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161-003
• MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, ' "�� DAT E: July 5, 2012 P. I. Super ' � FROM: Jeff J ones SUBJECT: Surface Aban donment Petro Inspector SRU 41 -33 Hilcorp PTD # 1610030 History: AOGCC Inspector visited well location on 9/4/2004 to inspect surface abandonment of SRU 41 -33. Casing was cut to proper depth and cement was observed to surface in all casings. Inspector returned to the location on 9/5/2004 to witness successful installation of marker plate. One unresolved issue: flowline stub in the well cellar. There was no final location clearance inspection done 41 at this time. J 3, 2012: I traveled to Hillcorp's SRU 33 well location to inspect the site for consideration of a final location clearance. I toured the location and I noted that the cellar was properly backfilled and the grade was returned to original pad level. , • }' .f 1 � S ;, bj _, -•%.! � . � x „ - 4 ♦ e 3 r.. .T �x • < r 7,: -* « �," j .n i r �. 'x w' , � a � y Summary: I inspected the well site at Hilcorp's SRU 41 -33 well and it appeared to be in compliance for a final location clearance. �C�ANN IV 0 7 2013 STATE OF ALASKA 6_9 ALA* OIL AND GAS CONSERVATION COM•ION VAzA- WELL COMPLETION OR RECOMPLETION REPORT AND LOG ` /ref 2-00q la. Well Status: Oil ❑ Gas ❑ Plugged ❑ Abandoned 20AAC 25.105 Suspended ❑ 20AAC 25.110 GINJ❑ WINJ ❑ WDSPL❑ WAG ❑ Other❑ No. of Completions: 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 4a. Location of Well (Governmental Section): Surface: 850' FNL, 740' FEL, Sec 33, T8N, R9W, S.M. Top of Productive Horizon: 850' FNL, 740' FEL, Sec 33, T8N, R9W, S.M. Total Depth: 850' FNL, 740' FEL, Sec 33, T8N, R9W, S.M. 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: TPI: Total Depth: x- 346,404 x- 346,404 x- 346,404 y- 2,465,561 y- 2,465,561 y- 2,465,561 Zone- 4 Zone- 4 Zone- 4 18. Directional Survey: Yes ❑ No (Submit electronic and printed information per 20 AAC 25.050) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): N/A 22. CASING, LINER AND CEMENTING RECORD CASING 22" 13 -3/8" 6 -5/8" WT. PER FT. Date of Test: Flow Tubing Press. GRADE Hours Tested: Casing Press: SETTING DEPTH MD TOP Surface Surface Surface BOTTOM 28' 2,104' 11,133' SETTING DEPTH TVD TOP Surface Surface Surface 23. Open to production or injection? Yes❑ No 0 If Yes, list each interval open (MD +TVD of Top & Bottom; Perforation Size and Number): RE( RECEIVED ,iUN 0 9 ?O(i Alaska OBI & Gas Cons. Cummissio! Anchorage Method Production for Oil -Bbl: Test Period _ol Calculated Oil -Bbl: 24 -Hour Rate —► 5. Date Comp., Susp., or Aband.: 6/3/2009 6. Date Spudded: 1/22/1961 7. Date TD Reached: 3/7/1961 8. KB (ft above MSL): 175' Ground (ft MSL): 9. Plug Back Depth(MD +TVD): Surface (0') 10. Total Depth (MD + TVD): - 11,133'MD (11,133'TVD) 11. SSSV Depth (MD + TVD): N/A 19. Water Depth, if Offshore: N/A (ft MSL) BOTTOM 28' 2,104' 11,133' SIZE N/A HOLE SIZE 18 -5/8" 12 -1/4 "- 8 -7/8" DEPTH INTERVAL (MD) 9,844'- 10,299' 6,010'- 6,545' 1,790'- 2,218' Surface -410' Gas -MCF: Gas -MCF: Water -Bbl: Water -Bbl: lb. Well Class: Development Exploratory❑ Service ❑ Stratigraphic Test❑ El 12. Permit to Drill Number: 161 -003 SOS Z 13. API Number: 50- 133- 10166 -00 14. Well Name and Number: Swanson Riv Unit (SRU) 41 -33 15. Field /Pool(s): Swanson River Field Hemlock Oil Undefined Oil 16. Property Designation: FEDA028339 [Swanson River Unit] 17. Land Use Permit: FEDA028339 [Swanson River Unit] 20. Thickness of Permafrost (TVD): N/A CEMENTING RECORD 2000 sxs cement 2528 sxs cement DEPTH SET (MD) N/A Choke Size: AMOUNT PULLED 24. TUBING RECORD PACKER SET (MD) N/A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. AMOUNT AND KIND OF MATERIAL USED 15 bbl class G cement 80 sxs LXT class G cement 74 bbl class G neat cement 50 bbl class G neat cement 26. PRODUCTION TEST Date First Production: of Operation (Flowing, gas lift, etc.): Abandonment N/A Gas -Oil Ratio: Oil Gravity - API (corr): 27. CORE DATA Conventional Core s) Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if nee ed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. r cf� RBDMS APR 2 5 7017 , 8 , ,1 i;d AUG 1 Form 10 -407 Revised 2/2007 CONTINUED ON REVERSE 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 4 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test, information per 20 AAC 25.071. Permafrost - Top Permafrost - Base Formation at total depth: 30. List of Attachments: Daily Operations Summary, Well Schematic 31. I hereby certify that the foregoing is true and correct to Printed Namrimothy C. Brandenburg the best of my knowledge. Title: Phone: Contact: Jack Newell 263 -7832 Drilling Manager Signature: /u • it 907 - 276 -7600 Date: 6/5/2009 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 la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for 1 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 and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 Chevron IIP W 1%0 Chevron - Alaska %. Daily Operations Summary Well Name SRU 41 -33 Legal Well Name SWANSON RIV UNIT 41 -33 Lease FEDA028339 Surface UWI 5013310166 ChevNo QA5339 Original RKB (ft) 15.00 Water Depth (ft) Primary Job Type Abandon Well - Permanent Job Category Abandon Objective Abandon well. Actual Start Date 9/19/2008 Actual End Date 10/10/2008 Primary Wellbore Affected SRU 41 -33 Wellbore UWI 5013310166 -00 Well Permit Number 1610030 5/61200900:00.5 /7 /2009 00:00 Operations Summary PJSM - Vac out cellar and shoot natural pad grade, prepare location for casing cut -off and abandonment summer operations. 5/26/2009 00:00.5/27/2009 00:00 Operations Summary PJSM - Vac out and pressure wash cellar, stage equipment for P&A 5/27/2009 00:00.5/28/2009 00:00 Operations Summary PJSM - Dig out cellar box, bleed down 6 5/8" x 13 3/8" annulus, cut bracing to wellhead 5/28/2009 00:00.5/29/2009 00:00 Operations Summary PJSM - Bleed down 6 5/8" x 13 3/8" ann. , cut off tree 4' below natural pad grade, tag cement 12' down and fill with Portland G cement. 5/2912009 00:00. 5/30/2009 00:00 Operations Summary PJSM - Weld on surface marker plate, fill in hole and clean /secure location. 6/3/2009 00:00 » 6/4/2009 00:00 Operations Summary PJSM - Excavate well stump and repair marker plate. Obtain GPS coordinate - Back fill. • Size Type Wt/ Grade/ Conn ID Top Btm Cement Sacks Cemen t Top 22 13 -3/8" 6-5/8" Conductor Surface Inter. 114.8#, B 54.5, J55, BTC 20.813 12.459 5.666 Surf Surf Surf 28' 2104' 11,133 2000 2528 Surf 5818' Cas __.........28 #, P110, BTC Completion 3 -1/2" Prod Tub 9.3 #, N80, AB Mod 2.992 Surf 10599' 2 -7/8" Prod Tub N80 6.5# 8 RND 2.165 10471 10599 Completion Jewelry Detail # Depth Length ID OD Item A 10317 Baker PBR w/ 10' Seal Assembly B 10333 Baker "SAB" Packer w/ Millout Extension C 10,375 2.867 3.500 3 -1/2" OTIS "XN" Profile Nipple D 10408 3 -1/2" Wireline re -entry guide 2 -7/8" Non - Serviceable Completion — Was left after fishing, did not want to loose well if fishing went bad E 10471 17.39' 2.165 2-7/8" Tubing Top (4' Tubing Pup and 13.39' tubing Above Mandrel F 10488 8 2.347 5.500 Camco MM Mandrel G 10529 14 Baker FHL Packer H 10567 6 2.313 Otis "2" S" Profile Nipple 2 -7/8" Baker Shear Out Sub 10599 1 10725 Reduced ID 6 -5/8" Casing (Collapsed) Perforation Data Dog egs ZONE TOP BTM Shot Condition 10,674' 11,074' 4SPF P &A 2009 10,618' 5SPF P &A 2009 H2 & H3 10,674' 10,715' 4SPF P &A 2009 27' @ 28' BP 1,950' 133/8 " - 2104' evron 9.4 PPG KCL RKB to Sea Level (MLW) = 179' Marker Plate 155' \ GL: 160' y PBTD = 11,088' TD = 11,131' MAX HOLE ANGLE = 2 5231 Swanson River Unit SRU 41 -33 Completed CIBP 5545' CM1 Staging Collar 6733' WBD SRU41 -33 Actual 11- 5- 08.doc Page 1 of 1 CVK OCTG Rotating Hours 22" 47 Rotating Hours 13 -3/8" 288 Rotating Hours 6 -5/8" 40 Rotating Hours Tubing "0" Rotating Hours Onshore Operations Swanson River Unit Well SRU 41 -33 Abandoned November 6, 2008 Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211... Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 21, 2009 8:18 AM To: 'Newell, Jack R [FEP]' Cc: Harness, Evan; Kanyer, Christopher V; Santos, Ronilo; Grimaldi, Louis R (DOA); Jones, Jeffery B (DOA); Noble, Robert C (DOA) Subject: RE: Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211 -33 Jack, Thanks for the update. Contact the Inspectors as necessary to finalize the work out. Call or message with any questions. Tom Maunder, PE AOGCC From: Newell, Jack R [FEP] [mailto:JNewell @chevron.com] �'�� ' 5 2010 Sent Thursday, May 21, 2009 8:14 AM To: Maunder, Thomas E (DOA) Cc: Harness, Evan; Kanyer, Christopher V; Santos, Ronilo Subject: RE: Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211 -33 Mr. Tom Maunder, • Swanson River Unit KGSF 3 PTD: 203 -074 Approved Sundry #308 -438 Activities were witnessed by Lou Grimaldi. Cut -off casings 66" below natural ground level. Used Class G cement to have cement to surface. Welded marker plate on to cut casings. We have prepped cellar for removal. Roads in the SRU are improving for mobilization of equipment to remove and bury marker plate. Swanson River Unit SRU 41 -33 PTD: 161 -003 Approved Sundry #308 -312 We have prepared location, shot for natural grade level. Pad and roads were soft to this location. Have not mobilized dirt equipment to cut -off casing, remove, and bury cellar. Swanson River Unit SRU 211 -33 PTD: 208 -152 Approved Sundry 308 -439 Activities were witnessed by Lou Grimaldi. Cut casings off 6' below natural ground level, Natural grade 29" below cellar grating. Cement to surface from drilling activities, no top fill. Welded marker plate. Prepped cellar, roads soft for crane movement. Waiting on road limitations, should be finished with activities within 30 days. Jack R. Newell •• Chevron North America Exploration and Production 5/21/2009 • Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211... Page 2 of 3 Midcontinent/Alaska SBU 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Tel (907) 263 -7832 Fax (866) 401 0624 Mobile (907) 529 -5450 • • From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, May 21, 2009 7:46 AM To: Newell, Jack R [FEP] Subject: RE: Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211 -33 Jack, Just a follow -up; was the work able to be accomplished? Tom From: Newell, Jack R [FEP] [mailto:JNewell @chevron.com] Sent: Friday, May 01, 2009 9:04 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Thomas_Zelenka @blm.gov; Tim.Lawlor @ak.blm.gov; greg_noble@ak.blm.gov Cc: Harness, Evan; Menapace, Michael Sam; Tyler, Steve L; Kanyer, Christopher V; Santos, Ronilo Subject: Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211 -33 Gentlemen, Follow up on phone voice messages to Tom Maunder, Jim Regg, Tim Lawlor: E -mail notification of proceeding: Swanson River Unit Well Abandonment: Continuation of surface clearance; We will be commencing as early as Monday May 4, 2009 to continue operations that were deferred due to ground freezing Fall 2008 on the below listed wells: The wells have previously been cemented to surface per approved sundry and other filings. Swanson River Unit KGSF 3 PTD: 203 -074 Approved Sundry #308 -438 Continue with approved operational goals. Swanson River Unit SRU 41 -33 PTD: 161 -003 Approved Sundry #308 -312 Continue with approved operational goals. Swanson River Unit SRU 211 -33 PTD: 208 -152 Approved Sundry 308 -439 Continue with approved operational goals. 5/21/2009 Chevron: Swanson River Unit, Continuation of Operations, KGSF3, SRU41 -33, SRU211... Page 3 of 3 If there are questions please call me, there is no particular order implied Thank you, Jack R Newell • • jnewell ©Chevron.com Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Tel 1 907 263 -7832 Fax 1 866 401 0624 Mobile 1 907 529 5450 Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7832. 5/21/2009 • • Chevron DATA TRANSMITTAL Francisco Castro Technical Assistant DATE November 5, 2008 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 SRU 41 -33 SRU 41 -33 CEMENT BOND LOG - VARIABLE DENSITY LOG GR /CCL ULTRASONIC CEMENT IMAGER GR/CCL 5" 26- Sep -08 26- Sep -08 1 1 500 -10290 500 -10300 PDS PDS 19I r. C. Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received B Date: la. Well Status: Oil ❑ Gas ❑ Plugged GINJ❑ WINJ ❑ WDSPL ❑ WAG ✓ Abandoned 20AAC Other ✓ Suspended ❑ 20AAC 25.110 of Completions: lb. Development Service' Well Class: Exploratory ❑ Test❑ ❑ 25.105 ❑ No. ✓ ❑ Stratigraphic 2. Operator Name: Union Oil Company of California 5. Date Comp., Sus. ,, or Aband.: 10/2008 12. Permit to Drill Number: 161 -003 . 3. Address: PO Box 196247, Anchorage, AK 99519 )�/I:� v 6. Date Spudded: 1/22/1961 13. API Number: 50- 133 - 10166 -00 4a. Location of Well (Governmental Section): Surface: 960' FNL, 1,320' FEL, Sec )L T8N, R9W, S.M. Top of Productive Horizon: 960' FNL, 1,320' FEL, Sec 3/3, T8N, R9W, S.M. Total Depth: / / 960' FNL, 1,320' FEL, Sec 3T3, T8N, R9W, S.M. 7. Date TD Reached: 3/7/1961 14. Well Name and Number: Swanson Riv Unit (SRU) 41 -33 8. KB (ft above MSL): 175' , Ground (ft MSL): 15. Field /Pool(s): Swanson River Field - Hemlock Oil Undefined Oil 9. Plug Back Depth(MD +TVD): Surface (0') 4b. Location of Well (State Base Plane Coorddinates, NAD 27): Surface: x- 346,404 y- 2,465,561 Zone- 4 TPI: x- 346,404 y- 2,465,561 Zone- 4 Total Depth: x- 346,404 y- 2,465,561 Zone- 4 10. Total Depth (MD + TVD): 11,133'MD (11,133'TVD) • 16. Property Designation: FEDA028339 [Swanson River Unit] 11. SSSV Depth (MD + TVD): N/A 17. Land Use Permit: FEDA028339 [Swanson River Unit] 18. Directional Survey: Yes ❑ (Submit electronic and printed information No ✓ 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): N/A per 20 AAC 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): USI -CE, CBL, Gamma Ray 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 22" Surface 28' Surface 28' 13 -3/8" Surface 2,104' Surface 2,104' 18 -5/8" 2000 sxs cement 6 -5/8" Surface 11,133' Surface 11,133' 12 -1/4 "- 8 -7/8" 2528 sxs cement 23. Open to production or injection? Yes ❑ No ✓ If Yes, list each interval open (MD +TVD of Top & Bottom; Perforation Size and Number): _ ) � y ' t -' 0 `J 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) N/A N/A N/A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9,844'- 10,299' 15 bbl class G cement 6,010'- 6,545' 80 sxs LXT class G cement 1,790'- 2,218' 74 bbl class G neat cement Surface -410' 50 bbl class G neat cement 26. PRODUCTION TEST Date First Production: Abandonment Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period -',■• Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate --. Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 27. CORE DATA Conventional Core s) Acquired? Yes ❑ No ✓ Sidewall Cores Acquired? Yes ❑ No ✓ If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 2 2008 gas or water 20 AAC 25.071. $0 12A' 10 -7rif 1/4 STATE OF ALASKA ALAW OIL AND GAS CONSERVATION COMAPION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10 -407 Revised 2/2007 �7 /TINUED ON REVERSE 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 4 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Top Permafrost - Base Formation at total depth: 30. List of Attachments: Daily Operations Summary, Well Schematic 31. I hereby certify that the foregoing is true and correct to Printed Name: Timothy C. Brandenburg ,,,,,.. the best of my knowledge. Title: j Phone: Contact: Jack Newell 263 -7832 Drilling Manager 7 Signature: (' " = r_ ( � .-- _ -�-�•" 907-276-7600 Date: 11/5/2008 Form 10 -407 Revised 2/2007 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 la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for / 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 and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Size Type Wt/ Grade/ Conn ID Top Btm Cement Sacks Cemen t Top 22 13 -3/8" _....._ 6- 5/ 8" ....................._ Conductor Surface Cas .... ................... 114.8#, B 54.5, J55, BTC #, , .._ BTC ......................_ 20.813 12.459 5 . 666 .... ............._ Surf Surf Surf 28' 2104' 11 , 13 3 ................_ 2000 2528 .... ................_ Surf Completion 3 -1/2" Prod Tub 9.3 #, N80, AB Mod 2.992 Surf 10599' 2 -7/8" Prod Tub N80 6.5# 8 RND 2.165 10471 10599 Completion Jewelry Detail # Depth Length ID OD Item Completion A 10317 Baker PBR w/ 10' Seal Assembly B 10333 Baker "SAB" Packer w/ Millout Extension C 10,375 2.867 3.500 3 -1/2" OTIS "XN" Profile Nipple D 10408 3 -1/2" Wireline re -entry guide 2 -7/8" Non - Serviceable — Was left after fishing, did not want to loose well if fishing went bad E 10471 17.39' 2.165 2-7/8" Tubing Top (4' Tubing Pup and 13.39' tubing Above Mandrel F 10488 8 2.347 5.500 Camco MM Mandrel G 10529 14 Baker FHL Packer H 10567 6 2.313 Otis "2" S" Profile Nipple I 10599 1 2 -7/8" Baker Shear Out Sub 10725 Reduced ID 6-5/8" Casing (Collapsed) Perforation Data Doglegs ZONE TOP BTM Shot Condition 10,674' 11,074' 4SPF P &A 2009 10,618' 5SPF P &A 2009 H2 & H3 10,674' 10,715' 4SPF P&A 2009 TCC 5818' 6.5/8 - - 11,131 w Swanson River Unit SRU 41 -33 Completed Onshore Operations Swanson River Unit Well SRU 41 - Abandoned November 6, 2008 RKB to Sea Level (MLW) = 179' Marker Plate 155' GL: 160' ti tz' @28' BP 1.950 d 13-3/8"- 2104' CIBP 2,218' TOC6pla PBTD = 11,088' TO = 11,131' MAX HOLE ANGLE = 2' a n 5231 CIBP 6.545' CMT Stang Collar 6733' OCTG Rotating Hours 22" 47 Rotating Hours 13 - 3/8" 288 Rotating Hours 6 - 5/8" 40 Rotating Hours Tubing "0" Rotating Hours WBD SRU41 -33 Actual 11- 5- 08.doc Page 1 of 1 CVK 1v Chevron Chevron - Alaska Daily Operations Summary • Well Name SRU 41 -33 Primary Job Type Abandon Well - Permanent Legal Well Name SWANSON RIV UNIT 41 -33 Job Category Objective Abandon Abandon well. Lease FEDA028339 Surface UWI ChevNo Original RKB (ft) Water Depth (ft) 5013310166 QA5339 15.00 Actual Start Date Actual Date 9/19/2008 10/10/2008 Operations Summary PTSM - PU 5" Tapered Mill, 4DC, & 4 -3/4" Combo Jars - RIH t/ 2064', RIH t/ 2385', All good © 5" Drift - POH for String mill 0000 - 9/25/2008 Operations Summary PTSM - Continue to clean casing w/ 6 -5/8 casing scraper - Scraped casing t/ 10,048 9/25/2008 00 :00 - 9/26/2008 00 :00 Primary Wellbore Affected SRU 41 -33 :00 8/13/2008 Wellbore UWI 5013310166 -00 Well Permit Number 1610030 Operations Summary Pre -rig wireline operations - PJSM - RU wireline & BOPE. Pulled first two 30' tubing pack offs and stops. RD for night. t'! rQ0 - '8/14/2008 #�: Operations Summary RU wireline & BOPE. Pulled 2 tubing patch pack offs and stops attempted to pull 3rd and 3.5" G stop became stuck. Shut down wireline operations. Prepare pad for rig arrival in early September. 9/19/2008 00 :0t6t 2 t ' 0800:00 r n Operations Summary MIRU Rig 106E from Franklin Bluff starting to arrive location 9/4, finish rigging up, test rig systems, okay, PTSM 9/19 - State BOP Test Witnessed by Lou Grimaldi: AOGCC - Witness waved by Tim Lawlor: BLM - Complete SOA AOGCC witnessed BOP Test 250 PSI Low / 3000 PSI High - OK 9/2012008 00:00 - 9121/2008 00:00 Operations Summary PTSM - PU Landing joint, pull on hanger to 160K worked hanger free - Worked seal assembly out of PBR, 118,000 String weight when free - POH w/ 3- 1/2" completion - Static Fluid losses 9 BPH. 22/2008 00 :00 Operations Summary PTSM - Continue to POH w/ 3 -1/2" completion 205 jnts OOH, PU 55K, SO - 45K Static fluid losses 8 BPH 9/22/2008 00:00 - 9/23/2008 00:00 Operations Summary PTSM - Finish LD 3 -1/2" tubing to PBR, All recovered - PU 5.5" String Mill, RIH to HOMCO patch @ 2065', No Go, POH 9123/2008 00x0 90200 t t v - 0 Operations Summary PTSM - Finish scraping casing t/ 10,342' - Circulate well w/ lease water until clean - POH 9/2612008 00:00 Operations Summary PTSM - Continue to POH - RU E -line and PU USI -CE, GR, and CBL for evaluation of well bore and 6 -5/8" tubular - Pull logs OOH. 912712008 0000 '200800:00 Operations Summary PTSM - Finish USI -CE, GR, and CBL logging - Perform witnessed BOP test - 250 PSI low/ 3000 PSI, hold each test for ten minutes - PU RTTS, RIH. 9/28/200800 :00 9/29/2008 00 :00 Operations Summary PTSM - TIH t/ 10,262' - Set RTTS, pump 18.2 bbls © 3 BPM, 300 PSI built to 840 PSI, pressure bled off - Pull up hole testing intervals above packer with no 6 -5/8" casing integrity results - POH t/ 2001 RKB' pressure test above packer/ 2000 PSI - held OK Operations Summary PTSM - Pressure test 6 -5/8" casing from 10,269' to surface - bad test - Continue w/ abandonment of wellbore - PU HES EZDrill squeeze packer, set © 10,299' , sting into squeeze packer for cement squeeze of production zones - Establishment of injection profile resulted in 3000 PSI pressure test w/ no bleed off below EZDrill © 10,299'. Called Tom Maunder (AOGCC) - Tim Lawlor (BLM) to advise of conditions - Obtained approval from agencies to lay in a 400' casing cement fill - Pumped 15BBIs 15.7ppg Class G cement. 9/0' 00:00: - 10/1/2008 00 00' Operations Summary PTSM. TOOH up to 9143', Circ at 8 BPM 2000 PSI. Change out power tongs. TOOH and LD star guide. - Tag and pressure test f/ 6000' to top of cement plug @ 9844' witnessed by Tim Lawlor, BLM - Tested to 2300 PSI/ 30 minute hold 1 200 t00 00 :00 3nr , f Operations Summary PTSM - Circulate in 9.4 PPG KCL Brine f/ TOC t/ 6613' - Test and chart casing t/ 2300 PSI for 30 minutes against RTTS packer and cement abandonment plug top @ 9844' 10/2/2008 00:00 -- 10/3/200800:00 Operations Summary PTSM PU EZDrill BP RIH & set © 6545' ORKB - PU 3 -1/2" IBT muleshoe joint & crossovers , TIH, t/ top of BP, tag, set 5k on BP - PU 3' above bridge plug - Mix and pump 80 sacks 15.8 PPG LXT Class G cement - Swap lease water t/ 9.4 PPG KCL kill weight fluid t/ 2000' Chevron W IP Chevron - Alaska %. Daily Operations Summary Well Name SRU 41 -33 ■ 0O8 00:00 - 10/4/2008 Legal Well Name SWANSON RIV UNIT 41 -33 00:00 Lease Surface UWI ChevNo FEDA028339 5013310166 QA5339 Original RKB (ft) Water Depth (ft) 15.00 Operations Summary PTSM - RU E -line, RIH tag cement @ 6010', witnessed by Mr. Bob Noble AOGCC - PU BP set © 2218' - PU TCP perforating guns, fire f/ 2189' 2209', all fired - Establish injection rates, .5 BPM 75 PSI, 2 BPM 350 PSI, 4 BPM 650 PSI, No communication to 6 -5/8" x 13 -3/8" annulus. RIH BP, set @ 1950' 10141200$•,00:00 -10/512008 00: 0` ... Operations Summary PTSM - Mr Jim Regg approved exemption for BOP test - Cement shoe, initial pressure 700 PSI - Pump 74 bbls 16.2 PPG Class G cement - displace bore to 9.4 PPG KCL - Pressure test cement plug & 6 -5/8" casing f/1790' to surface to 2300 PSI - Good, witnessed by Mr. Tim Lawlor, BLM - Mr. Bob Noble AOGCC 106 /20 0,& 00:00 - 10/6/200000:00 Operations Summary PTSM - Set BP © 520' - MU 1- 9/16" x 6' tubing punch gun, RIH t/ 501/ t507', all shots fired - Could not break circulation - MU 10' x 1- 9/16" tubing punch, all shots fired f/ 400' t/ 410' - Break circulation cleaned up after 40 bbl's - Mix and pump 50 bbls 15.8 ppg Class G neat cement - Return weight was 15.6 PPG - Surface abandonment perforating and cement job witnessed by Mr. Tim Lawlor, BLM. RD. {.n , 1018/2008 0000= 10/71200800:00 .r,�..F � � :•. . Operations Summary PTSM - Prepare rig for mob to next well project 1 017 /200800:00 - 10181206 0.d € "00 Operations Summary Demobe rig to SCU 312 -09. 101812008 00:00 - 10/9/2008 00:00 Operations Summary Demobe rig to SCU 312 -09. �; r 0/912008 00:00." _. Operations Summary DeMobe rig to SCU 312 -09 - Last report for SRU 41 -33 11 MEMORANDUM TO: Jim Regg • P. I. Supervisor FROM: Bob Noble Petroleum Inspector Oct 3, 2008 Bottom Plug: I met with Chevron's rep Jason Bradford and looked over the pressure recorder chart and the rig records on the bottom plug set on this well. The records showed the cement retainer was set at 10,299' in the 6 5/8" pipe. 15 barrels of cement were placed on top of the retainer. The TOC was tagged at 9844'. The pressure test was for 30 min. at 2500 psi. The pressure test looked good. A BLM rep witnessed this plug. Intermediate Plug: A bridge plug was set at 6550' in the 6 5/8" pipe. 17 barrels of cement were placed on top of the bridge plug. I witnessed a wireline tag of this plug. TOC was found to be at 6010'. I had the wireline operator tag the cement several times and it looked to be hard and at the same place each time. Oct 4, 2008 Surface Casing Shoe Plug A bridge plug was set at 2218' in the 6 5/8" pipe. A cement retainer was set at 1950'. Perforations were shot in the 6 5/5" pipe above the bridge plug. Cement was squeezed into the perfs around the surface casing shoe. Remainder of the cement was placed on top of the cement retainer for a total of 70 barrels of cement pumped. A rep. from BLM and I both witnessed a wireline tag and pressure test of the plug. TOC was found to be at 1790'. A 2300 psi pressure test was performed for 30 min and it held pressure. Attachments: none State of Alaska Alaska Oil and Gas Conservation Commission O01t) 3 DATE: Oct 3 -4, 2008 SUBJECT: Plug and Abandonment SRU 41 -33 Chevron PTD — 161 -003 2006 RE: Chevron: Swanson River Unit: SRU 41 -33 AOGCC Approval Request Page 1 of • • a . Maunder, Thomas E (DOA) From: Newell, Jack R [FEP] [JNewell @chevron.com] Sent: Wednesday, October 01, 2008 6:01 PM To: Maunder, Thomas E (DOA) Cc: Harness, Evan; Hammons, Darrell; Walsh, Chantal [Petrotechnical]; Bothner, Joseph A.; Bradford, Jason S (Jason.Bradford); Tyler, Steve L Subject: RE: Chevron: Swanson River Unit: SRU 41 -33 (161 -003) AOGCC Approval Request Mr. Tom Maunder. Re: Swanson River Unit SRU 41 -33 Current status: Cement fill plug @ 9844' Plan Forward: Progress: - Cement plug has been tagged/ 9844' - pressure tested to 13 PPG EMW and BLM witnessed. - Well was turned over to 9.4 PPG KCL kill weight fluid to 6300' Gas Storage sands * PU EZDrill Bridge Plug RIH and set @ 6546' * PU Drill Pipe RIH to set a cement casing fill to 6065' (Approximately 15 Bbls Class G Cement w/ Gas block additive) 13 -3/8" Shoe containment: * PU EZDrill BP set @ 2210' * PU EZDrill SVB and set @1950' * Pump 18 Bbls, Class G Cement, SD - PO EZDrill SVB, lay 100' cement on top of EZDrill SVB WOC, Tag TOC, Pressure test to 13.0 PPG EMW. Chart record results ND BOP/ NU Dry hole tree. Release rig to next well. This has been noticed by BLM - Mr. Tim Lawlor who said he will be there in the morning. Jack R. Newell ❑ $B! I ❑(BEI $B!I El (B Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, Alaska 99501 -3322 Tel (907) 263 -7832 Fax (866) 401 0624 Mobile (907) 529 -5450 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] 10/6/2008 RE: Chevron: Swanson River Unit: SRU 41 -33 AOGCC Approval Request Jack, I acknowledge our conversation and your plan forward. Call or message any questions. Tom Maunder, PE AOGCC • • Mr. Tom Maunder, Per our phone conversation and verbal approval to proceed with the near plan forward, Re: Well Swanson River Unit SRU 41 -33 Page 2 of !t Sent: Tuesday, September 30, 2008 8 :06 AM To: Newell, Jack R [FEP] Cc: Harness, Evan; Hammons, Darrell; Walsh, Chantal [Petrotechnical]; Bothner, Joseph A.; Bradford, Jason S (Jason.Bradford); Tyler, Steve L Subject: RE: Chevron: Swanson River Unit: SRU 41 -33 (161 -003) AOGCC Approval Request From: Newell, Jack R [FEP] [mailto:JNewell @chevron.com] Sent: Monday, September 29, 2008 7:50 PM To: Maunder, Thomas E (DOA) Cc: Harness, Evan; Hammons, Darrell; Walsh, Chantal [Petrotechnical]; Bothner, Joseph A.; Bradford, Jason S ( Jason.Bradford); Tyler, Steve L Subject: RE: Chevron: Swanson River Unit: SRU 41 -33 AOGCC Approval Request Activity: - We RIH and seta HES EZDrill SVB Squeeze packer @ 10,299'. -We stung into the EZDrill SVB squeeze packer - establish injection profile - We attempted to establish injection rate and profile into the G & Hemlock zones - We had a result of a 3000 PSI test with no bleed off - Held tight below the EZ Drill squeeze packer Our near plan forward: * Unstring from the EZ Drill cement retainer @ 10,299' and circulate at least one BU * Pump a cement volume (13 BBLs) to provide for a 400' casing fill from the top of the EZDrill cement retainer @ 10,299' * POH 700' above calculated TOC - circulate surface to surface strokes at max rate * WOC - Tag top of cement - Pressure test cement plug * Continue to evaluate casing for plan forward. We will perform the near plan forward and update progress. Jack R. Newell ❑$B! I E(BD$B! (0(B Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, Alaska 99501 -3322 Tel (907) 263 -7832 Fax (866) 401 0624 Mobile (907) 529 -5450 10/6/2008 RE: Chevron: Swanson River Unit: SRU 41 -33 AOGCC Approval Reyrt • Maunder, Thomas E (DOA) From: Newell, Jack R [FEP] [JNewell @chevron.com] Sent: Monday, September 29, 2008 6:57 AM To: Maunder, Thomas E (DOA); Walsh, Chantal [ Petrotechnical]; Tyler, Steve L Cc: Harness, Evan Subject: RE: Chevron: Swanson River Unit: SRU 41 -33 AOGCC Approval Request Mr. Tom Maunder, Follow up per our phone conversation late evening Sunday September 28, 2008. While performing the pressure test of the 6 -5/8" casing string we were unable to obtain a pressure test on the casing. We will be perusing the original sundry (308 -312) procedure and continuing with the abandonment of Swanson River Unit Well SRU 41 -33. Have contacted Mr. Tim Lawlor with the BLM and he has also concurred with our plan forward to abandon this well. Mr. Lawlor said he would be on location to witness the placement of cement at the G & Hemlock zones. Jack R. Newell ❑ $B! I ❑(BEl $B! 1 ❑(B Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, Alaska 99501 -3322 Tel (907) 263 -7832 Fax (866) 401 0624 Mobile (907) 529 -5450 2 From: Newell, Jack R [FEP] Sent: Saturday, September 27, 2008 2:31 PM To: 'Maunder, Thomas E (DOA) ; Walsh, Chantal [Petrotechnical]; Tyler, Steve L Cc: Harness, Evan Subject: Chevron: Swanson River Unit: SRU 41 -33 AOGCC Approval Request Mr Tom Maunder, Follow up to voice mail to 907 -345 -0850 RE: Swanson River Unit SRU: 41 -33, Change of sundry procedure request. Well SRU 41 -33 was to be abandoned per sundry notice 308 -312. 9/29/2008 Page 1 of 2 RE: Chevron: Swanson River Unit: SRU 41 -33 AOGCC Approval Roest Page 2 of 2 We have performed the procedure summary to the step of obtaining USI -CE, GR, and CBL logs. Evaluation of the logs show the well is a candidate for future use rather than an abandonment. Forward Proposed Plan: 1. Pressure test 6 -5/8" casing. PU seal assembly previously pulled from well. RIH sting in and pressure test to 2000 PSI. POH. 2. Run Kill String in Well: PU/ RIH 3 -1/2" Kill String to 6000'. This will put the tail of the kill string below the top of cement © 5818'. 3. Release rig to next well. Evaluate well for future use. We would like to have approval of this plan forward Will copy BLM with this same proposed plan forward. Please reply to all this is addressed to. Thank you, Jack R Newell ❑ $B! I ❑ (B❑ $B!1 ❑ (B jnewell @Chevron.com Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage,Alaska99501 -3322 Tel 1 907 263 -7832 Fax 1 866 401 0624 Mobile 1 907 529 5450 Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7832. 9/29/2008 • CONSERVATION COMMISSION GAS Timothy Brandenburg UNOCAL PO Box 196247 Anchorage, AK 99519 Dear Mr. Brandenburg: DATED this 9/ of September, 2008 Encl. 5CAMED SEP 1 1 20D8 Sincerely, • Cathy P. Foerster Commissioner / SARAH PALIN, GOVERNOR / -72e41,„ 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Re: Swanson River Field, Hemlock /Undefined Oil Pool, SRU 41 -33 Sundry Number: 308 -312 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. 1. Type of Request: Alter Change approved Abandon ✓ + Suspend ❑ Operational shutdown Repair well ❑ Plug Perforations Pull Tubing ❑ Perforate New Pool ❑ Perforate ❑ Waiver ❑ Other❑ Stimulate ❑ Time Extension ❑ Re -enter Suspended Well ❑ casing ❑ program ✓ ❑ 2. Operator Name: Union Oil Company of California 4. Current Development Stratigraphic Well Class: Exploratory ❑ Service ❑ 5. Permit to Drill Number: 161 -003 ' ✓ ❑ 3. Address: P.O. Box 196247 Anchorage, AK 99519 6. API Number: 50- 133 - 10166 -00 7. If perforating, closest approach in pool(s) opened by this operation property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No to nearest 8. Well Name and Number: Swanson Riv Unit (SRU) 41 -33' ✓ 9. Property Designation: FEDA028339 [Swanson River Unit] ' 10. KB Elevation (ft): 175' MSL -KB ■ 11. Field / Pool(s): Swanson River / Hemlock Oil / Undefined Oil 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): ,11,131 Total Depth TVD (ft): ,11,131 Effective Depth MD (ft): 11,088 Effective Depth TVD (ft): 11,088 Plugs (measured): 11,088 (cement) Junk (measured): N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 2,104' 13 -3/8" 2,104' 2,104' 2730 psi 1130 psi Intermediate Production 11,133' 6 -5/8" 11,133' 11,133' 12120 psi 10160 psi Liner Perforation Depth MD (ft): See attached schematic Perforation Depth TVD (ft): See attached schematic Tubing Size: 3 -1/2" & 2 -7/8" Tubing Grade: 9.3# N -80 & 6.5# N -80 Tubing MD (ft): 10,599' Packers and SSSV Type: Baker "SAB" & Baker FHL Packer / N/A Packers and SSSV MD (ft): 10,333' & 10,529' / N/A 13. Attachments: Description Summary of Proposal Detailed Operations Program ❑ BOP Sketch ✓ 14. Well Class after proposed work: Exploratory ❑ Development Service ❑ ✓ ✓ 15. Estimated Date for 9/8/2008 Commencing Operations: 16. Well Status after proposed work: Oil ❑ Gas ❑ WAG ❑ GINJ ❑ Plugged ✓ Abandoned ✓ WINJ ❑ WDSPL ❑ 17. Verbal Approval: Date: Commission Representative: 18. I hereby certify that Printed Name Signature the foregoing is true and correct to the best Timothy C. Brandenburg of my knowledge. Title Contact Drilling Manager Jack Newell 263 -7832 - one 276 Date 8/28/2008 COMMISSION USE ONLY Conditions of approval: Notify Plug Integrity Other: j ,..;\ Commission so that a BOP Test ❑ ZQIR @ VIS L `V� "l P representative Mechanical % C ` Integrity v may witness Test ❑ Location Clearance CGk,Ai s S.C.K APPROVED THE COMMISSION + Sundry Number: a* �/" - a 9, V\CICCAS Su BY hQ ' R4ttA 1 sq Sa COMMISSIONER s., VCS . - o 8 1 epic v - Subsequent Form Required: Approved by:A O 0-6 Ce__ s e-- Date: -8 Ca L o STATE OF ALASKA -fir A l1(�. ALA. OIL AND GAS CONSERVATION COMMION APPLICATION FOR SUNDRY APPROVAMEPI & as Cons. Corn n“ Anchorage 20 AAC 25.280 Form 10-403 Revised 06/006 GINAL S BFI._ LF? 0 9 2008 Submit in Duplicate Chevron 1 10 • • OBJECTIVE: • Plug, isolate zones, & abandon onshore well, Swanson River Unit: SRU 41 - 33. PROCEDURE SUMMARY: 1 MIRU Drilling Rig 106, Tree off operation, ND Tree - NU BOP and perform AOGCC witnessed test 2 Remove 3 -1/2" production tubing above packer (Fishing Needs) 3 Scrape 6 -5/8" casing to depth, Run USIT log to depth for hole qualification. 4 Prepare and isolate by cementing procedure per 43 CFR 3160 and Section V of the Onshore Oil and Gas Order No. 1 and Onshore Oil and Gas Order Number 2, G -Zone & Hemlock production zones cement from 10,300' to bottom of perforated production. 70 Bbl's LXT cement planned to be pumped. Contingency: Depending on USIT log results. k � - � `�a �L ♦ If necessary, prepare and isolate by cementing procedure, the Tyonek64 -5 (gas storage) sands per 43 CFR 3160 and Section V of the Onshore Oil and Gas Order No. 1 and Onshore Oil and Gas Oreder Number 2. Perforate and squeeze if USIT shows severe bonding issues, or lay in a balanced cement plug plug casing across area. 28 Bbl's LXT cement planned to be pumped. 'DO t a � —4. ♦ y ces' � repare and isolate water disposal sands (ranging from 2,000'- 2,450' MD) per 43 CFR 3160 and Section of the Onshore Oil and Gas Order No. 1 and Onshore Oil and Gas Order Number 2. Perforate and squeeze as necessary per USIT evaluation. 30 Bbl's LXT cement planned to be pumped. 5 Prepare and isolate upper bore from lower areas per 43 CFR 3160 and Section V of the Onshore Oil and Gas Order No. 1 < and Onshore Oil and Gas Order Number 2. 50 Bbls, LXT surface plug planned to be pumped.D-O R4� a V' 6 Release Drilling Rig 106. A h� v ` . 7 Excavate cellar, cut off casing 5' below natural GL, set 13 -3/8" identification plate, place GPS coordinates specifying coordinate system in daily report, bury plate. C L .L Co( r ik t2 ---� `&3a \\ " C,GS° \mac `ceG S r C:tk, \co\--t_ , NG 'r'C3 \ ,7,..AEC° c_t ckt Cam" , � V..1(°\ RUC Onshore Operation Swanson River Unit Well # SRU 41 -33 8/12/08 SRU 41 -33 REVISED BY: CVK 8 -28 -08 Size Type Wt/ Grade/ Conn ID Top Btm Cement Sacks Cement Top 22 13-3/8" 6-5/8" ._....______...... Conductor Surface Inter. Cas 114.8#, B 54.5, J55, BTC 28#, P110, BTC 20.813 12.459 5.666 Surf Surf Surf 28' 2104' 11,133 2000 2528 Surf 5818' Completion 3-1/2" Prod Tub 9.3#, N80, AB Mod 2.992 Surf 10599' 2-7/8" Prod Tub N80 6.5# 8 RND 2.165 10471 10599 Completion Jewelry Detail Depth Length ID OD Item 16' 2.992 3-1/2" Hanger 1 1580 2.867 5.968 3-1/2" GLM #1 2 2671 2.867 5.968 3-1/2" GLM #2 3 3493 2.867 5.968 3-1/2" GLM #3 4 4244 2.867 5.968 3-1/2" GLM #4 5 4872 2.867 5.968 3-1/2" GLM #5 6 5240 2.867 5.968 3-1/2" GLM #6 7 6032 2.867 5.968 3-1/2" GLM #7 8 6590 2.867 5.968 3-1/2" GLM #8 9 7115 2.867 5.968 3-1/2 » GLM #9 10 7677 2.867 5.968 3-1/2" GLM #10 11 8235 2.867 5.968 3-1/2" GLM #11 12 8795 2.867 5.968 3-1/2" GLM #12 13 9313 2.867 5.968 3-1/2" GLM #13 A 10317 Baker PBR w/ 10' Seal Assembl B 10333 Baker "SAB" Packer w/ Millout Extension C 10,375 2.867 3.500 3-1/2" OTIS "XN" Profile Ni. . e D 10408 3-1/2" Wireline re-entry guide 2-7/8" Non-Serviceable Completion - Was left after fishing, did not want to loose well if fishing went bad E 10471 17.39' 2.165 2-7/8" Tubing Top (4' Tubing Pup and 13.39' tubing Above Mandrel F 10488 8 2.347 5.500 Camco MM Mandrel G 10529 14 Baker FHL Packer H 10567 6 2.313 Otis "2" S" Profile Nipple 10599 1 2-7/8" Baker Shear Out Sub 10725 Reduced ID 6-5/8" Casing (Collapsed) Perforation Data Dog egs ZONE TOP BTM Shot Condition 10,674' 11,074' 4SPF 4 Ea 1/2" Jet Holes per/ foot, for DST 10,618' 5SPF 5 Ea 1 ,4" Jet Holes H2 & H3 10,674' 10,715' 4SPF 12/28/1993: 0 Phasing FISH None Reported A 13-3/8"- 2104' Baker Stage Collar 2008' TOC 5818' 6-5/8". 11,131' A RKB to Level LW) = KB le GL: 16t7 9 10 11 12 3 4903 4933' 30 Tub Patch 5018' 5048 30' Tub Patch 5083' -5113' 30' Tub Patch 5192' 5207' 15' Tub Patch 5701 5731 50' Tub Patch 5802' -5832'30' Tub Path A C 6 • CMT Staging Color 6733' PBTD =11,088' TD = 11,131' MAX HOLE ANGLE = 2 (d). 5231 HOMCO CSG Patch 2065' - 2085' OCTG Rotating Hours 22" 47 Rotating Hours 13-3/8" 288 Rotating Hours 6-5/8" 40 Rotating Hours Tubing "0" Rotating Hours WBD SRU41-33 3 10 94.doc Swanson River Unit SRU 41-33 Completed 03/10/1994 Onshore Operations Swanson River Unit Well SRU 41-33 Last Comp Page 1 of 2 JRN RKB to Sea Level (MUM= 179' Maker Plate 155' : GL: 160' TOC 5818' 6.5 /8" "- 11,131 Swanson River Unit SRU 41 -33 Proposed Onshore Operations Swanson River Unit Well SRU 41 -33 TO Be Completed Fall 2008 9.4 PPG KCL 9.4 PPG KCL IBP 2490' CR 5600" PBTD = 11,088' TD = 11,131' MAX HOLE ANGLE = 2 (ail 5231 OCTG Rotating Hours 22" 47 Rotating Hours 13 - 3/8" 288 Rotating Hours 6 - 5/8" 40 Rotating Hours Tubing "0" Rotating Hours WBD SRU41 -33 Proposed.doc Size Type Wt/ Grade/ Conn Dog egs Conductor .......... ............................... Surface .......... Inter. Cas Completion 3 -1/2" Prod Tub 9.3 #, N80, AB Mod 2.992 Surf 10599' 2 -7/8" Prod Tub N80 6.5# 8 RND 2.165 10471 10599 Completion Jewelry Detail # Depth Length ID OD Item A 10317 Baker PBR w/ 10' Seal Assembly B 10333 Baker "SAB" Packer w/ Millout Extension C 10,375 2.867 3.500 3 -1/2" OTIS "XN" Profile Nipple D 10408 3 -1/2" Wireline re -entry guide 2 -7/8" Non - Serviceable Completion — Was left after fishing, did not want to loose well if fishing went bad E 10471 17.39' 2.165 2-7/8" Tubing Top (4' Tubing Pup and 13.39' tubing Above Mandrel F 10488 8 2.347 5.500 Camco MM Mandrel G 10529 14 Baker FHL Packer H 10567 6 2.313 Otis "2" S" Profile Nipple I 10599 1 2 -7/8" Baker Shear Out Sub 10725 Reduced ID 6 - 5/8" Casing (Collapsed) Page 1 of 2 114.8#, B 54.5, J55, BTC 28# P110, BTC 20.813 . . . . . . . . . . . . . . 12.459 5.666 Top Btm Cement Sacks Surf ............ Surf Surf Perforation Data JRN 2000 2528 Cement Top Surf 5818' ZONE TOP BTM Shot Condition 10,674' 11,074' 4SPF P &A 2009 10,618' 5SPF P &A 2009 H2 & H3 10,674' 10,715' 4SPF P &A 2009 FISH None Reported Job - Plug & Abandonment Location - SRU 41 -33 Rig - Nabors #106E NABORS 106E BOP DATA Chevron Choke Line I 1:11141 • it "It pas 191/RI 1fl1 fl 1 Iq1 Kill Line Stack: Annular: Ram: Ram: Ram: Kill line: Chock line: Size 13 -5/8 in Pressure Rating 3000 psi Nace Trim Yes Make /Model Shaffer Spherical Pressure Rating 3000 psi Closing Volume Opening Volume Make /Model Shaffer SL VBR Pressure Rating 5000 psi Closing Volume Opening Volume Make /Model Shaffer SL Blind Pressure Rating 5000 psi Closing Volume Opening Volume Make /Model Shaffer SL Pipe Pressure Rating 5000 psi Closing Volume Opening Volume Line size 2 inch Valve (1st) Manual Valve (2nd) HCR Line size 3 inch Valve (1st) Manual Valve (2nd) HCR Matting GL Fnrm nRi C; -01 Rpvicpri Angust /9nnR Total Volume = Casing Make /Model ShafferT -55L1 Bowl: Pressure Rating 3000 psi Closing Unit Make Academy Model Number I-1180T Designed Pressure Rating 3000 Accumulator: Number of Bottles 12 Gallons /Bottle 15 Total Volume 180 Pre - Charge Pressure 1000 Percent Useable Fluid 67 Useable Volume 121 Nitrogen: Number of Bottles 4 Bottle Height 15 Average Pressure 2600 Equivalent Gallons of Useable Fluid /Bottle 10 Useable Capacity 40 LOG TYPE RUN ► NO. INTERVALS SCALE survey 1 1 well tests core desription 1 cored intervals core analysis 2) y p v1 .. C.. 1 -- r (I } 2., i0 coo' °-;1-5 3 i 5 A .. LOG • S' 0061 -- �. 1 o s I 5•04^� Lo) 4) c �- � I I 1 17.1 -- in O el d `r 5) ) C G tt�,..— N Q ��.,... \ r H o �b (-, cy 5 a 0 O r t i 3 -- � S 7 - 3 vvv A c 6 ' CI) 1 / 4 k i tb.--8) eke°. I '76- If (93 8) -- 1 3 0 ' --- L1000 ' 12 e hallo Al J. Lt 1 rc.c,'Fv' / 0 07 00 f% 10j V A a s. / i 6o - I b Y� ` �� 11 ' .__ 2- t , 12) ...t ✓� ac d 4 PQ. CCrJ 1 Ib &oa -- /6900' 13) ,,,2v . 9 .-• & o n °' --- to '130 , PAIIIVISIIIL. u 14) • 16) 17) 18) 19) CC GEOLOGICAL MATERIALS INVENTORY LIST ( check off or list data as it is received ) 407 1 drilling history survey 1 1 well tests core desription 1 cored intervals core analysis I dry ditch intervals digital data WELL NAME SIZJ `41-33 (J33 6o COMPLE ,� IOI' �is'ir� r _ j CO. CONTACT Ck_ E o' S n o' & . N E o e o PERMIT ar 1 - 03 1. Operations performed: Operation shutdown _ Stimulate _ Plugging _ _ Perforate — Pull tubing _ _ Alter casing_ Repair well X_ Pull tubing _ Other_ _ 2. Name of Operator Union Oil Company of Califomia (Unocal) 5. Type of Well: Development X_ Exploratory _ _ Stratigraphic__ Service -- 6. Datum elevation (DF or KB) 175' KB feet 3. Address P.O. Box 196247 Anchorage, AK 99519 7. Unit or Property name Swanson River Unit 4. Location of well at surface 850' South and 740' West from the NE Corner, Sec. 33, T8N, R9W, SM At top of productive interval Same as above At effective depth Same as above � I At total depth Same as above 8. Well number SRU 41 -33 9. Permit number /approval number 61- 0003/93 —317 10. API number 50- 133 - 10166 -00 11. Field /Pool Swanson River — Hemlock 12. Present well condition summary Total depth: measured 11,133' feet Plugs (measured) true vertical 11, 133' feet Effective depth: measured 10,720' feet Junk (measured) Collapsed casing @ 10,720' true vertical 10,720' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 22" Yes 28' 28' Surface Intermediate 2104' 13 -3/8" 2000 sx 2104' 2104' Production 11,131' 6 -5/8" 2528 sx 11,131' 11131' Liner Perforation depth: measured 10,618' (W.S.O.); 10,674' 10,764'; reperforated 10,674' true vertical Same as above Tubing (size, grade, and measured depth) See Schematic RECEIVE D Packers and SSSV (type and measured depth) See Schematic APR 1 1 1994 13. Stimulation or cement squeeze summary Alaska Oil & Gas Cons. Commission Intervals treated (measured) None Anchorage Treatment description including volumes used and final pressure None 14. Representative Daily Average Production or Injection Data Oil—Bbl Gas —Mcf Water —Bbl Casing Pressure Tubing Pressure Prior to well operation 222 261 1997 1100 400 Subsequent to operation 261 526 2644 2040 425 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations x _ 16. Status of well classification as: Oil x _ Gas __ Suspended _ _ Service _ _ 17. I her cer`i fy t : f a r, •� ing i .�� a and correct to the best of my knowledge. / : iii ,. Signed G. Russell Schmidt Title Drilling Manager Date 04/04/94 Form 10 -404 Rev 06/15/88 STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS SUBMIT IN DUPLICATE SWANSON RIVER FIELD SRU 41-S3 ACTUAL 3/10/94 22" 028' 13 3/8" 02104' 6 5/8" N -80 BUTT FROM 10,306' TO CASING PATCH 02051' DV 02008' 6 5/8" 28# P -100 *MD FROM 10,306- 11,131' PERFS 010,618' PERFS FROM 10,674- 10,764' CASING COLLAPSED 010,720' 6 5/8" 011,131' X L . GAS LIFT MANDRELS AS DETAILED A) 3 1/2" 9.3# N -80 AB MOD 010,317' (313 JTS) B) 20' HOMCO CASING PATCH 2065' -2085' 1 1) BAKER PR W/10' SEAL ASSBY 010,317' 2 2) BAKER SAB PKR W /MILLOUT EXT. 010,333' 3 3) 3 1/2" 9.3# N -80 AB MOD 010,344' 4 4) OTIS "XN" NIPPLE 010,375' 5 5) 3 1/2" 9.3# N -80 AB MOD 010,377' 8 6) WIRELINE RE -ENTRY GUIDE 010,408' 7 7) 13.39' PC. 2 7/8" TBG 010,471' 8 8) 4' 2 7/8" PUP 010,484' s 9) CAMCO MM MANDREL 010,488' l0 10) 2 7/8" PUP 010,496' 11 11) 2 7/8" 6.5# N -80 8RD 010,497' 12 12) BAKER "FHL" PKR 010,529' 13 13) 2 7/8" 6.5# N -80 8RD 010,535' 14 14) OTIS "S" NIPPLE 010,567' 15 15) 2 7/8" 6.5# N -80 8RD 010,568' 15 16) 2 7/8" BAKER SHEAROUT SUB 010,599' RECEIVED APR 1 1 1994 Aiaska %ci & Gas Cons. Commission TD 0 11,131' Anchorage DAY 1 (02/13/94) 11 -3/4" @ 2104' 6 -5/8" @ 11,131' 8.6 KCL BRINE OPERATIONS COMMENCED ON SCU 41 -33 AT 14:00 HRS ON 2/13/94. MOVE RIG FROM SCU 21A-4 TO SCU 41 -33. DAY 2 (02/14/94) 11 -3/4" @ 2104' 6 -5/8" @ 11,131' 8.5 KCL BRINE COMPLETED MOVING RIG KILL WELL, WELL ON VACUUM. R/U CHEMICAL CUTTER. DAY 3 (02/15/94) 11 -3/4" @ 2104' 6 -5/8" @ 11,131' 8.5 KCL BRINE CUT TUBING AT 10427'. N/D TREE, N/U BOP'S TEST SAME. HAD NUMEROUS PROBLEMS W /LOCK DOWN SCREWS. DAY 4 (02/16/94) 11 -3/4" @ 2104' 6 -5/8" @ 11,131' 8.5 KCL BRINE SCU 41 -33 POOH W /COMPLETION. L/D TUBING. FOUND 4" HOLE THROUGH GAS LIFT MANDREL AT 5995'. CHEMICAL CUT AT 10427' DID NOT CUT. END OF TUBING BADLY COLLAPSED AND CORRODED. TOP OF FISH 10453'. RIH W /O.S. PICKING UP DRILLPIPE. DAY 5 (02/17/94) REC E' V E D 11 -3/4" @ 2104' 6-5/8" @ 11,131' APR 1 1 1994 8.5 BRINE itaska Oil & Gas Cons. Commission Anchorage RIH W /O.S. P/U DRILLPIPE. WORK OVER FISH TO 10,466'. POOH RECOVERED 2 -7/8" TUBING COLLAR WITH 2.5" OF CORRODED TUBING. DAY 6 -9 (02/18-21/94) 11 -3/4" @ 2104' 6 -5/8" @ 11,131' 8.5 BRINE RIH W /OVERSHOT, TAG FISH AT 10,467'. ATTEMPT TO LATCH TUBING NEG. RESULTS. POOH RECOVERED THREE PIECES OF TWISTED JUNK TUBING. THE DECISION WAS MADE TO STOP FISHING AND COMPLETE THE WELL DUE TO THE HIGH RISK OF JUNKING THE COMPLETION AND NOT BEING ABLE TO PRODUCE THE WELL. RIH WITH 6 -5/8" CASIHG SCRAPER TO 10,400'. POOH L/D DRILL PIPE. RAN 3-1/2" GAS LIFT COMPLETION STRING. SPACED OUT LANDED COMPLETION. RAN "N" TEST TOOL SET IN "XN" NIPPLE AT 10378'. PRESSURIZED TUBING AND SET PACKER AT 10,340'. TEST TUBING TO 3000 PSI, ATTEMPT TO TEST ANNULUS TO 1500 PSI WITHOUT SUCCESS. PULLED "N" TEST TOOL. UNSCREW FROM ANCHOR AND POOH WITH COMPLETION. RIH WITH RTTS PACKER TO LOCATE CASING LEAK. DAY 10 (02/22/94) 11 -3/4" @ 2104' 6 -5/8" @ 11,131' 8.5 BRINE FOUND LEAK BETWEEN 2073' AND 2078' NEAR CASING PATCH FROM PREVIOUS W.O. POOH L/D R.T.T.S. RAN DIALOG CASING CALIPER FROM 10270' TO SURFACE HAD PROBLEMS WITH LOG. NO APPARENT HOLES BUT SOME CORROSION AROUND 6200'. MAKE GAUGE MILL AND SCRAPER RUN TO 2245'. TEST BOPS. DAY 11 (02/23/94) 11 -3/4" @ 2104' 6 -5/8" @ 11,131' 8.5 BRINE CONT. TEST BOP'S. WAIT 9 HRS ON HOMCO CASING PATCH. P/U 20' PATCH. SET PATCH FROM 2065' TO 2085'. POOH W /SETTING TOOL. DAY 12 (02/24/94) 11 -3/4" @ 2104' 6 -5/8" @ 11,131' 8.5 BRINE POOH. L/D TOOLS. WAIT 17.5 HRS FOR RESIN ON PATCH TO SET UP. RIH W /RTTS SET AT 2120'. TEST 2120' -0' TO 1500 PSI, OK. RIH W /RTTS. RECEIVED APR 1 1 1994 Adska Oil & Gas Cons. Commission DAY 13 -14 (02/25- 26/94) 11 -3/4" @ 2104' 6 -5/8" @ 11,131' 8.5 BRINE RIH W /RTTS. SET AT 10,300' TEST CASING TO 1500' PSI. POOH. RIH W /GAS LIFT COMPLETION. LATCH ANCHOR SEALS INTO PACKER, SHEAR OUT, SPACE OUT AND LAND HANGER. RUN PLUG TEST ANNULUS TO 1500 PSI. POOH W /PLUG. N/D BOP'S. N/U TREE TEST TO 5000 PSI. RELEASE RIG AT 16:30 HRS ON 2/26/94. MOVE TO SCU 33 -5. FINAL REPORT. RECEIVED APR 1 1 1994 Alaska 011 & Gas Cons. Commission Anchorage 1. Type of request: Abandon _ Suspend _ Operations shutdown _ Re —enter suspended well Alter casing Repair well X Plugging _ lime extension _ Stimulate _ Change approved program _ Pull tubing _ _ Variance _ Perforate _ Other 2. Name of Operator Union Oil Company of California dba Unocal 5. Type of Well: Development X Exploratory _ Stratigraphic _ service _ 6. Datum elevation (DF or KB) 175' K.B.. feet 3. Address P.O. Box 196247 Anchorage, Alaska 99519 -6247 7. Unit or Property name Swanson River Unit 4. Location of well at surface 850' South & 740' W from the N.E. Comer Sec. 33, TBN, R9W, S.M. At top of productive interval C ��� R Same as above " � At effective depth Same as above NOV 1 8; 93 3 At total depth iasa Oil & Gas Cons. Commission Same as above 8. Well number SRU 41 -33 9. Permit number ' / 10. API number is /� 6 50 -133 — 496-00 11. Field/Pool Swanson R emlock 12. Anchora Present well condition summary / Total depth: measured 11.133' feet Plugs (measured) true vertical 11,133' feet /� / 4/ ri 4 Effective depth: measured 10,720' feet Junk (measured) Collapsed casing @ 10,720' true vertical 10,720' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28" 22" yes 28" 28' Surface Intermediate 2,104' 13 3/8" 2,000 sxs 2,104' 2,104' Production 11,131' 6 5/8" 2,528 sxs 11,131' 11,131' Liner Perforation depth: measured 10,618 (W.S.O.); 10,674 to 10,764'; reperforated 10,674' to 10,715' true vertical Same as above Tubing (size, grade, and measured depth) 2 7/8" 6.5# N -80 to 10,600' Packers and SSSV (type and measured depth) 6 5/8" Baker Model FH packer at 10,567' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation November 29, 1993 15. Status of well classification as: Oil X Gas _ Suspended _ Service 16. If proposal was verbally approved Name of approver Date approved 17. I here cert that t = foil •' g is t' = -nd correct to the best of my knowledge. Signed 1 � tLU ��A G Cl Q � � � E�. Date 1 8 • AhN • 'i.3 'i.3 9 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may Plug Integrity _ BOP Test _ Location clearance Mechanical Integrity Test Subsequent form required Original Signed By David W. Johnston Approved by the order of the Commission witness _ 10 — ?104 Copy 2' Y" 7 , Approval No. . --3/7 / Approved Returned ' f " Commissioner Date if/ z- L/ 9 3 Form 10 -403 Rev 06/15/88 STATE OF ALASKA A. AND GAS CONSERVATION CC AISSION APPLICATION FOR SUNDRY APPROVALS SUBMIT IN TRIPLICATE Swanson River Field SRU 41 -33 Workover Procedure 11/19/93 1. Rig up electric line and jet cut tubing if 10,500'. MIRU. Kill well. Set BPV. Nipple down tree and nipple up B.O.P. Test B.Q.P. to 5,000 psi. Retrieve tubing. 6. Fish and recover packer from 10,528' Rill with new completkm string. Pressure test tubing/casing annulus to 3,000 psi. 9. Install BPV; nipple down B.O.P. Nipple up tree; pressure test to 5,000 psi. 10. Release Rig. RECEIVED NOV 13 1993 Alaska Oil & Gas Cons. Commission Anchorage 22" r, 28' 13 3/8" @ 2,104' 6 5/8" 24# N -80 Butt from 10,306' to casing patch 0 2051' DV 0 2008" 6 5/8" 28# P -100 * rnd from 10,306' to 11,131' Casing Collapsed 0 10,720' 6 5/8" @ 11,131' swArisori RIVER FIELD WELL # SRU 41 -33 PROPOSED TD AT 11,131'? 11/19/93 Gas Lift Mandrels as Specified 3 1/2" 9.3# N -80 Buttress Tubing BAKER 6 5/8" "SAB -3" PACKER @10,500' Otis "X" Nipple PERFORATIONS 10,618' PERFORATIONS 10,674 - 10,764' RECEIVED NOV 18 1993 Alaska Oil & Gas Cons. 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Mal _ all _s•N _•.1_,144 (A•• -• MS= OK IN .3MSIS •__I r' rar•r _ _•_•___w ole.t _II MIMEO W NI rr a_E_s_- ESa__ -_I .: ______ -I •••.11 - r _I ■_______ _E - -- _w. --_ •••_r.. -••• SIJ_ --_I _W_ ±rr__ - •_- s- •••E•1 r am= _r so as am _•______IM NO 411 iNI•W WE WI WI Ma•-a_M-__r •_•. a•___IM_•1 IOW- a _ - _ __I __.•__ - __I • •r..•___ss_ • <♦ 40 MI 11141 N PO • Y N r .• i • r 11 •. • -�. a • • 103 • • • a s • • 1 v V M NIA ♦ • 11 •••• .1501.211' :�- 5115.14► -- 1411.55' -- 1501.15' -- 1500.00• 10411.44' - 10511.11 -- 10311.01' TU11NC HEAD 1tf6INC HANCE1 tut Fit c*sSISC01 .112 115. 2 4 6.5 180 0.. 18C. 2)1" PIP CAMCO NM NANOREI , f r�+nh 2i ~PUP 19 OS.- 2 fr 6.5 * N•10 e.. TIC. VA 2-13. ' CAMCO N N MANDREL Du"' `f 23111P • 41 AS. Z• 4 LPN •110 10. TIC. ZWPIIP - CAMCO AN MANDREL ' r ZZ'PUP 3Z 11S. 2 7s 6.5'11.10 t1C. 2WPUP - CANCO NN MANDREL , t.•.t t ;:t t' i PUP 31 JIS.• 2 t. 6.5`~•101.e TIC. 24• PUP - CASCO NN MANDREL _ r r „tail, , , 1 - 2 K' PUP 31 J r S. 2A' 6.501110 1618. VP PUP • 1 .2 es•us - CAMCO NM MANDREL , 2 13 • Fss _ 24' PUP 1 JT. 27." 6.5 N • eO e.AAIC. - 6 h'; 2WIARER MOOR ENE PAR. 2.44 1 it 2•• CV N•80 1a. TIC. - OJ.IS S' NIPPLE Postpile 1.1.111 �1 1051132° R ECEIV��A� out sup. NOV NOV Q y ±� n i 8 ►J:1 -. C&Siti tat I Gid & Gas G s. NC AY�1 11.4.13 10? 01 FOC 11011' • Aube ge SRu 41 •33 i �• - .mom KILL LINE 3" 5000 psi ANNULAR BOP 10" 3000 psi PIPE RAMS 10" 5000 psi BLIND RAMS 10" 5000 psi DRILLING SPOOL 10" 5000 ps PIPE RAMS 10" 5000 p si I LLDL BOP STACK 10" 5000 psi Contract Exhibit E OPTION 1 FLOW CHOKE LINE== 3" 5000 psi RECEIVED NOV 1 8 fl3 ;,. - 31 :a 011 & Gas Cons. Commission Anchorage AREA: , Swanson ,River Field 4 PROPERTY: Swanson River Unit LOCATION AT TOTAL DEPTH: Straight Hole ELEVATION: 175' K.B. DATE: 11/83 BY: COMPLETION REPORT - REMEDIAL CHEVRON U.S.A: INC. DRILLED BY: Brinkerhoff Signal Inc's. Rig #31 DATE COMMENCED REMEDIAL WORK: 10/3/83 DATE COMPLETED REMEDIAL WORK: 11/4/83 LAND OFFICE: Anchorage ' LEASE NO: A- 028399 WELL NO: SRU'Y41 -33 API NO: 50- 133 - 1066 -00 T. L. PERRYMAN AREA SUPERVISOR SUMMARY TOTAL DEPTH: 11,133' PLUGS: 11,133' - 11,088' EFFECTIVE DEPTH: 10,725' collapsed casing DJG JDH Info Copy LOCATION AT SURFACE: 850' S & 580' W. of the. N.E. Cor., Sec. 33, T8N, R9W, S.M. CASING: 22" at 28' PERFORATIONS: 10,618' (W.S.0.) 13 3/8" at 2,104' 10,674' - 10,764' 6 5/8" at 11,131' REPERI: 10,674' - 10,715' MAY 3 0 1984 NEW PROJ. ENGR. Return Handle LCirc JSD DKC JSS SRII 41 -33 10/3/83 - 10/4/83 Accepted Brinkerhoff Signal, Inc.'s Rig #31 at 10:00 p.m. on 10/3/83. Completed up Rig #31. Rigged up Dresser Atlas. Perforated the 2 7/8" tubing at ith 4 -i" H.P.F. using a 2 1/8" slimkone gun loaded with circulating s. Rigged down Dresser Atlas. Attempted to kill well by circulating 470 bbls. fresh water down the tubing. Well continued to flow. Pumped 9.3 ppg. NaC1 water. 10/5/83 Pumped a total of 40 bbls. 9.3 ppg. NaC1 water down 2 7/8" tubing - tubing dead. 2 7/8" x 6 5/8" annulus still flowing with 200 psi. Pumped 100 bbls. 9.3 ppg. NaC1 water down annulus (no circulation out of tubing). Annulus still flowing with 200 psi. Set BPV, N.D. tree, N.0 Class III 5000# ROPE. 10/6/83 Tested pipe rams, blind rams, choke manifold, all valves and lines to 5000 psi. Tested Hydril to 2500 psi. Blair Wondzell (AOGCC) and Joe Russell (BLM) waived witnessing BOPE test. Pulled BPV. Filled tubing with 8.5 ppg. NaC1 water and gel. Pumped 130 bbl. 8.5 ppg. fluid mixed with 3 ppb. fine nut plug down 2 7/8" x 6 5/8" annulus at 1 bpm at 0 psi. Annulus continued to flow. Unsuccessfully attempted to plug leak by hesitating 15 minutes than pumping 1 bpm. Mixed and pumped an additional 2 ppb quick seal down 2 7/8" x 6 5/8" annulus. At 1 bpm had +10% returns after pumping 100 bbls. Continued to pump and hesitate quick seal. Annulus continued to flow. 10/7/83 Mixed and pumped 2 ppb quick seal and 2 ppb nut plug down 2 7/8" x 6 5/8" annulus through holes in 6 5/8" casing and back out 6 5/8" x 13 3/8" annulus. Established full returns - 6 5/8" x 13 3/8" annulus dead. Pumped down 2 7/8" x 6 5/8" annulus with returns out tubing and killed annulus. C. A. White ran in hole with 7/8" tool and did not locate plug in Otis pos. "2" S. nipple at 10,493'. Ran in hole to 10,638' and found plug in Otis pos "1" S nipple at 10,638'. Attempted to pull equalizing prong from plug without success. (Catcher filled with lost circulation material.) Dresser -Atlas perforated 2 7/8" tubing at 10,620' with 4 JHPF using a 2 1/8" slimkone gun loaded with circulating charges. Pulled out of hole with wireline. Closed blind rams to break lubricator apart, but the gun was not completely in the lubricator and the blind rams closed on the gun. Dresser Atlas pulled out of the rope socket while picking up to lift lubricator. Unsuccessfully attempted to engage gun with overshot. Hooked onto gun with bell nipple and pulled out of hole. 10/8/83 Unseated donut - released Brown cc safety joint at 10,560'. Laid down 331 joints 2 7/8" 6.5# N -80 tubing, 7 Camco mm mandrels, Otis "S" nipple pos. 2, Camco sleeve valve. 10/9/83 Ran in hole with Brown CC releasing tool on 3i" D.P. Tagged Brown CC safety joint at 10,607' (D.P. meas.). Attempted to engage packer unsuccessfully. Tool would pull free with 5,000# of pull. POOH to inspect tool. While pulling off bottom with 140,000# string weight low drum clutch chain broke. Blocks and D.P. dropped 70' to rig floor. Elevators remained latched suspending D.P. from rotary table. Installed and closed safety valve. Closed Hydril - secured well. Rig down 8/ hours for repairs. Pulled out of hole with D.P. 10/10/83 Completed POOH. Had 6 5/8" BOT H S 16 -1 packer and remainder of tubing on drill pipe. (Packer had released, but would not go below where it was set at 10,616' D.P.M. RIH with 5 5/8" bit and 6 5/8" casing scraper. Tagged obstruction at 10,720' (D.P.M.) (Note: Drill pipe measurements have been 47' deeper than original tubing detail. Corrected tubing tail depth to 10,720'.) Unable to ream down hole due to excessive torque. POOH with casing scraper. Replaced hydromatic boot. 1011/83 Dresser -Atlas attempted to RIH with vertilog tool. Tool too large to fit in 6 5/8" casing. Ran 5.5" gauge ring to 10,550'. RIH with Baker 6 5/8" model "D" drillable bridge plug to set at 10,533'. Charges did not go off. POOH with bridge plug to check setting tool. RIH with bridge plug and set at 10,533'. 10/12 /83 Rigged up Schlumberger. Ran ETT log and pipe analysis log from 10,548' to 100'. Rigged down Schlumberger. Ran and set Baker retrievamatic packer at 2,316'. Bled off + 150 psi of gas pressure from 6 5/8" x 13 3/8" annulus. Pressure tested 6 5/8" casing to 2,700' psi. Verified 6 5/8" casing compentency from 1,508' to bridge plug at 10,533' by repeat testing to 2,700' psi at 2,066' and 1,508'. Pulled packer from 2,316'. Set Baker retrievable bridge plug at 256' (above the estimated shallowest 6 5/8" casing leak). Tested bridge plug to 500 psi. Raised 5,000# Class III BOPE. Removed 3,000# tubing head. Installed 13 5/8" x 3,000# spacer spool and 3,000# x 5,000# adapter. 10/13/83 Nippled up Class III 5M BOPE. Tested 3F' pipe rams, blind rams, choke manifold and all valves and lines to 3,000 psi. RIH and retrieved bridge plug at 256'. Laid down 60 jts. of 31" D.P. RIH with Tristate spear. Engaged 6 5/8" casing at the 13 3/8" x 3,000# casing head. Weight indicator gained 7,000# when 6 5/8" casing with suspected part at 300' was pulled smoothly upward approximately 8'. Then the easing stopped when the uppermost casing collar, previously logged 10' below the wellhead approached the slips. Upstrain of 75,000# over the string weight failed to free the casing. The casing remained suspended in the wellhead, by the slips, when the upstrain was released. The spear was disengaged with the top of the casing stub at 12', which is approximately 1' below the 3P" pipe rams. The pipe rams could not be closed. Operations suspended. The casing head slips in the Shaffer KD head and were held in place with a snap keeper ring and did not allow the slips to pop out. 10/14/83 Resumed operations (down five hours). Ran in hole with open ended 3i" drill pipe and laid a 22 C.F. (19 SX.) Class "G" cement plug with 1/10% HR6L and .75% CFR- 2 to 15.8 ppg fresh water from 10,538' - 10,412'. POOH. 10/15/83 Ran in hole with open ended 3i" drill pipe and laid a 45 C.F. (24 SX.) Class "0" cement plug with 8% gel, 3% CaC12 with 33 C.F. fresh water from 298' - 250'. Cement failed pressure test. Formation took fluid at 14 BPM with no pressure. Worked through obstruction at 557'. POOH. Ran in hole with open ended 31" drill pipe and laid an 89 C.F. (43 SX.) Class "0" cement plug with 8% gel, 3% CaC12 and 65 C.F. fresh water from 313' - 193'. POOH. Ran in hole to 615'. Did not tag cement. Circulated out contaminated cement. POOH. Pumped 62 C.F. (33 SX.) Class "0" cement with 8% gel, 3% NaC1 and fresh water down 13 3/8" x 6 5/8" annulus. Displaced cement with 11 bbls. fresh water to 100'. 10/16/83 WOC. 81 hours gel. Ran in hole to 590'. Did not tag cement. Circulated out cement contaminated mud. Ran in hole with 3i" open ended drill pipe and spotted a high vise. 9.3 ppg gel /LCM pill 293' - 628'. POOH. Pumped 50 bbls. high vise. 9.3 ppg. LCM /gel mud down the 13 3/8" x 6 5/8" annulus. Pumped 62 C.F. (33 SX.) Class "G" cement with 8% gel, 3% CaC12 and fresh water down the 13 3/8" x 6 5/8" annulus. Displaced cement with 11 bbls. of gel /LCM mud to 100'. Had full returns. W.O.C. 8 hours. Ran in hole. Tagged cement at 104'. Tested cement plug and cement in 13 3/8" x 6 5/8" annulus to 500 psi. 10/17/83 Cut 6 5/8" casing at 42'. Nippled down 5,000 Class III BOPE. Engaged 6 5/8" casing with tristate spear at the 13 3/8" casing head. Removed 6 5/8" casing slips. Recovered 29' 6 5/8" casing (top of casing at 42'). Nippled up 5,000# Class III BOPE. Installed 3,000 psi accumulator. Tested Hyrdil to 2,500 psi. Tested 3i" rams, choke manifold and valves to 3,000 psi. Witness of test waived by Joe Russell (BLM) and Blair Wondzell (AOGCC). 10/18/83 Ran in hole with 9 1/4" washover shoe and tagged cement at 114'. Cleaned out cement to 138'. Ran in hole to 159'. Tagged obstruction. POOH. Washover tool had 9" of external wear on bottom of shoe. Ran in hole with tristate spear. Unable to pull 6 5/8" casing from 42' with 100,000# over string weight. POOH. Washed over cement stringers and cement 159' - 238'. POOH. Ran in hole with spear and recovered 246' of 6 5/8" easing from 42' to 301'. 10/19/83 - 10/20/83 Ran in hole with 121" bit and casing scraper. Cleaned out cement and cement stringers 188' - 298'. POOH. Ran in hole with 9" wash pipe with a 5 flat bottom mill and cleaned out cement and cement stringers from 301' to 365'. POOH. Ran in hole with mechanical cutter and attempted to cut 6 5/8" casing at 2,040'. POOH. Four of five knives on cutter were broken. Engaged 6 5/8" casing at 301' with spear. Failed to pull casing free with 40,000# over string weight. Ran in hole with mechanical cutter and cut 6 5/8" casing at 2,043'. Ran in hole with spear and recovered 1,738' of N -80, 24 #, Butt. 6 5/8 " casing from 301' - 2,035'. (Casing may be partially cut at 2,043'.) Recovered casing was heavily coated with scale and had a hole at +600'. Cleaned out casing to 2,035' with bit and scraper. Set Baker packers at 2,024', 1,063' and 502' and pumped down annulus. Did not locate leak in 13 3/8" casing from 0 - 502'. 10/21/83 Ran in hole with mechanical cutter to 2,048'. Cut 6 5/8" casing. POOH. Cutter carried a 2' piece of 6 5/8" casing to surface. Ran in hole with spear and engaged top of 6 5/8" casing at 2,037'. Failed to retrieve casing. POOH. Ran in hole with 10 5/8" overshot with 6 5/8" basket grapple and pack off. Engaged casing at 2,037'. Failed to free casing by jarring 60,000# over string weight. Pumped water down the drill pipe at 4.5 BPM with 300 psi which confirmedcasingter partially ext extension i 2,048'. POOH with overshot. Ran in hole with mechanical guide. Recut 6 5/8" casing at 2,048'. Failed to engage casing with spear. POOH. 10/22/83 Ran in hole with overshot and basket grapple. Failed to engage casing at 2,037'. P0011. Ran in hole with same overshot assembly with a 2' extension. Failed to free casing from 2,037' by jarring 75,000# over string weight. POOH. Ran in hole with 23' of 9" wash pipe and 9 sawtooth wash shoe to 2,060' without indication of obstruction. 10/23/83 Ran in hole with 8" pilot mill. Milled 6 5/8" casing 2,037' - 2,051'. POOH. Ran in hole with 8 3/8" overshot with 6 5/8" spiral grapple and stabilizing blades on 19' of 8 1/8" wash pipe. Worked overshot over casing stub at 2,051' - 2,059' by bumping the 50,000# string weight down. Sheared away from stabilized overshot at 2,059' by jarring 40,000# up. POOH. 10/24/83 Ran in hole and set Baker 13 3/8" full bore packer at 1,951'. Pressure tested 13 3/8" casing and shoe to 1,000 psi at 1,951' and 626'. Isolated 13 3/8" casing leak between 503' - 626' by pumping salt water at 31" BPM and 100 psi. Pulled packer at 1,951'. Ran in hole with open ended drill pipe to 751' and spotted a 20 bbl. gel /LCM high vis. pill. Pulled up to 626' and pumped 372 C.F. (200 SX.) Class "G" cement with 3% CaC12, 8% gel and 274 C.F. of fresh water. Displaced cement to 199' with 1 bbl. fresh water. Cement equalized at 184'. Displaced 101 C.F. of Class "G" cement out the 13 3/8" casing leak 503' - 626' with 175 psi pressure. Displaced 28 C.F. of Class "G" cement out the 13 3/8" casing leak with 225 psi pressure. Ran in hole with 12i" bit and casing scraper and cleaned out cement 368' - 620' and cement contaminated mud at 760'. Pressure tested 13 3/8" easing leak to 200 psi. 10/25/83 Ran in hole with dressing mill and dressed the 6 5/8" casing at 2,051'. POOH. Ran 241' (61" jts.) P -110, 23 #, 8rd and 1,754' (47 jts.) N -80, 24 #, Butt. 6 5/8" casing to stub at 2,051'. Set patch on 6 5/8" casing at 2,051'. Pressure tested casing and patch to 1,500 psi. Mixed and pumped 700 SX. (1,302 C.F.) of Class "G" cement with 8% gel and 2% CaC12 with fresh water up 13 3/8" x 6 5/8" annulus through stage collar at 2,008'. Displaced cement with 73 bbls. of mud to 2,008'. Bumped plug. Did not have cement returns to surface. Pressure tested 13 3/8" x 6 5/8" annulus to 300 psi. Nippled down Class III 5,000# BOPE. 10/26/83 Set 6 5/8" casing slips. Set and tested casing packoff. Installed tubing head. Nippled up BOPE. 10/27/83 Installed test plug. Tested BOPE and Hydril to 2,500 psi. Rams, valves and lines to 5,000 psi. Blair Wondzell (AOGCC) and Joe Russell (BLM) waived witnessing test. Removed test plug. Down 14i hours due to flywheel repair. 10/28/83 Tagged stage collar at 2,008' and cleaned out to 2,012'. Washed to 2,207'. Down 17i hours for engine repair. 10/29/83 Rig down 18 hours for engine repair. Circulated bottoms up at 3,000' and 7,000'. 10/30/83 Circulated bottoms up at 8,500' and 10,109'. Washed to 10,506'. Tagged obstruction, POOH, change BHA and RIH with globe junk basket. Rotated down from 10,506' to 10,518'. 10/31/83 POOH. Recovered 10" piece of stage collar closing dart in globe basket. Ran in hole with globe junk basket and cut 6' of core 10,518' - 10,524'. POOH. Recovered one casing cutter knife, 1 piece of stage collar and cement in globe basket. Ran in hole and cut 17' of core 10,524' - 10,541'. POOH. Recovered 1 piece of cement with globe basket. 11/1/83 Ran in hole with bladed mill with two junk baskets and drilled out retainer at 10,541', DPM, 10,553' W.L.M. RIH to 10,720' and unsuccessfully attempted to rotate. Blades hung up in perforations. Circulated bottoms up. POOH. Recovered small amount of retainer junk. Ran in hole to 10,720' with 3i" x 51" string mill. Could not rotate down due to excessive torque. 11/2/83 Displaced mud with lease water. POOH with string mill (mill scarred on outside taper at an O.D. of 5 3/8 "). Ran in hole with 2 7/8" tubing on 31" drill pipe. Could not get deeper than 10,725'. POOH. 11/3/83 Picked up BOP stack and changed rams from 31" to 2 7/8 ". 11/4/83 Tested 2 7/8" rams to 5,000 psi. Ran 315 joints 2 7/8 ", 6.5 #, N -80 8rd tubing to 10,600' with packer at 10,529' (see attached detail). Nippled down BOPE. Nippled up tree. Released rig 7:00 p.m., 11 -4 -83. 12/28/83 Reperforated from 11,674' - 10,715', 4 - 0.36" JHPF with Schlumberger's 2 1/8" Enerjet with 0 phasing. 1 Item KB - Tbg. head Tbg. hanger cut for Cossasco plug 112 jt. 2 7/8" 6.5# N -80 8rd tbg. pup Camco MM Mandrel w /dummy pup 79 jt. 2 7/8" 6.5# N -80 8rd tbg. TUBING DETAIL SRU 41 -33 Length Depth 19.50 1.00 19.50 3,478.90 4.00 8.22 3,503.20 .65 2,477.65 pup 4.12 Camco MM Mandrel w/ dummy 8.32 5,995.84 p .66 47 jt. 2 7/8" 6.5# N -80 8rd tbg. 1,480.61 pup 4.12 Cameo MM Mandrel w /dummy 8.32 7,489.55 p .66 32 jt. 2 7/8" 65# N -80 8rd tbg. 1,006.34 p 4.08 Camco MM Mandrel w /dummy 8.30 8,508.95 p .65 31 jt. 2 7/8" 6.5# N -80 8rd tbg. 928.05 p 4.05 Camco MM Mandrel w /dummy 8.31 9,500.00 p .67 31 jt. 2 7/8" 6.5# N -80 8rd tbg. 975.41 p 4.05 Camco MM Mandrel w /CEV 8.30 10,488.44 pup .65 1 jt. 2 7/8" 6.5# N -80 8rd tbg. 31.40 6 5/8" x 2 7/8" Baker Model FHL Packer 6.65 10,528.79 1 jt. 2 7/8" 6.5# N -80 8rd tbg. 31.65 Otis "S" nipple Pos. 1 w/2.313 ID 1.30 10,567.09 1 jt. 2 7/8" 6.5# N -80 8rd tbg. 30.93 2 7/8" Baker shear out sub .50 10,599.32 Landed at 10,599.82 32'.69' N M Z evM u Q ; 317.84' 1153.16' ass „�� K. 179' .41 j15' n_ L_ 104' TUBING HANGER 20” C©"1 0 FIRST JT. SAW TOOTH ON BOTTCM, NO COLLAR 23' ah,,, 325' .1 D.Y. 1160' • • wso soon' • w s o ssos' sass' • • • • • • _ I ss s' ssi o' • • • • • • i • tore TOP OF PLUG 0 2990' T.D. 3000' 92 JTS. EUE N -80 BUTTRESS HOLE IN CASINGG it 670', SQUEEZED WITH 300 SACKS DEMENT. 9 -17 -71 to 9 -27 -71 UNABLE TO SEAL. CEMENTED 3 N -80 0 28 ct_v'1Ck rha. .i Z/2.)' 4- JUNK: 21' OF PAIRED FORMED WIRE FROM STRIP JET, DEPTH UNKNG%4N SRU 41-33WD CASING a TUBING DETAIL SECTION 33 T.8 N. SM STANDARD OIL COMPANY OF CALIFORNIA J.W.W• AREA: Swanson River Field LAND OFFICE: Anchorage PROPERTY: Swanson River Unit WELL NO: SRU 41 - 33 LOCATION AT SURFACE: 850' S & 580' W. of the N.E. Cor. . , Sec. 33, T8N, R9W, S.M. LOCATION AT TOTAL DEPTH: Straight Hole ELEVATION: 175' K.B. DATE: 11/83 BY: ' COMPLETION REPORT - REMEDIAL CHEVRON U.S.A. INC. DRILLED BY: Brinkerhoff Signal Inc' s . Rig #31 DATE COMMENCED REMEDIAL WORK: 10/3/83 DATE COMPLETED REMEDIAL WORK: 11/4/83 LEASE NO: A - 028399 100 ,6 API NO: 50-133-1,8g-00 T. L. PERRYMAN AREA SUPERVISOR SUMMARY TOTAL DEPTH: 11,133' PLUGS: 11,133' - 11,088' EFFECTIVE DEPTH: 10,725' collapsed casing RECEIVED Alaska Oil & Gas Cons. Commission Ar:).ic rage CASING: 22" at 28' PERFORATIONS: 10,618' (W.S.O.) 13 3/8" at 2,104' 10,674' - 10,764' 6 5/8" at 11,131' REPERF: 10,674' - 10,715' 1984 ciL G SRII 41 -33 10/3/83 - 10/4/83 Accepted Brinkerhoff Signal, Inc.'s Rig #31 at 10 :00 p.m. on 10/3/83. Completed rigging up Rig #31. Rigged up Dresser Atlas. Perforated the 2 7/8" tubing at 10,478' with 4 -" H.P.F. using a 2 1/8" slimkone gun loaded with circulating charges. Rigged down Dresser Atlas. Attempted to kill well by circulating 470 bbls. fresh water down the tubing. Well continued to flow. Pumped 9.3 ppg. NaC1 water. 10/5/83 Pumped a total of 40 bbls. 9.3 ppg. NaC1 water down 2 7/8" tubing - tubing dead. 2 7/8" x 6 5/8" annulus still flowing with 200 psi. Pumped 100 bbls. 9.3 ppg. NaC1 water down annulus (no circulation out of tubing). Annulus still flowing with 200 psi. Set BPV, N.D. tree, N.0 Class III 5000# BOPE. 10/6/83 Tested pipe rams, blind rams, choke manifold, all valves and lines to 5000 psi. Tested Hydril to 2500 psi. Blair Wondzell (AOGCC) and Joe Russell (BLM) waived witnessing BOPE test. Pulled BPV. Filled tubing with 8.5 ppg. NaC1 water and gel. Pumped 130 bbl. 8.5 ppg. fluid mixed with 3 ppb. fine nut plug down 2 7/8" x 6 5/8" annulus at 1 bpm at 0 psi. Annulus continued to flow. Unsuccessfully attempted to plug leak by hesitating 15 minutes than pumping I bpm. Mixed and pumped an additional 2 ppb quick seal down 2 7/8" x 6 5/8" annulus. At 1 bpm had +10% returns after pumping 100 bbls. Continued to pump and hesitate quick seal. Annulus continued to flow. 10/7/83 Mixed and pumped 2 ppb quick seal and 2 ppb nut plug down 2 7/8" x 6 5/8" annulus through holes in 6 5/8" easing and back out 6 5/8" x 13 3/8" annulus. Established full returns - 6 5/8" x 13 3/8" annulus dead. Pumped down 2 7/8" x 6 5/8" annulus with returns out tubing and killed annulus. C. A. White ran in hole with 7/8" tool and did not locate plug in Otis pos. "2" S. nipple at 10,493'. Ran in hole to 10,638' and found plug in Otis pos "1" S nipple at 10,638'. Attempted to pull equalizing prong from plug without success. (Catcher filled with lost circulation material.) Dresser -Atlas perforated 2 7/8" tubing at 10,620' with 4 JHPF using a 2 1/8" slimkone gun loaded with circulating charges. Pulled out of hole with wireline. Closed blind rams to break lubricator apart, but the gun was not completely in the lubricator and the blind rams closed on the gun. Dresser Atlas pulled out of the rope socket while picking up to lift lubricator. Unsuccessfully attempted to engage gun with overshot. Hooked onto gun with bell nipple and pulled out of hole. 10/8/83 Unseated donut - released Brown cc safety joint at 10,560'. Laid down 331 joints 2 7/8" 6.5# N -80 tubing, 7 Camco mm mandrels, Otis "S" nipple pos. 2, Camco sleeve valve. 10/9/83 Ran in hole with Brown CC releasing tool on 3i" D.P. Tagged Brown CC safety joint at 10,607' (D.P. meas.). Attempted to engage packer unsuccessfully. Tool would pull free with 5,000# of pull. POOH to inspect tool. While pulling off bottom with 140,000# string weight low drum clutch chain broke. Blocks and D.P. dropped 70' to rig floor. Elevators remained latched suspending D.P. from rotary table. Installed and closed safety valve. Closed Hydril - secured well. Rig down 8i hours for repairs. Pulled out of hole with D.P. 10/10/83 Completed POOH. Had 6 5/8" BOT H S 16 -1 packer and remainder of tubing on drill pipe. (Packer had released, but would not go below where it was set at 10,616' D.P.M. RIH with 5 5/8" bit and 6 5/8" casing scraper. Tagged obstruction at 10,720' (D.P.M.) (Note: Drill pipe measurements have been 47' deeper than original tubing detail. Corrected tubing tail depth to 10,720'.) Unable to ream down hole due to excessive torque. POOH with casing scraper. Replaced hydromatic boot. 10/11/83 Dresser -Atlas attempted to RIH with vertilog tool. Tool too large to fit in 6 5/8" casing. Ran 5.5" gauge ring to 10,550'. RIH with Baker 6 5/8" model "D" drillable bridge plug to set at 10,533'. Charges did not go off. POOH with bridge plug to check setting tool. RIH with bridge plug and set at 10,533'. 10/12/83 Rigged up Schlumberger. Ran ETT log and pipe analysis log from 10,548' to 100'. Rigged down Schlumberger. Ran and set Baker retrievamatic packer at 2,316'. Bled off + 150 psi of gas pressure from 6 5/8" x 13 3/8" annulus. Pressure tested 6 5/8" casing to 2,700' psi. Verified 6 5/8" casing compentency from 1,508' to bridge plug at 10,533' by repeat testing to 2,700' psi at 2,066' and 1,508'. Pulled packer from 2,316'. Set Baker retrievable bridge plug at 256' (above the estimated shallowest 6 5/8" casing leak). Tested bridge plug to 500 psi. Raised 5,000# Class III BOPE. Removed 3,000# tubing head. Installed 13 5/8" x 3,000# spacer spool and 3,000# x 5,000# adapter. 10/13/83 Nippled up Class III 5M BOPE. Tested 3i" pipe rams, blind rams, choke manifold and all valves and lines to 3,000 psi. RIH and retrieved bridge plug at 256'. Laid down 60 jts. of 31" D.P. RIH with Tristate spear. Engaged 6 5/8" casing at the 13 3/8" x 3,000# casing head. Weight indicator gained 7,000# when 6 5/8" casing with suspected part at 300' was pulled smoothly upward approximately 8'. Then the casing stopped when the uppermost casing collar, previously logged 10' below the wellhead approached the slips. Upstrain of 75,000# over the string weight failed to free the casing. The casing remained suspended in the wellhead, by the slips, when the upstrain was released. The spear was disengaged with the top of the casing stub at 12', which is approximately 1' below the 3" pipe rams. The pipe rams could not be closed. Operations suspended. The casing head slips in the Shaffer KD head and were held in place with a snap keeper ring and did not allow the slips to pop out. 10/14/83 Resumed operations (down five hours). Ran in hole with open ended 3i" drill pipe and laid a 22 C.F. (19 SX.) Class "G" cement plug with 1/10% HR6L and .75% CFR- 2 to 15.8 ppg fresh water from 10,538' - 10,412'. POOH. 10/15/83 Ran in hole with open ended 3i" drill pipe and laid a 45 C.F. (24 SX.) Class "G" cement plug with 8% gel, 3% CaC12 with 33 C.F. fresh water from 298' - 250'. Cement failed pressure test. Formation took fluid at 1+ BPM with no pressure. Worked through obstruction at 557'. POOH. Ran in hole with open ended 3i" drill pipe and laid an 89 C.F. (43 SX.) Class "G" cement plug with 8% gel, 3% CaC12 and 65 C.F. fresh water from 313' - 193'. POOH. Ran in hole to 615'. Did not tag cement. Circulated out contaminated cement. POOH. Pumped 62 C.F. (33 SX.) Class "G" cement with 8% gel, 3% NaC1 and fresh water down 13 3/8" x 6 5/8" annulus. Displaced cement with 11 bbls. fresh water to 100'. 10/16/83 WOC. 8i hours gel. Ran in hole to 590'. Did not tag cement. Circulated out cement contaminated mud. Ran in hole with 3i" open ended drill pipe and spotted a high vise. 9.3 ppg gel /LCM pill 293' - 628'. POOH. Pumped 50 bbls. high vise. 9.3 ppg. LCM /gel mud down the 13 3/8" x 6 5/8" annulus. Pumped 62 C.F. (33 SX.) Class "G" cement with 8% gel, 3% CaC12 and fresh water down the 13 3/8" x 6 5/8" annulus. Displaced cement with 11 bbls. of gel /LCM mud to 100'. Had full returns. W.O.C. 8 hours. Ran in hole. Tagged cement at 104'. Tested cement plug and cement in 13 3/8" x 6 5/8" annulus to 500 psi. 10/17/83 Cut 6 5/8" casing at 42'. Nippled down 5,000 Class III BOPE. Engaged 6 5/8" casing with tristate spear at the 13 3/8" casing head. Removed 6 5/8" casing slips. Recovered 29' 6 5/8" casing (top of casing at 42'). Nippled up 5,000# Class III BOPE. Installed 3,000 psi accumulator. Tested Hyrdil to 2,500 psi. Tested 3i" rams, choke manifold and valves to 3,000 psi. Witness of test waived by Joe Russell (BLM) and Blair Wondzell (AOGCC). 10/18/83 Ran in hole with 9 1/4" washover shoe and tagged cement at 114'. Cleaned out cement to 138'. Ran in hole to 159'. Tagged obstruction. POOH. Washover tool had 9" of external wear on bottom of shoe. Ran in hole with tristate spear. Unable to pull 6 5/8" casing from 42' with 100,000# over string weight. POOH. Washed over cement stringers and cement 159' - 238'. POOH. Ran in hole with spear and recovered 246' of 6 5/8" casing from 42' to 301'. 10/19/83 - 10/20/83 Ran in hole with 121" bit and casing scraper. Cleaned out cement and cement stringers 188' - 298'. POOH. Ran in hole with 9" wash pipe with a 5i" flat bottom mill and cleaned out cement and cement stringers from 301' to 365'. POOH. Ran in hole with mechanical cutter and attempted to cut 6 5/8" casing at 2,040'. POOH. Four of five knives on cutter were broken. Engaged 6 5/8" casing at 301' with spear. Failed to pull casing free with 40,000# over string weight. Ran in hole with mechanical cutter and cut 6 5/8" casing at 2,043'. Ran in hole with spear and recovered 1,738' of N -80, 24 #, Butt. 6 5/8" casing from 301' - ;MI. (Casing may be partially cut at 2,043'.) Recovered casing was heavily coated with scale and had a hole at + 600'. Cleaned out casing to 2,035' with bit and scraper. Set Baker packers at 2,024', 1,063' and 502' and pumped down annulus. Did not locate leak in 13 3/8" casing from 0 - 502'. 10/21/83 Ran in hole with mechanical cutter to 2,048'. Cut 6 5/8" casing. POOH. Cutter carried a 2' piece of 6 5/8" casing to surface. Ran in hole with spear and engaged top of 6 5/8" casing at 2,037'. Failed to retrieve casing. POOH. Ran in hole with 10 5/8" overshot with 6 5/8" basket grapple and pack off. Engaged casing at 2,037'. Failed to free casing by jarring 60,000# over string weight. Pumped water down the drill pipe at 4.5 BPM with 300 psi which confirmed casing partially cut at 2,048'. POOH with overshot. Ran in hole with mechanical cutter and extension guide. Recut 6 5/8" casing at 2,048'. Failed to engage casing with spear. POOH. 10/22/83 Ran in hole with overshot and basket grapple. Failed to engage casing at 2,037'. POOH. Ran in hole with same overshot assembly with a 2' extension. Failed to free casing from 2,037' by jarring 75,000# over string weight. POOH. Ran in hole with 23' of 9" wash pipe and 9i" sawtooth wash shoe to 2,060' without indication of obstruction. 10/23/83 Ran in hole with 8" pilot mill. Milled 6 5/8" casing 2,037' - 2,051'. POOH. Ran in hole with 8 3/8" overshot with 6 5/8" spiral grapple and stabilizing blades on 19' of 8 1/8" wash pipe. Worked overshot over casing stub at 2,051' - 2,059' by bumping the 50,000# string weight down. Sheared away from stabilized overshot at 2,059' by jarring 40,000# up. POOH. 10/24/83 Ran in hole and set Baker 13 3/8" full bore packer at 1,951'. Pressure tested 13 3/8" casing and shoe to 1,000 psi at 1,951' and 626'. Isolated 13 3/8" casing leak between 503' - 626' by pumping salt water at 3i" BPM and 100 psi. Pulled packer at 1,951'. Ran in hole with open ended drill pipe to 751' and spotted a 20 bbl. gel /LCM high vis. pill. Pulled up to 626' and pumped 372 C.F. (200 SX.) Class "G" cement with 3% CaC12, 8% gel and 274 C.F. of fresh water. Displaced cement to 199' with 1 bbl. fresh water. Cement equalized at 184'. Displaced 101 C.F. of Class "G" cement out the 13 3/8" casing leak 503' - 626' with 175 psi pressure. Displaced 28 C.F. of Class "G" cement out the 13 3/8" casing leak with 225 psi pressure. Ran in hole with 12i" bit and casing scraper and cleaned out cement 368' - 620' and cement contaminated mud at 760'. Pressure tested 13 3/8" casing leak to 200 psi. 10/25/83 Ran in hole with dressing mill and dressed the 6 5/8" casing at 2,051'. POOH. Ran 241' (61" jts.) P -110, 23 #, 8rd and 1,754' (47 jts.) N -80, 24 #, Butt. 6 5/8" casing to stub at 2,051'. Set patch on 6 5/8" casing at 2,051'. Pressure tested casing and .patch to 1,500 psi. Mixed and pumped 700 SX. (1,302 C.F.) of Class - "G" cement with 896 gel and 2% CaC12 with fresh water up 13 3/8" x 6 5/8" annulus through stage collar at 2,008'. Displaced cement with 73 bbls. of mud to 2,008'. Bumped plug. Did not have cement returns to surface. Pressure tested 13 3/8" x 6 5/8" annulus to 300 psi. Nippled down Class III 5,000# BOPE. 10/26/83 Set 6 5/8" casing slips. Set and tested casing packoff. Installed tubing head. Nippled up BOPE. 10/27/83 Installed test plug. Tested BOPE and Hydril to 2,500 psi. Rams, valves and lines to 5,000 psi. Blair Wondzell (AOGCC) and Joe Russell (BLM) waived witnessing test. Removed test plug. Down 14i hours due to flywheel repair. 10/28/83 Tagged stage collar at 2,008' and cleaned out to 2,012'. Washed to 2,207'. Down 171 hours for engine repair. 10/29/83 Rig down 18 hours for engine repair. Circulated bottoms up at 3,000' and 7,000'. 10/30/83 Circulated bottoms up at 8,500' and 10,109'. Washed to 10,506'. Tagged obstruction, POOH, change BHA and RIH with globe junk basket. Rotated down from 10,506' to 10,518'. 10/31/83 POOH. Recovered 10" piece of stage collar closing dart in globe basket. Ran in hole with globe junk basket and cut 6' of core 10,518' - 10,524'. POOH. Recovered one casing cutter knife, 1 piece of stage collar and cement in globe basket. Ran in hole and cut 17' of core 10,524' - 10,541'. POOH. Recovered 1 piece of cement with globe basket. 11/1/83 Ran in hole with bladed mill with two junk baskets and drilled out retainer at 10,541', DPM, 10,553' W.L.M. RIH to 10,720' and unsuccessfully attempted to rotate. Blades hung up in perforations. Circulated bottoms up. POOH. Recovered small amount of retainer junk. Ran in hole to 10,720' with 3i" x 5i" string mill. Could not rotate down due to excessive torque. 12/28/83 11/2/83 Displaced mud with lease water. POOH with string mill (mill scarred on outside taper at an O.D. of 5 3/8 "). Ran in hole with 2 7/8" tubing on 3i" drill pipe. Could not get deeper than 10,725'. POOH. 11/3/83 Picked up BOP stack and changed rams from 3i" to 2 7/8 ". 11/4/83 Tested 2 7/8" rams to 5,000 psi. Ran 315 joints 2 7/8 ", 6.5 #, N -80 8rd tubing to 10,600' with packer at 10,529' (see attached detail). Nippled down ROPE. Nippled up tree. Released rig 7:00 p.m., 11 -4 -83. t Reperforated from X674'- - 10,715', 4 - 0.36" JHPF with Schlumberger's 2 1/8" Enerjet with 0 phasing. Item TUBING DETAIL SRU 41 -33 Length Depth KB - Tbg. head 19.50 Tbg. hanger cut for Cossasco plug 1.00 19.50 112 jt. 2 7/8" 6.5# N -80 8rd tbg. 3,478.90 pup 4.00 Camco MM Mandrel w /dummy 8.22 3,503.20 pup .65 79 jt. 2 7/8" 6.5# N -80 8rd tbg. 2,477.65 pup 4.12 Camco MM Mandrel w/ dummy 8.32 5,995.84 pup .66 47 jt. 2 7/8" 6.5# N -80 8rd tbg. 1,480.61 pup 4.12 Camco MM Mandrel w /dummy 8.32 7,489.55 pup .66 32 jt. 2 7/8" 65# N -80 8rd tbg. 1,006.34 pup 4.08 Camco MM Mandrel w /dummy 8.30 8,508.95 pup .65 31 jt. 2 7/8" 6.5# N -80 8rd tbg. 928.05 pup 4.05 Camco MM Mandrel w /dummy 8.31 9,500.00 pup .67 31 jt. 2 7/8" 6.5# N -80 8rd tbg. 975.41 pup 4.05 Camco MM Mandrel w /CEV 8.30 10,488.44 pup .65 1 jt. 2 7/8" 6.5# N -80 8rd tbg. 31.40 6 5/8" x 2 7/8" Baker Model FHL Packer 6.65 10,528.79 1 jt. 2 7/8" 6.5# N -80 8rd tbg. 31.65 Otis "S" nipple Pos. 1 w/2.313 ID 1.30 10,567.09 1 jt. 2 7/8" 6.5# N -80 8rd tbg. 30.93 2 7/8" Baker shear out sub .50 10,599.32 Landed at 10,599.82 ro: ,Q'TT' ) c`iocS �Tc'anUC 77 A/ /0 G- s7� 4/- RECEIVED BY CILVU UN U. S.A. INC... TRANSMITTA ACKNOWLEDGEMENT OF RECEIPT ATERIAL — (ALASKA) y.s._s- to G — - 4 /9 - DATE mission Ar ,crage REMARKS ON OTHER SIDE, THIS SHEET /3fr,/ DEPT.: FD — Folded R — Rolled PLACE: �� �� C�l/1 - ��,Q C ice`-- d _ . S — Sepia F — Film X — Xerox B — Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. -7'07 - - CC L.. -4/4 - 45" S S'E'z /4 S 4541 EL / .� E 3 ."' E ,° /4 £ K j/oe_4 SCI z-35" 3 -Seirzia S 7_6 - Zs - ( -i � OIMININVEMININI ON U.S.A. INC. BOX 7.839 ANCHORAGE, ALASKA 99510 / / 1 . DRILLING WELL ❑ COMPLETED WELL K] OTHER ❑ 2. Name of Operator Chevron U.S.A. Inc. 7. Permit No. 61 -003 3. Address P.O. Box 107839, Anchorage, Alaska 99510 8. API Number 50— 133 - 1066 -00 4. Location of Well 850' S & 740' W from the N.E. Cor., Section 33, T8N, R9W, S.M. 9. Unit or Lease Name Swanson River Unit 10.WellNumber SRU 41 -33 11. Field and Pool Swanson River - Hemlock 5. Elevation in feet (indicate KB, DF, etc.) 175' K.B. 6. Lease Designation and Serial No. A- 028399 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ❑ Alter Casing ❑ Perforations 3 Altering Casing ❑ Stimulate ❑ Abandon ❑ Stimulation ❑ Abandonment ❑ Repair Well ❑ Change Plans ❑ Repairs Made ❑ Other ❑ Pull Tubing ❑ Other ❑ Pulling Tubing ❑ (Note: Report multiple completions on Form 10 -407 with a submitted Form 10 -407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105 -170). (1) Reperforated the Hemlock H2 & H3 intervals 10,674- 10,715' w/4 JHPF and 0 phasing. (2) Returned the well to production. 14. I hereby certif that the foregoi is true and correct to the best of my knowledge. , 'i: � Signed ., Title Area Engineer Date 1 h The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date__.__.___________.__ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS Form 10 -403 Rev. 7 -1 -80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 1 . DRILLING WELL ❑ COMPLETED WELL B OTHER ❑ 2. Name of Operator Chevron U.S.A. Inc. 7. Permit No. 61 -003 3. Address P.O. Box 107839, Anchorage, Alaska 99510 8. API Number 50— 133 - 1066 -00 . 4. Location of Well 850' S & 740' W from the N.E. Cor., Section 33, T8N, R9W, S.M. 9. Unit or Lease Name Swanson River Unit 10.WellNumber SRU 41 -33 11. Field and Pool Swanson River - Hemlock 5. Elevation in feet (indicate KB, DF, etc.) 175' K.B. 6. Lease Designation and Serial No. A- 028399 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate X1 Alter Casing ❑ Perforations ❑ Altering Casing ❑ Stimulate ❑ Abandon ❑ Stimulation ❑ Abandonment ❑ Repair Well ❑ Change Plans ❑ Repairs Made ❑ Other ❑ Pull Tubing ❑ Other ❑ Pulling Tubing ❑ (Note: Report multiple completions on Form 10 -407 with a submitted Form 10 -407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105 -170). (1) Reperforate the Hemlock H2 & H3 intervals 10,674 - 10,715' w/4 JHPF and 0 phasing. (2) Return the well to production. This work will be done the week of December 26, 1983. A k.„ of o n o/ DEC 2 7 1i Alacka 011 & Gas Cf..ns. Commis or An :horagO Verbal approval from Blair Wondzell on 12/22/83. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Area Engineer Date a oa The space below for Commission use Conditions of Approval, if any: , Approved Cnn : Returned ORIGINAL SIGNED ,j 1 -sK3 BY LONNIE C. SMITH By Order of Approved by COMMISSIONER the Commission Date /a -ag -c STATE OF ALASKA ALASKA ()IL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS Form 10 -403 Rev. 7 -1 -80 (fr �t Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 1. DRILLING WELL ❑ COMPLETED WELL )Z OTHER ❑ 2. Name of Operator Chevron U.S.A. Inc. 7. Permit No. 61 -003 3. Address P.O. Box 107839, Anchorage, Alaska 99510 8. API Number 50 133- 1066 -00 4. Location of Well 850' S & 740' W from the N.E. Cor., Section 33, T8N, R9W, S.M. 9. Unit or Lease Name Swanson River Unit 10.WellNumber SRU 41 -33 11. Field and Pool Swanson River - Hemlock 5. Elevation in feet (indicate KB, DF, etc.) 175' K.R. 6. Lease Designation and Serial No. A 028399 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ❑ Alter Casing ❑ Perforations ❑ Altering Casing Stimulate ❑ Abandon ❑ Stimulation ❑ Abandonment ❑ Repair Well ❑ Change Plans ❑ Repairs Made Xl Other ❑ Pull Tubing ❑ Other ❑ Pulling Tubing Xl (Note: Report multiple completions on Form 10 -407 with a submitted Form 10 -407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105 -170). (1) Move in, rig up Brinkerhoff Rig 31. (2) Recovered 2 7/8" tubing. . (3) Cut and recovered bad 6 5/8" casing from 2051'. (4) Cement squeezed 13 3/8 " casing. (5) Ran new 6 5/8" casing with casing patch and Baker stage collar to 2051'. (6) Cemented 6 5/8" x 13 3/8" casing from stage collar @ 2008' to surface. (7) Cleaned out 6 5/8" casing to 10,720' - tagged collapsed casing. (8) Ran 2 7/8" completion tubing to 10,600' and set packer at 10,529'. (9) Rig down and move out Brinkerhoff Rig 31. #- EI 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. = " ( ' ? q t y }s` W ge i Area Engineer Date �` Signed / . . lit+ AS / . — Title The space below for Commiss on/ °` _. .I Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date _ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS Form 10-403 Rev. 7 -1 -80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 1 . DRILLING WELL ❑ COMPLETED WELL OTHER ❑ 2. Name of Operator Chevron U.S.A. Inc. 7. Permit No. - 3. Address P. O. Box 107839, Anchorage, AK. 99510 8. API Number I o 1 up.. 00 lir 50 - 133 — 0 4. Location of Well 850' S & 740' W from the N.E. Cor., Sec. 33, TBN, R9W, S.M. 9. Unit or Lease Name Swanson River Unit 10. Well Number SRU 41 - 33 11. Field and Pool Swanson River Hemlock 5. Elevation in feet (indicate KB, DF, etc.) 175' K.B. 6. Lease Designation and Serial No. A- 028399 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate L Alter Casing rZ , Perforations ❑ Altering Casing ❑ Stimulate ❑ Abandon ❑ Stimulation ❑ Abandonment ❑ Repair Well (I Change Plans ❑ Repairs Made ❑ Other ❑ Pull Tubing (M Other ❑ Pulling Tubing ❑ (Note: Report multiple completions on Form 10 -407 with a submitted Form 10 -407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105 -170). • See attached program. • ' } RECEIVED ,p t Stj T li Y S ,,ti3 _ - ) 9 c,,,7,,_- � Alaska Oil & Gas Cons. Com fnissiot1 Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Area Engineer Date 6/31 113 The space below for Commission use Conditions of Approval, if any: ApPt o ,. ,� %P`f Returned_ ORION!. SIGNER - - 7 .,: - ---. —' pp SIVI T BY LONNIE Y. � 1 a By Order of . Y 3 Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7 -1 -80 ' STATE OF ALASKA AND GAS CONSERVATION CUmMISSION SUNDRY NOTICES AND REPORTS ON WELLS 0° •=r Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SRU 41 -33 - PROGRAM 1. Prior to moving in work -over rig, perforate tubing with 0.092" wire line and Kinely perforator above Otis S nipple at 10,493'. Circulate the hole full of lease water, hole in casing at 650' may not allow hole to stand full. 2. Move in and rig up work -over rig. 3. Set back pressure valve, nipple down tree, nipple up 13 -5/8" 5M Class 111 BOPE. Alert Minerals Management Service and Alaska Oil & Gas Conservation Commission 24 hours prior to testing BOPE. Test BOPE to 5000 psi. 4. Pull back pressure valve and circulate well with lease water to make sure well is dead. Have weight material available. 5. Pull plug from Otis "S" pos. 2 nipple at 10,568'. Kill well. Recover tubing and packer at 10,568'. Lay down the 2 -7/8" tubing. Visually inspect for salvage value. Note: criss -cross safety joint at 10,560', back off at safety joint if packer will not come free. Mandrels may not allow CC joint to back off and tubing may need to be cut. 6. Clean out to 1 1,088' or as deep as possible with 5 -5/8" bit and 6 -5/8" casing scraper. 7. Run either Dresser Vertilog or Schlumberger PAL and ETT logs from 10,674' to surface. 8. Depending on the data from the logs, set two retrievable bridge plugs; set the first one below all bad casing near the perforations. Spot 10' of sand on plug. Test casing with packer to 3500 psi if casing below 2,104' looks bad on logs. Set second bridge plug above known leak and all bad casing. 9. Pick up BOP stack, remove tubing head, and nipple up on 12" 3000 psi casing head. Retest BOPE to 3000 psi. Alert Minerals Management Service and Alaska Oil & Gas Conservation Commission 24 hours prior to test. Retrieve upper bridge plug. 10. Cut 6 -5/8" casing at + 2050'. Recover and visually inspect 6 -5/8" casing. 1 1. Clean out to the top of the 6 -5/8" casing with IN" bit and 13 - 3/8" casing scraper. 12. Lay a cement plug above the top of the 6 -5/8" casing stub. 13. Isolate leak. Pump 2 two hundred sack stages of cement through hole(s). Cement slurry to be determined by depth of leak, pump -in rates and pump -in pressures. Do not attempt to squeeze. 14. Drill out cement plug and clean out to top of 6 5/8" casing. 15. Run 6 -5/8" casing with casing bowl on bottom and a stage collar + 120' below 13 3/8" casing leak. Cement 6 5/8" x 13 3/8" annulus to surface through stage collar. Land casing and nipple up tubing head and BOPS. Alert Minerals Management Service and Alaska Oil & Gas Conservation Commission 24 hours prior to BOPE test. Test BOPE to 5000 psi and casing to 1500 psi. 16. Retrieve 6 -5/8" bridge plug. 17. Run production tubing as shown in the new tubing detail dated 3/24/83. Hydro -test tubing to 5000 psi. 18. Land tubing, set packer at + 10,540', and test packer to 2000 psi. 19. Set back pressure valve, nipple down BOPE and nipple up tree. Test tree to 5000 psi. 20. Rig down and move out workover rig. 21. Turn well over to the Production Foreman. COMPANY WELL RUNS TRANS, "1ITTAL AND ACKNOM,EDGEMENT OF RECEIPT OF MATERIAL (ALASKA) TO: Ar DEPT.: PLACE: THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. l ,H &L/RO/✓ (/, INDUCTION ELECTRICAL LOG DUAL. INDUCTION LATEROLOG BOREHOLE COMPENSATED SONIC BOREHOLE COMP. SONIC w /caliper BOREHOLE COMP. SONIC w /gamma BOREHOLE TELEVIEWER - CONTINUOUS DIPMETER - High Res. CDl f - POLYWOG PLOT CEMENT BOND LOG CASING COLLAR LOG. - Perf. Rec. CO.•TENSATED FORMATION DEN. COMPENSATED NEUTRON FORMATION ANALYSIS LOG FORMATION DENSITY LOG F F FORMATION TESTER FORMATION FACTOR F F GAMMA RAY GAMMA RAY - NEUTRON GAITIA RAY COLLAR LOG MICRO LOG MI CROLATEROLOG MUD LOG NEUTRON LOG PROXIMITY MICROLOG RttiA COMPARISON PLOT SANDSTONE ANALYSIS S AR A.B AN D SII)EWALL NEUTRON POROSITY SONIC TEMPERATURE LOG alRElxa41 'v2/6' SCALE XEROX SEPIA .BLUELINE 2" .5" DATE: COMPLETION REPORT DIRECTIONAL SURVEY CONE DATA SARABAND TABULAR LI TI;: _ TETE C ?E:C-- 198.E By: Received and checked by: Alaska Oil 8: Gns Cons. Commission Anchorage 1 1 100 200 DEPT.* �': �, ' � / ' 2 ATr: TRANSMITTA AND ACKNOWLEDGEMENT OF RECEIPT Gi .fATERIAL — (ALASKA H..VRO U.S.A. Luc. THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE • Dr: r . 1�� °� ►� /0,•si3 Ul: 1. 33 • ., ; • DATE / //, 77 /' / 4 / i��� fi / � / • • / — �•�� ! % � ( • � � y J 7 ' 1 COMM I 1 COMN , _ 1 COM 1� RE3 ' : IG - Blue , BY ; I � /7" ' -y C..iE Lii"v 741:0 Form _10 -403 REV. 1 -1073 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data TEST WATER SHUT -OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Convert to waste water disposal 15. DESCRIBE. PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. SIGNED Propose to convert SRU 41 -33 to annular casing injection. Recent evaluation shows that the current disposal wells are barely adequate to handle the current water production. Additional disposal capacity is needed to prevent any curtail- ment of oil production in the event problems develop with a disposal well and to handle increasing field water production. Further data attached. 16. I hereby certify th ' he foregoing is true and cor�e�t (This space for State office u NOTICE OF INTENTION TO: PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate J TITLE, Arpa Fngi nppr See Instructions On Reverse Side SUBSEQUENT REPORT OF: WATER SHUT -OFF REPAIRING WELL FRACTURE TREATMENT - -~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) VLD APR 81977 • �I • Dl (Iv ( .o a DATE 7-/- 77 APPROVED BY TITLE DATE CONDITIONS OF APPROVAL, IF ANY: STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. API NUMERICAL CODE , 50 -133- -00 11 P 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.) 6. LEASE DESIGNATION AND SERIAL NO. A- 028399 1 OIL GAS WELL WELL, OTHER Water Disposal 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 2. NAME OF OPERATOR Chevron U.S.A. Inc. 8. UNIT, FARM OR LEASE NAME Swanson River Unit 3. ADDRESS OF OPERATOR P. 0. Box 7 -839, Anchorage, Alaska 99510 9. WELL NO. SRU -41 -33 4. LOCATION OF WELL At surface 850' S & 740'W from N.E. corner of Section 33. Straight Hole 10. FIELD AND POOL, OR WILDCAT Swanson River 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T8N, R9W, SB & M 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 175' KB 12. PERMIT NO. Form _10 -403 REV. 1 -1073 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data TEST WATER SHUT -OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Convert to waste water disposal 15. DESCRIBE. PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. SIGNED Propose to convert SRU 41 -33 to annular casing injection. Recent evaluation shows that the current disposal wells are barely adequate to handle the current water production. Additional disposal capacity is needed to prevent any curtail- ment of oil production in the event problems develop with a disposal well and to handle increasing field water production. Further data attached. 16. I hereby certify th ' he foregoing is true and cor�e�t (This space for State office u NOTICE OF INTENTION TO: PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate J TITLE, Arpa Fngi nppr See Instructions On Reverse Side SUBSEQUENT REPORT OF: WATER SHUT -OFF REPAIRING WELL FRACTURE TREATMENT - -~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) VLD APR 81977 • �I • Dl (Iv ( .o a DATE 7-/- 77 APPROVED BY TITLE DATE CONDITIONS OF APPROVAL, IF ANY: Pertinent data concerning this proposal: 1. Formation water quality: approximately 4300 ppm TDS (Figure 1) 2. SRF waste water: approximately 22,200 ppm TDS (Figure 2) 3. Total production water @ SRF: approximately 10,000 BWPD (Figure 3) 4. E -log and mechanical data: (Figure 4) Note that even if all the waste water was put into this well for 10 years, it would only cover a radial distance of 1615'. 5. Estimated injection pressure: 0 to 100 psig This estimate is based on injection pressures experienced at current disposal wells in the same sands. 6. Estimated injection rate: 3500 BWPD This is purely an estimate at this point. Actual rates will depend on actual volumes of water produced and the condition of other disposal wells. Actual disposal volumes for all disposal wells will be reported on a quarterly basis. 7. Corrosion Inhibitor: SRU 41 -33 PROPOSAL TO CONVERT TO WATER DISPOSAL a. Bimonthly slug treatment with Magna Mag "B" to maintain sulfate reducing bacteria at 1 -100 colonies maximum. b. Five gallons /day of Magna MEP #480 corrosion inhibitor is injected into the waste water at the 1 -4 and 1 -33 tank settings. 8. Injection interval monitoring: Periodic ratio - active tracer surveys will be run to determine that the injection is con- fined to the proper interval. 1 APR - 8 ri- 42- 91= 3IY9'4 WELL NO. SRO 221-33 OIL B/D COMPANY S TANUARD OIL CO WATER B/D 109 LOCATION ALASKA GAS MCF /D 15 36 SAMPLE SOURCE OIL GRAVITY ZONE METHOD RADICALS ' PARTS PER MILLION Sr UM C C I uM M.Y;'4ESIUM SULFATE CHLORIDE CA %ATE BICARBONATE - TO I AL BrI2ON sw•t.��r- --s-:.sl.-w mnswilemomme ■ssrrw ws- s r r/1- -wr- ■wwllmo-ss mowimmomme r- -nsww-M rM-M.. -gmm ssw s rs ■-wtaw ■sssrs. - �Ir -sssss Mlle mismosmamme w amisomra- ww s -- w7RMmow OIMMWMOOMM OMOWAMOVIMI -w- t�wswr 11: --ww wawt."..ir r-str -ss--- r-r. wwsw- ssr.mws sr--rtm rs ■Mr.msssa- swctawasw sr-ssruM- sswwscss iiiriswa ismirammorm ■MamMw--M ■sw n-srs sum-- --r momemmism wi srM- -- -MSS ■-w--t ass -M-MM+;rsw ■wsswrwrs -w- - -w.sw mummonmem --cAIMMr- ssMc°orws- ■-s yw- -n ■-- L-wMM- swwwrt=r- -sMwwwma -- wss-wae- w i w iiii um M- -MIMAO MICVMMISOM Mrs MM-wM -1V-wsMMM wr-us-M -s sawssr I wM -Maw- OMMUMBrnda MUMMOMWM ls�sM is a1.wMSSMs In s-sMM- tmliminumme witnaggsmo w i 000 --■ ssw ---_M wimmemomm mmouvimismis MMMrs suns MM u N - ■-w =s maimeemonsim WOMNUMOMMIS M w e Mi mrammimmilme - w- _ . ii_ i i w ■- i Iw - -s immaiesmons sonrAmalless -s-uss---s CORMINIS M taw - - - -■ SS-MA- SS rM-a► AMMO-- MM- GI.i -M- -r immiw o a-MSrr rrrara--rsr wrwt i.ag∎miii -alum--um - M:'ws -MMwM IMis--- -sr sme.w-M-rrr immusimmomm s--w a>.-w-• CUMUSWAS monworammem sonswonstomi r-Hma a. mftwes worm- MUM mum ■Mw►.i N" s■ mkamommems mimosa wawa wt iw-w w_ - .i ■ iw-sw- mss■ ■s-•M=$"11-r WiAMOMO.TIM -M -s ws-rc� -s iiwwww-ws s-m.a --■mess sst t--wr--• rw rww-s--w -ii - a-r-M- M-i. summillommul mumwmaimm ss,w•M -s--- -r ss -ssw-r Mf ■- -• /-/w missanummul + m. a.rse +i iris A *US.PGJEYTIIL ,.. womb. 1 RESISTIVITY SIGNED R M Y AMA DA SEOC,HEMICAL ANALYSIS OF WATEf MILLIGRAMS PER LITER 1293.4 90.2 76.9 2.7 1866.3 0. 902.4 4239.9 0. RrMARKS - -- STABILITY AT 100' F. 4 - /..20 'No +K STANDARD OIL CO. of CALIF, W.O. I.,Oper Swanson River Unit 221-33 Elev. 209' K.B. Fr. N.W. Cor. Sec. 33 T.. 8 N., R.9 W., Saes M. 560' S. a 2110'E. Surface Location t: `>/ALENT SALT = 215.0 (VG, RtESISTIVI rY = -1.450 CNLOR INI T'Y = 179.72 G /G, SPECIFIC GRAVITY =1.00459 HYDROGEN SULFIDE ABSENT CI +I +Br ARC REPRESENTS "CONCENTRATION OF SOLIDS IN REACTING VALUE EQUIV. PER MILLION 56.26 4.90 6.33 0.06 52.64 0. 14.'19 134.97 TICKER GRAPH % REACTING VALUE Wi t _ APPROVEDC E F I E B E R -- 10 -391 SAMPLE DATE 9/10/64 REPORT DATE 9/25/64 LABORATORY NO. 309 -64 W- 8 5 4 SAMPLED BY ANALYST R C LOEB Co+ Mg+ Ba+ Sr k REACTING VALUE PERCENT 41.68 3.63 '4.69 0.04 39.00 0. 10.96 100.00 OHM -METER AT 77 DEG F PH = 7.91 CO X HCO OH RECEIVED .APR - B 1`�77 y ysion Qt C)i! and C tiger attor SO NORMAL SEA WATER" FIGURE 1 WASTE WATER ANALYSIS SWANSON RIVER, ALASKA Cations - Mg /Liter Sodium Potassium Ammonium Calcium Magnesium Barium Iron Anions - Mg/Liter Sulfate Chloride Hydroxide Carbonate Bicarbonate Borate Iodide Silica CHEVRON OIL FIELD RESEARCH COMPANY La Habra, California Organics (Diethylether) Mg /Liter Salinity as Salt Mg /Liter Total Dissolved Solids Mg/Liter Suspended Solids Mg /Liter Turbidity- Equivalent Mg /Liter as Kaolinite Suspension Specific Gravity - @60 ° F Resistivity Ohm -Cm @75 ° F Freezing Point ° F Viscosity C'Poise @ 72.7 ° F pH SRF 1 5200 100 40 2740 105 45 2.1 25 12840 0 0 930 35 10 65 48 21,170 22,140 36 125 1.019 29.5 29.46 0.955 6.40 39 19,40o 20,460 23 The three water samples were designated as follows: SRF1 - Discharge of water injection pump from waste water pit. SRF2 - Discharge from SCU waste water SRF3 - Discharge from SRU waste water line into pit. line into pit. Project 30,286 April 15, 1969 SRF2 SRF3 5800 4600 95 �o 35 1610 4010 85 105 6o 25 2.6 1.5 Trace 11770 0 0, 915 35 to 40 82 1.018 31.2 29.3o 0.996 6.26 50 14 0 0 825 3o 15 40 46 23,370 24,00o 6 55 1.020 26.8 29.57 1.003 6.75 RECEIVEIJ APR 81 77 D;v!ision of QiI and Gis r E' FIGURE 2 Ing 111 f „ IluIt ' •. uur iiiuuaa iimiuI uiiit:i MI II11�1 :,'� I II• }1111+ `tl 1. #. { 1 r 11111 t } 11111 11 1 r 11 'l ltl ' II RRi 1 , 1 111 11 ; ! 1 Il�t 1I ��• 1111 l1! }I''l�' 111 1J1 ; Iii :1111 }} II i }1 } II11Fi� {�� l; � ,I TIFF { I } F I - - t -91111 '1i :: 111111111 HIIIIII!I I1111 _,_ I Ii Ei i, i,lj ;tI t +{ - H 1111 t' I,'tfif G1 aj; f, f H '= ANN 1111 Rini MEE'} ,I!' RIM M1011 ; : F: •IIIF i 4 - 11111 IMINI IIIIIEEE!II }} 1111 I!Ni I ■E€E � N : 1 4 IF!IOL h ri { Illll a 1 i.. - NM! tt - EII1 u! 4 II!OII� I;�IIII 111 -- �,,�� Ne M■. ■ ■. Fli1 .MMMr.NMI ■ ■- �IN111MI.E� EIH111111 :0RRI i u ' 1. R1i €sEu €�ii : } k -- o �'a} RE1101111II }' }INEM-51111E4B-11 IIIEI11IFi11111i ! Ib # i :.. II'I'' ►' ! ! ►' ' 1 HHI 1 111ii: 11111 ' 111 11{IL'r:I NIl ZL�1911i``rr9 Pa ..■rr I' r ri�rampan noel _ IDIIIIIIIIIIIH ''��' I 1111111111111111 ;,} AIM ::_� li IIIII {IIiI =� M' IHIIHIO;•i, : 111! 1,' RFR ��; 111111111110111111111111111111 ,I� i11111 � _ i1I1'iHlIfflIllHhII• .r I} ' I, ��hII1 ' }�; }' ►' RRi _ Mill "1 ! ! 11111 i,' ; ! H;ohlgII:ionh1l ! 11; OIIIhI W 1 1 ;31' o Ifi } IIHIIIII1HIHH1fll.• 11 Pi x' 15111 , }I' ,113 I tlf 1 1 f 1, 1 } 1 1 _x . , - _�'Ii1IIli1 111111' Ili: it'' !l , } ,u 1 J III �' I !' j1111111111111111111111 — I 1; 11 a IlIIllhI . i 1 t 1 i �' } 1, rli ii; ` ! 1 . - IIHUIIIOIIIII }'!;, i I will 1E10 r {+ .-1111 '� I - :1._.. - -_l.- .i�I,� IIf'II,,.,�1. ■i ■i'1 } .� .- , II Ana } t 11111111 I�`�t { � -! � I �• - } -`� I, t ':, 11.14 IIFN at 1111010111001111111111 l{ 1 rnII i1I11�1111F'I 11111 IIIIIF 4 : .UII1I11fl ,I'lii�tl � I I j II r:l i• �1�_ } -1 F 'tl i�t 'i: ' . }' ! Ili =r 1111 Illi I- ,t} }11 11 I t. t- _1 I ,)•I, Il' ' lII l{ }�� 111•11Milla 0110l'!0OilIF 6111111911 1 } 1 } tj t F 111 l 11111110!ll ;: { i I }I 1 i i il li I 1118 : + 111 EN i t i i n i ■■ rte, I -- -E L • }' l i { 1: I�I 1 i ' t i. i�} I , I 1 _11111 }# " III X111111 1 } '1101Ra II�'1# 1 1' r► }I = REI{RI� Hl MUMIlil�l ,' } ; , ; ! annum MMIE IEE BIBEI I1Hli!lI HfiIl1H ' f;''' BIUM NtUU� 0Huh1dIi � nmil �IiIEEEEIlt11 rt I } } 1 110 I ,li I 1111 ' ",1:1 i1 l ZTPTPV • Vl'1 -Th nxs 1 i ;I 1 '' i 0/8 FIGURE 3 CEIVED 1977 011 and Gn G;onsPr7a0ar. SPONTti',SOUS- POT ENT IAL mittivolts l 22" Cem• @ 28,: a c �, ►'r�► 2600 sk: Gloss --- 1351 Cox @ 2104" to S�+rF . __..__ , ,�.��s— top--- pr•— ==' � s� – � -- - j ► , 14" /101 518_sk _caft- r.Ean d 1c i'►st' f RESISTIVITY ohms. m /m IND 1 CONDUCTIVI'!L 1Iimhos /m = I i'1i I -a-------aaa-a I 00' sand interval orosit of 257 , a 1 e 00' far 1i y andiIthe a formation caw p 9 ears, 000 the waste maximum r case h 10,000 BWPD injected waste 031 miles) only covered a medial distance IM , - well within the boundaries of the ■�`, S of wanson River Oil Field 1615' C . � r S iL Iii1OM ■mmrrm�„r�„■m � 'ilii-iii ; ■ iiiiii;J ,,, g rma ammuwasomsammu na mom m e mowassrommom m „, ummmommunu. mummumu mmummusimuram mmummum mom mummummummuommum um mum momommemormum mum monmmumm.m. mommomm somumummumme muummum mom muommumm.m.mmumm om .. WWWWWWWWWOMMOVIORWOM g 11111101111111111111111111111111111.111111111111111111111a IMUUM101711 11110111WWWWOROOM N 17001 01117MOOMOSEM MEMO OW" MOMMINAammla 01 ,0 4 4110111 w illummtiamor 11110111MMOO weir WitarlISINS lll 111111+1111114111111111111111111111111 l avi II III 11111111 : 12 •, 5 HVED - 8 1977 Aso 4 rtrrn 7. 1 -10.73 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data TEST WATER SHUT -OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS Convert to waste water disposal 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ail pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Propose to convert SRU 41 -33 to annular casing injection. Recent 'that the current disposal wells are barely adequate to handle the Additional disposal capacity is needed to prevent any curtailment in the event problems develop with a disposal well 1) Formation water quality: approx. 4300 ppm TDS (Figure 2) SRF waste water: approx. 22,200 ppm TDS (Figure 3) Total produced water @ SRF: approx. 10,000 BWPD (Figure 4) E -log and mechanical data: (Figure Note that even if all the waste water was put into this well for 10 years, it would only cover a radial distance of 1615' (Figure 4). 16. 1 hereby certify that the forego SIGNED (This space for State office use) NOTICE OF INTENTION TO: g is true and co Submit * *Intentions" In Triplicate ect & **Subsequent Reports" in Duplicate WATER SHUT -OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) SUBSEQUENT REPORT OF: Area Supervisor TITLE APPROVED BY TITLE CONDITIONS OF APPROVAL, IF ANY: See Instructions On Reverse Side !6<4 1,4,c REPAIRING WELL ALTERING CASING ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) DATE DATE evaluation shows current water. of oil production 1) 2) 3) 4) RECEIVED JAN 281977 Division of 011 and Gas Conservation AnohoraOo i� > -j7 STATE OF ALASKA CIL AND GAS CONSERVATION COMMITTEE 5. API NUMERICAL CODE 50- 133 - 10166 -00 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.) 6. LEASE DESIGNATION AND SERIAL NO. ' A- 028339 . 7. IF INDIAN, ALLOTTEE OR TRIBE NAME GAS 111 OIL WELL ■ WELL 1 OTHER Water Disposal 2. NAME OF OPERATOR Chevron U.S.A. Inc. 8. UNIT, FARM OR LEASE NAME Swanson River Unit 3. ADDRESS OF OPERATOR P. 0. Box 7 -839, Anchorage, Alaska 99510 9. WELL NO. SRU 41 -33 4. LOCATION OF WELL At surface 850' S and 740' W from NE corner of Sec. 33 10. FIELD AND POOL, OR WILDCAT Swanson River 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 33, T8N, R9W, SB &M 13. ELEVATIONS (Show whether DE, RT, GR, etc.) 175' KB 12 PERMIT NO. 4 rtrrn 7. 1 -10.73 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data TEST WATER SHUT -OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS Convert to waste water disposal 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ail pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Propose to convert SRU 41 -33 to annular casing injection. Recent 'that the current disposal wells are barely adequate to handle the Additional disposal capacity is needed to prevent any curtailment in the event problems develop with a disposal well 1) Formation water quality: approx. 4300 ppm TDS (Figure 2) SRF waste water: approx. 22,200 ppm TDS (Figure 3) Total produced water @ SRF: approx. 10,000 BWPD (Figure 4) E -log and mechanical data: (Figure Note that even if all the waste water was put into this well for 10 years, it would only cover a radial distance of 1615' (Figure 4). 16. 1 hereby certify that the forego SIGNED (This space for State office use) NOTICE OF INTENTION TO: g is true and co Submit * *Intentions" In Triplicate ect & **Subsequent Reports" in Duplicate WATER SHUT -OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) SUBSEQUENT REPORT OF: Area Supervisor TITLE APPROVED BY TITLE CONDITIONS OF APPROVAL, IF ANY: See Instructions On Reverse Side !6<4 1,4,c REPAIRING WELL ALTERING CASING ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) DATE DATE evaluation shows current water. of oil production 1) 2) 3) 4) RECEIVED JAN 281977 Division of 011 and Gas Conservation AnohoraOo i� > -j7 • -- .. 1 ik wr► u a no, • uuu u Nam OP''sE uu. 4 •t_1•AI t Mal . tau u�u� 1,u®u , uu WI t'uu Y ER tuu INN 1115.1111101111111 uu 1711I11111111111111111111111 ILBIIVU■uuu r);113111111111111111111111111 s 4 rIIIIIIIIIIIIIIIIIIIIII al fimmemnimm IMIIIMIIIIIIIIIIIII :auuuuu11u IN ri11111.11111111111111111111 111111111111 1 u ! i 1 I 1 II imuuuiu Pl u ■u1uu 11111111111111111.1111111111 Oloomonmo or uuuuu � ~ u u iiur i unomial smoommum aui: -ex. ill tV 0 0 N W O 0 N A O: 0 0 vnans. my m INDUCTION • 22" Cem. @ 28' • • 13 Cem e ?/04" to 2co_skc . c%ss 16" NORMAL INDUCTION 50, 500 111111111111US/ 1T1 = ohm *. m` /m 1000 _ V,6 1 /, 131' CV ,2528 skr.__rft. Lo ,_...ir licalea top or__4knf �4 0 111111 11 III 1111 ASSUMING a formation porosity of 25%, a 100' sand interval and the maximum case of 10,000 BWPD injected for 10 years, the waste water will have only covered a radial distance of 1615' (0.31 miles) - well within the boundaries of the Swanson River 011 Field u iiii i di, i• Er 11111111111117 rouninprommouns 0 O Mr= ri 11 l< 111111Elifiliel •,ion N I O► Q r _ _ �'a :x.33 - iz,.F t i^, I If-1F 500 wiLL No,. SRO 221 -33 { COMPANYrANOARD OIL L LOCATION ALASKA SAMPLE SOURCE ZONE _... _ .' RADICALS PARTS PER MILLION St'I U I U; s CALCIUM MAfiNEAUM SULFATE. ClILOR I LIE CAtBO' ATE BICARBONATE TOLAL BORON EQUIVALENT SALT . 215.0 GIG, RESISTIVITY = 1.450 . CHLORINITY = 179.72 G /G, SPECIFIC GRAVITY = 1.0045, HYDROGEN SULFIDE ABSENT DISTRIBUTION C V CIIATI ERTUN E S PARKER 11C .W A I EJ F I c F 1 IC LABO UT0RY IIC UIST SECT WELL FILE CHARGL U 82248 SIGNED R M Y AM A DA e MILUGRAMS PER LITER OIL B/D PIE DATE 9/10/64 WATER B/D 109 REPORT DATE 9/25/64 GAS MCF /D 1536 LABORATORY NO. 3U9-6 4 W— 854 OIL GRAVITY SAMPLED BY METHOD ANALYST R C L U E B 1293.4 98.2 76.9 2.7 1866.3 0. 902.4 4239.9 n. Na +K 4 Cl +I +ar REACTING VALUE EQUIV. PER MILLION 14.79 , 134.97 TICKEU GRAPH X REACTING VALUE MC REP RESENTS "CONCENTRATION Of SOLIDS M NORMAL SEA WATER" APPROVEd% E FIEIlE °' C'r1 Co+ Mg+ 8a+ Sr REACTING VALUE PERCENT 56.26 41.68 4.90 . 3.63 6.33 4.69 0.06 0.04 52.64 , 39.00 0. O. 10.96 100.00 OHM —METER AT 77 OEG F PH = 7.91 CO X HCO OH RECE1VE,D JaN.2e 1s77 FIGURE 1 Division of 011 and Gas Conservation I 50 Anohorago WASTE WATER ANALYSIS SWANSON RIVER, ALASKA Cations - Mg /Liter Sodium Potassium Ammonium Calcium Magnesium Barium Iron Anions Mg /Liter Sulfate Chloride Hydroxide Carbonate Bicarbonate Borate Iodide Silica CHEVi0N OIL FIELD RESEARCH COMPANY La Habra, California SRF1 SRF2 SRF3 520o loo 40 2740 105 45 -2.1 25 12840 0 0 930 10 65 . Organics (Diethylether) Mg /Liter 48 Salinity as Salt Mg /Liter 21,170 Total Dissolved Solids Mg /Liter 22, Suspended Solids Mg /Liter 36 Turbidity - Equivalent Mg /Liter as Kaolinite Suspension Specific Gravity - @60 °F Resistivity Ohm -Cm @75 ° F Freezing Point ° F Viscosity C'Poise @ 72.7 °F pH 125 1.019 2 0.955 6.4o Trace 11770 0 0 915 35 10 . 40 39 19,400 20, 460 23 The three water samples were designated as follows: SRF1 - Discharge of water injection pump from waste water pit. SRF2 Discharge from SCU waste water line into pit. SRF3 - Discharge from SRU waste water line into pit. Project 30,286 April 15, 1969 5800 460o 95 �0 35 1610 4010 85 105 6o 25 2.6 1.5 82 1.018 31.2 29.30 0.996 6. 5o 1418o 0 0 825 3o 15 40 46 23,370 24,000 55 1.020 26.8 29.57 1.003 6.75 RECEIVED • JAN 28 1977 Division of Oil and Gas Conservation Anchorage FIGURE 2 i r111 } 1 -y l r ! +! t 11 t ;11 1 t ; 1 1 . 1 , 11i1tp i . i 1! i, T I I I I 1 ± T 11 - I. /s -- -- 1 . ... � • . .: ' 3 .lr _ . r ` . F _ T . T t - .. I } i � l • • I j 1 ! . .. r te.. � ; I : ' , : ; 1 W as ,Npr t } I I !1; r : r'l' ... _, , r 1 .! `�'. . , i t t ,ir 11..� . ` , • 1.,• 1441. — es6t 1 • { : . • ...1', . ! /-� r. 1111. -- 21161 . .,.. ... .: .. _ L. . .... ... .. ... -... .. t... •., .. - .., —...- - Li.-1- :.... ,.. .... .. i' , _ 1 1=1-1 '! • ri;! • t 1! : i t ,Nnr YrN 8--6I , • - 08 6 1 . trot ..:- -. .. _.:. • 1 .. ...-. 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MI= 1_MEI MIME NM IMO= N MUM -Ammillomm. 4 MOM MN 4110111111 111111 1 1 1 ow 22" Cem @ 28' . /31 Celn. 2 >04" to SWr a :e N 0 0 0 0 KtbI, I IV1TY I CONDUCTIVITY ohms. m2 /m illimhos /m - o;,m; m /m 16" NORMAL 50 IND UCTION wiri 2000_skc G /oss 500 INDUCTION 500 1 000 5 QQ 6 " Ceirn La' 8,1312-49111"A° . + 4529_.Sks__.trtt.�wul —l.o ._i�►dt�aee� top_ ofiGtrt dR e- 0 111111111111111 1 11 O r gm mom% MIR= MO 11,011111001 r pissrarm 1 ii, li IIIIIIIINI Idol millow 11111 111111110: 0 r, A Illi 0 114 L � ASSUMING a formation porosity of 25%, a 10 and the maximum case of 10,000 BWPD inject the waste water will have only covered a r of 1615' (0.31 miles) - well within the bo Swanson River Oil Field sofa') 0 0' sand interval ed for 10 years, adial distance undaries of the VED 1977 s Conservation a ll 3 m(' 1 ID E 4 I1 +. ..� . . ..... . .. I. ! • 3 . 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ZL-9I ParSPPV " . - -t � ' .. 71:1 ..7.....::::1-=:: . :. : i :» .. , i• . - -.-1 1 lrllf ! 51 1.1 tt .1,3 —+ _ � -• -I: • :- .1 "" :11• i` 1 1 1 61 -4. i4 i•- 1 M 1 : ts. ; s I .... a - . 1 . ./ :. 11 r Pot ill ... .'.. s ) ! I ::,., : :. I r a,n, "" - 29 - 61 i ! • .• • ivi o n t 1 a { .•� Ct3risorY 4iuit ' a l • 3 2 • • • S, • • r N 0/9 TO: PLACE: COMPANY \Yer,41_ RECEIVED BY TRANSMTTAL ACKNOWLEW;EMENT OF RECFJPT 01 TEMAL - (ALASKA) DATE THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE .IMMEDIATELY. • WELL HISTORY LOG 2" 5" at_ 4/- 1, REMARKS Oiii . .)10E , THIS SHEET /1 I 11 /4 $1 -34 41-9 el- 8' FD Folded R Ro!Led S - Sepia F - Film X - Xerox B - BIuerine iI 41 If #1 11 1 100 200 ) // 1 1 t 1) 1/ I/ 1 •■••••••••••••■• i.'_ites-e e Box 937 Rock Springs, Wyo. 82901 Area Code 307 Tel. 362 -6488 Producing Formation Elevation (CHF, DF, KB, etc.) Datum subsea, or Tubing set at Casing set at Production Packer at Perforations Subsurface Controls . (Nipples, etc.) instrument Data Company Running Survey Element Range & No. Clock: - Range & No. Calibration Date Static Pressure Data Pressure at Datum @ ) Shuit -in Time Pi at Datum Shut -in Tubing Pressure Shut -in Casing Pressure Top of Oil Top of Water Temperature at Date of Last Test Pressure @ ; Datum, Last Test Shut -in Time Last Test Flow Test Data Remarks: 0690 Choke Size Period of Stabilized Flow Stabilized Production Oil Gas Water Flowing Tubing Pressure Flowing Casing Pressure feet Opera or . Hopper C. A. White Wire Line Well Service Box 156 Casper, Wyoming 82601 SUBSURFACE PRESSURE SURVEY C. A. White K2 7079 6000psi 3 Hr. April 1, 1975 psig hrs. psig psig 166 °F psig in hrs bbls /day MCF /day bbls /day psig psig Depth D 0 200 400 600 800 000 020 1040 1060 1069 Time Standard Time Press. ft 3437 3690 3867 4060 4263 4429 4426 4429 4471 4468 Oil Company Press., P, psig At hrs. Box 962 Soldotna, Alaska 99669 Area Code 913 Tel. 262 -4496 Company Lease Well No. 4 1"33 Field Swanson River State Alaska Test Date April 10, 1975 Zero Point KB GRD AP 2 53 177 193 203 166 Tubing Press. A D 2000 2000 2000 2000 2000 200 200 200 90 Casing Press. Static Test Gradient .126 .089 •097 •102 •083 Remarks Phone SEC.-AND M or 33 .E T INT . 8N 9W UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY state ,Al County Kenai Peninsula The followine is a correct report of operations ard wells) for the month of January_ , 1 ,9_ client's address _ _. -. P.00Box_ 7*839---- - - - -- - -.._ -- - Anchorage Alaska B, ?-6201 RANOK WELL No. DAT• PaOorcico BARSSLS Or OIL SWANSON Remedial work commenced ; January ' 1963* tree an £nstelled BOPE. Palle tubing 2 7/8" ubing equipped with pac r and m tubing t 1002'* Retuined well to prod Rig relgased jJanuary 11, 1963. U.S.G.S State - U. S. F Riehfie Maratho Union - Files GRAVITY RIVER 14. • R. eh SL, C Si! n ed UNIT 41 -33 (15) H. Sojste Marshall �d ild"life - . W. Perry R� Ro Ritter( - Ge rge Sowar4s . M. Li an roducing (2) NOTE. —There were runs or sales of oil; LESSEE'S MONTHLY REPORT OF OPERATIONS Budget Bureau No. 42- ApprOral expires 12.31 -tiO. LAND . Anchbrr _ _. LEASE NUMBER - 28339 uNl, - _._.Zweac_ison_ River Unit Field _. __ .. Swanson' River production drillinf and producing Swanson River Unit C07fl/ Z7►If •.� _ Cd. ! CALIF • WOI os' • N V;;;Iy • ant's tide . District Superintendent ._ (.ALLONs')V BARRELS OY ILEMA1.1KS co. FT. OF GA, (,ilsoLiss WATER Of (If drilling, depth:, it abut down, ,.mu:iu• (Itl thousar *1s) 7:BcovsazD none, so state) date and re,idt of :e•t for ganuline 00111uD1 OF groA DMsion Alaska D Removed x•-mas ut of hole* Reran ndrels. Landed ction. Fig 1 i troleum Branch Mines and Minerals t. of Natural Resourr4V! M cu. ft. of gas sold; runs or sales of gasoline during the month. (Write "no" where applicable.) NoTE. -- Report on this form is required for each calendar month, regardless of the status of operations, and Must be filed is duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form. 9 -328 15---21,766-8 U. $. 3OVL/INaEHi Pu�rl«o OFFICE (Jpnuary'3930) CASING SIZE WEIGHT, LB /FT. !I DEPTH SET (MD) HOLE SIZE CEMENTING RECORD AMOUNT PULLED Z7 Z6 1 3 ' ''s Z1 oil - aooa C / 11 13► q /1 24'28 .� 26. LINER RECORD 27. TUBING RECO11D SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MD) vig IQ IbS)ti 28. PERFORATIONS , OPE,N TO PRODUCTION (interval, size and number) 4- � I Di (. - (0 coy .AC 1 RE, CE2.ILNT SQUET R, ETC. 29. ACID, SUOT, F:; "Z DEPTH INTERVAL (MD) AMOUNT AND KIND OF MA'IEEIAL USED 1 urns P- WELL COMPLETION OR RECOMPLETION REPORT AND LOG * Ia. TYPE OF WELL: b. TYPE OF COMPLETION: NEw R'ORIC (� EN LJ BACK I: SVR. Other 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirementa)* At surface At top prod. interval reported below At total depth 13. DATE SPUDDED 14. DATE T.D. REACHED 18. 'TOTAL DEPTH, MD & TVD 24. TYPE ELECTRIC AND OTHER LOGS RUN 30. . DATE OF TEST. LHOURS TESTED . CIIOKE SIZE FLOW, TUBING CASING PRESSURE PRESS. 32. LIST OF ATTACHMENTS (t DVS 3 l • DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) 19. PLUG, BACK SIGNED 0 eq ' C61.4 6-76 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 011, 1 I;AS WELL L_1 WELL l__J DRY 0 Other 15. DATE COMP SUSP OR ABAND. CASING RECORD (Report all strings set in well) CALCULATED OIL -BBL. GAS -MCP. 24-HOUR. RATE MD & TVD PRODUCTION PROD'N FOR TEST 1'IGlIOD 20. IF MULTIPLE COMPL., HOW MANY' TITLE OIL -BBL. SUBMIT IN DT! , -SATE • -- (See other In- structions on reverse side) 22. PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BOTTOM, NAME (MI) AND TVD)" 16. ELEVATIONS (DF, RKB, RT, 21. ROTARY TOOLS DATE FIRST PRODUCTION PRODUCTION ME1HOD (Flowing, ga..3 lift, pumping -size and type of pump) GAS- MVICF, 1 1 W AILH. -BBL. *(See Instructions and Spaces for Additional Data on Reverse Side) 5. API NUMERICAL CODE $o 133-- /o K.6 6. LEASE DESIGNATION AND SERIAL NO. 9. WELL NO. RI.,- 4 ( - 33 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT,FAR.M OR LEASE NAME 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT Nit 3 66 GR, ETC) *117. ELEV. CASINGHEAD 4 I NTERVALS DRILLED BY CABLE TOOLS 23. WAS DIRECTIONAL SURVEY MADE 'WELL STATUS ( Producing or Enid -in) WATER -BBL. TEST WITNESSED BY 33. I hereby certify that the foregoing and attached information is complete and correct as determined from all available records GAS - OIL R.1TIO OIL GRAVITY -API (CORR.) DATE __'r (j3_-- ARY OF FORMATION TEST'S Iru L.uLINc; INTERVAL TESTED. PRESSURE DATA AND RECOVERIES OF OIL, GAS. 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: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional inter val to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement ": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). WATER AND MUD DATA. AT'ACII 'BRIEF DESMIIRITIONS OF L.ITIIOLOGY, POROSITY. FRACTURES. APPARENT !MPS AND DETECTED SHOWS OF OIL, GAS OR WATER. 35. GEOLOGIC' MARKERS NAME MEAS. DEPTH TRUE VERT. DEPTH ELEVATION: 175' K.B. DATE: May 5, 1961 TOTAL DEPTH: 11,133' COMPLETION REPORT - NEW WELL SUMMARY JUNK: 88' of Schlumberger 2 1/8" jet capsules. STANDARD OIL COMPANY OF CALIFORNIA - WESTERN OPERATIONS INC. - OPERATOR AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage Lease No.: 028339 PROPERTY: Swanson River Unit WELL NO.: SRU 41 -33 SECTION 33, T. 8 N.,R. 9 W., Seward B & M LOCATION: Surface: 850' south and 580' west kt right angles from northeast corner Section 33, T. 8 N., R. 9 W., Seward B & M. B. ids 15'rgve ,ground. I �` .. ; BY: a i ';' :ter - 'A" C. r C. V. CEATIERTON, District Superin- tendent DRILLED BY: Coastal Drilling Company DATE COMMENCED DRILLING: January 22, 1961 DATE COMPLETED DRILLING: March 12, 1961 DATE OF INITIAL PRODUCTION: March 16, 1961 PRODUCTION: Daily Average 432 Flowing Oil 428 Gravity 35.4 Water 4 TP 1650 Gas 85 Bean 8/64" PROPERTY OF DEVELOPMENT ENGINEERING ALASKA DIVISION PLUGS: 11,133 - 11,088 CASING: 22" Conductor cemented at 28' 13 3/8" casing cemented at 2104' around shoe with 2000 sacks. 6 5/8" casing cemented at 11,131' around shoe with 2528 sacks. COMPLETION REPORT - B4CKER AND GAS LIFT INSTALIATION STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - Operator AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage Lease No.: A- 0 PROPERTY: Swanson River Unit WELL NO.: SRU 41.33 Section 33 T. 8 N., R. 9 W., Seward B & M LOCATION: Surface: 850' South and 740' West from Northeast Corner of Section 33. ELEVATION: 175' K. B. K. B. is 15' above ground. DATE: July 1, 1963 BY: CONTRACTOR: Santa Fe Drilling Company, Rig #35 DATE COMMENCED REMEDIAL WORK: January 5, 19 DATE COMPLETED REMEDIAL WORK: January 11, 1963 CASING: 22" cemented at 28' 13 3/8" cemented at 210+' 6 5/8" cemented at 11,131' C.V. CHATTERTON, District Superintendent SUMMARY TOTAL DEPTH: 11,133' PLUGS: 11,088' - 11,133' JUNK: None COMPLETION REPORT SWANSON RIVER UNIT SRU 41 -33 Section 27, T. 8 N., R. 9 W., Seward B & M STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR PERFORATION RECORDS: 1. 5 -e jet holes at 10,618'. 2. 4 - in jet holes per foot 10,674 - 10,764'. WELL SURVEYS: 1. Schlumberger I -ES log interval 11,128 - 2,105'. 2. Schlumberger Sonic log interval 11,125 - 10,000' and 8,000 - 2,105'. 3. Schlumberger Micro log interval 11,127 - 10,000'. 4. Schlumberger Neutron Collar log interval 11,0+0 - 9,500'. 5. Schlumberger Cement Bond log interval 11,035 - 5,5 6. Baroid mud log interval 9,870 - 11,133'. DRILL STEM TESTS: 1. H.C.T. W.S.O. Test #1 on 5 -e holes at 10,618'. W.S.O. Page 2. COMPLETION REPORT SWANSON RIVER UNIT SRU 4 1 -33 Section 27, T. 8 N., R. 9 W., Seward B & M STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR January 22, 1961 Spudded at 12 NOON, January 22, 1961. Drilled 12 *" hole 0 - 452' 452' drilled 79 pcf mud January 23, 1961 Drilled 12u" hole 452 - 2,733' 2,281' drilled 81 pcf mud January 24, 1961 Drilled 12k" hole 2 ,733 - 3,035' 302' drilled Opened 12i" hole to 18 5/8" hole 0 - 1,564' 1,564' opened 81 pcf mud. January 25, 1961 Opened 12, —��" hole to 18 5/8" hole 1,564 - 3,025' 1,461' opened Circulated a hour. Pulled out. 84 pcf mud. January 26, 1961 Circulated and conditioned hole 2 hours. Commenced running 13 3/8" casing. Casing froze at 2,104'. Cemented casing at 2,104' in a single stage with 2000 sacks of cement using Halliburton power equipment. Used 1 top and 1 bottom rubber plug. Cemented around shoe with 2000 sacks of cement. Pumped 50 bbls. of water ahead, mixed 2000 sacks of cement in 7# mins. using Halliburton truck, dis- placed in 28 mins. using rig pumps. Average slurry weight 116#. Bumped plug with 1200 psi. Full circulation.; Good returns. Cement in place at 2 :20 PM. Page 3. COMPLETION REPORT SWANSON RIVER UNIT SRU 4 1 -33 Section 27, T. 8 N., R. 9 W.., Seward B & M STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR January 26, 1961 Qg ti =4 CASING DETAIL: ALL 51 joints or 2,116' Above K.B. 12' Casing landed at 2,104' Landed casing. Welded on casing head. January 27, 1961 Flanged up. Installed and tested BODE with 1500 psi for 30 mins. OK. Tested Kelly cock, pipe rams, and hydrill with 1500 psi.. OK. Drilled out cement and shoe 1,977 - 2,100. January 28, 1961 Drilled 124" hole 3,035 - 3,786' Drilled 9 7/8" hole 3,786 .. 4,087' January 29 - February 24 1961 Drilled 9 7/8" hole 4,087 - 10,630' 6,543 February 25, 1961 Cored 8 7/8" hole. Core +1 10,630 10,654' Cored 24' 13 3/8" 54.5# J -55 8 R Equipped with Baker Guide Shoe and Baker Flexi -flow float collar, and D.V. Collar. 751 drilled drilled Baroid mud logging unit installed on February 20, at 9,870'. Recovered 24' Page 4. 84 pcf mud 79 pcf mud 301' drilled 78 pcf mud 1961. Commenced logging 8o - 98 pcf mud 98 pcf mud COMPLETION REPORT SWANSON RIVER UNIT SEU 41 -33 Section 27, T. 8 N., R. 9 Seward B & M STANDARD OIL CO. OF CALIFORNIA, W.0.1. - OPERATOR February 25, 1961 Continued ' Sandstone. As immediately above. 24' Cut and recovered. Page 5. Core Description: 2' Sandstone. Hard, fine grained, well cemented calcareously cemented, micaceous sandstone with micaceous (primarily biotite) partings. Shows dull white (mineral ?) Fluoresence NOSC dip flat to 15 ° . Siltstone. Hard, fine grained, micaceous siltstone. Inclusions and small streaks of coal. NOSCF. Dip 17 ° . 22' Oil Sand. Firm, fine to medium grained, well sorted oil sand. Good even bright yellow fluoresence. Light amber cut, good odor, stain. Dip 17 - 21 °. 74' Siltstone. Firm to hard, fine grained, micaceous siltstone with inclusions and streaks of coal. Micaceous partings and streaks of hard fine grained sandstone becoming more sandy toward base of interval. Slight odor dull white (mineral) fluoresence. No cut. Dip 7 ° ±. Oil Sand. Firm fine to medium grained well sorted oil sand. Good even bright yellow fluoresence, light amber cut, good odor. 62' Sandstone. Hard, fine grained, micaceous sandstone with occasional coal inclusions becoming fewer toward base of interval. One 4" streak bled oil and occasional OSCF noted on partings - otherwise NOSCF. Dip 10 on micaceous partings. 1z' Oil Sand. Firm, fine grained well sorted micaceous oil sand. Bright yellow fluoresence, good odor, light amber cut. Core recovery, poor a/c core badly broken during; extraction from barrel. 1' Sandstone. Very hard calcareously cemented 14 11 sorted 'salt and pepper' sandstone NOSCF. 1' Oil Sand. Hard fine grained well sorted oil stained sand. One u" pebble noted. Core bled oil. Bright yellow fluoresence, light amber cut, good odor. COMPLETION REPORT SWANSON RIVER UNIT SRU 41 -33 Section 27, T. 8 N., R. 9 W., Seward. B & M STANDARD OIL CO. OF CALIFORNIA, W.O.Z. - OPERATOR February 26 - 27, 1961 Cored 8 7/8" hole. Core #2 10, 654 lo, 682' Cut 28' Recovered 28' Page 6. Core Description: 3' Siltstone. Firm, grey, fine grained, micaceous siltstone with streaks and inclusion of coal and carbonaceous material. One 2" streak fine grain oil sand 30" from top of core. Slicken sides noted at top of core. NOSCF. Cross bedded. 1' Sandstone. Hard, fine grained, calcareously cemented in part, micaceous sandstone NOSCF. One 2" streak fine grained oil sand near base of interval. 8' Siltstone. Firm, grey, carbonaceous siltstone becoming finely sandy and micaceous at intervals. Coal inclusions and streaks. Dip on micaceous intervals 0 - 5 NOSCF. One 2" streak fine grained oil sand near base of interval. 4' Oil Sand. Firm, fine grained, silty, micaceous oil sand with barren streaks where sand appears to have poor permeability grading to fine - medium grained oil sand. Good stain. Good fluoresence, odor, and cut. 1' Coal and silty coal. 32' Siltstone. Firm grey carbonaceous Siltstone with coal streaks and inclusions. One 2" streak fine grained oil +ained sand. 72' Oil Sand. Firm, fine to medium grained, micaceous becoming massive evenly sorted at intervals, oil sand one thi: coal streak noted. Evenly stained. Bright yellow fluoresence, light amber cut, good odor. 28' Cut and recovered. Cored 8 7/8" hole. Core #3 10,682 - 10,691' Cut 9' Recovered 9' Core Description: 4' Oil Sand. Firm fine to medium grain well sorted massive oil sand. Even oil stain and bright yellow fluoresence. Good odor and light amber cut. One 9" streak very hard calcareously cemented fine to medium grained. sandstone. 22' below top of core. C a IETI4N REPORT SWANSON RIVER UNIT 8AU x=-33 Section 27 T. ,8 N::;• ` : W: Seward B & M Page 7. STANDARD OIL CO. OF CA FO" ' , W. O.I . - OPERATOR February 26 - 27 ,z 1004.. Qdptinued 5e Conglomea 0i1 Sand. Firm fine to medium grained matrix with rounded averaging " in diameter and ranging up to 1" in diameter. Pebbles are predominantly quartz and chert. Even bright yellow fluoresence on sand matrix. Good stain, odor and cut. Becomes increasingly conglomeratic toward base of core. 9' Cut and recovered. Cored 8 7/8" hole. Core 34 10,691 - 10,698' Core Description: 6' Conglomeratic Oil Sand. Firm massive conglomeratic oil sand with fine to medium grained oil sand matrix. Rounded pebbles of chert and . quartz ranging up to 1" in diameter but predominantly ± u" in diameter. Good OSCF. One 9" streak of very hard fine to medium grained calcareously cemented sandstone. One micaceous and carbonaceous parting noted in this interval. Streak at 106. NOSCF. 1' No recovery. 7' Total Cut 7' Recovered 6' February 28, 1961 Cored 8 7/8" hole. Core #5 10,698 - 10,726= Core Description: Cut 7' Recovered 6' Cut 28' Recovered 28' 99 p cf mud 2' Oil Sand. Firm, fine to medium grained with occasional coarse grains, moderately friable, massive oil sand. Bright yellow fluoresence, even oil stain, amber cut good petroleum odor. 4' Conglomeratic Oil Sand. Firm, moderately friable massive conglomer- atic oil sand. Matrix fine to medium grained oil sand with rounded pebbles up to 1" in diameter. Average pebble diameter u ". Streak of oil sand as above at 10,702'. Good OSCF. C0NPI TION REPORT SWANSON RIVER UNIT MU la..33 Section, 27 T. 8 N. R. 9 W., Seward B & M Page 8. STANDARD OIL C(, OF CALIFORNIA, W.O.I. - OPERATOR February 20 1961 Continued ■r wrwr �r arwww 1' 011 Sand as described in first 2' of core with occasional pebbles. 2' Sandstone. Very hard, medium grain with some coarse grains and occasional pebbles, calcareously cemented, salt and pepper sandstone. Occasional carbonaceous inclusions. Banding and micaceous streaks indicate fair dip of 20 °. Good slicken sides at middle of interval NOSCF. Oil Sand. Firm, moderately friable, fine to medium grained, massive wwbroseawastersft oil sand. Well sorted except for occasional pebbles of ± " dia- meter. Occasional carbonaceous inclusions. Sand has brown sugar appearance. Even stain yellow fluoresence amber cut good odor. 12' Oil Sand. As described immediately above except becoming more firm and no pebbles evident. Cut and recovered 28' March I 1961 Cored 8 7/8" hole. Core #6 10,726 - 10,754' Cut 28' Recovered 28' Core Description: 4' Oil Sand.. Medium grained, firm, finely micaceous, evenly sorted slightly silty, brown oil sand with good even saturation, golden fluorescence, dark brown cut, and sweet petroleum odor. Interbedded Carbonaceous Siltstone. Medium gray, micaceous, with laminae of fine grained, clayey brown oil sc. :4. Coal streaks. Dip 10 - 11 good. 2' Pebbly Oil Sand. Medium to coarse grained, poorly sorted, brown oil sand with rounded pebbles up to ir in diameter. Golden fluorescence, br cut, sweet petroleum odor. 3' Oil Sand. Massive, medium to coarse grained, locally poorly sorted, micaceous, slightly silty, as above. Brown oil sand, golden fluorescence and dk. br. cut. 1' Pebbly Oil Sand. As above. 4i Oil Sand. Massive, medium to coarse grained, locally granular, micaceous, firm dark brown oil sand, as above. Good P & P. Golden fluorescence and br. cut. l' Gray Sandstone Shell. Lime cemented, medium to coarse grained, pebbly and cobb y with some coal pebbles. iOSCP. 12' COMPLETION REPORT SWANSON RIVER UNIT SRU 41 -33 Section 27, T. 8 N., R. 9 W., Seward B & M STANDARD OIL CO.. OF CALIFORNIA, W.O.I. .. OPERATOR March 2, 1961 Cored 8 7/8" hole. Core 10,754 - 10,771' Core Description: Page 9. March 1, 1961 Continued 62' Conglomeratic Oil Sand. Pebbly to cobbly, coarse grained. Poorly sorted brown oil sand with rounded to sub - rounded pebbles and cobbles of white quartz, black chert, dark green metamorhics and red Jasper up to 12" in diameter. Average, 1" in diameter. Good P & P. Golden fluorescence. Br. cut. Even saturation and sweet petroleum odor. 12' Brown Oil Sand. Medium grained, firm, as above. 2' Pebbly Oil Sand. As above with pea sized pebbles. Good fluor. & Dk. br. cuts. Good. Pet. odor_. 1' Lime Cemented Gy Sandstone Shell. As above NOSCF. Cut 17' Recovered 14' 99 p cf mud. Oil stained Conglomerate and Conglomeratic Oil Sand. Massive, poorly sorted., firm to crumbly, coarse grained granular brown oil sand matrix with rounded to sub rounded pebbles and cobbles up to 12" in diameter. Average 2" in diameter of dark gray and white quartz, black chert, greenish gray and dark gray metamorphics and rare red jasper. Good even oil saturation, golden fluorscence, dark brown cut, and sweet petroleum odor. Good. r & P. Lime Cemented Gray Sandstone Shell. Medium grained, tight, limy, pebbly. NOSCF. 1' Pebbly Oil Sand. Massive, medium to coarse grained, pebbly firm, slightly friable. Dark brown cut, good odor, good P & P. 3' No recovery. 99 pcfmud March 3, 1961 Cored 8 7/8" hole. Core #8 10,771 - 10,790 Cut 19' Recovered 172' Core Description: 8 Pebbly Oil Sand. Massive, coarse grained to locally medium grained, also granular, micaceous, with rounded pea size pebbles, good even COMPLETION REPORT SWANSON RIVER UNIT SRU 41 -33 Section 27, T. 8 N., R. 9 W., . Seward B & M Page 10. STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR March 3, 1961 Qontinued oil staining. Golden fluorscence, brown cut, sweet petroleum odor. Good P & P. 3" Limy Sandstone Shell. Tight, pebbly, NOSCF. 7,i-," Oil Stained Conglomerate. Massive, poorly sorted conglomerate with coarse grained brown oil sand matrix. Pebbles and cobbles rounded as above of Gy quartz, black chert, etc. Average 1" in diameter. One cobble 3" in diameter. Even oil saturation. Golden fluorscence, brown cut. Faint petroleum odor. Gray Conglomerate. Lithology as above with local spotty oil staining, badly broken, crumbly, friable coarse to medium grained gray sand matrix. Looks wet. No petroleum odor. Spotty dull fluorscence. No cut. 1 ' No recovery. March 4, 1961 Opened 8 7/8" hole to 9 7/8" hole. 10,630 - 10,790' Drilled 9 7/8" hole. 10,790 - 10,805' March 5 - March 6, 1961 Drilled 9 7/8" hole 10,805 11,133' T.D. 160' opened 15' drilled 99 pcf mud 328' drilled 99 pcf mud Circulated and conditioned mud. Pulled out. Baroid mud Logging unit released March 6, 1961 99 pcf mud March 7, 1961 Attempted to run Schlumberger I -ES log, tool failed to operate. Attempted to run Schlumberger Sonic log, hit bridge at 10,549'. Laid down tools. Ran in, circulated and conditioned mud. Ran Schlumberger I -ES log 11,128 - 2,105', Sonic log 11,125 - 10,000' and 8, 000 - 2,105', Micro log 11, 127 - 10, 000' 99 pcf mud COMPLETION REPORT SWANSON RIVER UNIT SRU 41 -33 Section 27, T. 8 N., R. 9 W., Seward B & M STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR Page 11. March 8, 1961 Circulated and conditioned mud. Laid down D.P. Ran 268 joints of 6 5/8" casing. March 9, 1961 Cemented 6 5/8" casing at 11,131' around shoe with 2528 sacks of cement treated with 0.3% HR -4 using Halliburton power equipment. Used 1 rubber plug. Pumped 50 bbls. of water ahead, mixed 2528 sacks of cement in 80 mins. using Halliburton truck, displaced in 42 mins. using rig pumps. Average slurry weight 117#. Lost circulation last 10 mins. of displacing. Cement in place at 3:30 AM 3 -9 -61. Casing Detail: Top 3 Juts. Next 154 Jnts. including X -ove Next 93 Jnts. including X -ove Bottom 18 Jnts. ALL 268 Jnts. Above K.B. 123.38' r 6 ,59 0 .3 1 ` r 3,703.20' 724.42' 11,141.31' 10.31' 6 5/8" 28# P -llo 8 R 6 5/8" 24# N -80 BT 6 5/8" 24# N -80 BT 6 5/8" 28# P -110 8 R equipped with float shoe and float collar 1 jnt. above. Landed, casing at 11,131' Installed and tested secondary* pack off with 3500 psi, OK. Flanged up. Installed and tested BOPE with 1500 psi. OK. Tested blind rams, pipe rams, hydrill and Kelly cock with 1500 psi, OK. Ran Schlumberger Cement Bond log interval 11,035 - 5,500' and Neutron Collar log 11,040 - 9,500'. March 10, 1961 Ran Schlumberger jet gun and perf'd. 5 - i holes at 10,618' for H.C.T. W.S.O. Test #1. Tool assembly as follows: 2 outside BT recorders, 5' of 2 7/8" perf'd. tail pipe, 6 5/8" Type "C" hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrosping tester, and dual closed in valve. Used 2,617' of W.C. Ran on 10,562', 2 7/8" EUE Tubing. Set Packer at 10,580' with 17' of tail to 10,597'. No ISI Pressure. Opened tool to surface at 12:42 PM for 6o min. flow test. Puff blow then dead. Shut in tool at 1 :42 PM for 40 min. FSI Pressure. Pulled packer loose at 2 :22 PM. Recovered 15' net rise, all drilling fluid.. PRESSURE DATA: IH IF FF Top Inside Bottom Inside Top Outside Bottom Outside W.S.O. OK. Clock did not run. 7328 1207 1205 Clock did not run. 7426 1232 1230 FSI FH 1488 7249 108 7333 COMPLETION REPORT SWANSON RIVER UNIT SRU 41 -33 Section 27 T. 8 N. R. 9 W., Seward B & M STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR March 10, 1961 Continued Laid down tester. Ran 2 7/8" tubing, joint one stand up, to 11,007'. March 11, 1961 Backscuttled drilling fluid in hole with oil, preceded oil with 50 bbls. of water. Landed tubing at 10, 646' . Tubing Detail: 337 Jnts. Landed tubing gt ..10, 645.96' Removed APE. Installed and tested Xmas tree with 2500 psi. OK. Ran Schlumberger collar locator to bottom. Recorded casing and tubing collars to 10,400'. Tubing shoe recorded at 10,657'. Attempted to run 90' Schlumberger string shat of 2 i/8" capsules. Ran 88', parted and dropped down the tubing. Chased string shots with Schlumberger sinker bars to below interval to be perf'd. March 12,,,.1961 Ran Schlumberger string shot and jet perforated 4 - 2" holes per foot over the interval 10,764 - 10,674', using through tubing procedure. Removed Schlumberger tools. Production test as follows: Formation oil to surface at 10 :30 AM. Flowed oil to tank until 12 :15 PM. Started flowing to trap at 12 :20 PM. Repre- sentative flow rate and cuts as follows: Flow Per t hour hour % Total Cut 4.2 4.0 3.4 2.0 JDK:10 2 7/8" EUE Tubing 10,623.96' Pup Joint 6.00' Landing Nipple 2.00' Below K.B. 1+.00' Flow Rates Oil. Gas Bean d Size 10.5/ 725 B/D 98 MCF /D 64 990 B/D 156 MCF /D 13/64 Water % Emulsion 4.o 3.4 1.8 0.9 0.6 1.6 1.1 with Tbg. Press. 1640 1600 0.2 T T T 150o 75 1490 75 Page 12. beveled collar on bottom and pup CL4s. Trap Press. Press. % Sand & Mud Corr. Gravity 34.8 34.7 Shut well in at 2 :30 PM. Shut in pressures: Tbg. Press. 1730 psi, Csg. Press. 1525 psi. Produced estimated. 267 bbls. oil. Flowed 182 bbls. to tank and 85 bbls. to trap. Installed. Cosasco plug. Rig released 3 :00 PM March 12, 1961. Mr. J. B. Hundley Drilling started.: Drilling completed: Well completed: Total depth: Casing record: Production: Junk: Remarks: COMPLETION REPORT (NEW WELL) Swanson River Unit No. 41 -33 - Alaska U. S.L. Anchorage 02 3399 January 22, 1961 March 6, 1961 March 12, 1961 11133', plugged 11131' - 11086'. 22" conductor at 28'. 13 -3/8" 54.5# J -55 casing cemented at 2104'. 6 -5/8" 28 & 24# P -110 & N -80 casing cemented at 11131'. Perforated 10764' - 10674' with 4 -i" jet holes per foot. Well on production test at 10 :30 A.M. March 12, 1961. Flowed 267± bbls. formation oil at maximum rate 990 B /D, 3.4 %, 34.8°, 156 MCF /D, 1600/1490#, 13/64" bn. Well shut in at 2:30 Pat March 12, 1961. Well on production March 16, 1961: 3-16: 3 -17: 3 -18: 3 -19: 3-20: 3 -21: 3 -22: 3-23: Development Engineering Alaskan Exploration Division Anchorage, Alaska March 28, 1961 (js) 90' x 2 -1/8" capsule jets at 11086'. Drilled by Coastal Drilling Co. (Standard Oil Co. - Operator) 235 B /N, 1 %, 35.4, 34 MCF /D, 1525/1650, 8/64" bn. 13 hrs. 435 B /N, 1%, 35.4, 68 MCF /D, 1525/1650, 8/64" bn. 24 hrs. 4 35 B /N, 1%, 35. 71 MCF /D, 1525/1650, 8/65" bn. 24 hrs. 427 B /N, 1 %, 35.4, 79 MCF /D, 1525 /1650, 8/64" bn. 24 hrs. 428 B /N, 1%, 35.4, 86 MCF /D, 1525/1650, 8/64" bn. 24 hrs. 431 B /N, 1 %, 35. 7 MCF /D, 1525/1675, 8/64" bn. 24 hrs. 431 B /N, 1%, 35.4, 76 MCF /D, 1525/1650, 8/64" bn. 24 hrs. 432 B /N, 1 %, 35.0, 84 MCF /D, 1525/1650, 8/64" bn. 24 hrs. This is the twelfth well completed in the Hemlock Zone, Swanson River Unit, Swanson River Field, Alaska. This is the first well completed by perforating through tubing . in crude oil. R. J Misbeek COMITION REPORT S ANSON RIVER UNIT SRU 41 -33 Section 27, T. 8 N., R. 9 W. Seward B & M STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR Depth 34 3,035 ' 4,085' 5,231' 8,567' DEVIATION DATA Degrees 0 - 30' 1 - 00' 0 - 45' 2° - 00' 1° - 45' PRODUCING DEPARTMENT TELEPHONE BR. 7 C. V. CHATTERTON DISTRICT SUPERINTENDENT P. O. BOX 7-839 CONFIDENTIAL Mr. D. D. Bruce Alaska Oil & Gas Conservation Commission 329 Second Avenue Anchorage, Alaska Dear Sir: Enclosed, herewith, is the Completion Report for the Swanson. River Unit Well No. 41 (15) for your informa- tion and files. Enclosure • May 22, 1961 ANCHORAGE ALASKA Very truly yours, STANDARD OIL COMPANY OF CALIFORNIA Western Operations, Inc. C. V. CHATTERTON rrrvI\ MAY 24 19(ii STANDARD OIL COMPANY OF CALIFORNIA - WESTERN OPERATIONS INC. - OPERATOR AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage Lease No.: 028339 PROPERTY: Swanson River Unit # A1" so .13S./C1/46 • 6a WELL NO.: SRU 41-33 SECTION 33, T.8 N. , R. 9 w., Seward B & M LOCATION: Surface: 850' south and 580' west k.t right angles from northeast corner Section 33, T. 8 N., R. 9 W., Seward B & M. ELEVATION: 175' K.B. DATE: May 5, 1961 TOTAL DEPTH: 11,133' COMPLETION REPORT - NEW WELL BY: SUMMARY JUNK: 88' of Schlumberger 2 1/8" jet capsules. 9s .15'- a have ,ground. �,.R' r ., ,:fWi�. �' .. C. V. CEATTERTON, District Superin- tendent DRILLED BY: Coastal Drilling Company DATE COMMENCED DRILLING: January 22, 1961 DATE COMPLETED DRILLING: March 12, 1961 DATE OF INITIAL PRODUCTION: March 16, 1961 PRODUCTION: Daily Average 432 Flowing Oil 428 Gravity 35. Water 4 TP 1650 Gas 85 Bean 8/6/+" PLUGS: 11,133 - 11,088' CASING: 22" Conductor cemented at 28' 13 3/8" casing cemented at 21Q+' around shoe with 2000 sacks. 6 5/8" casing cemented at 11,131' around shoe with 2528 sacks. 7 MAY 24 1 77 i.•F Is Alaska % :j L v i. Laces COMPLETION REPORT - PACKER AND GAS LIFT INS SWANSON RIVER UNIT 41 -33 Section 33 T. 8 N. R. 9 W. Seward B & M Tr' vi xW uIL OuMk'ANY OF CALIFORNIA, WESTERN January 5, 1963: Commenced rigging up at 6:00 PM. January 6, 1963: Rigged up and conditioned Black Magic Mud. January 7, 1963: Killed well, removed x -mas tree and installed BOPE. K. B. to tubing hanger Donut and nipple Pup joint 45 joints 2 7/8" tubing Camco MM Mandrel w /RD ( #1) 46 joints 2 7/8" tubing Cameo MM Mandrel w /RD (#2) 41 joints 2 7/8" tubing Cameo MM Mandrel w /RD ( #3) 33 joints 2 7/8" tubing Camco MM Mandrel w /RD (#4) 30 joints 2 7/8" tubing Camco MM Mandrel w /RD (#5) 26 joints 2 7/8" tubing Camco MM Mandrel w /RD (106) 22 joints 2 7/8" tubing Camco MM Mandrel w /CEV (#7) 86 joints 2 7/8" tubing Otis "5" nipple (Pos. #2) 1 joint 2 7/8" tubing 1 Camco Sleeve Valve 1 joint 2 7/8" tubing Brown CC Safety joint Pup joint Brown 6 5/8" X 2 7/8" HS -16 -1 packer 2 joints 2 7/8" tubing Otis "S" Nipple (Pos. #i) 1 joint 2 7/8" tubing Otis Expandable Plug Nipple Tubing Landed at 15.00' .72' 1.62' 1417.59' 12.93' 1451.07' 13.11' 1291.07' 13.10' 1039.42' 13.02' 9 13.14' 820.30' 13.11' 695.66' 13.06' 2720.15' 1.58' 30.90` 2.61' 31.74' 1.07' 8.02' 6.00' 63.441 1.62' 31.35' 1.06. 10,672.42 ' Tr LI ATION OPERATIONS, INC. - Operator January 8, 1963: Pulled tubing loose, ran to 10,960' and circulated. Pulled tubing out of hole. Ran casing scraper and cleaned ou to 10,960'. Circulated. January 9, 1963: Puled out of hole. Ran saw tooth shoe and recovered junk consisting of 2 1/8" capsule jets left in hole from original completion. Cleaned out to 11,088'. Circulated. January 10, 1963: Reran tubing equipped with packer and gas lift mandrels. All tubing (334 joints) is 2 7/8 ", 6.5 #, N.-80 EUE 8R R2. TUBING DETAIL K.B.Depth 15.72' 17..34' 1434.93' 1447.86' 2898.93' 2912.04' 4303.11' 4216.21' 5255.63' 5268.65' 6217.61' 6230.75' 7051.05' 7064.16' 7759.8 777 10,493.03' 10,494.61' 10,525.51' 10,528.12' 10,559.86' 10,560.93' 10,568.95' 10,574.95' 10,638.39' 10,640.01' 10,671.36' 10,672,42' • COMPLETION REPORT - PACKER AND GAS LIFT INSTALLATION SWANSON RIVER UNIT 41-33 Section 33 T. 8 N. R. 9 W., Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - Operator Removed BOPE, installed x -mas tree and displaced mud with oil. January 11, 1963: Set packer at 10,569' and returned well to production. Rig released at 8:00 AM. sat 5 S.R. HANSEN 1ec. M OI. X RANGE o* W1 NO. n• Pesos". C GRAVITY Ov FT. 08 G (In (In thnn8and1) GALLONS Or RECOVERED BAsastS Or none, so state) $ Z?�dABYfl ` "S. W �wN e( i�A 1s "ft"' seaman — p Sal 41 33 8 9w r NE Co = d (C re f6) 8 7 le 10,726 - 10,754'. Full recovery. Co d (C re #7) 8 7 4 4 ch r3 tb - 14 0 rc:$ Ur\ et-4 •r4 34 3 A 4 he „ co co 0 cf;' ° 1 C.) a 9 11 4- 14 ti al CO PO, le 10,754 - 10,771'. 14' tocovered. Co . d (C re #8) 8 7 le 10,771 - 10,790'. 17--' re covered . Ope , ed 8 h� r/8". Drilled 9 7/3" hole + 0,790 11, ca.s 33' '.D. Ran 1 . ng a* 11,13; Onic, and $icro 28 sacks. lo - . Celae Inota d and ted. 6 5/8" sted HOPE. logs. E - tablish an Neutron Col. went Bond d W.S.O. at 10,418'. Displace th crude oil. , ; d 2 7 8" tubing at 1O,.57'. Installe ested X.ma tree. • erf'd. - in jet hol s pe foot 10, ' 0,674' us ng thro : • tubi. procedure. Flo T.P d o 1 at 990 , 14 pe i . C . P . , 156 M1CF D ;: > s, ; /64" n, 1600 psi si Trap P s sure, ' .0% cut 0.9% water, 1.1�, emu sion, tra• & M, 34. C.G. .hut in resource, 173'' psi T.F., 152 P. Rig leleased ;:O0 PM - 12 c U.'.G.S. - Me I. Soyster 2) ka 0 & G .� . ._ geld �Oi1. �iche.rd x -a C. W. rry M. L. 11 W. C. shop c*Ii. Oil Co. Uni n Oil Co. yyodu J.' J. s • Produ age Sowards E. Smith Explo Land UNITED STATES DEPARTMENT OF THE INTERIOR IOR. GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS State_ _..__r__ _- County_Lenai peninsula m Swanson River The following' is a oorreot report of operations and production ; inaludin f drazling and producing wells) for the month of _ _March ..__ 19 . Swanson River Unit ��^^'' 7-839 4e �aN ■ Q 4tent'a reps _ _ 1la__, ,K _. �d 7 Phone Budget Bureau Nu. 42- 8366.6_ Approval oapire4 1.- 41-60 LAND omcc __An , •. rage _._-.- - LEASE NUMt1EA 02 ;329 LJrs°r .___.. Swanson River Company S Signer .agent's title _C..._ 'EA`I'r'FR` 11 NoTz. —`"here were runs or sales of oil; - --- . ---- .__- .._ - -- M au. ft. of gas sold; runs or sales of gasoline during the month. (Write "no" where applicable.) NOTN. -o--- Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Fcorra 9-399 11--- 9&166 3. Y. 4.v INN MY ►WTNTIMI orrIci (January 1960) LESSEE'S MONTHLY REPORT OF OPERATIONS State Ll. . County Kenai Peninsula The following is a correct report of operations and wells) for the month of February agent's address i' • 0 • Box 7-839 Anchoraae, -Alaska BRoa i ay 7-6201 Phone SEC. AND � OF% Twr. 33 8N NE- NR4 RANGE cc W WELL DAYS I I CD. FT. OF OAS No. P BARRELS OF On. GRAVITY (In thousands) Swa son liver Unit .1 -33 (15) Drilled j 7/8" hole 5881 - 10,630'. Cored (Core #1) 8 7/8" hole 10, 30 10,654'. 'u.11 recovery. Cored (Core #2) 8 7/8" hole 10, 54 - '10,682'. Full recovery.` Cored (Core #3) 8 7/8" hole 10,682 -'10,691'. }Full recovery. Cored (Core #4) 8 7/8" hole 10, 91 - ;10, 698' , 6' recOve red. Cored (Core #5) 8 7/8" hole 10, 98 - 10,726'. Full recovery. U.S O.S. Ala ka 0 Ric Uni Ohi Fil - M. R. Soyster, ( ) GCC - V. iel4 Oil Corp. - C. W. Perry - IA. L. Hill - W. C. Bishop 8114th Sowards n Oil Co. - C. Oil Co. - Geo Producing E p1oration I.nd ge NOTE.—There were UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Meld Budget Bureau? No..12- R;;36.5. Approval expires 12- 31 - -tD. LAND OFFICE Anchorage LEASE NUMBER 028399 UNIT --- -..Swe nsQu1 L ive ' Swanson River production (including drilling and producing , 1961 , Swanson River Unit STA%D&IID OIL CO. OF CA m Copany -- -4 tern peratians, Si 5ned � -- - ✓Igent's title _ District Superintendent-Alaska GALLONS OF BARRELS OF REMARKS GASOLINE WATER (II (If dril ot for down, es e. T 1.INC( ?t'�;RF.D none, so state) content of Ira:) runs or sales of oil; N"1 cu. ft. of gas sold; runs or sales of gasoline during the month. ( \Vrite ''no" where applicable.) NOTE.— Report on this form -)s required for each ealeP:dfu" month, regardless of the F(aiu.; of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding Irtonth, unless otherwise directed h; the Forin 9°32I3 15 - 2571111 !1 U. 5. ,,VLRNMi"NT PRINT'M' orr,cr (January 1950) itertie 1 Y R RT OF OPERATIONS Dattla_ n a River escreeii report ff operotieves end prodemdilio rtaskatlibad drettot wed r „to 61 b _ guns or of oil; Pte. ANL& M eu. ft. of gas ; runs or sales of gasoline during the month. (Write., 'Imo" wig b t) Nom—Upon an this fin V required for each as/ender month..., regardless of the status of operations, and toast be hied in duplicate with the ssrpervisor by ths 6th of the sding month, waiass othancias directed by the supervisor. Gaimm7 ink ht , rnt 9 -331 r,!•. ;951) SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF INTENTION TO DRILL X SUBSEQUENT REPORT OF WATER LHUT -OFF NOTICE OF INTENTIpN 10 CHAN PLANS SUBSEQI'C.",r RET'CRr OF :4100 ING G -OR AC;:7.ITaNG NOTICE OF INTENr1C!N TO TE T l'. ATER Si T -Of F SUBSEQUENT REf ORT Of ALTERING rASING NOTICE OF ANTE TO 1 ";E OR!t I OR ",'CELL SUBSEourNr DEPORT OF RE !?RH HNG 00 RFP:IN NOTICE OF IN'E'.:',''! TO SHOOT OR ACIDILE- _. SULISEQ'JENT REPORT OF ABANC•tThYENT NOTICE OF ,INTENTION TO 100 L OR At TER CASING - SUPPLf MENTARY WELL HISTORY NOTICE OF INTENTION 10 AI,AN0ON '.ti ELL (I'i'•I I Addross P. 0. Box 7 -839 (SUBMIT IN TRIPLICATE) UN ITED STATES DEPARTMENT OF THE I NTEPiOR GEOLOGICAL SURVEY itNDl(AT ABCVt BY (CHECK MA NA TURF OF REPORT, N T;( E' F. C.•ftiF l% C.A' (17) Approximately i N Well No. SRU 41 iocatt.di 660 ft. Iron' $ Erne and 660 ft. from line of sec_. 33 Et Sec. 33 T. 8 N•, R. 9 W. Seward. B & M Swanson River Kenai Peninsula K•B• The elevation of tl:(• xilusailiotim above , ca level is 180 ft. (Approximately) (State names rf and e,pe(te.i •1e t !I. ,h } ' ist sands; +.hov sire., weights, anal ng t lsa of rt ing points, . d all other irnp(,rtar t prop, send w( 1. Drill to 3000' and cement 13 3/8" casing. 2. Install & test Class III Blowout Prevention Equipment. 3. Drill ahead to approximately l0, 900' , Log, and cement 7" casing in two stages. 4. Obtain requisite water shut -offs. 5. Selectively jet perforate attractive sands and test as necessary. P- 6. Run 2 7/8" tubing and complete. 1 understand the' this plan of work must receive nt:f.resvai i .t wrt'.,ng t,y the t:rolog : r" ry tr,.tc..c (, }•e rutt(,na l I=linerals Company S ,M OIL COMPANY A or CALIFORNIA, WESTERN t PXRATIoNsi,.7►DiC Resource Anchorage Alas proved ,J DETAILS OF WORK } FitU!C� I ! %Uri 'ot 4:; i33. . 3. A;,;m,t :i O. XI Land ()Nice Anchors.ge Lease No 028399 )nit Swaneon River January 11 , 61 Alaska p.,we :; „ tn ?,• It. r,:,erlt- 6 1961 J. T. CROCKER - Dtstrict Superintendent -Alaska D. D. Bruce, Petroleum Geologist Division of Mines and Minerals Alaska Dept. of Natural Resource APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK APPLICATION, TO DRILL a DEEPEN ❑ PLUG BACK 0 NAME OF COMPANY OR OPERATOP. DATE , 3961 Address __ City State DESCR.I-PTION OF WELL ` AND LEASE Name of lease Well number Elevation (ground) ..It Well location (give footage from section lines) Section— township —range or block & survey Field & reservoir; (-If wildcat, : so state) T County ,. - ' — - Distance, in miles, and direction from nearest town or post office Nearest distance from proposed location to property or lease line: feet Distance from proposed location to nearest drilling, completed or applied —for well on the same lease: MO feet Proposed depth: Rotary or cable tools Approx. date work will start ifkatairar 25, 19 Number of acres in lease: ": Number of wells on lease, including this well, completed in or drilling to this reservoir: If lease, purchased with one or more Name Address wells drilled, from whom purchased: Status of bond 11100 1110M0* 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) ( pp ( er Approval Date: Approved By • CERTIFICATE: I, the undersigned, state that I am the .i of th (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 d complete to Original Signe W. E. WHITNEY the best of my knowledge. - fo Permit Number • _ 1 /' - 'f State Geologist Notice: Before sending in this form be sure that you have given all information requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Signature pagMR Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P -1 Authorized by Order No. 1 Effective October 1, 1958 i#ard Oil Co. of Califocata Posit No. 3-61 Issued 1 46-61 avaasou *Ivor Unit No. 43.33 ( toe: e'N 10 ms See 33, •,.SISK not 175' U Ice $1.4 Coats.: Coastal eats Co. wit 141 Copit41 34•1.1133 terf 44 *mss 11 Cast 22 0 Se r 3104 v 12100 sa 3s 1 I1131 oa 2-7 IS till bow 106464
