly converted well prior 1o the end of the o~. 1998 summer. 3) the well handles, by far, the smallest portion ot the Swanson River water disposal needs when compared to the other two disposal wells. 4) the cemented-in-place tubing completion is possibly one of the lowest risk designs to d ~ isolate injection fluids from potential USDW. 5) the cost of a CTU cieanout and acid work required to unplug the tubing appears excessive compared to the small water volumes injected, the Iow risk that this type of well poses, and the short time frame of planned continued use. Thank you for your consideration of this request and if you have any questions, please contact me at 263-7661. Sincerely, kar~n ' CC: Mr. D. Whitacre Mr. K. Lucas t Mr. G. Merle ORIGINAL ~ JAN-08-98 THU 15:51 SEP 1 [ 'c37 ;~,::';;;:'4 UNOCAL aSSET GaS GRP ["fix NO, FRf/'"~Sb~NSON R t UEI~ TO AHC '"""%,I,ID FLOOP, WELL SERVICE .REPORT ~,U2 PRGE.001 O, pera_ tion Detail! ,.---- i iiiii i .... i HI II1' ....... ' JRN-08-98 THU 15:51 · UNOCRL RSSET GRS GNP F'RX NO. ; qOCAL ALASKA RESOUR S WELL SERVICE REPORT III]11 IlL I. I. _ Date: Wireline Company: Work Being Done: Present Operations: Unocal Supervisor: Wireline Umt Number: Zero Wirelin, e at 1214197 POLLARD WIRELINE GAUGE TUBING KEN LUCAS #5 T,,ub, ing Hanger .... III Well Number: Location: AFE # I PO #: Wireline Crew: Total Wireline Miles: Fill Tagged at (KB): Well KB: t', U~ J }ill SRU 41-33 WD SWANSON RIVER ROOT/BOWMAN 1 MILE Time I0:00 Operation Details ARRIVED ON LOCATION & HELD SAFETY MEETING. STAND BY WHILE ROUSTABOUT CREW CHANGES OUT TEE ON WELL HEAD, 11:30 RIG UP LUBRICATOR & BOP'S. PRESSURE TEST 12:30 RIH WI1 ¼, TOOL STRING W/1.625" GAUGE RING, TOOLS STOPPED ~ 87? WORKED TOOLS AND FELL FREE. RIH TO 113' WORKED TOOLS THROUGH TO 187' WLM. WORKED TOOLS, BUT COULD NOT GET PAST 187' WLM. POOH 13:30 PUT WELL ON INJECTION TO CLEAN UP TUBING 13:35 RIH W/1.625" GAUGE RING. TOOLS STOPED @ 87' WORKED THROUGH TO 91'. WORKED THROUGH TO 113', WORKED THROUGH TO 187' WLM. COULD NO~: GET .... TOOLS PAST 187' WLM. POOH 47 14:00 RIH W/1.50 GAUGE RING. TOOLS STOPPED AT 87'. WORKED THROUGH TO 1t3' WLM. COULD NOT GET PAST 113' WLM. POOH 14:50 OPENED WELL TO INJECTION 15:00 SHUT WELL IN AND RIH W/1,50 GAUGE RING. TOOLS STOPPED AT 87' WLM, WORKED THROUGH TO 113' WLM,WORKED TOOLS BUT COULD NOT GET PAST 113'. POOH 15:30 RIH W TAPERED TUBING BROACH ( 1,25 TO 1,50" ) TOOLS STOPPED AT 87'. WORKED THROUGH TO 113' WLM. WORKED TOOLS BUT COULD NOT GET THROUGH TIGHT SPOT AT 113' WI_M. POOH 17:00 RDMO Work String Detail: ( 1%" TOOL STRING ) RS; 10' STEM; K J; HYD JARS; SPANG JARS; & VARIOUS SIZES OF GAUGE RINGS Description of any tools or debris left in NONE the hole: .., .. Brief Summary of ~HIED TO GAUGE TUBING FOR SURVEY BUT COULD NOT GET TOOLS PAST 113' WLM Total Work Completed: Ticket #: Daily Cost: #t061 I Day #: $1240.00 [ Cum,dative Cost: Well Downtime Hours: J~N-O?-98 ~FD ~ 1:20 UNOCRL RSSET GR$ CTRP FRX NO, 907ZU3'fBf4 F:I~CY"'"~,~blf-.INSON P..IUEI~ TO IqNCH,.~ND ~=LOOP, , WELL SERVICE REPORT V, U1/U2 ~o --oa7 II III IIl~L, a~H~ I. IL IIIII II I IIIII | [ III Date: .~, ./0.._,-_~"~ . Welll: ..... /4/~ ~ ~ ..... , · ~ ~ ~mli~G~ny: ~~ff,.~~-~ L~n:"'. _~~'~.. :..:, '."': W~k ~lng Do~:~ :~~ ~ .... ~_ ,~ pm,.t o~o~:i ...... ~ ......... ,. "'. ",] m~,~ c~w: ~, ~ ~,~ ...//~Zc. . II II H~ I II ......... ~' Date: Wireline Company: Work Being Done: Present Operations: Unocal Supervisor: Wireline Unit Number: Zero Wireline at ..... UNUOSL A~SE'I* (~A~ (~.P l~A,~ NU. ~JU f/U,~ I~ f~ f NOCAL ALASKA RESOURCES WELL SERVICE REP JRT I II 1214197 POLLARD WlRELINE GAUGE TUBING KEN LUCAS #$ .Tu,,bin~ Han;er,,,, Well Number: Location: AFE # I PO #: Wireline Crew: Total Wireline Miles: Fill Tagged at (KB): Well KB: _J I I I J .1111 I [ SRU 41-33 WD SWANSON RIVER ROOT/BOWMAN 1 MILE Time 10:00 11:30 12:30 13:30 13:35 14:00 Operation Details ARRIVED ON LOCATION & HELD SAFETY MEETING, STAND BY WHILE ROUSTABOUT CREW CHANGES OUT TEE ON WELL HEAD, RIG UP LUBRICATOR & BOP'S. PRESSURE TEST RIH Wi1%" TOOL STRING W/1.6:~5" GAUGE RING. TOOLS STOPPED @ 87'/ WORKED TOOLS AND FELL FREE. RIH TO 113' WORKED TOOLS THROUGH TO 187' WLM. WORKED TOOLS, BUT COULD NOT GET PAST 187' WLM. POOH PUT WELL ON INJECTION TO CLEAN UP TUBING RIH W/1.625" GAUGE RING. TOOLS STOPED @ 87' WORKED THROUGH TO 91'. WORKED THROUGH TO 113', WORKED THROUGH TO 187' WLM, COULD NOT GET TOOL~ PAST 187' WLM. POOH 47 RIH WI 1,50 GAUGE RING. TOOLS STOPPED AT 87', WORKED THROUGH TO 113' WLM, COULD NOT GET PAST 113' WLM. POOH '14:50 OPENED WELL TO INJECTION 15:00 SHUT WELL IN AND RIH W/1.50 GAUGE RING. TOOLS STOPPED AT 87' WLM, WORKED THROUGH TO 113' WLM.WORKED TOOLS BUT COULD NOT GET PAST 113', POOH 15:30 RIH W TAPERED TUBING BROACH ( '1,25 TO 1.50" ) TOOLS STOPPED AT 87', WORKED THROUGH TO 113' WLM, WORKED TOOLS BUT COULD NOT GET THROUGH TIGHT SPOT AT 113' WLM. POOH 17:00 RDMO Work String Detail: Description of any tools or debris left in the hole: ( 1%" TOOL STRING ) RS; 10' STEM; K J; HYD~JAi~,',~~~ VARIOUS SIZES OF GAUGE RINGS Brief Summa~ of j TRIED TO GAUGE TUBING FOR SURVEY BUT COULD NOT GET TOOLS PAST 113' WLM Total Work ~ Completed: ~. Ticket #:t #1061 I Day#: Dally ,Cost:, $1240.00 Cumulative Cost: I Well Downtime Hours: j J .. C,&4nl r-timpani UMr'Lr_ I IUIII DATE· .. I K~ ' WELL NAME CO. CONTACT I .... ,b~cc (~,EOLOGICAI.. ~TEI~LS INVE~IT~RY LIST ' - [ check off or list data as it is 407 ! drillin9 histo~ suwey I j ~ell tests J ~re desri'pti,onl cored inte~l's ~re anal~is ,d~ dish inte~als digital data " 'LOG TYPE RUN INTERVALS SCALE NO. i . ~., ~! ,~',9 7"~¢~. L-,,2 ~,.,L,_._.__,,.~ / 6',, ' -- ~,~f'~ /" ~" ,..~... ', , ,,, , , , , ! r;! , .! , .] , · 13) 14) lq i i i , 16) _ ,.~7) _ 18] 19] Alaska Oil Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska §9501-3192 907-279-1433 The following data is hereby acknowledged as being received: Io~o- ,Z~O' Dated: Copy sentto sender: Yes No ,~ Unocal North American/.~.~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region November 11, 1993 lVlr. Russ Douglas Commissioner AOGCC 3301 Porcupine Dr. Anchorage, Alaska 99504 Dear Mr. Douglas: On July 23, 1993 Schlumberger ran a Water Flow Log for the purposes of a mechanical integrity test in well SRU 41-33WD. The ball got dropped somewhere along the line and we just received the interpretation from Schlumberger. I apologize for the delay in getting this to you To ensure that "this will never happen again", I have instituted some measures to track the Sundry information. Ralph P. Holman RECEIVED enclosures: Water Flow Log ~0V ] 5 19~) Log interpretation /~S~ .O~l & Gas Cons. [;omm~ssion ', chorago ~..-~- STATE OF ALASKA ..-.. ALASKA .~. AND GAS CONSERVATION CO" ~ISSlON REPORT OF SUNDRY WELL OPERATIONS,/")Z) Perforate ~ 1. operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Pull tubing __ Other X ~ (DF or 2. Name of Operator 5. Type of Well: 6. Datum e~e~,ation Unocal Development __ KB 179' above MSL F--xplorato~y ~ feet. 3. Address SbatJgraphi~ __ 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 Senate X_ Swanson River Unit 4. Location of well at surface 8. Well number 960' FNL, 1320' FEL, Sec., 33, T8N, R9W, SM SRU 41-33WD At top of productive interval 9. Permit number/approval number Straight hole ~ o-.-~ ~,2-,7 ~. ,.,.,., At effective depth 10. APl number /~' "" Straight hole 50-133-10167-00 At total depth 11. Field/Pool Straight hole Swanson River/Sterling 12. Present well condition summary Total depth: measured 3000 feet Plugs (measured) 2990 true vertical 3000 feet Effective depth: measured 2990 feet Junk (measured) 2990 true vertical 2990 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 23' 20" D riven 23' 23' Surface 325' 13-3/8" 272 sx 325' 325' Intermediate Production 3000' 5-1/2" 726 sx 3000' 3000' Liner 2875' 3-1/2" 300 sx 2875' 2875' Perforation depth: measured 2882 - 2926, 2940 - 2978 true vertical 2882 - 2926, 2940 - 2978 Tubing (size, grade, and measured depth) 3-1/2", N-80@ 2875' (tubing cemented to surface) Packers and SSSV (type and measured depth) DrCPlVF[') 13. Stimulation or cement squeeze summary lb L ~ ~ · ' -- Intervals treated (measured) ~OV '~ 5 Treatment description including volumes used and final pressure At~sk, a Olt & Gas Coas. Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys runX_ Daily Report of Well Operations __ Oil~ Gas ~ Suspended ~ Service Water disposal 17. I here~'~,;ertl, f? that_thg, for/~lo~g is t~e.. and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE UNOCAL ) WATER FLOW ADVISOR SRU 41-33 WD, SR 72 Company: Field: Well: Logging Date: Objective: UNOCAL Swanson River Unit 41-33 WD, SR 72 July 23, 1993 Mechanical Integrity Test Disposal Well RECEIVED NOV 1 5 1993 Naska uti & Gas Cons. Commission Anchorage Schlumberger Wireline and Testing 500 West International Airport Road Anchorage, Alaska 99518 (907) 562-2654 UNOCAL SRU 41-33 WD, SR 72 Water Flow Log July 23, 1993 Interpretation Summary Mechanical Integrity Test- 1247 BWPD Station Depth Flow / No Flow 1) 2848' No Flow 2) 2850' No Flow 3) 2824' No Flow 4) 2710' No Flow 5) 2275' No Flow 6) 2250' No Flow 7) 2090' No Flow 8) 1800' No Flow 9) 1700' Potential USDW Flow Detected Flow at this station is attributed to a drop in rate from 1247 BPD to 250 BPD while this station was being recorded. This may be explained as a momentary reverse in fluid direction (up) when the surface injection pressure dropped causing pressure and fluid to "back up" as pressure relief was briefly up the hole instead of down. The original injection rate was reestablished and no flow detected on the following two repeat stations. 10) 1700' Potential USDW No Flow 11) 1700' Potential USDW No Flow 12) 1600' No Flow 13) 1500' No Flow RECEIVED 14) 1408' Potential USDW No Flow 15) 1255' Potential USDW No Flow NOV 3,5 1993 16) 1060' Potential USDW No Flo~ska u,, e~ was Cons. C0mmiss~ Anchorage Conclusion: This well continues to have mechanical integrity. No fluids are communicating in the casing annulus from the disposal zone to any underground source of drinking water. The one flow anomaly at 1700' can be explained by the rapid drop in injection pressure during the test and the subsequent two repeats testing negative at the same depth. Recommendation: Though temperature is not necessary to evaluate mechanical integrity, there is a temperature anomaly in this well which has been noticed during previous tests that should occasionally be monitored. It is due to injection of warmer produced fluids in a nearby well which is a useful monitoring tool in itself. In the event that vertical communication starts to occur in the area of the offset well it may show up at this wellbore as another temperature anomaly but at a different depth. Therefore, it is recommended that a temperature be mn on the next MIT along with the Water Flow Log to look for possible warming anomalies in other zones. Well SRU 41-33WD Mechanical Integrity Test July, 1993 Objective Determine mechanical integrity of the well with oxygen activation log and verify that the well is not affecting the fresh water aquifer. Procedure Prior to log_~ng 1. RU slick line and tag fill with 2.8' gauge ring. 2. Notify AOGCC and BLM 24 hours prior to logging. Mechanical Integri~ Test (MIT): Ox?gen Activation 1, Establish a stabilized injection rate into the well with a 900 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 lubricatorl RIH w/GR/CCL/OA log. The O/A log should be configured to detect upward flow. 3. Tie in. . Check for upward flow at the following stations: Depth Reason 2850' 2824' 2710' 2250' 2275' 2090' 1700' 1408' 1255' 1060' Above perforations Deepest confining layer Confining layer Heat anomaly noted in 10/10/89 PITS Heat anomaly noted in 10/10/89 PITS Heat anomaly noted in 10/10/89 PITS Potential USDW* Potential USDW* Potential USDW* Potential USDW* RECEIVFr NOV 1 Anchorage * Underground source of drinking water. . Make further stops to check for flow as deemed appropriate by on site Unocal representative. 6. POOH o. ,I . o -o , #CL~ Z~ C, AS~0 · 67o,, SC~KZ~D ~'m X)O SACZS .REC£.IVED · NOV 1 5 199~ Oil & Gas Cons. Commission Anchorage ~.mltmD .,~ N..8o · 287S, · I.D. · SRU 41~33 C~SlNG & TUBING SEC?ION $$ T. SN.,R. gW. 8%AIIDAW) OZL CI)I~AN% Oil CAL,17C~ Station 1) 2848' Station 2) 2850' 300.000 ~"~', 240.000 180.000 cps / cYCLE 120.000. 60.0000 0.0 0.0 12.0000 24.0000 36.0000 48.0000 60.0000 TIME(SEC) FILE NUMBER DATA ACQUIRED 6 23-JUL-1993 11804 ******************************************************************************* DETECTOR , FAK TDT-P DETECTOR DEPTH - 2846.3' F MINIT~ON DEPTH - 2848.3 F ** UP FLOW ~ONFIGURATION ** ."LOW NOT DETECTED FLOW VELOCITY - 0.0 FT / MINUTE- ~LOW RATE INDEX - 0.0 BWPD FOR FLOW OUTSIDE CASING ******************************************************************************* RASING SIZE ' 3.5 IN SFT TYPE - 178 ~ Tcm~ - 415,8.0 c, F~ Tc~ - 1,346.0 cps NEUTRON ON TIME ' 10.0 S NUMBER OF C~CLES SUMMED ' 15 PEAK BACKGROUND SIGNAL ' 70.0 :{2 .4 CPS / CYCL~ ~ STATIO~*~ SICaAL - ,1.7 .. !.~. qr~ &~C~_. .... 1100.00 880. 000 ................................................................... i ...................................................................................................................................... 660.000 .................................................................................................................................................................... CPS/CYCLE 440.000 220.000 0.0 O. 0 12.0000 24.0000 36.0000 48.0000 60.0000 SEC) , ~ILK NUMBER OATA ACQUIRKD 7 -. 23-JUL-1993 12m06 ******************************************************************************* DETECTOR - NEAR TDT-P DETECTO~ DEPT~ - 2849.4 .F MINITRON. DEPTH - 2850,0 F · ~0~ NOT now V'm.~ZT~ ~13%7---~--~ ~ASING SIZE - 3.5 IN SPT T~PE - 178 ~ T~]K - 41598.0 CPS FA~ TC~K - 19346.0 CPS ~EUTRON ON TIME - 10.0 S NDMBEK OF C~CLES SUMMED - 15 PEAK BACKGROUND SIGNAL- 375.3 +/- 1.0 CPS/ CYCLE Station 3) 2824' Station 4) 2710' 300.000 240.000 IlO.O00 120.000 60.0000 0.0 0.0 TIME(SEC) ............................................ i...,..~ ..................................... · ................................................................................. t ......................................... _. 12.0000 26,0000 36,0000 48.0000 60.0000 FII,Z NUI~ER DATA ACQUIRED 11 23-JUL-1993 12150 DETECTO~ - FAK TDT-P DETECTO~ DEPTH - 2822.0 F MINZTRON DEPTH - 2824.0 F ** UP FLOW CONFIGURATION ** LOW NOT DETECTED ~ '~ELOCIT~ - 0.0 ~ I q, OW KATE INDEX - 0.0 ~ FOR FLOW OUTSIDE CASING ****************************************************************************** ,,,,,= 300.000 RECEI ED 240. 000 ........................................................................................................................................................................................................................... NOV 1 5 1t95 18o.ooo ........~.. ............................ [ ............................................ ? ............................ .~.S.g L.Oil.&..~as.Cons,,.Commiss,~ ............. ....... .120,000 60,0000 ..................................................................................................................................................................................................... 0,0 0,0 12.0000 2~, ~000 ~6,0000 ~8,0~00 60.0000 T~ ( S gC ) FILE NUMBER DATA ACQUII~D 12 23-JUL-1993 13~ 17 ._. ********************************************************************************** DETECTOK ,, FAB TDT-P DETECTOR DEPTH - 2708.1 F MINITRON DEPTH - 2710.1 F ** UP ~ COI~IGURATIOll ** ~LOW NOT DETECTED ~OW ~IT~ - 0.0 rf / gI~t~r%1' ~LOW RAT~ INDEX ,- 0.0 BWPD FOR FLOW OUTSIDE CA~ING ASINO SIZE - 3.5 IN SPT T~PE - 178 .~EAK TCHK . - 41,98.0 C~ ,AK TC~K - 19346.0 CPS PEAK STATIONAKY SIONAL - 89.3 1.9 CPS C'~CLE [OTAL FLO~NC SICNAL - 0.0 '* 0.0 COUIlTS / CYCLE station 5) 2275' Station 6) 2250' 600.000 400.000 200.000 0.0 0.0 12.0000 24.0000 36.0000 48.0000 60.0000 TIH]:(SEC) PILE NLI~ER DATA ACQUIRED 14 23-,TUL- 1993 13 z 49 ******************************************************************************* DETECTU~ - Ne. AR TDT-P DETECTO~ DE~ - 227&.7 ~ ~NI~ DE~ - 2275.3 ** ~ ~ ~O~T~ ~ ~ DE~ ' -- ~OW ~ I~EX ' 0.0 B~ ~R ~OW OUTSIDE ~SING ******************************************************************************** ~ ~ - ~I5~.~ F~ ~ - 193~6.0 ~ ~ STATIO~I SIGg - 377.7 3.7 CPS ~C~ ~ ~NG SIG~ - 0.0 0.0 ~UN~ / 300.000 240.000 x8o.ooo CPS/CYCLE 120.000 60.0000 0.0 .............................................................................................................. '"EC"E-I-V ~ ...... NOV ~ ,-,.~o.sKa u. ~ Gas Cons. ~ Anchorage .......................................... ................ ...................................................................................... ................................................................................................................................................................................. q ............................................. I I , EF 0.0 12.0000 24,0000 36,0000 48.0000 60.0000 TI:HE(SEC) ~ILE NUI~ER DATA 16 23-JUL-1993 14118 ******************************************************************************* DETECTOR = FAR TDT-P DETECTOR DEPTH - 2248.0 F MINX'IRON DEPTH ** UI~ ~ CONFIGURATION ** .q. OW NOT DETECTED ~LOW VELOCITY - 0.0 ~T / M'r_NUTE ~.OW RATE INDEX - 0.0 BWPD ~OR FLOW OUTSIDE CASING · ,~I~ING SIZ~ - 3.5 III srl' ~ - 178 ~ TCHK ' 41598,0 CI~ FAR TCHK ' = 19346.0 CPS ~UTRON ON T]~qE , I0.0 S NUMB~ OF CYCLES PEAK'BACKGROUND SIGEAL- 102.3' +f .$ CPS/ C~CLE ~i.q STATIONARY SIGNAL - 92.6:3 1.8 CPS / CYCLE L'OTAL ~OWING SIGNAL - 0.0 : 0.0 COUNTS , CYCLE Station 8) 1800' Station 7) 2090' 300.300 240.000 tSO,O00 120.000 60.0000 0.0 0.0 TIME (SEC) 12,0000 24. 0000 ~6. 0000 ~8. 0000 60,0 FILE NUMBER DATA ACQUII~D 17 23-JUL-1993 14446 ******************************************************************************* DETECTOR - FAE TDT-P DETECTOR DEPTH - 2088.1 F MINITRON DEPTH - 2090.1 F ** UP FLOI4 CONFIGUP, ATION ** FLOW DETECTED ******************************************************************************* :ASING SiZE g 3.5 IN SFT TYPE - 178 ~ TCHK : 41598.0 CPS FA~ TCHK - 19346.0 CPS NEUTRON ON TLtlE 10.0 S NUt. ER OF CYCLES SUNNED - 15 STATIONAKY SIGNAL g 96.6 1.9 CPS CYCLE TOTAL FLOWING SIGNAL ~ - 17.3 7.3 COUNTS / CYCLE 300. 000 180,000 CPS/CYCLe- 120. 000 60.0000 ' 0.0 O. 0 12.0000 TII~(SEC) 24. 0000 36. 0000 48. 0000 60. 0000 FILl tlmlB~i~ DATA ACOUI~ED 28 2,3-JUL-1993 18 s.52 *************************************************************************** Drl'gC'l'l~ - FAR TDT-P DETECT~[ DEPT~ - 1797.9 · MINITRON DEPTH - 1799.9 F ~ ~T DE~C~ *--**--*--*----************************************** ~ ~ ~ 41~.0 ~ ~ ~ - 193~6.0 CPS ~ aTAT1~Y ~ ~ 93.3 ~ 1.9 ~ / ~C~ ~ Sl~ .- 0,0 ~ 0,0 ~S / ~C~ ' -- Station 9) 1700'a Station 10) 1700'b 640.000 480. 000 CI'S IC~'l~ 320. 000 160.000 0.0 0.0 T~(SgC) 12. 0000 24. 0000 36. 0000 48. 0000 60. 0000 ,II~ ~lt DATA AcquIIID 19 _,. 23.*JUL-1993 15821 ****************************************************************************** DETECT(~ - FAR 'rDT-P DETEcTO~ DEPTg - 169~.0 F H~IIT~ DEPTg - 1700.0 F ,Ira. UF'~,ON :COIlFZGIJ~TI~I ** ~ RATE INDEX ~ lO3.& ~ . POl FLON OUTSIDE CA~ING ~ASIIIG Sl~ ' 3.5 ~ S~ ~ = 178 ~OH ~ ~ = 10,0 S ~ ~ ~ S~ ~ STATIO~Y SIG~ = 255.1 4.4 240. 000 ............................................................ R ............................ . " · 18o.ooo ............ '~ .................. I ....................................................................................................... ~t'g~ga"Oll'"~"gaggOhg'"';Z;;;;,,,,~, o.ooo ......... . ........................................... .................................. 60' 0000 ......................................................................................................................................................................................................................... o.o o. o ~2. oooo 2~. ~ooo a~. oooo ~. oooo 6o. oooo T~ (SEC) PILE NUMBER DATA ACQUIRED 27 23-JUL-1993 18825 ******************************************************************************* DETECTOR = FAR TDT-P DETECTOR DEt'~ - 1698.0 F HINITRON DEPT~ - 1700.0 ** UP ~ COIIFIG~TIO] ** ~ DETECTED ~ VELOCIT~ - 16.3 ~ / MINUTE' ,~.OW RAT~ INDEX - .6 BWFD FOR FLOW OUTSIDE ~ING :ASINC SIZE = 3.5 HI SFT TYPE = 178 ~ TCH~ - 41598.0 CI~ FA~ TC~ - 19346.0 C?S IEUTROR Oil TIHE - 10.0 S RUHBER OF C'~CLES SUMHED - 13 ~ $?A?IONAR¥ $I¢1~L - 101.¢ 2.2 ¢I~ tOTAL FLOWING SIGNAL - 15.2 6.4 COUNTS / CYCLE Station 11) 1700'c Station 12) 1600' 960. 000 720.000 480. 000' 240.000 0.0 TII~ (SEC) 0.0 12. 0000 24. 0000 36. 0000 48. 0000 60. 0000 · .~ILE NUMBER DATA ACQUIRED 30 23-JUL-1993 19z20 ******************************************************************************* DETECTOR - NEAK TDT-P DETECTOR DEPTH - 1699.4 P MINITRO%I DEPTH - 1700.0 ** UP FLOt/ CONPICURATION ** FLOW DETECTED FLOW VELOCITY NOT QUANTZPIABI,E. FLOW RATE INDEX NOTQUANTIFIA~LE. ********************************************************************************** ,,~,~ : s~,,,,..o ,.,..~ ,,.u.~o., o., T~ ,o.o ,--.. o, ~..., S--D - 300.000 2~0.000 180.000 CPS/CtCLE 120.000 60. 0000 ................................................................................................................................................ 0.0 I 0.0 12 · 0000 24 . 0000 36 · 0000 TLME (SEC) 48.0000 60.0000 rlT.r. NUIgEB DATA ACQUIRED 26 23-JUL-1993 17~57 ******************************************************************************* DETECTOR - FAR TDT-P DETECTOR DEPTH - 1598.0 F MINITRON DEPTH ** UP FLOW G0gPIGURATZON ** NOT DETECTED VELOCITY - 0.0 FT / HINUTE ~ RATE INDEX - 0.0 BWPD FOR FLOW OUTSIDE CASING ******************************************************************************* ~,SING SIZE - 3.5 IN SPT TYPE - 178 ~ TCHK - 41598.0 CPS FAR TCBK - 19346.0 CPS ~EUTRON ON TII~ - 10.0 S NUMBER OF CYCLES SUMI~D - PEAK STATIONARY SIGNAL - 113.9 I C1~3 CYCLE IDTAL FLOWING SIGNAL - 0.0 .0..0 COUNTS / CYCLE Station 13) 1500' Station 14) 1408' 300.000 2~0.000 180.000 C~IC~C~I 120.000 0.0 0.0 TIHE(SEC) 12 . 0000 24.0000 36.0000 z,8. 0000 60. 0000 rlL~ NUI~ER DATA ACqUIP, ED 25 23-JUL-1993 17-~ 28 *********************************************************************************** DETECI'~ - FAA TDT-P DETECTOR DEPTH - 1498.0 · HINTTRON DEPT~ - 1500.0 F ** UP FLI~ COI~I~TIOII ** ~ NOT DETECTED ~ V~IXIIT'I - 0.0 FT I ~Zlfl, Yll ' FLOW RATE INDEX - 0.0 BWI~D FOR I'LOW OUTSIDE CASING :~Sllr,, SIZE - 3..5 Ill SFI' ~ - 178 ~EAR ~ - 41598.0 CI~ FAA TCHE - 19346.0 CPS' ~IEUTRO~ Otq TIHE - 10.0 S NU~, Ole C~CL~ SUI~ED - 1~ PEA~ STATIONARI SIGNAL - 108.1 1.9 CI~ C~CLE OTAL FLOW'[NC SICNAL - 0.0 O. 0 COUNTS ! CYCLE 300.000 240.000 180.000 C~S/C~C~ 120.000 12.0000 2~.0000 36.0000 48.0000 60.0000 60. 0000 ................................................................................................................................................................................ 0.0 /~-- 0.0 rll~ (SEC) rILE NULvlBER DATA ACQUIRe) 20 23-JUL-1993 ****************************************************************************** DETECTOR - F~ ~T-P DE~C~ DE~ - 140~.2 F ~NI~ DEP~ - 1408.2 ** ~ ~ ~IG~TION ** ~ DE~C~ ~ HL~I~ - 6 8 ~ I ~ ' -- '~ "~ ~R ~N OUTSIDE ~ING SIZE - 3.~ ~ SFT ~ - 178 ~ ~~ SIG~ - 12,.7 +1- .6 ~ ~ ~ STATIO~ SIG~ - 10,.* ~ 2.0 ~I ~C~ ~T~ ~K SIG~ - 16.3 .,_ 6.~ ~ / ~C~ Station 15) 1255' Station 16) 1060' 300. 000 240.000 180.000 CPSlC~C.Z 120.000 60.0000 0.0 0.0 TII~ (SEC) 12.0000 24.0000 36.0000 48.0000 60.0000 FILE NUHBER DATA 23 23-d'U~-l~93 16~31 ******************************************************************************* DETECTOR - FA~ TDT-P DE~CTOR DE~ - 1253.0 F ~NI~ DEP~ - 1255.0 F _ . _ ** UP ~ ~G~TION ** ~OW ~T DE~C~ ~OW ~LOCI~ - 0.0 ~ ] ~OW ~ INDEX - 0.0 B~ ~R ~OW OUTSIDE ~SING ********************************************************************************* ~ING SiZE - 3.5 ~ SPT ~ - 178 ~ TC~ - 4~598.0 ~ F~ ~ ~ ~9346.0 CPS ~U~ON ON T~ - 10.0 S ~ ~ ~S S~D - 15 ~ STATIO~Y SIGN~ - 114.2 2.0 C~ ~C~ ~T~ ~O~NG SIGN~ - 0.0 0.0 ~ / ~CLE 1200.00 . [ 960. 000 ........................... 720. 000 480. 000 1 .................................. N]V '1 5 ~99~, Ataska U~l & Gas Cons. Co~misslon Anchorage 240. ooo ........................................................................................... [ ....................................................................................... 1 .................................... O. 0 12. 0000 24 · 0000 36 · 0000 ~8. 0000 60. 0000 'l~(S£C) FILE NUMBER DATA ACQUIRED 24 23-JUL-t993 16~58 ******************************************************************************* DETECTOR = ~ TDT-P DETECTOR DEFII! " 10~9.4 F MINZTEON DEPTH = 1060.0 ** UP FLO~ CONFIGL~ATION ** FLOW DETECTED ~LOW VELOCITY NOT QUANTIFIABLE. ' . E~,OW KATE INDEX ~OT~UA~TIPIA~LE. **********************~******************************~******************** ~I~ Sl~ - 3.~ ~ SFT ~ - 178 ~ ~ - 4~598.0 ~ F~ ~ - 193~6.0 CPS ~ ~ T~ - 10.0 S ~ ~ ~ S~D - 15 ~ STATI0~ SlG~ = 448.4 3.9 C~ ~C~ ~T~ ~~ SlG~ - 33.8 10.4 ~S I ~C~ STATE OF ALASKA ALASKA~-', AND GAS CONSERVATION COl~'-'~ SION APPLICA, FOR SUNDRY APi .. ,IOVALS 1. Type of request: Abandon Suspend ~. Operaliom ~hutdown Alter oaring ~ Repair well ~ Plugging ~ Change approved program 2. Name of Operator Union Oil Company of California (Unocal) Pull tut)lng Variance 5. Type of Wel: RECEIVED d U L - 8 199 Alaska 0il & Gas Cons. CommiSSiOn Anchorage 3. Address P.O. Box 196247 Anchorage, Alaska 99519-$247 4. Location of well at s~'face 960' FNL, 1320' FEL, Sea 33, T8N, R9W, SM At top of productive Interval Straight hole At effective depth Straight hole At total depth Straight hole __ Re- enter euepended well__ Time extension ~ Stimulate m Perforate Other X 6. Datum elevation (DF or KB) 179' KB Present well condition summary Total depth: measured 3000 feet Plugs (measured) 2990 true vertical 3000 feet 2990 12- Effective deptl~ measured 2990 feet Junk (measured) true vertical 2990 feet 7. Unit or Property name ~wanson River Unit 8. Well number SRU 41-33WD 9. Permit number ~,,'--27 ~,~ 10. APl number ~' ' 50-133-10167-00 11. Field/Pool Swanson River/Sterling ORIGINAl_ Casing Length Size Cemented Measured depth Structural Conductor 23' 20" Driven 23' Surface 325' 13-3/8" 272 sx 325' Intermediate Production 3000' 5-1/2' 726 sx 3000' Uner 2875' 3-1/2' 300 ax 2875' 23' 325' 3000' 2875' Perforation depth: measured 2882-2926, 2940-2978 feet true vertical 2882-2926, 2940-2978 Tubing (size, grade, and measured depth) Peckers and SSSV (type and meas~ed depth) 3-1/2", N-a0 @ 2875' ~oJbing oememted to mxfece) 13. Attachments Description summary of proposal m Detailed operations programX__ BOP sketch 14. Estimated date for commencing operation July, 1993 16. If proposal was verbally approved Name of approver Date approved I5. Statusof well classification as: Oil _ Gas ~ Suspended _ Service Water disDosal correct to the best of my knowledge. FOR COMMISSION USE ONLY Plug Integrity _ BOP Test Location clearance _ Conditions of approval: Notl~ Commission so representalt~ may wll~eu Mechanical Integrity Teatm Subsequent form required 10- ~'o~ .. Approved by the order of the Commission Original Signed Dy David W. Johnston Form 10-403 Rev 06/15/88 Approved Copy Returned Commissioner Date SUBMIT'iN iF~IPLICA~ Well SRU 41-33WD Mechanical Integrity Test July, 1993 Objectiv,e Determine mechanical integrity of the well with oxygen activation log and verify that the well is not affecting the fresh water aquifer. Procedurg Prior to lom?ing 1. RU slick line and tag fill with 2.8" gauge ring. 2. Notify AOGCC and BLM 24 hours prior to logging. Mechanical Integri_tv Test (MIT): Oxygen Activation Log . Establish a stabilized injection rate into the well with a 900 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. Check for upward flow at the following stations: Depth Reason . 2850' 2824' 2710' 2250' 2275' 2090' 1700' 1408' 1255' 1060' Above perforations Deepest confining layer Confining layer Heat anomaly noted in 10/10/89 PITS Heat anomaly noted in 10/10/89 PITS Heat anomaly noted in 10/10/89 PITS Potential USDW* Potential USDW* Potential USDW* Potential USDW* * Underground source of drinkin8 water. RE(ZEIVED Alaska Oil & Gas Oons. 6ommiss'~o~ 'Anchorage Make further stops to check for flow as deemed appropriate by on site Unocal representative. 6. POOH ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures tUPLICATE October 27, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Results of Pump,In Temperature Survey of SRU 41-33WD Swanson River Field Dear Mr. Chatterton: This is to submit the results of the pump-in temperature survey (PITS) that was performed on SRU 41-33WD on October 10, 1989. The test was done to prove that current injection practices (over 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 injection is confined to the perforations with no channeling occurring (see attached survey). In addition, the survey shows a heating anomaly at approximately 1970-2350' MD. The close proximity of SRU 31-33WD' which is continuously injecting warm produced water, explains this anomaly. The presence of this heated interval conf'mns the previous interpretation that SRU 31-33WD is injecting up to approximately 1970' MD while over parting pressure. If you have any questions concerning this matter, please contact Stacy Strickland at 263-4914. Sincerely, T. S. McCorkle TSM:SLS:ch:0011 Attachment S. W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company Commission ARCO Alaska, Inc. is & Subtidlary of AtlanticRichfleldCofnpany AR3B--6279 · STATE OF ALASKA co ,ss,o. llPt I¢41'! APPLIC. TION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Alter casing __ Change approved program __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 '"4. Location of Well atsurface Suspend __ Operation shutdown __ Re-enter suspended well __ ., Repair well__ Plugging __ Time extension __ Stimulate _.~ump- i n Temperatur, Anchorage, AK 99510 960' FNL, 1320' FEL, At top of productive interval ~traight' Hole At tffective depth At t~tal depth 12. ~resent well c~)ndition summary' Total depth: measured true vertical Pull tubing __ Variance __ 5. Type of Well: Devetopment Exploratory Stratigraphic Service Sec. 33, T8N, R9W, SB&M Pedorate __ Other.Z_ Survey Datumelevation(DForKB) 179' KB. UnitorPrope~yname Swanson River Unit 8. Well number SRU 41-33WD 9. Perr~it number 10. APl number 50--133-10167-00 11. Field/Pool Swanson River/Sterling 3000 feet Plugs(measured) 2990-3000' MD 3000 feet 2897 feet Junk(measured) 2897-2990' MD 2897 feet Effective depth: measUred true vertical feet Casing Conductor Surface Production Tub ing Perforation depth: Length Size Cemented Measured depth True vertical depth 23' 20" -- 23' 23' 325' 13-3/8" 272 sx 325' 325' 3,000' 5-1/2" 726 sx 3,000' 3,000' 2,857' 3-1/2" 300 sx 2,857' 2,857' measured 2882-2926' MD; 2940-2978' MD truevertical 2882-2926' MD; 2940-2978' MD RECEIVED Tubing (size, grade, and measured depth) 3-1/2", N-80 e ~ tubing is Packers and SSSV (type and measured depth) cemented to surface JAN - 2 t99P., Alaska Oil & Gas Cons. AnChorage 13. Attachments Description summary of proposal __ Detailed operations program X BOP sketch 14. Estimated date for commencing operation ! 15. Status of well classification as: August, 1989 16. If proposal was verbally approved Oil __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~...~./~~ Title Cook INlet Engineer lng Manager Date , FoR COMMISSION USE'~NLY conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test_ Subsequent form required 10- ~O~ Gas __ Suspended __ Water Oisoosal lApproval No' Approved by order of the Comm~~ Form lO-403"Rev 06/15/88 Commissioner SUBMIT IN fRIP~CATE Pump-In-Temperature-Survey SRU 41-33WD SR 72 Obtective: To determine the interval(s) receiving disposal water in this well while injection is maintained above parting pressure. Well Dat~: Completion 3-1/2", 9.2#, N-80 tbg cemented from shoe (2857' MD) to surface Perforations: 82' Total; top most @ 2882' MD, bottom @ 2978' MD Last PBTD tag: 2907' MD on 6/1/89 (1.75" impression block) Current Pressures: ~930 psi tbg. inJ. pres.; PC is cemented Est. Parting Pres.: 825 psi surface injection pressure Note: Verify that sundry approval has been obtained and that well has been injecting above parting pressure (825 psi injection pressure or 925 BWPD) for at least three days prior to performing this temperature survey. Procedure: 1. SI well for at least 24 hours. e Hold safety meeting. Assure that at least 300 Bbls of cold (~50'F) 3% NaCl 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 PBTD. Do not exceed a 30 fpm line speed below 1200' MD. e e Tie-in with tbg tail. Re-log bottom 200' at 30 fpm to verify temP tool repeatability (down run). Leave tool on bottom. . RU pump truck and tie into tbg. Pressure test lines to 1000 psi. Pump at least 300 Bbls of cold brine (~50°F) at over 850 psi surface injection pres. SI well. 8. POOH to 1200' MD at 30 fpm. . 10. Log down to PBTD at 30 fpm recording temperature data. 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. Pump-In-Temperature-Survey SRU 41-33WD SR 72- Page Two 11. 12. POOH. RDMO. Retum well to injection. AJ~GO Ala~k~ ~x~. i~ ~ ~t~idiary of Atlantl~ Fli~t~l Gompan¥ AP.~-~O1-A tSII.41' '1 ~c,. cf. · · I · llel' e' · I I Ittl~ ~o1111' r · FIRST ,IT. :SAM TOOTH Cl ~3TTCM~ IO CCLLAA .roi, ?.D, ~3(:X), · )iCLE n~ C~O · 670', SqUE;EZED T.'~TH .34:0 '~--bM.~T. ~-XT-TX Lo Y-27-?..:L UIIAB~, TO SEAl,. 7-~ SRU 41;33 CASING /~ TUBING DEl SECTION $$ T. 8 N.,R..gw. ST~DAP, D 023, E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead 0CT-14-'92 WED 14:55 ID:CODKINLET/N.V EHBR 1EL NU:~Y ~.~..~.~po wr~JJ, ro- ~,.. ,-., ~,~.. ,~,..,. , .~~=,~,,~.,~ .............. ~ ~. .. .'. ' ' '.,. ~,.,. ~...:~. ,~'~ ~ ,~.. . ~ ~ -.,..~ .... · ~ . ' . : . .' ' '[~'; . .'~ u/ ,. ~f, -- . ..... ; ,.$'.... . .. . .... ~,~..~ . .1 . .. . .. ~ d,%~ i Il, r - ~ ' m I ,. I Jm NELL ~UilVEY Pro-ffl2 IK[T~ OR INIIKI I' .Jill ILL___ ' · 't ARCO Alaska, Inc. Post Office Box'*~t u0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 19, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Results of Step Rate Testing on SRU 41-33WD. Dear Mr. Smith: ARCO has completed the step rate testing as outlined in our Sundry Request dated November 8, 1991. The daily reports for that work are included along with a plot showing the resulting injection rate versus pressure profile for the well. The data clearly shows that a significant increase in fluid injection rate can be realized with a minimal increase in wellhead injection pressure. The step rate test was designed to determine the increase in water injection capacity that would be realized by boosting the injection pressure on 41-33WD. Oil production from the Swanson River Field is typically constrained by our limitation in water disposal capacity. The step rate tests have shown that by raising the injection pressure on this well we will be able to meet all of our current water disposal needs. We believe that Area Injection Order # 13, as written, would allow us to increase the injection pressure from the current 1,000 psi up to 1,400 psi. However, if you feel that it would be more appropriate to amend the AIO, we would be happy to submit a formal request outlining our intentions. In either case ARCO will submit, for your approval, a quality assurance plan that would ensure that all of the injected fluids are remaining within the interval approved in the Area Injection Order. ARCO ~ Inc. is a Subsidiary of Atlantic Richfield Company RECEIVED DEC 1 9 199} Alaska Oil & Gas Cons. t;ommissior' Anchorage Mr. L. Smith November 7, 1991 Page 2 If you have any questions please contact Jim Zernell at 263-4107. Sincerely, JCW:JTZ:czm:0023 Attachments cc: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED DEC 1 9 199] Alaska Oil & 6as Cons. Commissio~ Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 19, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Results of Step Rate Testing on SRU 41-33WD. Dear Mr. Smith: ARCO has completed the step rate testing as outlined in our Sundry Request dated November 8, 1991. The daffy reports for that work are included along with a plot showing the resulting injection rate versus pressure profile for the well. The data clearly shows that a significant increase in fluid injection rate can be realized with a minimal increase in wellhead injection pressure. The step rate test was designed to determine the increase in water injection capacity that would be realized by boosting the injection pressure on 41-33WD. Oil production from the Swanson River Field is typically constrained by our limitation in water disposal capacity. The step rate tests have shown that by raising 'the injection pressure on this well we will be able to meet all of our current water disposal needs. We believe that Area Injection Order # 13, as written, would allow us to increase the injection pressure from the current 1,000 psi up to 1,400 psi. However, if you feel that it would be more appropriate to amend the AIO, we would be happy to submit a formal request outlining our intentions. In either case ARCO will submit, for your approval, a quality assurance plan that would ensure that all of the injected fluids are remaining within the interval approved in the Area Injection Order. ARCO ~ Ina. I. a ~ of Atlantic Richfield Company Mr. L. Smith November 7, 1991 Page 2 If you have any questions please contact Jim Zernell at 263-4107. Sincerely, JCW:JTZ:czm:0023 Attachments cc: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION sORIGINAL 1. Type of Request: operation Shutdown Pull tubing 2. Name of Operator AR(~O Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface Stimulate Alter casing Repair well 5. Type of Well: Development Exploratory Stratigraphic Service 960' FNL, 1320' FEL, Sec.33, T8N, RgW, SB&M At top of productive Interval Straight Hole At effective depth Plugging At total depth 12. Present well condition summary Total Depth: measured true vertical 3000' feet 10,935' feet Plugs (measured) Perforate __ Pull tubing Other SRT 6, Datum elevation (DF or KB) 179' KB feet 7. Unit or Property name Swanson River Unit 8. Well number ~RIJ 41-33WD g. Permit number/approval number !0. APl number 50-133-10167-00 1 1. Field/Pool Swanson River-SteM in,c] 2,990-3,000' MD Effective depth: measured 2,897' feet true vertical 2,987' feet Junk (measured) 2,897-2,990' MD Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Current: Current: Length Size Cemented 23' 20" --- 325' 13-3/8" 272 SX 3,000' 5-1/2" 726 sx 2,875' 3-1/2" 300 sx measured 2,882'-2,926'; 2,940'-2,978' MD true vertical 2,882'-2,926'; 2,940'-2,978' TVD Tubing (size, grade, and measured depth) 3-1/2", N-80 @ 2,875'; tubing is cemented to surface. Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Measured depth True vertical depth 23' MD 23' TVD 325' MD 325' MD 3,000' MD 3,000' TVD 2,875' MD 2,875' TVD RECEIVED DEO 1 9 1991 Al;lEk~ nil ~. t~oo r, .... ..... :~, .... Anchorage N/A Treatment description including volumes used and final pressure 14. Rel2resentative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1700 ggo Subsequent to operation 1700 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'-~~'~~'- Title Cook Inlet Regional En.qineer Form 10-404 Rev 06/15/88 Service 990 SUBHIT IN DUPLICATE ' 11-16-1981 14:08 ~? __8.83 ~i,030 SWANBON RIVER PRODUCTION mm i i i ,m TI.Il. BLOOK .!. {1.1MMAI~' ~,,ONI'INUED ON mA?K 1i-16-1991 i4:09 907 283 1030 SW~$ON RIVER PRODUCTION P.06 [ in, I I I ·, i i1 DESCRIPTION DAIkY AC.,~UM. TOTAL ~ I IIII .... I II i i ii IIIII ~.~,__-~_-~eE~ .......... ______wV~ ---11 II I I II ~~L ........... H~,~,j~ON ........ ~.~ ~[t ~),a ' ~ ......... I i, ii -- .... I Ill Ill ' ~ I I[ [ i - ~ , , · ........ _[[ i [ i. · nl [[1[[[- . ~ ~ ~ ~ i III I I If Ill l[ -='-' ' '" Anchom~e [ [ [ mil [[ [ Ill [ [ I [[ ill i [[ [[[[[ [ _ Illll I .... "-[ , ~1-~6-1881 08:~7 807. 10~0 ARCO Alaska, In(=. <) ~Ntdllry of AtllJ1tle illlr, hfleld ~ptny ~e.u .<lt-.4g CONTRACTOR SWANBON R I VER , :>UCT I ON P. 0 ! WELL SERVICE REPORT ___ JOPERATION AT REII~¥ TIME. _l.'~o o IdO~ C, .... L, zo 1._?.o~ ,' . - Il 75' l ~'~,~ ,_~o RECEiYED '- 1,7415 __ A Im,-L -.. ,-.c~au ulJ & Gas Cons. commission iii ,,Illl I I '~l~l~l~l-A CHECK THIS B~K IF SUMMARY'cONTINUED ON BACK i i ii w,.. i...v.,. ..... 2700 2600 2500 2400 2300 f2200 21 O0 2000 1900 1800 1700 1600 15oo 14oo 1300 42-33WD 11/22/91 SRT ...... Extnapohited bo#om hole pre~ur, rak - · WHIP 0 - -- . ~ - I ff I · I I I I ! I ! .I I I I I I t L. _L./ I I I I I I · e I I I I I I I t I ! I I. 2000 2500 3000 3500 4000 4500 5000. 5500 6000 6500 7000 RATE (13WP!)) .I 41-33 WD 11/22/91 SRT DATA (BWPD) (psig) 2219 1025 3705 11 O0 4272 1190 4913 1240 6900 1400 Fie I 6RJ? /~PII100' ,,,Pi (psig) (psig) 64823 0.024 6 5 0.56 1 6 108232 0.021 108 1.37 40 124796 o.o2oe 126 1.61 52 137276 0.0206 137 : 2.17 62 143521 0.0205 143 2.36 68 201566 0.02 201 4.54 131 NOr[E: Fgk:tJon factor and AP from Crane's 'l~essum Drop in Liquid Unes for Tud)uloot Flow~. (psi0) 2278 2330 2468 2417 2442 2539 Extrapolated 11 ~23~91 ,Step Rate Test SRU 41-33WD 1,400 1,200 1,000 800 600 400 200 Normal operating pressure and rate · SRT #1 Data ~ ~ ~ E] SRT#2Data !-- 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 Injection Rate, Bbl Water/Day 12/17/91 jtz L e · .o · m · o. .o D.V. · ~e · ~23'1~lT. ~-l?-Tt te ~/-~ ~lAItl t~ SWAt,,. r. *. · · · ' ,' ' RECEIVED · · i ~em 8N~" · . O~C 19~99~ ~laska Oil & Gas Cons. Corr~missio~ Anchorage ,'mae 80o8* · ~ or PLUG ~J ~0, 'r-D. SRU 41~33 CASING & TUBING DETAtt SECTION $$ T. ~ Iq.,R. 9 W. SI4 Post OffiCe B~., ,00360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering November 8, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Step Rate Testing on SRU ~;~S~ Dear Mr. Smith: disposal facility at our Swanson River Field. Currently the field's oil' produCtion is limited by the amount of produced water that can be injected into the existing water disposal wells. In an effort to increase the amount of fluid that can be handled, ARCO plans to perform a step rate test of limited duration on SRU 41-33WD. Currently this well takes approximately 1,700 BWPD through perforations below 2,882' at 1,000 psi wellhead pressure. In June of 1991 ARCO performed the routine MIT along with a pump-in temperature survey on the subject well. The MIT verified that the well was properly containing all injected fluids. Furthermore, the pump-in temperature survey showed that all of the fluids were remaining within the zone of injection below 2,880', even though the well is operated above parting pressure. The step rate testing outlined on the attached procedure will establisff'~ the injection capacity of the well at surface pressures up't0 1,400:=psi; Of equal importance, it will also verify that the surface equipment is capable of operating at the higher pressures for a sustained period of time. (During the testing the other water disposal wells will be isolated from the higher injection pressures). If it is determined that SRU 41-33WD is capable of taking a significant amount of fluid at the higher injection pressures, additional facility equipment and cost will need to be evaluated. The justification for that equipment would be based on the incremental ~l~~~.~c~lld be realized by making the modifications. ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company NOV - 8 1991 Alaska Oil & Gas Cons. Commission Anchorage Mr. L. Smith November 7, 1991 Page 2 ARCO will promptly report the results of the testing to your office. If the results are favorable we will submit an additional Sundry application formally outlining the planned operation of the well at the higher injection pressures. At that time we will also outline a proposed program for assuring the protection of any potential fresh water aquifers. If you have any questions on this proposed procedure please contact Jim Zernell at 263-4107. Sincerely, T. Wellman TW:JTZ:czm:0139 Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation Alaska 0il ~ Gas ~0ns. APPLICATION FOIl SUNDFW APPFIOYAL$ - 2. Name cd Opemt~ i 5. Type of Well: ! ,ARCO Alnek~"- Irte. 3. Addr~ P. O. ~x 10G~O. A~horn~e, AK gg510 Pull tubln~l __ Variance _ Pedorate __ Other X , , 6. Datum -'--'-.-~,;,,q (OF or KB) Oevek~mem Exploratory Strltigrephlo Servic~ 4. Location M well at .udm~ 960' FNI. 1320' FEI., Sm:. 33, T8N, Rgw, SB&M Straight Hole At effeellw delalh 12. Pmlertt wMI (xxldl~ I~ Total I:)et~: mM~m~l 3,000 true ~ 3,000 Effective deplh: ~ea~red 2,897 mm venk=l 2,897 C~ 23' 2o' S~am 325' 1 3.3/8' In~ p~~ 3,000' 5-1/2' U~ 2,875' 3-1/2' Current: 2,882'-2,925'; 2,940'-2,978' MD true vertical Current: 2,882'-2,928'; 2,940'-2,978' TVD Tubing (~lz~, gr~M, m~l mermaid d~ 3-1/2', N-80 ~I 2875'; tubing ie cemented to eurface. pac~er~ and SSSV (ty~ .nd mmmur, d de;m) feet Plug~ (measured) feet feet Junk (meaaumd) feM 272 ex 726 ex 300 ex 179' KB 7. Unit or Property rmme Swarmon River Unit 6. W~l n~T.~i SRU 41.33WD 10. APl number 50-133.101 11. FIMd/PoM Swaneon River/Sterling feat 2,990-3,000' MO 2,897-2,990' MD 23' MD 23' 'I'VD 325' MD 325' TVD 3,000' MD 3,000' TVD NOV - g !991 Alaska Oil & Gas Cons. Oor~gf~ss'mg Anchorage 13. AttKhmlnto Detailed opemtimt prngr~m X · 14. Esdmal~l dato for oomm~n~ng operltion ._Ngv.. 1991 16. If propo~ll wee v~ ipprovld Name of ~_F.~-.~."'-.'= D_me__ ~_...,2Droved 17. I hereby oertily that the foregoing ia true ~md corre~ to the be~t M ~j~ k,-,o~1~. Si~F.:--~ '7'2~~~--- ,Tltle C_-oo_k inlet R_~ton.l Engr. FOR ~ _ILL~__ONLY Conditlona of apl:wOrM: Notify Commia~ion ~o repmeentativ~ may witne~ Plug Integrity __ BOP Teat _ I.ocatl~ clMranoe __ Med~enl¢~l Integrity Teat _ Subaequent form require 10-_ '~;' + [II:[I~INAL ,SIGNED B~ LONNIE C, SMITH --J-- -- C~lllll II;-----"- I Appmvi~, by ;'~ =.-~ ol ~, ---""" Form 10-403 Rev 5/03/89 BOP ~k~% _ i16. Statue of well cleelifica&tion aa: Oil __ Om ,. Suapended Sendee X lWater Disposal) 325" I).T. ·" e'lll lYtI'* ellll* · 1'OP OF' PLU(3 ~l ?.D. H~E x# CASCO · 670*; S43U~EZED WXTii ,~O SA(:ZS ',~J. t g. NT. ~-lT-TX Lo ~027-T3. UldXBLg TO SEAL. Cn,A~?£D ~ N.-80 · 2875t RECEIVED · N 0 V - Alaska Oil & Gas' ~ Co,Is. Anchorage 7-21"1'7 SRU 41 ~:3:3 W.D CASING & TUBING DETAIL SECTION SS T. BN.~R. gW. SM , , _. - .~'.'-,* x'l-~,,.~.. '~ .: ..:';,' dellleile. Step-Rate Injectivity Test SRU 41-33WD SR# 263 Well Status: On injection at 900 psi and an average rate of 1,400 BWPD. Minimum Restriction: 3-1/2" tubing cemented in place to 2,875'. Last tag was a 2.5" GR to 2,870'. Perfs partially covered with fill. To establish the injectivity rate versus pressure relationship for the well above the current facility operating pressure. Step-Rate Testing Procedure:. 1) Hold safety meeting with all field personnel associated with the operation. 2) Make necessary arrangements at 1-33 waste water facility to permit increasing the pressure to 1,400 psi. Will require sufficient pump output for -6+ BPM. Note: The National J-250 pump is reported to have an output of 6.1 BPM and is rated to 1,500 psi in its current configuration. 3) Prior to performing the step-rate testing shut-in 41-33WD disposal injection for at least 6 hours. 4) Shut in SRU 31-33WD and 21-33WI) to protect these wells from the higher pressures that will be used during the injectivity test on 41-33WD. 5) Begin injecting into 41-33WD with the existing pump at 1-33 WW facility. Record injection rate and wellhead pressure in 100 psi increments of ~ pressures beginning at 200 psi. Allow the well to stabilize at each step. Plot the rate versus pressure to find the formation parting pressure. Increase pump pressure until a maximum of 1,400 psi pump pressure is reached or until the maximum rate capacity of the pump reached. 6) After testing put all the disposal wells back in service at their normal operating pressures. R E C E IV E JTZ/0014 SR 262/Page 1 NOV - Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Torn Wellman Regional Engineer Cook Inlet Engineering 0fl August 14, 1991 Mr. L. Smith Alaska Oil 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 REEEIVED AUG 1 § 1991 Alaska 0il & Bas Cons. Cornmisslen Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS oRIGIN 1. TyPe of Request: Operation Shutdown Pull tubing 2. Name of Operator ARCO Alaska, Inc, 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 960' FNL, 1320' FEL, Sec.33, T8N, RgW, SB&M At top of productive interval Straight Hole At effective depth Stimulate ... Alter casing Repair well 5. Type of Well: Development ~ Exploratory __ Stratigraphic __ Service Z~_ At total depth Plugging Perforate ,, Pull tubing Other MIT 6. Datum elevation (DF or KB) 179' KB feet 7. Unit or Property name Swanson River Unit 8. Well number SRU 41-33WD 9. Permit number/approval number 12. Present well condition summary Total Depth: measured true vertical 3000' feet 10,935' feet Effective depth: measured 2,897' feet true vertical 2,987' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Current: Current: Length Size Cemented 23' 2O" --- 325' 13-3/8" 272 SX 3,000' 5- 1/2" 726 SX 2,875' 3- 1/2" 300 Sx measured 2,882'-2,926'; 2,940'-2,978' MD true vertical 2,882'-2,926'; 2,940'-2,978' TVD Tubing (size, grade, and measured depth) 3-1/2", N-80 @ 2,875'; tubing is cemented to surface. Packers and SSSV (type and measured depth) 3. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Plugs (measured) 2,990-3,000' MD Junk (rneasured) 2,897-2,990' MD Measured depth 23' MD 325' MD 3,000' MD 2,875' MD True vertical depth 23' TVD 325' MD 3,000' TVD 2,875' TVD N/A RECEIVED AUG 1 § t991 Alas&l.011 & 6as Cons. Commlssien RnohoraDe 1'4. RePresentative Daily Average PFoduction or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 2000 Subset ,tion 2000 Tubing Pressure ggo ggo 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run~ Daily Report of Well Operations X~ Oil __ Gas Suspended~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service ned Form 10-404 Rev 06/15/88 Title Cook Inlet Regional Engineer Date SUBMIT IN DUPLICATE Form 3160--5 (November 1983) (Formerly 9--331) UNi! ) STATES su.mT IN (Other Instructions . DEPARTMEN] OF THE INTERIOR .e,. BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not t~se this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) ARCO Alaska, Inc. ADDR~IBa OF OPRRATOR P.O. Box 100360 Anchorago, AK 99510 LOCATION OF WELL (Re~rt location clearly and In accordance with any 8~te r~ulremen~.* S~ also space 17 below.) At suda~ 1. O,Lw~LL FI OASw,,.L {-'{ OT.E, }{ Water~.Disposal 2. 96011FNL, 1320' FEL, Sec. 33, T8N,~ R9W, SB&M 15. E~V&TION$ (Show whether Dr, ~, O~ etc.) 179' KB 14. PERMIT NO. Form approved. Budget Bureau No, 1004--0135 Expires_ August 31, 1985 5, LRABm DESIGNATION AND JlIIAL NO. A-02_8399 6. Ir INDIAN, ALLOTTRR 0a TItlBR NAME 7. UNIT AGBREMmNT NAMm Swanson River Unit 8. FABM OR LmAdBg NAMR 9, WELL l~O, SRU 41-33WD 10. FIELD AND ~, OR WILDCAT Swanson R I ver / St0r I Ing 8UUVBY OB AREA Sec. 33, T8N, R9W, SB&M 12. eooN~, Ga F,-ISH{ tS. ,~,T, K~.na I{ Aln~kn 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICR OF INTENTION TO: TEST WATRR SHUT-OFF { [ PULL OR ALTER CASING FRACTURE TREAT MUL~IPLm COMPI.ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other) ~ ~ SUBIEJUIN! tllq)l~ 0r: FRACTURE TitRATIfENT . ALTERING CARING 8HOOTING OR ACIDIEING ABANDONMENT° (Other) MIT (NOTE: Report result~ o~ multiple eompletlou ou ~ell Completion o~ Reco~pletlou Eeport Rnd ~ form.) 17. v~:scaiag ;.no[.osEo OR COMPLETED OPERATION.e- (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any propo;ed work. If well is directionally drilled, give subsurface locations and measured and ~rue vertical depths for all markers and ~ones p~rtl- nen~ to this work.) * ARCO Alaska, Inc. on 6/21/91 successfully completed aMechanical Integrity Test on SRU 41-33WD. Please see attached for test results. AUG 1 2 199'1 18. I hereby certify that the foregoing is true and correct (This space for Federal or State ol~ce use) APPROVED BY CONDITIONS OF APPROVAl** LP ANY: TITLE DA~lll '*See Instructions on Revm~ 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. ...... JUN-~.4-'91 06:14 Il' :'-~NSON RIUER TEL NO: ~65: ~9~9 ARCO Alaska, Inc. ~1~11~¥ of Atl~ntl; RIr, hflel~l WELL SERVICE REPOR1 FIELD- DISTRICT- 8TATE I DA¥~' OPERATION ATREPORT TIME ~,br,, 7'c,__ JDA'rE /t,:o 7 -/~ (~ GHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK I I l NSON R I UER TEL NO: 2~5: REMARK8 C.,ONTINU~O; /7 :ZC, -/7: ¢~ DESCRIPTION DAILY ACCUM. TOTAL i m m mill ...... CAMCO- .......... : .... ,, I - - _ OTIS ,. 80HLUMBERGER , DR~_~ER-ATL~8 ................ I:X)W~l ~ ....... HALLIBURTON .... , i i "¢L~ I I · ARCTIC COIL TUBING .......... FRAGMASTER ................. B. J. HUGH~$ .............. Ro%t-__-hoUt. .......... iii .... ~I1~8~ol ....... _~_~t$t0~ ................. - -- Pre~oU O~_fety Me~ing ' , i~1 i i i i iiii illl _ AFB ii ii ..... ii . i . . _ -- II I III m i,i -- i ~- i i I Il I III i ii ii i i iii i ii - II .-- i . i ii ii i I II TOTAL FIELD ESTIMATE .... _~~'~ ~ ~:"~'~_- -~""'0,~/-- "'/'~_~ ~ . ZUN-24-'91 06:16 I.~ M'~NSON R I UER TEL 1,,10:265! ARCO Alaska, Ino. ~) · d~i~li~y of Atlantlo Rlohfiold Oom~a~ty WELL SERVICE REPOR WELL ]PBDT C, ONTRAC'I'OR __ _,.5,¢//_~/...~~-'~'~,E~, //g'~ ~O ...... - 01__: ~0- FIELD. DISTRICT- STATE I DAY8 I DATE OPERATION AT REPORT TIME ._ /~// ~ /._. _//',~/L tiE. _. CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WATER FLOW ADVISOR SRU 41-33 WD Company Field Logging Date Processing Date Reference - ARCOALASKA INC. - SWANSON RIVER UNIT - JUNE 20, 1991 o JULY21, 1991 - 74657 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 REC[~VE~) ARCO ALASKA, INC. Swanson River Unit SRU 41-33 WD Production Logs 20-Jun-91 INTERPRETATION SUMMARY WATER INJECTION DISPOSAL WELL This suite of production logs was run to determine the mechanical integrity of well, SRU 41-33 WD. This well has 3 1/2 inch tubing cemented to surface inside a 5 1/2 inch liner that is inside 13 3/8 inch surface casing. The depth of the casings are: 3 1/2 --- 2875 feet, 5 1/2 inch --- 3000 feet, and 13 3/8 inch --- 325 feet. The 5 1/2 inch casing is plugged back to 2990 feet. The 5 1/2 inch casing is perforated from 2882 to 2978 feet in two intervals. The depths of interest are: Lowest Accessible Depth* Deepest Confining Layer Confining Layer Deepest Potential USDW** 2890 Feet 2824 Feet 2710 Feet 1700 Feet *Schlumberger depth, 6/21/91, was 2876 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 indict no water flowing. Stations reading were taken at the following depths with the WFL log to determine if there is water flowing in the upward direction. DEPTH RESULTS 1060.0 No Water Flow Detected 1255.0 No Water Flow Detected 1408.0 No Water Flow Detected 2090.0 No Water Flow Detected 2250.0 No Water Flow Detected 2275.0 No Water Flow Detected 2710.0 No Water Flow Detected 2824.0 No Water Flow Detected 2867.5 No Water Flow Detected ARCO ALASKA, INC. Swanson River Unit SRO 41-33 WD Production Logs 20-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 injection of 300 BWPD at 63 DEGF, the LONG DASHED BLUE LINE is the temperature log run immediately after injecting 300 BWPD at 980 PSI and at 63 DEGF' the DASHED GREEN LINE is the temperature log run 3.0 hours after injection ofcold water stopped, and the DOTTED BLUE LINE is the temperature log run 6.0 hours after injection of cold water stopped. The warming up after the injection of cold water indicates no "heat sinks" above 2867.5 feet. CONCLUSION --- There is no injected water flowing up the well behind casing above 2867.5 feet. The composite of the logs run on SRU 41-33 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. Presented in Track Two are the time lapse temperature logs. Solid Red Curve Base log before cold water was injected into the well. Long Dashed Blue curve Log immediately after injecting cold water. Dashed Green Curve LOg run three hours after cold water injection. Dotted Blue Curve 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. ARCO ALASKA INC, SRU 41-33 WD, SR 72, JUNE 21,199! ( 7~57 ) GR 1991 TIME LAPSE TEMPERATURE TIME LAPSE PRESSURE -20 (GAPI) 60 60 (DEGF) 110 00 (PSI) 1500 4OO 5OO 6OO 7O0 800 900 1000 1100 1200 1300 1400 1500 1600 !700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 m ~m m ~m~ ARCO ALASKA, INC. ~ Swanson River Unit SRU e,1-33 WD WELL: SRU 41-33 WD Water Flow Log Summary DEPTH Production Logs 20-Jun-91 ACTIVATION CYCLES FIFTEEN ~1' TWO FT ONE let BURST TIME STACKED DETECTOR DETECTOR DETECTOR SECONDS VELOCITY VELOCITY VELOCITY FPM FPM FPM 1060.0 2 11 0.0 STATISTICS 0.0 1160.0 10 10 0.0 0.0 0.0 1255.0 2 8 0.0 0.0 0.0 1255.0 10 10 0.0 0.0 0.0 1255.0 10 6 STATISTICS STATISTICS 0.0 1255.0 2 6 0.0 STATISTICS STATISTICS 1408.0 2 6 0.0 STATISTICS 0.0 1408.0 10 6 0.0 0.0 0.0 2090.0 2 6 0.0 0.0 STATISTICS 2090.0 10 6 0.0 0.0 0.0 2250.0 10 6 0.0 0.0 0.0 2250.0 2 6 0.0 0.0 0.0 2275.0 2 6 0.0 0.0 STATISTICS 2275.0 10 6 0.0 0.0 0.0 2275.0 2 6 0.0 STATISTICS STATISTICS 2710.0 2 7 0.0 0.0 0.0 2710.0 10 6 0.0 0.0 0.0 2824.0 10 6 0.0 0.0 0.0 2824.0 2 5 STATISTICS 0.0 0.0 2867.5 2 6 0.0 0.0 0.0 2867.5 10 6 0.0 STATISTICS 0.0 2867.5 10 6 0.0 0.0 0.0 There are some measurements with the WFL log that indicate flow, but after closer inspection of these measurements, the values are based on statistics in the signal. All of these measurements were rep~e~ed to verify that there was no water flow at these depths in the well. 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 SRb ,1-33 WD Production Logs 20-Jun-91 WATER FLOW LOG EXAMPLES imm 900.000 720.000 540.000 CPS CYCLE 360.000 180.000 0.0 TIM£($EC) ;'ILl MUM])£R ])ATA ACQUIR£1) ]}£TECTOR = M£AR TI)T-P Depth 2867.5 No Water Flow Detected Flow Velocity = 0.0 Ft./Minute oo · .e D.V, · L16Oo · Clptnfl'n ~ LBo · · ?.D. · · · .. ?- ~'1-1"? ,M~S' · SRU 41~33 V,(D CASINg & TUBING O£TAIt SECTION 33 T. IN~9~ ~ 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:007 la Attachment CC' Mr. W. Watson Mr. B. C. Dehn Marathon Oil Compaxlv__ UNOCAL Corporatio~ E ~ ~/[V E 0 ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company 3UN 1991 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ORIGINAl 1. Type of Request: Abandon _ 2. Name of Operator Alter casing m Change approved program Suspend_ Operation Shutdown __ Re-enter suspended well ~ Repair well Plugging_ Time extension _ Stimulate ~. Perforate Other X f M I T I 6. Datum elevation (DF or KB) Pull tubing ~ Variance 5. Type of Well: Development ~ Exploratory _ Stratigraphic ARGO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 960' FNL, 1320' FEL, Sec. 33, T8N, R9W, SB&M At top of productive interval Straight Hole At effective depth 12. At total depth Present well condition summery Total Depth: measured 3,000 feet Plugs (measured) true vertical 3,0 0 0 feet Effective depth: measured 2,897 feet Junk (measured) true vertical 2,8 97 feet 17g' KB 7. Unit or Property name Swanson River Unit 8. Well number SRU 41-33WD 9. Permit number feet 10. APl number 50-133-10167-00 11. Field/Pool Swanson River/Sterling 2,990-3,000' MD 2,897-2,990' MD 13. 14. Estimated date for commencing operation Casing Length Size Cemented Measured depth Structural Conductor 2 3' 2 0" - - 23' MD Surface 325' 13-3/8" 272 sx 325' MD Intermediate Production 3,000' 5-1/2" 726 SX 3,000' MD Uner 2,875' 3-1/2" 300 sx 2,875' MD Perforation depth: measured Current: 2,882'-2,926'; 2,940'-2,978' MD R E C E iV true vertical Current: 2,882'-2,926'; 2,940'-2,978' TVD Tubing (size, grade, and measured depth ~( ~ 3-1/2", N-80 @ 2875'; tubing is cemented to surface. Packers and SSSV (type and measured depth) ,b,J~ska, Oil & Gas G0ns~ Attachments Description summary of proposal _ Detailed operation program X June, 1991 16. If proposal was verbally approved Name of approver True vertical depth 23' TVD 325' TVD 3,0O0' TVD 2,875' TVD BOP sketch Date approved 15. Status of well classification as: Gas Suspended Service ~, (Water Disposal) 17. I hereby certify that the foregOing is true and correct to the best of my knowledge. Si~lned /~~~ Title Cook Inlet Regional En~r. FOR COMMISSION USE ONLY Conditions of approval: NotifY Commission so representative may witness Plug integrity BOP Test _ Location clearance Mechanical Integrity Test ~ Subsequent form require 10- ~/~ Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY I nMMII:: ~ RUITI.I IApproval No. ~. ! / p, eturnea SUBMIT IN TRIPLICATE Well SRU 41-33WD MIT & P/'~ SR 246 Revised Objective Determine mechanical integrity of the well with oxygen activation log (MIT) and verify that the well is not affecting the fresh water aquifer (PITS). Current Status SRU 41-33 WD is on injection. Minimum Restriction: 3 1/2' tubing. Last Tag: 2864' WLM w/ 1.70" gauge ring (11-29-89) Suspect scale buildup on tubing. Pressures: TP 980 psi PC 0 psi SC 0 psi Procedure · Prior to Looaina _ _ -- 1. RU slickline and tag fill with 2.5" gauge ring. 2. Contact Anchorage Office to verify Sundry Approval and notify the State and BLM 24 hours prior to the MIT. 3. Tie-in log is Injection Analysis: Schlumberger (10-10-89). · Mechanical Inteq~,,_ Test. (MIT}: Oxtlqen Activation Loq 1. e Establish a stabilized injection rate into the well with a 900 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 OA log should be configured to detect upward flow. 3. Tie in GR. Log from fill depth to 1000' MD. Verify repeatability. 4. Check for upward flow at the following stations. Depth 2850' 2824' 2710' 2250' 2275' 2090' 1700' 1408' 1255' 1060' Reason Above perforations Deepest confining layer Confining layer Heat anomaly noted in 10-10-89 pits Heat anomaly noted in 10-10-89 pits Heat anomaly noted in 10-10-89 pits Potential USDW* 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. · Prior to Pump-in Temperature Surv¢p {PITS] 1. Shut-in well for at least 12 hours. 2. Assure that 300 bbls of (~45°F) lease water is on location. not use produced water (too warm). NOTE: Do · (PITS] 3. RU E-line. Pressure test lubricator. . . RIH w/ CCL/temp tool (CCL on top). Record temperatures from surface to PBTB. Do not exceed 30 fpm. Tie-in. Re-log the bottom 200' to verify repeatability. Set tool at 200' MD. 6. RU pump truck and pressure test lines. Pump 300 bbls lease water at 900 psi injection pressure. RD pump truck. 7. Log down to fill depth 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, I hour apart. 10. POOH. RD E-line. 11. Return well to service. · #GL~ ZU CJLS~ · 670'~ S~U~D b~ XX) SACZS 'C~4~IT. ~-XTo7X t,o ~.,27-ZX UIdABLK TO SGI,. .0 . .. ,! D.V. · L1AO* '1 I · 'r.D. · · SRU 41~33 W.]). CASING & TUBING DETAIL SECTION $$ T. 8 N.,R.9 W. ~ 8TAHIMJ~ OTL ~~ ~ ~~ , , . d oWo~o ARCO Alaska, Inc. Post Office B~,,. 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures November 7, 1989 Mr. C. V, Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Sundry Approval: Acid Stimulation SRU 41-33WD Swanson River Field Dear Mr. Chatterton: ARCO Alaska, Inc. requests approval to acid stimulate SRU 41- 33WD with 15% HC1 to increase injectivity. "-~ If there are any questions pertaining to this matter, ple%ase~ contact Stacy Strickland at 263-4914. ~ Sincerely, T. S. McCorkle TSM:SLS:ch:0015 Attachment cc: S. W. Ohnimus A. t~ Kukla UNOCAL Corporation Marathon Oil Company RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 STATE OF ALASKA Al- A OIL AND GAS CONSERVATION COMMI,. ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well __. Change approved program __ Operation shutdown __ Re-enter suspended well __ ,, Plugging ~ Time extension ~ Stimulate ~ Puli tubing __ Variance __ Perforate __ Other Name of Operator ARCO Alaska, Inc. Address P. O. Box 100360 Anchorage, AK 99510 Location of well at surface 960' FNL, 1320' FEL, Sec. 33, T8N, Rgw, SB&M At top of productive interval Straight hole At effective depth At total depth 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 179' KB 7. U..nit or Property/name bwanson r~iver Unit 8. Well number SRU 41-33WD 9. Permit number ~ b/' '~' ? 10. APl number 50-- 133- 10167-00 11. Field/Pool Swanson River/Sterling feet 12. Present well condition summary Total depth: measured 3000 feet true vertical 3000 feet Plugs (measured) Effective depth: measured 2897 feet true vertical 2897 feet Junk (measured) Casing Conductor Surface Production Tub ing Perforation depth: Length Size Cemented 23 ' 20" -- 325' 13-3/8" 272 sx 3,000 ' 5-1/2" 2,875' 3-1/2" measured 2882-2926' MD; 2940-2978' MD true vertical 2882-2926' TVD; 2940-2978' TVD 726 sx 300 sx Tubing (size, grade, and measured depth) 3-1/2", N-80 @ 2875'; tubing is cemented to surface. Packers and SSSV (type and measured depth) 2990-3000' MD 2897-2990' MD Measured depth True vertical depth 23' 325' 23' 325' 3,000' 2,875' 3,000' 2,875' 13. Attachments Description summary of proposal __ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation ! 15. Status of well classification as: November, 1989 16. If proposal was verbally approved Oil __ Gas Suspended ~ Name of approver Date approved Service Water D i sposa I 17. I hereby~ that the foregoing ,strue and correct to the best of my knowledge. Signed ~¢J", ~;:~, ~~ Title Cook In let Engineer lng Manager Date co ,ss,o, o. Y Conditions of approval: Notify Commission so representative may witness JApproval No. Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form required 10- Original Signed By Approved by order of the Comm~ssioner David W. Johnston Commissioner FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SRU 41-33WD Acid Stimulation Procedure SR 96 Objective: To stimulate SRU 41-33WD with 15% HCI to increase water injectivity by removing scale deposits. Well Data: Completion: Last PBTD Tag: Pressure Data: Tubular Capacities: 3-1/2''' EUE 8RD Tbg. to 2875' MD 2897' WLM (6/1/89) Tbg=880psi; PC =5psi; SC =0psi 3-1/2" tbg. = 0.0087 bbl/ft Procedure: Note: Verify that Sundry approval has been obtained prior to performing this work. 1. Hold safety meeting with all personnel involved in the treatment. 2. Flush clean pump truck, lines, and mixers. 3. Titrate acid on location to ensure proper acid concentration. . MIRU stimulation company. Install service company filter (2 micron). Pressure test lines to 4000 psi. , , Shut-in produced water injection. Pump acid stimulation in the following order. or 0.6 BPM while pumping. Do not exceed 800 psig a) Lead Spacer: 420 gal (10 bbl) filtered lease water b) Acid: 2000 gal (48 bbl) 15% HCI acid with additives* c) Tubing Displacement: 1050 gal (25 bbl) filtered lease water . . RDMO. Allow perforations to soak for 12 hours. Tag fill with 1.7" gauge ring prior to returning to injection. 9. Return Well to injection. *Acid System: 15% HC1 0.2% A250 (corrosion inhibitor) 0.2% F75N (non-io~c suffact~t) 20~/1000 gal L58 (iron sequesterin~ ..~,7' CRq · )25' HA]lOC i).V. · ' _ Hcx,8 IX CASCO · 670~ SQUgEZgD b'Z'fl, i ,t00 SACZS -- '~.,Ar.,HT, %].7-71 t,o ~-27-7.! UtlABI,~ TO SE, AC, -. . . . 7-2,/,,-Z? ~f~: , , SRU 41 33 W.l) · . .~ 1'01, OF PLUO Il 2~90t ,,~ CASING 8~ TUBING DETAIL ~.~. ~oo, SECTION 33 .T. SN.,R. BW. ~ . __ · . ' . 8'rAXDAltD OIL .~ -..' .':.-,..~'.r-:~-t~-'-~''-..': . . · ._ .k,.-,:- ,,...;.....~-d.Z~.~b~.'./x o;,.:,': *' '. ..... :; ~ :' ........ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures ORIGIN October 27, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Results of Pump-In Temperature Survey of SRU 41-33WD Swanson River Field Dear Mr. Chatterton: This is to submit the results of the pump-in temperature survey (PITS) that was performed on SRU 41-33WD on October 10, 1989. The test was done to proVe that current injection practices (over 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 injection is confined to the perforations with no channeling occurring (see attached survey). In addition, the survey shows a heating anomaly at approximately 1970-2350' MD. The close proximity of SRU 31-33WD, which is continuously injecting warm produced water, explains this anomaly. The presence of this heated interval confirms the previous interpretation that SRU 31-33WD is injecting up to approximately 1970' MD while over parting pressure. If you have any questions concerning this matter, please contact Stacy Strickland at 263-4914. Sincerely, T. S. McCorkle TSM:SLS:ch:0011 Attachment cc: S. W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company RECEIVED OCT 1 1589 Oil & Gas Cons. Anchora~j Cornrni, slon ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 STATE OF ALASKA AL, ~ OILAND GAS CONSERVATION COMMIb,~,ON 0 R I 6 REPORT OF SUNDRY WELL OPERATIONS IN AL 1. Operations performed: Operation shutdOwn __ StimUlate__ Plugging__ Pedorate__ Pump- i n Temperature Pull tubing __ Alter casing __ Repair well __ Pull tubing __ Other ~ $ u r vev 2. Name of Operator. ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 4. Location of well at surface 960' FNL, 1320' At top of productive interval Straight hole At effective depth 99510 At tOtal depth 5. Type of Well: Development __ Exploratory __ Stratigraphic --w- Service ,z, FEL, Sec. 33, T8N, R9W, SB&M 6. Datum elevation(DForKB) 179' KB feet UnitorPropertyname Swanson River Unit 8. Wellnumber SRU 41-33WD 9. Permit number/approval number 10. APl number 50-- 133-10167-00 11. FielCPool bwanson River/Sterlinc. 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production ~ Tubing Perforation depth: 3000 feet Plugs (measured) 3OOO feet 2897 feet Junk (measured) 2897 feet Length Size Cemented 2990-3000' MD 2897-2990' MD Measured depth 23 ' 20" -- 0-23 ' 325' 13-3/8" 272 sx 0-325' 3,000' 5-1/2" 726 sx 2,875' 3-1/2" 300 sx measured 2882-2926' MD; 2940-2978' MD truevertical 2882-2926' MD; 2940-2978' MD is cemented to surface. Tubing (size, grade, and measured depth) 3-1/2", N-80 @ 2875'; tubing Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure True vertical depth 0-23' 0-325' 0-3,000' 0-2,875' 0-3,000' 0-2,875' RECEIVED OCT 3 11989 Alaska Oil & 6as Cons. Commisslort Anchoraff3 14. Representative Daily Average Production or Injection Data Oit-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 600 5 860 Subsequent to operation 5 5 0 15. Attachments J 16. Status of well classification as: Copies of Logs and Surveys run .Z._ I Daily Report of Well Operations ~ Oil M Gas M Suspended 17. I hereby certify that the foregoing is true and correct to the best of mY knowledge. Signed /~. ,(~'. /~j,, ~.~.~k~ Title Cook In let Form 10-404 Rev 06/15/88 78O Sewice Water Disposal Engineering Mgr. Date/g/~ ~/~f SUBMIT IN DUPLICATE OCT-11-' 89 ~?:28 ~: SWANS~ RIUER TEL NO: 2651383 ARCO Alaska, Inc. WELL SERVICE REPOR' tFIELD · DISTRICT- STAT! OPERATION AT REPORT TIME .. CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~?oo hr-* e.r--~r 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 August 14, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Sundry Approval: Pump-In-Temperature Surveys SRU 41-33WD and $CU 43-4MD Swanson River Field Dear Mr. Chatterton: ARCO Alaska, Inc. requests approval to perform the attached pump-in-temperature surveys on $RU 41-33WD and on SCU 43-4MD 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 above parting pressure. The recommended surveys will make multiple temperature passes from 1200' to PBTD after injecting cold brine into each well. The resulting data will define where the cold fluid travels when injection is over parting pressure. If there are any questions pertaining to this matter, please contact Stacy Strickland at 263-4914. Sincerely, T. S. McCorkle TSM:SLS:ch:0006 Attachment CC: S. W. Ohnimus A. R. Kukla Anchorage UNOC~ Co.craYon M~a~on Oil Comply ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 /"~: STATE OF ALASKA . ~ k 5KA OiL AND GAS CONSERVATION COMk ~ION APPLICATION 'FOR SUNDRY APPROVALS 1. Type of Requ;gst: Abandon __ Suspend __ Alter casing __ Repair well __ Plugging __ Change approved program __ Pull tubing __ Variance __ 2. Name of Operator / 5. Type of Well: ARCO A I aska, I nc. ! Development Exploratory 3. Address Stratigraphic P. 0. Box 100360 Anchorage, AK 99510 ServiceX 4. Location of well at surface 960' FNL, 1320' FEL, At top of productive interval Straight Hole At effective depth Operation shutdown __ Re-enter suspended well B o .... in Temperature Time extension m Stimulate ._Z' u'''~' At total depth Perforate __ Other _X.. S U rvey 6. Datum elevation (DF or KB) 179 ' KB feet Sec. 33, T8N, R9W, SB&M Z UnitorPropedyname Swanson River Unit 8. Wellnumber SRU 41-33WD 9. Permit number &, o - oo ! 10. APl number 50--1.53-10167-00 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 Tubi ng Perforation depth: 3000 feet Plugs (measured) _5000 feet 2897 feet Junk (measured) 2897 feet Length Size Cemented 23 ' 20" -- 325 ' 13-3/8" 272 sx 3,000' 5-1/2" 726 sx 2,857' 3-1/2" 300 sx measured 2882-2926' MD; 2940-2978' MD 2990-3000' MD 2897-2990' MD Measured depth 23' 325' 3,000' 2,857' True vertical depth 23' 325' 3,000' 2,857' truevedical 2882-2926' MD; 2940-2978' MD Tubing (size, grade, and measured depth) 3-1/2", N-80 @ 2857'; tubing Packers and SSSV (type and measured depth) 13. Attachments is cemented to surface Description summary of proposal m Detailed operations program 14. Estimated date for commencing operation 115. August, 1989 16. If proposal was verbally approved Oil Name of approver Date approved · ServiCe 17. I hereby certify that the foregoing is true and correct to the best of my knOWledge. Signed o~...30'.,~~ Title Cook INlet Engineer i ng Manager Date 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- Status of well classification as: Gas ~ Suspended Water Disposal Approved by order of the Commissioner Original Signed By David W. Johnston FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Pump-In-Temperature-Survey SRU 41-33WD SR 72 Objective: To determine the interval(s) receiving disposal water in this well while injection is maintained above parting pressure. Well Data: Completion Perforations: Last PBTD tag: Current Pressures: Est. Parting Pres.' 3-1/2", 9.2#, N-80 tbg cemented from shoe (2857' MD) to surface 82' Total; top most @ 2882' MD, bottom @ 2978' MD 2907' MD on 6/1/89 (1.75" impression block) =930 psi tbg. inj. pres.; PC is cemented 825 psi surface injection pressure Note: Verify that sundry approval has been obtained and that well has been injecting above parting pressure (825 psi injection pressure or 925 BWPD) for at least three days prior to performing this temperature survey. Procedure: 1. SI well for at least 24 hours. . Hold safety meeting. Assure that at least 300 Bbls of cold (-50*F) 3% 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 PBTD. Do not exceed a 30 fpm line speed below 1200' MD. 5. Tie-in with tbg tail. . Re-log bottom 200' at 30 fpm to verify temp tool repeatability (down run). Leave tool on bottom. . RU pump truck and tie into tbg. Pressure test lines to 1000 psi. Pump at least 300 Bbls of cold brine (-50°F) at over 850 psi surface injection pres. SI well. 8. POOH to 1200' MD at 30 fpm. 1 Log down to PBTD at 30 fpm recording temperature data. 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 o~ Atlantic Richfield Company AR3B-6OO1-A PumP-In-Temperature-Survey SRU 41-33WD SR 72 - Page Two 11. 12. POOH. RDMO. Return well to injection. ARCO Alaska Inc. is a subsidia~/of Atlantic Rlcl~ield Company AR3B-6OO1-A ~.911.4 I' D,V, · 0 · II FX2~T ,IT. SAi, r TCX:A'Ii Cli BOTTC:Kj, I10 CCLLAR ,. liCLE Z, C~I~O · 670'; SQUgEZED I, ITI'H JO0 SACKS '~,H.~T. 9-17-71 t,o 9-27-7.2 UNABLE TO SEAl.. - . . C~E~T'~,D ~, N-80 · 28S7t TOP OF PLUG T.D, .:3(XX)* 7-~/-~-~ ~' SRU 41 CASING & TUBING DETA! SECTION 33 T. 8N.~R.9W. ~ S~ANDA~ OZL COm'ANY O~ ~~N~ E-Line BOPE's ..___ Grease Head/ Hydraulic Packoff ~-- Lubricator Extension Manual Rams Swab Valve Double Maste~ Valves ,, Wellhead ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMITFAL #282 TO: John F. Boyle COMPANY: AOGCC DATE: Jan. 3, 1989 FROM: Tom Wellman COMPANY: ARCO Alaska, Inc WELL NAME:Listed below Transmitted herewith are the following Folded R~ed Mylar Tape RA Tracer SCU 41-33WD L,~ ~' Receipt Acknowledgement: Return reciept ALASKA, Inc. n%~ltt~0-:.r~ ~'-~ ~ ATFN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510- ARCO Alaska, Inc. ? Post Office £ 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures December 20, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Results of RA Tracer Test of SRU 41-33WD for UIC Monitoring Swanson River Field Dear Mr. Chatterton: This is to submit the results of the RA tracer testing that was performed on SRU 41-33WD on September 30, 1988. The test was done to prove the mechanical integrity of this water disposal well, as required by UIC regulations. This testing replaces standard MIT pressure testing of the casing/tubing annulus. Standard testing could not be performed as the tubing in SRU 41-33WD is cemented in place. The "timed run" RA tracer log was obtained in accordance with the submitted Sundry, as previously approved by your office. The results prove this well's mechanical integrity and fulfill Parts I and II of the MIT requirements (see attached). Please note that Joe Russell (with the BLM) witnessed this test. If there are any questions concerning this matter, please contact Carol Baker at 263-4643. Sincerely, T. S. McCorkle TSM:CMB:ch:0008 Attachments cc: Mr. A. R. Kukla Mr. G. A. Graham Marathon Oil Company UNOCAL Corporation ECEIVED DEC 2 1 I988 Alaska Oil & Oas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 STATE OF' ALASKA ~"-" AL`,/ A OIL AND GAS CONSERVATION COMMI,. ~N REPOR't OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ 'Stimulate Plugging __ Perforate __ Pull tubing ~ Alter casing __ Repair well ~ Pull tubing ~ Other 2. Name of Operator ARCO Alaska, inc. 3. Address P. 0. Box 100360 Anchorage, AK 99510 5, Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 960' FNL, 1320' FEL, Sec. 33, T8N, R9W, SB&M At top of productive interval 960' FNL, 1320' FEL, Sec. 33, T8N, R9W, SB&M At effective depth 960' .¢:NL, 1320' FEL, Sec. 33, T8N, RgW, SB&M At total depth 960' FNL, 1320' FEL, Sec. 33, T8N, Rgw, SB&M 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production Tubing Perforation depth: 3,000 feet 3,000 feet 2,990 feet 2,990 feet Length Size Cemented Plugs (measured) J u nk (measured) 23 ' 20" -- 325' 13-3/8" 272 SX 3,010' 5-1/2" 726 SX 2,875' 3-1/2" 300 SX measured 2,882 - 2,926' MD; 2,940 6. Datumelevation(DForKB) 179' KB ~ UnitorPropertyname Swanson River Unit 8. Wellnumber SRU 41-33WD 9. Permit number/approval number ~-116 10. APl number 50-- 133-10167-00 11. Field/Pool Ster I ing Measured depth 23' 325' 3,000' 2,875' 2,978' MD True vertical depth 23' 325' 3,000' 2,875' truevertical 2,882 - 2,926'TVD; 2,940 - 2,978' TVD Tubing (size, grade, and measured depth) 3-1/2" N-80 2,875' Packers and SSSV (type and measured depth) DEC 1, 1988 feet 13. Stimulation or cement squeeze summary Intervals treated (measured) Oil & Gas Cons. 6ornmiss~ot; Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 Subsequent to operation 435 BPD 15. Attachments [ 16. Status of well classification as: Copies of Logs and Surveys run ~ I Daily Report of Well Operations __ Oil __ Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of mY knowledge. Signed ~'~,-~, ~.-~ Title Cook Inlet Form 10-404 Rev 06/15/88 0 780 Service Water Disposal Engineer in~ Manager Date/2-/.~0/8 ~ SUBMIT IN DUPLICATE RA TRACER TEST RESULTS SCU 41-33WD 9/30/88 Procedure Progression: 1. Run baseline GR from PBTD to surface. Tie-in. 2. Set off RA slug at 80'. 3. Collect data from "timed-mn" (for each interval): Inj. Rate Tool Time for RA Slug to Calculated Estimated Surface Depth. Travel from Prey. Depth Inj. Rate Fluid Loss 28.4 fpm 300' 7 min. 31.4 fpm 0'* 20.0 fpm 1,150' 42 min., 16 sec. 20.1 fpm 0 26.0 fpm 2,000' 33 min., 32 sec. 25.3 fpm 0* 26.0 fpm 2,870' 29 min. 30.0 fpm 0'* Within accuracy of test. As fluid appears to be traveling faster than is being injected at surface, it appears that the tubing ID must be restricted (i.e., due to scale build-up). 4. Pulled tool uphole to 2,823' MD to monitor for injection occurring at perfs and channelling up. No radioactive response was detected. 5. Shot a second RA tracer slug at 2,850' MD. Remained in place to again monitor for communication behind pipe. No response was detected. 6. Logged GR from PBTD to surface and overlayed with GR from step #1. No out-of- zone injection was detected. RECEIVED DEC 2 1 J.958 Alaska Oil & Gas Cons. Anchorage ,I D,V. · TOP OF PLUO ~J 29~0t TUB]IlO ItidlG~:'~'-'x HCLg XN CA.S~:~ · 670,, S~UgEZI~D k"XTli JO0 '~.~,)IT. ~-17-71 t,o ~-27-7.:~ UNABLE TO S~L.' .o RECEIVE~:? Anchorage SRU 41~33 W.D CASING & TUBING DETAIL SECTION ;~;~* T. Il N.~R. gW. SM ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering September 19, 1988 C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Sundry Approval RA Tracer Survey for MIT SRU 41-33WD Swanson River Field Dear Mr. Chatterton: ARCO Alaska, Inc. requests approval to perform the attached RA tracer test on SRU 41-33 WD to prove the mechanical integrity of this water disposal well, as required by UIC regulations. Standard MIT pressure testing of the casing/tubing annulus (Rule 6 of the UIC permit) can not be performed on this well as its tubing is cemented in place. The recommended alternative procedure (attached) is a "timed-run" RA tracer log in conjunction with running a GR log before and after RA tracer injection. This method was approved by the EPA on December 10, 1987 (52 Federal Register 46837, et seq.) and should fulfill Part I of the MIT requirements. In addition, we recommend placing the RA tracer receptor at two locations above the top perforations to look for injection moving up behind pipe to fulfill Part II of the MIT requirements. If there are any questions pertaining to this matter, please contact Carol Baker at 263-4643. Sincerely, T. S. McCorkle TSM:CMB:cmk:0001 Attachments CC: Mr. J. Coltart Chevron Mr. D. Jones Marathon Mr. G. Graham UNOCAL ARCO Alaska, Inc. is a Subsidiary of AflanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown r-] Re-enter suspended well [] Alter casing [] Time extension D Change approved Program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska Inc. 3. Address Post Office Box 100360 Anchorage, AK 99510 4. Location of well at surface 879' FNL 1320' FEL Sec 33, T8N, R9W, SB&M -.. At top of productive interval 879' FNL 1320' FEL Sec 33, T8N, R9W, SB&M At effective depth 879' FNL 1320' FEL Sec 33, T8N, R9W, SB&M At total depth 879' FNL 1320' 1;EL Sec 33, T8N, R9W, SB&M 5. Datum elevation (DF or KB) 179' KB 6. Unit or Property name Swanson River Unit 7. Well number SRU 41-33 WD feet 8. Permit number 9. Apl number 50-- 133-10167-00 10. Pool Sierling 11. Present well condition summary 3000 Total depth: measured true vertical 3000 Effective depth: measured 2990 true vertical 2990 feet feet feet feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 23' Surface 325' 13-3/8" Intermediate Production 3010' 5-1/2" Tbg~ 2875' 3-1/2" Perforation dep_th: 2882' 2926' 2940' - 2978' Tubi no~_l/2{s,z,~,, ~,~a_~) a~d 2r~7a~,u red depth) Packers and SSSV (type and measured depth) Cemented 272 SX 726 SX 300 SX Measured depth 23' 325' 3000' 2875' Cement shoe @ bottom of tubing True Vertical_ depth 325' 3000' 2875' 12.Attachments Description summary of proposal [] Detailed operations program [] Well sketch 13. Estimated date for commencing operation September, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~~,.~ ~ 7'~/H,C.o~/r-/~ Title Cook lnlet Engineering Manager Commission Use Only Date Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH FOrm 10-403 Rev 12-1-85 Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ,Approved Copy Returned Commissioner I Approval No. ~_ 7/~ by order of the commission Date ~-~,~- ~;~ Submit in triplicate~..~ RA Tracer Survey SRU 41-33WD Objective: To determine if SRU 41-33WD has injection integrity (ie: does not have injection into intervals above the perforations.) This condition must be met prior to returning this SI well to injection. Well Data: Completion: Minimum Restriction: 3-1/2" tubing to 2875' MD (Note: tubing is cemented into 5-1/2" production casing.) Well is suspected to have scale build-up which causes tubing restrictions. (ID was greater than 2.8" above 1829' and between 2.7" and 2.8" to PBTD 12-24-87). PBTD: 2888' MD (13' below tubing tail WLM; 6/88) Tubular Volume: Clean tubing = .3652 gal/ft; 2.8" ID = .3491 gal/ft (Note: in clean tubing injectant will travel 15.97 ft/min at a 200 B PD injection rate). Procedure- NOTE: Prior to performing this survey assure that the State has approved the associated sundry (contact Carol Baker, x4643) and notify the State and BLM 24 hours prior to test. In addition, the wellhead pack-offs need to be tested. 1) 2) 3) 4) 5) 6) 7) 8) Establish a stabilized injection rate into well with a 900 psi injection pressure. (Allow to stabilize for at least 24 hours.) Record injection rates and pressures during survey. Hold safety meeting to discuss possible hazards and safety procedures. RU conductor line and pressure test lubricator. RIH with GR/CCL/RA tracer (1 ejector with a sensor above and below ejector) with time drive. :~. Tie-in log ..... Log GR from PBTD up 200' and from PBTD to surface. Verify repeatability. Set-off RA tracer slug at surface (one second slug from tool). Immediately RIH to 300' going slowly (30 fpm) until tools have exited RA tracer slug. Record time when a large "hot" kick is detected (approximately 5 large chart divisions). ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A 9) 10) 12) 13) 14) If no 16) RIH to 1150', going slowly (30 fpm) until tools have exited RA tracer slug. Record time when the large "hot" kick is detected. RIH to 2000', going slowly (30 fpm) until tools have exited RA tracer slug. Record time when the large "hot" kick is detected. RIH to 2870', going slowly (30 fpm) until tools have exited RA tracer slug. Record time when the large "hot" kick is detected. Remain stationary at 2825'. Watch for a secondary arrival of RA tracer indicating communication behind pipe. (Wait for 25 minutes following the first response.) Place bottom detector at 2850' MD (25' over the tubing tail). Release an RA tracer slug from the tool. Time how long it takes to travel to the detector and calculate water velocity in the tubing.Again watch for secondary tracer returns indicating communication behind pipe. (Waiting 25 minutes following the first response.) If results from steps #8-11 indicate that fluid-loss is occurring within the tubing, set-off another RA tracer slug from surface and RIH to 2850' MD. Record the arrival time of the "hot" kick. Once RA tracer slugs have exited perforations, run a GR pass from PBTD to surface. Note any new "hot" spots. tubing leaks have been indicated skip to step #18. If results from steps #8-11 and # 14 indicated that a tubing leak exists in this well, determine which interval(s) may have a leak(s) from the data obtained in steps #8- 11 and #15. Using RA tracer slugs ejected from the logging tool, determine the velocity of injectant at different intervals within the leaking interval(s) to determine the leak location(s). (ie: If velocity at 300' (step 8) was greater than velocity down to 1150' (step 9), determine velocity at the point half way between (725') using RA tracer velocity shots. Repeat this procedure as needed to narrow-in on the leak location(s).) POOH. Send a sample of any solids found on the tool to a lab to determine the HCL solubility. ARCO AlaSka Inc. is a subsidiary of Atlantic Richfield Cornpany AR3B-6OO1-A .I D.V. · TOP ?.D. ;)000, TUBXIIC) NANGgR YIRST ~. SAd TOOTH CB IO~OI, lO ~ Hcx, g XX CJLS~O t 670,, ~Ug£ZgD k"x'r~ .XX) SAC~ '~T. 9..17-7X to 9-27-7.1 U~JABX~ TO SEAl..- .. 7-2 SRU 41- 33 W.D CASIN6 & TUBING DETAIL SECTION 33 T. 8N.,R.9W. STu~aJ) OX]. cx3m, J~ m, ~,x~ - E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Mastex Valves Wellhead ALASKA OIL AND GAS CONSERVATION COMMISSION STEVE COWPER, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHON E: (907) 279-1433 TET,ECOPY NO; (907)276-7542 May 20, 1988 ADMINISTRATIVE APPROVAL NO. AIO 13.1 Re: Relief from Rules 4 and 5 and amend Rule 6 of Area Injection Order (AIO) No. 13 to accommodate ~~S'on:River Uni~~ Wells 21-33 WD D. S. Joiner Engineering Manager Cook Inlet/New Ventures ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Joiner: ARCO Alaska, Inc. (ARCO), as operator of the Swanson River Field (SRF) by letter dated April 28, 1988 requested modification of AIO No. 13 rules to accommodate SRU wells 21-33 WD and 41-33 WD. These two Swanson River wells were recompleted in May 1972 and October 1971 (respectively) by cementing the tubing in place; therefore, casing pressure testing, monitoring, and reporting, as required by AIO' No. 13, can not be accomplished. ARCO has asked for administrative relief from the requirements of Rules 4 and 5 and approval' to use an alternative test method to accomplish the purposes of Rule 6. Swanson River Unit wells 21-33 WD and 41-33 WD had been recom- pleted by cementing the tubing in place and were operating as disposal wells approved by the EPA at the time the UIC Class II program in Alaska was taken over by the Alaska Oil and Gas Conservation Commission (AOGCC). Therefore, these wells are accepted "as is" by the AOGCC under "Rule 3 Fluid Injection Wells," item (3). As provided by Rule 9, "Administrative Relief" the operator is hereby relieved of the requirements to monitor and report tubing/casing annulus pressures under Rules 4 and 5 but must cOntinue to monitor and report tubing pressures and injection rates as required by 20 AAC 2.5~432~ Administrative Approval AIO No. 13 May 20, 1988 Page 2 ical integrity of an underground injection well. Therefore, as provided by "Rule 9 Administrative Relief", Rule 6 is amended to read: Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity the running of RTSs. Lonnie C. ~ 'Chairman Commi s s loner W. W. Barnwell .Commissioner BY ORDER OF THE COMMISSION dlf:3.AA AIO 13 TABLE I Wells under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future UtilitS 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12 -34 22-23WD 243-8 14-34 Wells SI for Inefficient Producti on 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 ~ 343_33''' ATTACHMENT E-I Injection Well Data Water Disposal ^vg. Wells Rate(BPD) Max. Rate(BPD) Avg. Press(psi) Max. Press(psi) Depth Inj.(ft.) Depth of Well(ft.) SRU 31-33W 327/$ /$500 769 1000 2100 2/$61 SRU 32-33w 651 /$500 778 1000 2100 2520 SRU 41-33W 125 . . /$500 913 1000 .2..8,82 3000 5RU 21-33W 2805 /$500 73`5 1000 2.1. 2_ ,0 3._8Q~ SCU 43-4W~¢ .... 4`500 Shut In 1000 3100 6660 Gas Injection Ave. Wells Rate(MCFD) Max. Rate(MCFD) SCU 31-/$-2 39,950 SCU 323-/$ 35,680 SCU 332-/$ 27,6/$0 ~~ 3¢1-/$ 37,6t40 341-8 30,300 U 31'2-9 /$/$, 000 SCU 321-9 29,9/$0 SCU 323-9~- ~ 3.5,920 SCU 3#3-33 0 SRU 332-1~ 0 SRU 312-22 0 SRU 31/$-27 0 SRU 331-2~ {g 0 , /$5000 5075 45000 5370 45000 5095 /$5000 5355 4`5000 5160 /$.5000 `5270 /$.5000 `515`5 45000 `5105 45000 Shut In /$`5000 Shut In /$5000 Shut In 45000 Shut In /$`5000 Shut In 6 7 `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/$ 11146 11520 1077`5 11119 10850 1081/$ 10785 107/$5 10750 1099`5 11982 11000 11/$3/$ 11620 ARCO Alaska, Inc. 110500 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.232 SWANSON RIVER FIELD - UNIT 051950 09- Sep-87 August 1987 Name of Operator Fi eld and Pool Month and Year of Injection II. WELL NO. I I I I 314-4 I 523-4 I 332-4 I 341-4 I 341-8 I 312-9 I 523-9 1343-33 :412-10 ; 521-9 :43-4WD ! 2. API NUMBERI3. Cf4. FIELD~5. DAYSI TUBING PRESSURE I CASING PRESSURE :DAILY AVERAGE INJECTION:TOTAL MONTHLY INJECTION 50- ~ LI & POOL I IN ~ : I : Ai CODE I OPER i&. MAXI7. AVERAGE:8. MAX PSIS ~ PSIS I SI l___SI I 772100 I 772100 I 7721.00 : 772100 I 772100 I 772100 : 772100 ~ 772100 I 772100 I 772100 I 772036 i PSIS I 30 :5,450 I 4,958 ~5,.500 0 ! 0 I 0 I 0 30 15,500 I 5,005 1'1,040 30 15,550 I 5,141 I2,860 0 : 0 I 0 I 0 30 15~350 I 4~945 11,240 0 I 0 I 0 I 0 0 I 0 I 0 I 0 30 15,450 I 4,991 II~9&O 0 I '0 I 0 I 0 I I I I I I I I I I I I I I I I I I I I I I I I I I : I I I I I : I I I I I I I I I ; I I I I I I I I 153-10104-00 133-10106-00 133-10107-00 133-10109-00 133-10120-00 133-10123-00 133-10126-00 153-101&8-00 IS 155-2020&-00 IS 153-10125-00 IS 153-10111-00 ID I I I I I I I I I I I I I I I I I I l : I I I AVERAGE:lO. L. IQUID 111. GAS PSIS I 2,359 I I 0 656 I I 2,376 I I 0 I 1~109 I I 2,368 1 0 I I 0 I I 1 ~815 I I 0 I 0 I I I I l I I I I I I I I I I I I I I I 13. LIQUID I' 14. GAS I ( MCF ) I I 5g,259 Ol 31,~32 57,120 OI 40,483 35,148 Ol Ol 25,706 ( BBL ) I (MCF) I I 1,177, l&5 6' -) 948, 1,113~609 I 1,214,475 I I, 054,428 I I 0 1 I I 0 1 0 1 771 ~182 I : I I I I I : I I ! I ' I I : I ; I II hereby certify that the foregoing is true and correct to the best o~ my I.'no~ledge I ~ Signed ~, ~ ITikle Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I15. I' TOTAL I I 0 I &,27~,814 Submit in Duplicate ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTIONREPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 SWANSON RIVER FIELD - UNIT 051994 August 1987 Name o{ Operator Field and Pool Month and Year of Injection :1. WELL:2. API NUMBER:5. CI4. FIELD~5. DAYSI TUBING PRESSURE ~ CASING PRESSURE :DAILY AVERAGE INJECTION:TOTAL MONTHLY INJECTION : NO. : 50- : L~ & POOL : IN ~ ~ : I : I A~ CODE : OPER :&. MAX:7. AVERAGE:8. MAX 9. AVERAGE:lO. LIOUID 111. GAS 15. LIQUID I 14. GAS 1512-22 1135-10147-00 IG 1514-27 1133-10154-00 1551-27 1135-1015&-00 IG 1452-15 1135-10141-00 121,55WD'I155-101&2-O0 ID 131-33WD :52-55WD 141-35WD I I I | I I I I I I I I I I I I I I 772100 772100 772100 772100 77205& 77205& 77205& 77205& I PSIG I PSIG I I - I I - ~ I I - I I - i : 29 i 875 : 754 I 29 I 820 i 74& 50 I 875 I 759 50 I 850 i 751 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 l I I I I I I I I I I I I I I I I I I I (BBL) 2,675 2,770 2,071 145 II hereby certi{y that the foregoing is true and correct to the best of my knowledge I I S i gned I I I ITitle I Form 10-405 Rev. 12-1-85 Date ~ /~ ~-'~ 7 INSTRUCTIONS ON REVERSE SIDE |15. I I I I I I ITOTAL I I ! I ! . I (BBL) I (MCF) I I 77,581 80,518 62,119 4,352 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 224, .570 I I I I I I I I I 0 1 I Submit in Duplicate I I PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUOHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY UNIT S-ll UNIT S-14 UNIT T-1 UNIT T-7 UNIT U-3 UNIT U-h UNIT U-5 UNIT U-9 UNIT U-lO UNIT X-6 UNIT X-ll UNIT X-23 UNIT X-24 bNIT X-26 UNIT Y-3 UNIT Y-5 UNIT Y-6 UNIT Y-7 UNIT Y-11RD PRUDHOE BAY UNIT Y-18 UNIT OR LEASE TOTAL POOL TOTAL FI ELD TOTAL SWANSON RIVER, HEMLOCK OIL POOL ARCO ALASKA lNG SOLDOTNA CK UNIT 314-4 SOLDOTNA CK UNIT 323-4 SOLDOTNA CK UNIT 332-4 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 309,53~ 26~,425 174,467 380,162 602,357 515,072 264,751 183,322 244,173 294,661 149,980 173,54~ 262,057 282,344 76,~92 49,131 84,323 22,223 43,679 306,429 14,519,526 39,536,156 84,445,002 39,536,156 88,810,140 SOLDOTNA CREEK UNIT SHUT-IN SHUT-IN 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 1,148,650 31 1,080,598 31 871,402 31 1,090,670 31 153,799 6 1,246,967 30 749,378 31 1,089,518 31 7,430,982 6:975:040 7,115,160 1,241,472 2,275,741 2,727,957 2,791,476 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 2,653,403 102,640 597,32.1 6,4O9,296 1,388,876 294,742,9'15 233,327,280 207,759,340 231,764,932 218,694,6~7 304,0~4,302 33,033,8~2 170,911,513 111,413,676 - - ENHANCED RECOVERY - - WELL NAME AND NUMBER ARCO ALASKA lNG SWANSON RIV UNIT 331-27 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL TRADING BAY, MICDLE KENAI C OIL POOL UNION OIL CO CF CALIFORNIA ADL-18731 TRADING BAY ST. A-SRD-2 TRADING BAY ST A-12RD TRADING BAY ST A-26 TRADING BAY ST A-29 UNIT OR LEASE TOTAL POOL TOTAL TRADING BAY, MICDLE KENAI O OIL POOL UNION 0IL CO OF CALIFORNIA ADL-18731 TRADING BAY ST A-SRD-2 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 SWANSON RIVER UNIT SHUT-IN SHUT. IN-"'~. SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN 7,430,982 7,430,982 CUM. OIL CUM. WATER ~13,934 15,582,616 4,~98,822 6,267,061 7,348,68b 21,618,136 CUM. GAS 28,263,659 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 1105A0 Name of Operator SWANSON RIVER FIELD - UNIT 051~4 Fi eld and Pool December 1986 Month and Year of Injection I 1. WELL NO. I : I I 1512-22 -J 514-27 i 4:52-15 1 I I I I I I I I I I I · I I 2. API NUMBERIS. Cf4. FIELDI5. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION 50- I LI & POOL I IN I I I I I Al CODE I OF'ER I&. MAXIT. AVERAGEI8. MAXI~. AVERAGEIIO. LIQUID Ill. GAS I 1~. LIQUID I 14. GAS I SI l___SI 15~-10147-00 I G I 772'100 155-10154-00 I G I 772100 15~-1015~-00 I G I 772100 1~5-10141-00 I G I 772100 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I i I I I I I I I I I' I I I I I I I 'I I I I I I I I I I I I I I I I I I I I I I I I I I I .... I ......... I PSIG I PSIG I PSIG I PSIG I (BBL) I (MCF) I (BBL) I ...... I I ...... I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I · I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I~. ~-~-.,.-~,~ I-.- I I I I I I I'""'~'"-'--.. I I I I I I I I I I I I I I I ~5 .~,' I (MCF) I II hereby ¢ertif)6 that the ~or~ego~ing I Si gned _ I is true and correct to the best of my knowledge I I ITi~le SupIrvi~m~ New Ventures Compliance and revenue Form 10-405 Rev. 12-1-85 Date __~'~__~_~_ ....... INSTRUCTIONS ON REVERSE SIDE I15. I : Alaska Oil & Gas I I I I I I I I I I ITOTAL I 0 I 0 I I I Submit in Duplicate ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 2O AAC 25.252 ARCO Alaska, Inc. 1105C)0 Name of Operator SWANSON RIVER FIELD - UNIT 051950 Fi eld and Pool December 198& Month and Year of Injection :1. WELL~2. API NUMBERIS. Ct4. FIELD:5. DAYS~ TUBING PRESSURE I NO. 50- ~ L~ & POOL I- I A~ CODE I : SI 514-4 155-10104-00 523-4 155-10106-00 552-4 155-10107-00 · :...-t_.)541-4 155-10109-00 ~'*~ 541-8 I 512-9 : 525-9 1412-10 : 521-9 I i___SI I 7721¢)0 I 50 15,500 I 5,015 12,500 I 1,56¢) I 772100 I 772100 I 50 I5,500 I 5,071 I 700 ; 594 I 772100 I 50 15,550 I 5,157 I1,200 I 849 155-10120-00 IG I 772100 I 50 15,500 I 4~882 11,400 I 1,54S 155-10123-00 IG I 772100 I 50 15,000 I 4,6~7 12,850 I 1,267 135-10126-00 IG I 772100 I 17 15,200 I 5~140 11,600 I 1,585 135-10168-00 IG I 772100 I 0 I 0 I 0 I 0 I 0 155-20206-00 IG I 772100 I 0 I 0 I 0 I 0 I 0 155-10125-00 IG I 772100 I 50 15,540 I 5,150 11,600 I 1,0G9 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ' I I I ,I hereby ce, tify that the ~or.~ng is true and c~rrec, to the best of my kno, ledge sien% ........ - ..................- . ~uper~or~ Ne~ Ventures C~mplian~e and Revenue a ITitle D e ...... FOrm 10-40~ ~ev. i2-1-8~ INSTRUCTIONS ON ~EVE~SE SIDE I I I I 52,501 I I 975,018 I 29,526 I I 885,785 I 24,058 I I 721,15~ I 2~,951 I I 898,524 I 25,121 I I 695,&26 55,165 I I 1,054,878 25,550 I I 450,602 0 I I 0 OI I OI 20,970 I I 115. TOTAL I I I I I I I I I I I I I I I I I I I I I I I I I -- i ~,V' "'I' I I I I :-' "$ -- ~ 13t l ' I I I' I I I- I 1 I I I 0 I ~2~55 I I Submit in Duplicate LEASE NO. IENHANCED RECOVERYI COMP.DATE + ........ STATUR PRODUCT JAN FER MAR APR MAY ~~ SHANSON RIVER, HEMLOCK ARCO ALASKA INC $OLBOTNA CK UNTT ~1~-~ APT UNIT051950 ALASKA INDIVIDUAL HELL%0DUCTION FOR 1986 JUN JUL AU~ SEP OCT NOV DFC YEAR TnTAL CUM. 08/15/60 HTR ' 1GINJ GAS 1055857 1026590 1189909 1165806 1228666 1211657 1257286 1288552 1505704 1125075 1022955 975018 15808655 291785565 $OLDOTNA CK UNIT 525-4 APT UNIT051950 OIL 0'6/01/61 HTR " GINJ GAS 926806 895795 1014689 1021515 1095847 1095954 1110742 1160265 1165222 986857 950909 885785 125059~2 250168775 SOl~OTNA CK UNTT ~3~-4 APT ]~-]~lfl7-fl0 UNIT051950 0IL ) 06/05/60 glR 1OlNJ GAS 729520 694699 694'207 768554 848986 808659 855755 906429 908925 775879 755068 721155 9465572 20555682~ ~D[D~TNA CK UNTT . 34]-4 APT UNIT051950 0IL 03/21/60 HTR 1GINJ OAS 966182 959897 1105510 1006702 1191650 11256531151896 1167267 1142665 989567 1047597 898524 12728666 228845715 UNIT051950 0IL 07/14/61 HTR 1GINJ GAS 772050 721011 855765 795562 858795 851801 877666 885~19 861456 802085 790782 695626 9761772 21711626~ $OI~OTNA CK UNTT 312-g ,API UNIT051950 0IL 10/09/60 HTR 1GINJ GAS 1150860 1105266 1275468 1219~54 1266462 1242821 1268188 1518592 1512222 1120~15 1159677 1056878 ~0IDOTNA CK UNIT ]P]-g API UNIT051950 0IL 07/19/61 HTR ' 1GINJ GAS 787999 770786 961516 857121 859651 824009 859796 852454 865441 701058 657886 629091 9546566 51111755 SOL~OTNA CK UNIT ]~]-9 AP~ UNIT051950 0IL 07/17/61 HTR ° 1GINJ GAS 868162 887705 1057606 1002092 1041454 1027008 1054326 1105468 1110180 1002927 967125 450602 11552455 168145955 SOLDOTNA CE UNIT ql~-10 API APl API 153-10161-00 111415676 6018206 9029539 2056925 6645550 UNIT051950 OIL 06/11/72 HTR ° 1HINJ GAS SOLDOTNA CK UNIT UNIT051950 OIL 05/08/61 HTR ' 1GINJ GAS -= SNANSON RIV UNIT UNIT051994 0IL 10/24/59 HTR ' 1GINJ GAS SHANSON RIV UNIT UNIT051994 OIL 08/06/61 HTR 1GINJ GAS 4~2-]5 54-15 API 133-10142-00 III 4 ~ LEASE NO. IENHANCED RECOVERYI COMP.DATE ~ --~ STATUS PRODUCT JAN FEB ' AR ~~ SHANSON RIVER, HEMLOCK SHANSON RIV UNIT 312-22 API UNI~TO51g94 OTL ALASKA INDIVIDUAL HELL~ODUCTION FOR 1986 YEAR APR MAY JUN JUL AUO SEP OCT NOV DFC TOTAL CUM. i33-ioi47-oo d 08/11/62 HTR 873988 1GINJ GAS 2~017269 SWANSON RIV UNIT 514-27 API i~$-i0154-00 UNITOSlgg4 O~I 06/14/60 HTR 1GINJ GAS 78332178 SHANSON RIV UNIT 551-27 API 155-10156-00 UNITO5199~ OIL o2/17/5~ HTR ~ 1GINJ GAS 28265, - ARCO ALASKA TNC OPERATOR OIL TOTALS HATER 8,337,995 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 8,113,868 8,369,6~9 8,393,~51 8,667,789 7,311,775 95,601,663 POOL TOTALS OIL HATER SWANSON RIVER. HEMLOCK 8,357,995 GAS 7,041,527 7,852,406 8,187,302 8,680,226 7,~99,819 6,288,655 1,929,187,012 7,215,396 8,113,868 8,369,~9 8,593,~51 8,667,789 7,311,775 95,601,665 FIELD SWANSON RIVER TOTALS OIL HATER 8,557,995 GAS 7,0ql,527 7,852,406 8,187,502 8,680,226 7,~99,819 6,288,655 1,929,187,0 7,215,596 8,113,868 8,$69,~9 8,393,~51 8,667,789 7,311,775 93,601,665 : SWANSON RIVER WELL ~t i~__ SRU 312-22 --~ 8~ --SRU 314-27 51 ~/Sf <~_ SRU 331-27 ) S~CU 323-4 .iSCU 332-4 ~ SCU 341-4 ~ SCU 341-8 :SCU 312-9 ~ SCU 321-9 ~ SCU 323-9 5~ /~/~ -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-in Injecting Injecting Injecting Shut-in Injecting Injecting Injecting Shut-in GRU13/2c RECEIVED FEB2 "' .... Alaska Oil & Gas Con~,. Commissiom Anchorage STATE OF ALASKA AL. ,KA OIL AND GAS CONSERVATION C~ ..,MISSION APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator ARCO Alaska, Inc. 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 5. Datum elevation (DF or KB) 3. Address Post Office Box 100360 4. Location of well at surface Sec. 33, T8N, Rgw, S.B.&M At top of productive interval At effective depth At total depth Anchorage, AK 99510 ';11. Present well condition summary See attached sbhematics Total depth: measured feet true vertical feet 6. Unit or Property name Swanson River Unit 7. Well number SRU 21-33WD, SRU 41-33WD 8. Permit number 9. APInumber 133-10162-00, 50-- 1~3-10167-00 10. POOl Sterling Plugs (measured) feet Effective depth: measured feet true vertical feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth RECEIVE.l) Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) NOV 1 Naska 011 & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal [] Detailed operations program ~ WaiSt 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 .z~/~~;:2, ~ Title Manager, Cook Inlet Engineering Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI -'7 ~ Approved Copy Approved by Returned .~ // Commissioner Form 10-403 Rev 12-1-85 by order of the commission Date /',/I q/~,~'~. Submit in triplicat~ 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. $RU 41-33WD pressure Test Production Casing Via Tubing PROCEDURE NOTE: 48 hours prior to h~itiating pressure testing procedure, contact the A~ at 279-1433 and ~ BLM at 267-1240, and inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. 1. RU slicidine unit. lYF lubricntor to 2000 psi. RIH with gauge ring and tag bottom. 2. RIH with *DD" bridge plug and set in joint nbove the casing shoe at 2875'. e Install a pen recorder to monitor the tubing during the test. Pressure tubing to 1500 psi. Hold for 30 minutes, noting initial and final pressures on robing. If the pressure bleeds off then reset the plug in another tbg joint to verify ff it holds. Retest. 4. PC)OH with "DD" bridge plug. If pressure test was successful then return to injection. NOV 1 g Oil & Gas Cons. commission Anchorage ARCO Alaska inc. is a sut~idimy M P~c Riclfmlcl Coney AR3B-6OO1-A 20" CBt · buh'~ t IL tilt II I~ ~ -- TUBDIO HANG~It o. Z911.41' " .. #CLE: XN CASZNG · 670', SQUEEZED b*XTH .300 SA(ZS '~T. ~XT-7X to 9-27-7.~. UtIABL~ TO SEAL. -. . ,! D.V. · '"'"" . RECEIVED · · NOV 1 9 1987 I · l lieS* Alaska Oil & Gas Cons. Commission Anchorage 'tOP OF PLUG ClflqgHTF, D ~ N..60 · 2875t T.D. .., 7-~1--~? ~n~..,E' SRU ,41 ~;~$ W.] CASING Ell TUBING OET/~ SECTION $$ T. SN.,R. gW. S ARCO Alaska, Inc. Post Office Box 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 RECEIVEI) SEP o 9 ! Naska 011 & Gas gons. Commlsobll Anohorago REPLY TO ATTN OF: ~/S 409 U.S, _NVIRONMENTAL PROTECTION A(:,_,,~CY REGION 10 - 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 MAR,.. a 'l~86 O. L. Weaver Area Operations Superintendent Chevron U.S.A., ;[nc. P.O. Box 107839 Anchorage, Alaska 99510 ~]ES ENG SR ENG 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 conv~enience. Sincerely, / / cc:~C.V. Chatterton, AOGCC Joe Dygas, BLM irector, Water Division MAR 0 7 19BG STATE OF AtASKA OIL AND GAS CONSERVATION COMMITTEE . WE,, TYPE OF WELL: oH, ~ ~*s "'F~ WELl. ~ WELL ~ DRY ~ Other _~a~ TYPE OF CO~Ptm~O~: Disposal W~:LL ~ Ov~ ~ ~X niCK ~Svm Other 2. NAME OF OPERATOR Chevron U.S.A. Inc. 3. ADDRES,~ OF OPERATOR P. O. Box 7-839, Anchorage, AK 99510 4, LOC~.'rmX o~' WELL (Report location clearly and in accordance with a~y 8tate requirementa)* Ki:L /Vt0 Sec. 33 At te~ ~rod. !ntervM repot.ed ~elow at total depth Same 50-133-~"~ii~901 2 I:N~ '~ A-028399 Swanson Riw~~T~f~ I STAT TEC 10, FIE~ ~ND POOL, T Swanson Riv~. ~. 11. SEC,, T., R., 5I., (Bi[~qTM ~a~r ~ i ~ O~Em'IVE) Sec. 33~ TSN~ RgW SBaM 12. PEI~d~IIT NO, Same I ' 1~ , 2¥~ & TVD~9. ~ , · ..... ~, ~ MULT~LE CO~L., [ 21. INTERYALS DItlI,~,E9 BY 3000'MD 3000'T~ 2990'MD 2990'TVD PRODUCING !N~RVAL(S), OF ~.IS COMP~TION--TOP, BO~OM, NAME (MD AND ~)- ~23~ WAS D!I{ECT1ON~L , SUHVEY MADE Top 2882'MD 2882'T~ Bottom 2978'~ 2978'T~ No 24. TYPE ELECTRIC AND OTHEq{ LOGS RUN ,1111~..5' i -- , · CASING RECORD (Report all strings set in well) .. 13-3/811 [ 54.5~ [ ] 325I. 117-1/2" l.,~276.qk._q ........ ] ......... ~n-n~_ I 1 000 ! 8-q3/4,, lshoe w/300sksCPZZ6,9' w/42fsks None '" 3-1~2; I 9.3# ' [ I 2857" [,, ,,[ 160sks,, .... ] ..... None 26. "" LINER R~COP~D '" " I 27. TUBING RECOHJ3 28[ PE/iFORATiONS OPEN TO PRODUCTION (interval size and number) 2,3. ACID Si:CT IYi{~I.C'tURn' CE...IENT SQ'Jr":'Z'''' ETC I" 2882-2926' Ten 1/2" Jet Holes 2940-2978 Pe>r Foot , i, i 30. DATE FII~ST PI~.ODUCTION 6-25-80 DATE OF T'~ST, 6-25-80 nouns ~nSTra~ lct*ox~ sizr~ P~.On':~ FO-~ [ - - ITEST PEit!OD ,24 I /~' CAS[;~G PRESSURE ICAi,C~TD OI~EBL. ~s (8o~d, u~ed ~or ~ue~, vented, etc.) FLO~V, TUDING all ,p,~i PISPO~ITION OF DEPIli 1NTEI-IVAL (MD) 2882-2987' P~OD UCTION PI%eDUCTION MEIHOD (Flowh~g, ga3 lif~, p~mping--size and type of pump~ In. jecting. Waste Water OIL--EP.L. GAS--AICF. I GAS--?JCF. 1 32,LIST OF ATTACHMENTS iiA?,iOUN£ AND I.Z!ND OF I¥1A'IE?,IAL USF_.D 10000 Galst 12% HCL 3% HF , · {V, ELL S'['ATUS ~ Producing or Injecting W£,'i'EI'~--BBL. [ G~kS-OIL [l.%.'I'lO 9697 i WATEP.--EBL. [ OIL GRAVITY-A/':'1 (CORR.) 969? I _ tTE~T WITNESSW-D BY 3.2. I hereby certify that the foregoit~,and attached information is complete and' correct as determtne'd from all-~vail,~}de records ..... 7, / 7/~l/YCt , , *(See InstructiOns and Spaces for Additional Data on Reverse Side) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Conservation Division Alaska Region 800 "A" Street, Suite 201 Anchorage, Alaska 99501 June 18, 1980 Mr. C.F. Kirkvold Chevron U.S.A., Inc. P.O. Box 7-839 Anchorage, Alaska 99510 Re: Request for a permit to dispose produced water in SRU #34-28, Swanson River Pooling Unit, Alaska Gentlemen: The subject request for permit to dispose produced water down the 11 3/4-7" annulus and out the shoe of the 11 3/4" casing at 2038' in SRU #34-28 is hereby approved for a period of 15 days from June 16 through June 30, 1980. In the event use of this well is desired for water dispoSal after June 30, 1980, an application under NTL-2B will have to be submitted and approval obtained. Based on past experience with wells #41-33 and~we are no longer in favor of disposing salt water down th~'~s of any producing oil or gas well. We prefer to have a separate disposal well cased into the receiving formation with the water injected through tubing set in a packer located just above the casing shoe (for open hole completion) or perforations.*' . Sincerely, Harold ,7. Hedlu~d Acting Deputy Conservation Manager for Onshore Minerals. June i9, '1980 Mr. C. F. Kirkvold Area Operations Supe~tntenden CheVron U, S.A. inc. P. O, Box 7-839 Anchorage, .Alaska 99510 equest--Swanson Slyer leld, ,i-3 Ugand 3,. 2s. Dear Hr. KirkvOld~ ~olosed are approved ~opies of the Sundry Notices you s~itted on Ju~e 1.6, 1980 to Mr. Harry Kugler. You will notice the approvals apply only to the physical mechanics' to protect %he fre.~ water Sources and/or the safe o~I producing capability of each well. Approval-.for disposal, o~ injection Of fluids into any zone .other than ua hydrocarbon bearing' formation' must be obtained from either US ~eoloqtcal Survey and/or US Environ~ental Protec- tion Agency or Alaska Department of .Environmental Conservation. From-the' hist~ry of tubular failures due to corrosion associated with your disposal systems we have concluded that~ 1: The use of any oil or gas well for long term annular injection/disposal, should be discontinued. . 2. -Disposal 'we-lis should be properly designed and upgraded or replaced so .as to provide protection of fresh water s~ces and allow normal monitoring of casing intergritY. 3. Failed uasin~, in wells such as SRU 41-33 and 41-33WI should be repaired or repla~ed prior to further production operations in those we118. CommissiOner Enclosure Form 10-403 REV. 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.) 5. APl NUMERICAL CODE 50-133-1066-00 6. LEASE DESIGNATION AND SERIAL NO. 028399 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1.WELLL...jOIL r'-] WELLGAS D OTHER Waste Water. Disposal 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME CHEVRON U.S.A. INC. SWANSON RIVER UNIT 9. WELL NO. 3. ADDRESS OF OPERATOR P. O. BOX 7-839, ANCHORAGE, ALASKA 99510 4. LOCATION OF WELL At su ~ace 1320' W '/y along N. line and 960' S'/y. at right angle from N.E. Corner of Sec. 33 T8N, R9W. ' 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 179' K.B. CheCk Appropriate Box To Indicate Nature of Notice, Re 14. ~RU 41-33 W.I. 10. FIELD AND POOL, OR WILDCAT / SWANSON RIVER 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) SEC. 33, T8N, R9W 12. PERMIT NO. 27 )ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertinent details, and give pertinent dates, including estimated date of starting any proposed work. 1. Move in snubbing unit with 10,000 psi B.O.P.E. and 3,000 psi stripper. 2. Clean out to 2990' effective depth. 3. Reperforate 5~" casing with four ½" holes per foot from 2978-2940' and 2926-2882'. 4. Inject 10,000 gallons of 12-3 HCL-HF acid through perforations 2978-2940' and 2926-2882 ' 5. Return well to produced waste water disposal. ~s~s~ o= ~ ~3~o~ ~ hy~~ ~~ ~o~o~(s) ....... "20~C 25.250 ~ge 22) AJaska 16. I hereby certify that the foregoing is true and correct (This space for State offil~e use) ~ ~ IFA /~'~"~"~'~-'..~a, TITLE CONDITIONS OF APPROVAL, ~e Instructions On Reveme Side DATE DATE Approved i~etur,3ed Dec. 1973 U~,~ED STATES ¥ DEPARTML..; 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 Form 9-331--C for such proposals.) 1. oil gas well ]--] well other Waste Water Disposal 2. NAME OF OPERATOR CHEVRON U.S.A. INC. 3. ADDRESS OF OPERATOR P. O. BOX 7-839, ANCHORAGE, ALASKA 99510 4. LOCATION OF wELL (REPORT LOCATION CLEARLY. See space 17 below.)1320W'/y along N.Line & 960 S'_/y at R.A. AT SURFACE: ]~rom N.E. corner. Sec. AT TOP PROD. INTERVAL: Same AT TOTAL DEPTH: Same 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA REQUEST FOR APPROVAL.TO: SUBSEQUENT' REPORT OF: 12-1 TEST WATER SHUT-OFF [] [] FRACTURE TREAT' [] [] SHOOT OR ACIDIZE [] [] REPAIR WELL [] [] PULL OR ALTER CASING [] [] MULTIPLE COMPLETE l'-'J [] CHANGE ZONES [] [] ABANDON* [] J--J' (other) . . .~,,. :. :; ~ 028399' - .-": INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT,NAME :, SWANSON ~I'v'E~ UNiT 8. FARM OR LEASE NAME SWANSON -R IJN~T --.o_, 9. WELL NO. .,:' lc-~ ~ . ._ C' -:- --' SRU 41-33:W:~. 10. FIELD OR Wii'DCAT NAME- --; ': SWANSON -~ . - ~ 11. SEC., T., R., '.M:, OR BLK. AND sURVEY OR AREA :- = ~ E' :: ."' : ~ SEC. 33 -~8N',-%R9WI''I '"" --: ~2. COUNTY OR PARiSHI 13. STATE~. '- KENAI ~_: :~:: '-'-I ~' ALASKa' 3-71 :; ;. i, - ~.-c, '- . o ~RECEIVED '~' ~" - L. (NOTE: Repo~ results '~f mulNple~plet~on'or zone cONSt~V~]ION DiVlS~ONsu~Vt~ ~ U. ~..GEOLOGICAL A~0RAGE~_ A~SKA r ,. 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and.zones pertinent to this work.)* , 1. Move in snubbing unit with 10000 psi B.0.P.E. and' 300:O~t~s:: st~ipp.er..= · r, =. ;%.~ .,.~ · 2 Clean out to 2990' effective depth. "': ,":,--": ':":" ' · · 3. Reperforate 5½" casing with four;~½" holes per foot t~-r~d~ ,2~..78-294'0~.. :land 2926-2882 ' * :' ': :=" " .';-; L- ' .- F....: -. -. _-- . 4. 'Inject 10,000 gallons of 12-3 HCL-HF acid through p~"rf~r'ations 2978-2940' "' :' :" :"' :" ' and 2926-2882' .~< y-r :.': : -. 5. Return well to produced waste water disposal. /~2T£tq~',~z. oF /,c/J-~ T/O,~ /~u 7/-//--~ ~)E.,~L., ":.'_: .. : ... Ft. Subsurface Safety Valve: Manu. and Type ~'. E:- - : :. ,.= : :- ' ..- 18. I hereby certify that the foregoing is true and correct : :. ~, ?: _ ,. c'.. _. ',' SIGNED ' ~(~.~ILE Area Engineer -'..:~ d.: :~ ; ~ ~ ~"' : , ,- ,/~/?, / ~ '_ (Thi& so~~' ' ~deral or State office use) : ; - ' t " - :' i~ ' APPROVED BY/I~~/ '/~~/ /%[. ~ILL _ ' __ oAlk. - '_ . ~.t CONDITIONS OF APPROVA~IF ANY: - vAtion Manager, for Onshore Mznerais .- ,-. ~, '. _ 'See Inst~ctlons on Reverse Side '~ 20" Cig4 · i i mi i i , ~ I - ' i ,, i % . I I J _ FT.~I' JT. SA~ TOOTH ON BOI'TGM~ NO COLLk~ , ,_HO~g IN CASING ~ 670~, SQUREZgD WI1TI 300 SACKS C~N?. 9-17-7! to 9-27-71 UNABL8 TO SEAL. ,I 1160t W I · BIOS' gUNKs 21s OF PAIRED FORMED WIRE FROH 3TRIP JET, DEP?it UNKNC~I · TOP OF P~O ti 2YYo, · SRU 41 '-- 33 W.D CASING & TUBING DETAIL. SECTION 33 T. SN.,R. gW. SM STANDARD OIL COMPANY OF CALIFOKNIA · ~or,m F--3 IKIL~.,. 9--30~117 .~'~,_ STA~2 ~..: ALASKA ~umn'~t "lntentfo:~x" in 'l~il~icate & "S'u[Jsequcnt i~cport$" ul Duplicate OIL,' AND GAS CONSERVATION COMMITI'EE SUNDRY NOTICES AND REPORTS ON WELL~ (Do not use this forra for proposals to dii!l or to deepen or plug back to a diffieren[ re~ Use "APPI.iCATION FOIL PEP. SII'I'--" for sucll proposals,) 1, OIL [J GAS ~ WELL wz~,~ L~ OT~a Water Disposal 2. NA..ME OF OPF, I%ATOR o,.a~.d~.~.d 011 Co. of Ca.!if_~o.r..nia~ !..."0I ~; ADDP~ESS OF'OPERATO~ P. 0. Box 7-a39 4. IX)CATION OF WELL At surface -.~ ,,.- f ~,o© sou~h and 1320' west of the [C~ Corner, Sec. 33, ~-8-N, R-9-W, SBaM 13. ELEVATIONS (Show who!her DF, RT, GR, etc. 179' KB 14. 5."''Ari N,.,I~LE/1/fJAL CODE LEASE DESIGNATION A~ND S}ltlIA. L NO. SWAHSON RI~R UNIT 028399 7. 1F 1NDI~, ~LO'iWEE OR TRIBE N~ 8. UNI2~ F~ OR L[~SE NAME Swanson Eiver Unit 9. W~L W! 41-33 10. FIE~ ~D POOL, OR Swanson River 11, SEC., T., II., M., (BOTTOM O~E~IVE) Ig. PElleT ~O. Check Appropriate Box To Indicate Nature of NOtice, Re ~ort, or Other Data NOTICE OF INTI~NTION TO': TEST WATER BHUT-0FF I~- PULL OR ALTER CASING FRACTURE TREAT i~__j M UL/IPL: COMPLETE ~_~ ~et~y~ine ~n~tipn of_ casing [IUBSEQUENT REPORT OF: WATER SltUT-OFF [['__ REPAIRING WELL FRACTURE TREATMENT ~-- ALTERING SHOOTING OR ACIDIZING ABANDONMENT* (Other) NOTE :.Report results of multiple completion on Well ompletlon or Reeompletlon ,Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including e~timated date of Btarttug any proposed work. Determine condition of casing and repair as necessary. WOPX PERFOP~D: (August 30 - October 7, 197i) Completion Report attached. 1. Pulled tubing and circulated hole Clean. 2. Pressure tested casing, and found holes at 670'. 3. Squeeze - cemented holes in 5-1/2" at 670'. 4. Cemented 3~,' inner liner at 2857'. 5. Reperforated with 2 holes per foot intervals 2882-2926' and 2940-2978'. 6. Returned well to service. DISTRICT SUPERI~fENDENT TITLE DATE NOV. ~'w'i~9 71 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF A1~f: TITLE · See Instructions On Reverse Side DATE ., DIVISION' OF ©iL AND GAS ANCI4ORAG~ WELL SCU WI41-33 REMEDIAL WORK SUbEVlARY August 30 to October 7, 1971 PURPOSE OF WORK: Determine condition of casing and repair as necessary. WORK PEP~ORMED: Squeeze-cemented holes in 5-1/2" casing at 670'. Cemented 3-1/2" N-80 liner at 2,857'. Reperforated 2,882-2,926' and 2,940-2,978' with 2, 2-1/3" capsule jet holes per foot. PRESENT CO~ITIONS: Casing: 20" conductor cemented at 23' 13-3/8" 54.5~ J-55 cemented at 325' 5~" 17fFf & 20~N c~nented at 3005' 34" N-80 liner cemented at 2857' Junk: 21' of paired, formed wire from strip jets. Depth unknown. August 30, _197_1 Move in equipment and rig up to pull tubing. .Augupt_ j3,.1. ~..i 97 i Pulled tubing - swabbing hole.. Recovered 30 joints; left 18 in hole. September 1, 1971 Unable to run overshot. Shut down and wait for power swivel, September 2-6, ,September. 7-9, 19_71 Rig up power swivel and related equipment. Ran 4-3/4" bit and cleaned out to top of fish at 937'. September 10 & 11.,~. 1971 -Ran overshot with 3-1/16" grapple and washed over fish to 943'. Pulled out without fish. Ran overshot with 2-19/32" grapple and worked over fish. Pulled out and recovered 10 singles. Made~cleanout run with 4-3/4" bit to 1248'. .September 12-14.~ 1971 Ran overshot with 2-19/32" basket grapple, unable to engage fish. Ran Bowen 3-15/16" overshot. Washed. over fish. Pulled out without fish. Laid down wash pipe. Ran overshot with 3-1/16" spiral grapple. Engaged fish. Pulled out and laid down 8 singles, all of fish. Ran 4-3/4" bit. Hit bridges and cleaned out to 1902'. WELL SCU WI41-33 REb[EDIAL WORK SUMMARY S~tember-15_ ~& 16, 1971 - 2 - Ran Baker squeeze packer to test casing. Located .holes in casing at 670'. Set packer at 1714' and p~ped below at 800 psig. Surface ~ressure dropped to 450 psig 5 minutes after shut-in. Tagged bottom. Pulled up and set Baker squeeze packer at ].890'. Pumped below packer at 1000 psig, surface pressure · dropped to 450 psig 5 minutes after shut-in. Ran wire line 1-7/8" sinker bar to top of fill at 2551'. Se:-~tembe_r 17_ 1971 Ran Baker bridge plug and Baker squeeze packer. Set bridge plug at 714', pulled up and set packer at 678'. Pressure tested casing between packer and plug OK at 1400 psig. Dumped 2 sacks of sand down tubing. Pulled packer loose and reset at 560'. Squeezed diesel-bentonite slug as follows; 15ft3 diesel ahead, slug mixed 7ft3 diesel with 30 sacks of bentonite followed by 27ft3 diesel. Ran 4-3/4" bit and cleaned out to top of sand at 705'. Ran Baker cementing packer and set at 560!. Squeezed cement as follows: 15ft3 water ahead, 50 sacks of cement mixed with 35ft3 of water~ and 27ft3 of water behind. Se~.mb~r I9~ 1971 Ran 4-3/4" bit and cleaned out cement 629' to 672' dropped through to 68~'. Pressured up casing, hole at 670' leaked. Ran Baker squeeze packer and set at 560'. Pumped mixture 8 sacks~bentonite and 2-1/2 xacks of LCM mixed with~ 75ft3 water followed by 50 sacks of cement mixed with 35ft3 water. September 20,.,1971 Ran 4-3/4" bit and cleaned out cement from 636' to 687', no cement 677' to 687'. Pressured up casing, holes at 670' leaked. September 21, ..1..97! Ran Baker squeeze packer and set at 560'. Mixed 8 sacks of Bentonite and 2 sacks of LCMwith water and pumped down tubing. Mixed 7 sacks of Bentonite and 5-1/2 sacks of LCM and pumped down tubing. Mixed~5 sacks of Bentonite and 6 sacks of LCM and pumped down tubing. Mixed 50 sacks of cement with 35 f~ water and displaced with 28f~ water. September. 22, 1971 · Released Baker squeeze tool and pulled out. Ran 4-3/4" bit and cleaned out cement 618' to 672' and circulated to 687'. Pressured casing to 700 psig, shut in pressure dropped to 200 ps%g. Ran Baker'squeeze tool and set at 560'. Mixed 50 sacks of cement with 35f~ water (water mixed with 3½ sacks of Cacl2), displaced with 35ft3 water. After 2 hours, pressured tubing to 1,400 psig, held OK. · WELL SCU WI41-33 REMEDIAL WORK SU~W~kRY -3- $~eptember 23,. 1971 Released packer and pulled out. - Ran 4-3/4" bit and cleaned out cement 669' _to 685' - still in cment. Pressured c_~sing to 600 p$ig, dropped to 225# after shut-in. Ran Baker squeeze ~packer and set at 560'. Mixed 50 sacks of cement with 35ft3 water and displaced with 28ft3 water. · September_.24, 1971 Released packer and pulled out. Ran 4-3/4" bit and cleaned out cement 632-671' . and stringers to 685'. Ran Baker squeeze packer and set at 560'. Pressured ...... UP_;. hol~s broke down at 500 ~ps~ and bled down to 2Q0__p_si_g.~ .............................................. · Sept.e,mber.. 27 ~ .19.?1 Ran 4-3/4" bit and cleaned out to top of bridge plug at 714'. Ran in with packer retrieving tool, engaged and recovered Baker bridge plug. Ran in with 4-3/4" bit and cleaned out 1900-2570'. Septembe,.r, 28~ 1971 Pulled bit and made up and ran Baker squeeze packer. Set packer at 2565'. Tested below packer to 2000 psig - no breakdown. September 2.9, 1_9.7.1 Pulled squeeze packer. Ran 4-3/4" bit and cleaned out 2570~2978' and circulated hole clean. September 30., ' .197.1 Pulled bit, measured out of hole. .Dumped 16-sacks of sand down casing. Rigged up to run 3-1/2" tubing. O~c~.ober ! & 2~ 1971 Ran 3-1/2" tubing and tagged top of sand at 2,885'. Pulled up 30' and' circulated hole clean. Spot 3 sacks of sand on bottom - tagged top at 2861'. Landed 3-1/2" ...... · ~bimg at 2859'.--Mixed--t60~sacks-of.cement containing 3% CaC12 with water; displaced with 142ft3 of water. No returns at surface. October 4 & 5 Made up 2-15/16" bit and 6-2" drill collars on drill pipe. Located top of cement at 2757'. Drilled out cement to 2864' and circulated out sand to bottom at 2990'. Flow tested well; rates were inadequate. October 6~ 1971 Rigged up GO-International. Ran magnetic collar locator'and perf log. Tagged bottom at 2986' and 3-1/2" shoe at~_7' <E-Log depths). Perforated the WELL SCU WI41-33 RE~DIAL WORK SUMMARY - 4 - following intervals 2 JHPF with 2-1/8" 24 gram capsule jets as follows: Run ~1 - 2978-2959' Run ~2 - 2959~2940 - Stuck gun after firing. Pulled loose with 1500~. Left 21' of paired wire in hole. Ran 1-3/4" sinker bar to 2987'. Run ~3 - 2926-2.904 Run 4)4 - 2904-2882 Otto.ber _._7 ~_ . 1971 Rigged down and loaded out equipment. Returned well to servtee. (,~UILIIi?' IN TRII'i, ICATE) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS Nf3TIC£ Of INICNI~_',',~ T,") Dr~!L,L NO~('E OF IN][NII~.N TO CII.~N,jL NOTICF Of IN'FENr:'~N ]O 1~' I V. ATER SI~Ui NOTICE OF INT[~;Ii~': 10 ~ ~. r:r~l~ I ON REi',~;- ','.'ELL NO'lICE OF INIf~,~',~N ro gH:JO/ OR ACIDIZ~; . NOTICF Of- INTF',Th)N IO PULI ('R Al TER CASING NOTICE Ol INT[NIION 10 ~f'ANPON WELL ' X SUBSEQUFNT RFFO'RI Of' WATER SHUT-OFF SIJBSEQI'[ NT REPCR r OF SHOO'lING OR ACIDIZING ;' SUBSEOUENIr RETORT OF ALTEHING CASING "SUBSEQUFN/ REPORT OF RE.DHIL!.ING OR RI:P-'IR SUBSt_QUFNT REPORT OF ABANDONMENT SUPPLI MENTARY WIlL HIc, IORY JAN 18 1961 Development E~gine~ i . ~ INDICA1F. A~().J UY ( HE('~', MAPK ~IATURF OF ~EPORT, ~J'.)TlCt-. ()R (',rHr-l,r {;ArAJ · · . ...... January 11 .......... 19 61 ( 17 ) Approximately .,.I I E 1 '¢,'cll No.$RU b.1.-33~ t,,c ,ted/ 660 fi, irc,, i~'~ Ii,',.,: and 660 ft. from ,:1~I li,~e of sec. (1¢ ~'c. a: .... '4., ) ['l ~ l'-) I{:~l~t'r) (3~, f ~1 B~on ~r Ke~t ~~u~ . ., A~a~ ...... K.B. Thc elevation ,,f tl~,.~~ :,l,~,vc ~-,t level is 1~ ft. (App~xim~) DETAILS OF WORK l. D~ll to 30~' a~ ce~ 13 3/8" oasis. 2. Install & test Class III Blowout Prevention Equipment. 3. Drill ahead to approximately 10,900' , Log, and ce~ent 7" casing in two stages. Obtain requisite water shut-offs. Selectively Jet perforate attractive sands and test as necessary. 6. Run 2 7/8" tubing and co~zplete. Company Ad(Jr ,'.ss STA1E~RD OIL C0~P~ OF CALIFORIrL~, WEST~J~N ~PERATIO~8, INC. P. O. ~ox 7-839 _. ' Anchorage, Alaska J. T. C~R District Superinten~ - Alaska · ,i. ., :' d' ,; ~4 · CO COMPLETION REPORT - NEW WELL ORIGINAL s~mm~o OZL C~m~ 'OF CAZ~FOmmA - WESTE~ ~m~0~S~ Z~C. - ~A~a / ~> ? PROPERTY: WELL NO.: LOOATION: Kenai Peninsula, Cook Inlet Area LAND OFFICE: Anchorage Lease No.: 028399 Swanson River Unit SR~U _WI ~1-~33 'SEC. 3~ Pro~ected, T. 8 N., R. 9 W., Seward Surface: 960' south and 1320 west from northeast Corner Section 33 (Projected) T. 8 N., R. 9 W., Seward B ELEVATION: 179' X.B. DATE: October 26, 1960 K.B. is 15' above ground. BY: J. ~$UU~R, District Superintendent '- -- -. : .... -. - f-' '.'- .' .- :- .- L ' ELi _ - ...... '~ .... ': '" ' ..... P'~ -J J ~ .... ld~j '11 i Ill' II ii 11 Il T ' ' DRII. I~D BY: Coastal Drilling Company DATE COMMENCED DRILLING: August 8, 1960 DATE COMPLETED DRILLING: August 17, 1960 DATE OF INITIAL PROOUOTION: SIJMMARY TOTAL DEPTH: 3000' " PLUGS: 3000 - 2990' 20" Conducto$ cemented at 23' 13 B/.8" Surface Dipe cemented at 325' with 272 sacks around shoe 5~" Casing cemented at~~ with 726 sacks around shoe PERFORATION RECORD: 1. 5 - ~" holes 2000 - 2001' 2. 5 ~" holes 2305 - 2306' 3. 5 "holes 2707 2708' %- k I" holes per foot, interval 2926 - 2882' 44' - 177 shots WELL SURVEYS: 1. Schlumberger YES Log interval 2999 - S25' 2. Schlumberger Sonic Log interval 2999 - 3 ..... ,~.Schlumberger Micro Log interval 2999 - S25' 4. , Schlumberger Neutron Collar Log interval 2000 - 2926' DRILL STEM TESTS: 1. HCT WSO ~1 on perforated interval 2000 - 2001' 2. HOT WS0 ~2 on perforated interval 2SO5 - 2S06' 3. N~T WSO ~S on Perforated interval 2707 - 2708' SWANSON RIVER: UNIT WI ::(41- 33 Section 33, T. 8 N.~ R. 9 W., Seward Page 3. Spudded in lC: $0 A~ August 8~ 15~60. Drilled 1R~" hole, 0 - 267' Drilled 12~" hole 267 - 324' Opened 12~" hole to 17½" hole 0 - 32~' Drilled l?~" hole 267' drilled 57' drilled 32~' opened 84 per mud 76' p. cf mud 324 ~ 327' 3' drilled Circulated and conditioned hole for casing. Cemented 13 3/8" casing at S25' in single stage &round shoe with 276 sacks of construction cement, last 150 sacks trea~ed with 3~ CdC12, using Halliburton Power Equipment. Used i bottom and I top rubber plug. Mixed cement i~ 30 mina. and. displaced with Halliburton trm~k. :2op rubber plug displaced with 47 bbls. of mud. Good remurns. Cetera% in place at B:15 PM. CASING DETAIL: All 8 Jnts. or 316. ~'4' Total 8 Jnts. or 316' Below K.B. ..... _9'_ ,. Oemented at 325 ' Landed casing, installed and tested BOPE. Cleaned out cement to bottom. 13 3/8" ~4..~ J ~5 e~uim~ea with float shoe Orilled 7 5/8" hole Ran in found cement at 270' Ram in with bit. 327 - 1,462' 1~135' drilled 77 pcf mud SWA~eSON ~ ~ WZ section 33, T: 8 N.~R. 9 W;, SeWa~,.d B & M Page 1,462 - 3,000''~ 1,538' drilled Circulated and conditioned mud f0~~10gs. 84 pcf mad ~n Schlumberger 1ES, Sonic and 'Micro Logs over interval 2999 - 325'. Opened 7 5/8" hole to 8 3/4" hole 327 - 1,840' 1,513' opened 83 pcf mud. Opened 7 5/8" hole to 8 3/4" hole 1,840 - 3,000' 1,160' opened Cemented ~" casing at 3000' in two stages with 726 sacks of conetx~etion cement using Halliburton Power Equipment. FIRST STAGE: ~.th 300 sacks aro~ud shoe. Used one top and one bottom rubber plug. Mixed in 20 mins. and displaced in l0 sins. with Halliburton tr~ck. Pumped ~_0 bbls. of water ahead. Displaced ~th 68 bbls. of mud. Cood returns. Average slurry weight ll5 - ll?-~ per. SECOND STAGE: with 426 sacks through DV Collar at 1!69'. Mixed and displaced cement in 50 ~.,ins. using Halliburbon truck. Pumped l0 bbls. of water ahead. Displaced with 28 b~ls. mud. Bumped plug and closed DV Collar with 2400 psi. Good returns. Average ~siurry weight ll5 - 117~ Def. CASING DET~L: Top 1 Jnt. or ~2.69 ' Ne~t 7 Jnts. or 285.15' Next 26 Jnts. or 835.32' ~.78' Next 47 Jnts. or 1756.~0' Next 2 Jnts. or 8%. 10' 4.46' ALL 83 Jnts. or 3010.O0 Above K.B. 10.O ~o~ N-8o ~" 17~ Halliburton DY ~ollar at 1160' " 2o~ Baker Shoe, Float, and Whirler Collar. Scratchers aud C~u%ralizers from 198~ - 202o', ~O72 - 2104', 2290 - 2326', ~lo - ~4~0'~ ~700 - 2736', 28~8 - ~888' ~9~0 - Landed at 3000.0, C ~PLETION REPORT SWANSON RIVER UNiT WI 4_1.-33 Section 33 T. 8 N;~ R. 9 W.~ Seward August Page 5. Picked up 2 7/8" DP, unsble to circUlate with 4 5/8" bit,` 4" D.C. and 2 7/8" DP hanging at 600'. Ran open end DP, circulated and co~'.,.ditloned ~ad at 600' and ll60'. Drilled out DV Coll~,r. Cleaned out to 2875'. Circulated amd conditioned mud every 600'. Drilled ~ut cement 2875 - 2990~ Tested DV Collar with 2000 psi. with rig ~, ~m~s fainted to hold pressure. ~ 84 pcf mad August !5, 1960 ".' · Tested DV Collar with 2000 psi., 15 rains., OK.. Ran Schlumberger Neutron- Collar Log. B~u Schlumberger Jet gun and perf~d. 5 - ½" holes 2000 - 2001'. Halliburton WSO Test on holes at 2000 - 200i'~ Tool assembled as follows: One %-~s~{ de: :-BT ~e~orde~-5'~~ perf,~'.' tail '~f~ ~n~ok pusher, ~" Type C Packer, VR safety joint~ hydraulic Jars, inside BT recorder, hydrospring tester. Ran TO Valve on top of 3 jnts. 2 7/8" tubing. Set packer at 1954', tail to 1978' · No cushion. Open tool at '6:55 PM for I hour and ~0 min. flow test. ~" surface bean open. for 20 rains. 3/8" surface beau for balance of 'test. Shut in at 8:25 P~ i'or ~0 mires. FSI pressure. Attempted 30 min. ISI pressure, TO valve leaked, 1~ blow then dead. Recovered ~0' drilling fluid. PRESSURE DATA: Ok~tside BT Recorder Inside BT Recorder IH ISI IF · F~ Fsi ]~H 1002 7 ~ 4 ~ 10~ 1037 24 ~ 24 24 '~O3~ WSO - OK Ran Schlumberger jet gun and perf'd.~ 5 ' ½'" holes 2~S -$2~'. .A_u_gu~st ~6~,,... ~969 Halliburton USO T~st on holes at ...... , "' , · " ~ ° 2305 - 2306 · ~ ~-~ ~.~~- ~ ~~.~ for 30 ~n. ISI pressu~. ~ened tool at 2:3~' ~[ ~"~ surface be~ open for 15 ~., we~ puff then' ~a~.~. ~/~" ~~e bean open for 45 ~ns., no cha~e. Shut in tool FSI pressure. Reco~red ~' of ~l~ng fled; ~ ~ ~~. PRESSURE DATA: Outside BT Recorder Inside BT Recorder WSO - OK -~' COMPLETION REPORT SWANSON RIVER UNIT WI ~1-33 section 33 ~. 8 3., ~R.~ ~9 W.~ ~.ewar. d B & M S~NDARD OI~. 'C0. OF CA~FOm~A, W.O.X. - Page 6. August. 16., .1969 (,Continued) Ran Schlumberger jet gun and perf'd. 5 - ½" holes 2707 - 2708'. Halliburton WSO Test on holes at. 2707 - 2708'. Tool assembled as before. No'~cushio~.' ~et' 'packer_ at 2~73" tail to 2697', TC Valve one stand above tools. Opened tool mt 8:02 AM for ISI pressure. TC Valve leaked. ~" surface bean open for 30 rains. 3/8" surface bean opened at 8:B2 AM for 30 rains, mild steady blow. Shut tool in at 9:02 AM for 43 min. FSI pressure. Pulled packer loose at 9:45 AM. Recovered 30' gassy drilling PRESSURE DATA: IH ISI IF FF FSI FH Outside BT Recorder: Inside BT Recorder: 1420 25 25 25 ll5 1410 1426 31 31 31 119 1426 WSO - OK Ran Schlumberger jet gun and perf'd. 4 - ½" holes per foot 2926 - 2882', 4~ feet, 177 holes for injectivity test. On injectivity test, pumped in 100 bbls. of water at 2000 psi in 1~ mins., 100 bbls. of water at 1000 psi in 25 rains. Laid down 2 7/8" DP. Augus~ 17.,. 1960 ~!.. casing. Picked up 2" tubing and hung at 1483' Welded tubing head on ~m · .R!.g.._,released 10:00 AM, August !7~,~ 1~60. PRODUCING DEPARTMENT TELEPHONE 47001 J. T. CROOKER DISTRICT SUPERINTENDENT t :/ P. O. BOX 8 3 9 · A N C H O R A G E · A LA S K A September 8, 1960 CONFIDENTIAL Alaska Oil &-Gas Conservation Commission 329 Second Avenue~ Anchorage~ Alaska Dear Sir: Enclosed~ herewith~ are one field print and one sepia copy of the Composite Induction-Electrical Log for the S~nson River Unit Well WI 41~33~ Run No. I at recorded interval 325 to 2,999 feet~ for your information and files. -~ Enclosures Very truly yours, STA~l~RD OIL C0~PANY OF CALIFORNIA Western Operations, Inc. J. T. CROOKER RECEF ,tED SEP 9 I960 Oil & ('las Sect:kin D~vi'sion of Mit;es and Minerals ~'. '.; ;-¥,,t. of Natural Resources PRODUCING DEPARTMENT TELEPHONE 47b01 J. T. CROOKER , DISTRICT SUPERINTENDENT P. O. BOX 8 3 9 · ANCHORAGE ,ID.ky 29, 1960 · ALASKA . . R£CEIV£U AUG 4 1960 Mr. Richard V. Murphy, Petrole~a Eng. Division of Mines amd Minerals Alaska Oil amd Gas Conservation Commission 329 Second Avenue Anchorage, Alaska Oil & Gas Section Division of Mines and Minerat~ 2klaska Dept. oE Natural Resource~ Dear Mr. Murphy, Attached herewith is our propoSal to drill SRO ~I 41-33, a waste water disposal well. The welI will be located adjacent to our S~anson River oil cleam~ facilities'in the ~ of Section 33, T8N, R9W. It is to be used to inject produced and sump water into permeable samds between 2,000 and 3,000 feet, the exact intervals to be determiaed by a stud~ of the surveys which are to be run after drillimg to total depth. Necessary water shut-offs will be obtained to prevemt migration and to isolate any h~drocarbon preducimg formations. At your convenience we will review the surveys with you prior to perforating the imjection intervals. Very truly yours, Attachment STAND ~ARD OIL COMPANY OF CALIFORNIA ·. .Westera Operations, Inc. fl RECEIVED AUG 10 1960 ,as Section Division of Mir, es and a~' ~aska Dept. of Natural Hemurces -/ = UNITED STATES DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. Approval oxplres LAND OFFICE .._~~~ .......... LE~E NUMBER __0_a_~_~ LESSEE'$ MONTHLY REPORT OF OPERATIONS .................................................................... ~geld Tke followinff is a correct report of operations and prod~ctio~ (inel~dinff drillinff a~d produein~ wells) for t~e mo~tk of ....... ~~ ....................... , 19_~., ___~.~F~~., ~t ........................... ........... ,,. ................................. ~ ~ -(-~~~~~.~. ]~l~a 7 5/~_ ~te: ~7' ~o 3~'. ~ ~'xo~, mom ~e~ea ~" maln~: a~ 3~'0 ~ea out emn~ ~o IvO~e~vi~y ~st - P~ed l~ ~~s ~ter at ~c, t. I ' ~s~ 0 & O C,I - R~ V. ~~ ~le: ~x~lomtion ' ' ] Pmducl~ Nor~.--There were .............................. L ......... runs or sales of oil; ~ .............................................. M cu. ft. of gas sold; ............................................. runs or sales of g~.soline during the month. (Write "no" where epplic~ble.) Norz.~Report on th. is ~orn, ~s required !Or each calendar men,h, regardless of the ~%a~us of cq~erl~t,~ons, and must be filed in duplicate with the supervi.~or by the Otb o~ t~e succeeding men,h, unless o~herwise directed by the · ~or~n 9-329 (January 19~) If~--257G6*S O S. (..,~z~U~T r~lNTl,~O o~rlc~ APPLICATION TO DIspO'5.- OF SALT WATER BY INJECTION INTfi .~ POROUS FORMATION Operator S~ 0~1 CO. Of C~lt, f. J Address ' 'Wester~ ~t~p~ inc. J P. 0. ~x 7~, ~~, ~~ Location SEC-TWP-RGE or Block ~ Survey CASING AND TUBING DATA Name of string Size Length Cement Data Surface Casing Intermediate Long String Tubing 13 2t! 3000' 2500,+- $uffici.ent (;ement to fill to suzTace 2 Sta~jes: 3000 'to i?00'; Iii,CC' 'to $'mrface Name,. Model and Depth of Tubing Packer Name and Top and Bottom of Injection' Zone . Sands ~ithin Upper Kenai.. 1600' - 3300' . Is Injection through Tubing', Casing or ..&nnulus? J Perforations or Open Hole? Tubing.J Fe~'$, , List all Cement ~queeze Operations, Giving Interval and Number Sacks Cement Is this a new well Drilled for Disposal? }~r~ckish ~ Is Injection Zone Productive of Oil or Gas in This Field? I Depth of Deepe~~'l~Cater Zone Depth of Shallowest Productive Zone lO,5(X)'~; 0i1~35C~3:t Gas Anticipated Daily Injection Volume (bbls.) is Injection to be by Gravity or Pressure? Presstu~e Minimum 2o0 Maximum J Open or Closed System? i?re~entLy' ~:'~o~'nJClo~ed except "' ~' '~ JA~p~OX. Pressure (Psi) [ Source of Wate~ to be I~fl Are there any other Salt ~¢ater Disposal Wells 'using this same Zone in this Field? Name of Operator of Disposal VCell in same zone Standard Oil Co. cf Cal~, ~ W. O, ~ Inc. Is this well so cased and completed that water can enter Yes or no no other formation than the above set out injection zone? "les Yes or No It[ so name one such well below Il,es Sti~,~ 22,-2~ Lease Name ~a:mon Liver '0nit Have notices of this application been mailed or given to all operators within 1/2 mile of this injection well? Well No. 22-23 Yes or no 'None itequired List names and addresses of all operators within one-half (%) mile of this injection well: ...... ,~ .......... --~-------- , ~'~:~e, Division o~ Mines Mi~¢als * P/h:,,; ¢ (company), and that I a~ author~ed by said company to make this report; and that this pared under my supervision and direction and ~hat the facts stated therein are true, correct and complete the best of my ~ow]edce. INSTRUCTIONS: 1. Attach a complete full-scale electrical log of this well, if available. Indicate on electrical log, or by other evidence, the base of fresh water zones in this field. 2. Attach waivers from all operators within one-half (V~) mile of the injection well, or copies of letters notifying such operators of this application. Also attach waiver from surface owners of land on which the disposal well is located, o.r copy of letter from operator making this appication, notifying such surface owners of this appli- ca.tiou and requesting waivers. 3. Should all necessary waivers not accompany application, the Com- mission shall hold such application for a period of 'ten (10) days from date of receipt. If, after said ten (10) day period, no protest or request ~or hearing is received, the application will 'then be processcd. Alaska Oil and Gas Conservation Commission Application To Dispose of Salt Water By Injection Inlo a Porous Formation Form No. P-16 Aulhorized by Order No. 1 Effective October 1, 19~8. PRODUC lNG DIE]PARTM IrNT T ELla'PH ON ~ 47001 J. T. CROOKER DIITRICT SUPERINTENDENT P. O. BOX 8 3 9 Mr. John B. Nakala Refuge ~ger Kenal National ~oose Range Kenal, Alaska Dear John, A N C H O R A G E - A LA S~~ ju~ ~8, Attached herewith is the well program for our proposed waste water disposal well, SRU ~WI 41-33, as mentioned in proposal ia our letter to you dated July 7, 1960. This well will be drilled to a depth of 3,000' for the purpose of disposing of produced and sump water from the Swanson River and Soldotna Creek Units, in selected intervals between 2,000 and 3,000 feet. ~]~e exact intervals are to be deter- mined from analysis of the surveys run after drilling to total depth. Present surface facilities will be removed from SRU 22-23, however, the well will be maintained for emergency injection usage. We thank you for your approval on this and the other proposals submitted to you in our letter of July 7, 1960, and will keep you informed as to the progress of this and other projects. Very truly yours, STANII~RD OIL COMPANY OF CALIFORNIA 'Western Operations, Inc. .~. Atl~a~nts J. T. CROOKER NOTED AUG 9 1960 ...... ,~.~LDSWORTH Commissiofler , ;" APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK APPLICATION TO DRILL NAME OF COMPANY OR OPERATOR DEEPEN [] PLUG BACK [] DATE Standard Oil Cemrmny of Calif'ornia, ~;estern O~rns.~ Inc. Address City State DESCRIPTION OF %VELL AND LEASE Name of lease Lanson Hirer Unit %Veil location (give footage from section lines) 660' 'W'l,v. along ~ line & ~' S'~. % ~/A fr~ Ni~; Cot. $~. 33~ TSN~ B,~ Field & reservoir (If wildcat, so state) ~anson ~?,ive~r },;ield UPper Kenai Sands Distance, in miles, and direction £rom nearest town or post office 16 miles ~'~o~h ofot~li~. ~'' "~ ,~ A~,ska ~earest distance from proposed location to property or lease line: Well number Elevation (ground) WI ~1-33 165' Section--townsl%ip--ran~e or block ~ survey ICounty Kc, nat ~%'ecinet Distance from proposed location to nearest drilling. completed or applied--for well on the same lease: '2000 ' ~eet Proposed depth'. Dot-cry or cable tools 3000 ' ~tar~ Number of acres in lease: 176o 'If lease, purchased with one or more wells drilled, from whom purchased: ~ame Approx. date work will start ,A~ust 12: 1960_ .......................... Number of wells on lease, including this well, completed in or drilling to this reservoir: Address Status of bond ~ot ~%e~u~r~d Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producing zone) pit,pose tO drill waste water injection '~,,~ell to dliSpOSe O~ pro~uce~ and sump water. CERTIFICATE: I, the undersigned, state that I am theDist. SuDt* of the ,Standar(~ Oil (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. 1~. ,i5' (.,.]/,,~..2){2)liJi~ Permit Number' ~ Xf ~ Approval Date' ~,U.S 9~960 I ' . ~ ~- i ~ ') ' all information requested. ~ueh unnecessary correspond- ~ ence will ~hus be avoided. ~ I See Instruction on Reverse Side of Form ~ Alaska Oil and Gas Conservation Corn. mission Application to Drill, Deepen or Plug Back Form ATo. P-1 / Authorized by Order No. 1 Effective October 1, 1958 _ $ WA N~O_N RIV£~ UN/T OIL ForD~ 9-~31 (Feb. (SUBMIT IN TR1PL[C.4TE) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAl... SURVEY t"ttltlg,;'t J~,k:r~ :,ii N'~,..t.'j Jf. 3:.~. ~,. ?tJq .ro~liJ t'>.!~ir~> !'.., ~ ,,ih L ..... ,,,,,. 028~,,t~. ...... SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF H',I'I'tNTION TO DRILL NOTICE Of INTEN"flON 'tO CHANGE; PI ANS NOIICE OF INI'£NTION 'lO l£S'I' V, AI£R NOTICE OF INIENIlON TO RE.Dq;LL O~? REPAIR VvELt. NOTICE OF IN rFNI{ON TO S}IC)OI OR ,kC IDIZE NOTICE OF INIE,';'TION rO PULL OR Ai. TER CAS{NO NOTICE OF INTE~'I'ION TO AS/,NDON \¥£LL ,, SUBSEQUENT RE'PO,RT OF WATER SHUT.OFF'. :! SUF:;SEQUEh'F REPORt ,':)F' SHOO t'lNO OR A('IDIZING ... ' SUBSEQULNq REF'ORF C;~ Ah'T'ERIN(~ CASING ....... : - 'SUBSEQUENT' REPORT r'.,RE-DRILLiNG OR REPAIR ...... SUBSEQUENT REPORT O~ ADANOONMEN'F ....... ~ . ,' SUPPLEMENTARY WELL HISTORY _ . ' .i ~ .... .. ,.. Well NdiiRU 1¢1:1,1-3.:1s located 660 ft. hom !, line and ~ . ft. from, j lineof sec. .... River Uni~ Thc elevation of t:h,,' :xicm~t~:~kl~ :~}',,ovc sca level is . 1~5 ft. approxo DETAILS OF WORK Propose to drill waste water disposal well in accordance with the &~tached program. Cmnpany Standard Oil ¢o~v of California, Western Opera%ions, Inc ............ Address P, O. litox 7-839 A~a~laors~, Alaslram DIALLING PRO~ FIELD: Swanson River PROPERT~ & WELL: SRU WI ql-33 LO~ATXON: Approximate~ 660' westerly along north line and 660' southerly at right angle from northeast corner Section 35, T. 8N., R.~9 W. BLOWOUT PREVENTION EQUallEd:.~' Class II WELL CORRELATIONS K. B. Elevation: (Estimated 1~5' ) MAWR SUBSEA DRILLED AY ll95 ~B~o B 2~o 268~ PROGRAM 1. Cement 20" ID Co~ctor 5' below cellar floor. 2o Drill 12~" hole to 300'. 3. Open hole to 17~-" and cememt 13 3/8" casing with sufficient con- struction cement to reach surface. 4. Install Class II ~0PE and test as directed. 5. Drill 8 3/~" hole to ~O00' -and run Induction Electric Log, Micro- log, and S~n~c 6. Cement 5~ sing ~at ~000' in two stages. First stage around shoe to theoretically cover to 1700'. Second stage through DV collar approximate~ 1~00' to reach ~o surface. 7. Obtain water shut off above selected injection intervals and as necessary to isolate any sands with hydro carbon content. ? 8. Perforate selected intervals as indicated. (Approximately 200' - ~O0' in A20 - B~ %nterVal) 9. Run 2" tubing, hang as directed, displace mud with water and make injectivity tests With cementing trucks. 1Oo If satisfactory inj'ection, install tubing head, rerun tubing, move off rig. ·