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175-039
/ 7-5- o3q Guhl, Meredith D (DOA) From: Monty Myers [mmyers@hilcorp.com] Sent: Tuesday, July 01, 2014 12:39 PM To: Davies, Stephen F (DOA); Janise Barrett; Stan Porhola Cc: Schwartz, Guy L (DOA); Guhl, Meredith D (DOA); Bettis, Patricia K (DOA) Subject: RE: Reporting Compliance - Information Needed (Second Request) Attachments: 143016_SCU_33-05 SLD NAD 27.pdf Good afternoon Steve. This is the most recent plat I had drawn up by McLane back in February. Let me know if this helps clarify things for the SCU 33-05. The new name for this well is SCU 44-05 after we sidetracked it back in April. The other schematics should be coming from Stan Porhola. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA)[mailto:steve.davies(aalaska.govl Sent: Tuesday, July 01, 2014 12:13 PM To: Monty Myers; Janise Barrett; Stan Porhola Cc: Schwartz, Guy L (DOA); Guhl, Meredith D (DOA); Bettis, Patricia K (DOA) Subject: Reporting Compliance - Information Needed (Second Request) Stan, Monty, Janise: Here are four requests for information sent by AOGCC to Hilcorp during mid-June that have not yet been filled. Please forward this information to Meredith Guhl so that she can complete her reporting compliance review of these well history files. 1. RE: SRU 11-22, PTD 213-055, Updated Well Schematic (Sent Mon 6/16/2014 9:48 AM) Please provide an updated well schematic for SRU 11-22 by 6/30/2014. 2. RE: SCU 33-05, PTD 175-039, Location of Well discrepancy (Sent Mon 6/16/2014 9:59 AM) Please provide the most recent surveyor's NAD 27 plat for this well so that the coordinates can be confirmed. Please provide the plat by 6/30/2014. 3. RE: Well Completion Report BCU -14A PTD 213-19 (Sent Mon 6/16/2014 10:26 AM) 1 have not received the updated 10-407 as requested, nor an updated well schematic. Please submit an updated 10-407 along with an updated well schematic by 6/30/2014. 4. RE: BCU -016, PTD 214-001, KB/GL elevations and schematic (Sent Mon 6/16/2014 9:40 AM) Can you clarify the discrepancy between the survey data and the schematic/10-407 numbers reported? Janise provided me with an updated schematic, but the discrepancy remains. Please provide the requested information by 6/30/2014. Thank you for your help. Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Guhl, Meredith D (DOA) Sent: Monday, June 16, 2014 10:26 AM To: Monty Myers; Janise Barrett; Stan Porhola Cc: Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Subject: RE: Well Completion Report BCU -14A PTD 213-196 Monty and Stan, I have not received the updated 10-407 as requested, nor an updated well schematic. Please submit an updated 10-407 along with an updated well schematic by 6/30/2014. Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 T8N SECTION LINE (NOT TO SCALE) 32 33 T7N R9W 5 4 SECTION COR (COMPUTED) N: 2461225.492 E:342353.112 SCU 33-05 ASBUILT SURFACE LOCATION NAD 27 ASP ZONE 4 N:2457909.946 E:341744.448 LAT: 60°43'29.227"N LON: 150°53'02.139"W 571' FEL 3323' FNL ELEV: 153.335' NAVD88 3323' FNL (NTS) NOTES 1. BASIS OF HORIZONTAL; NAD83 US FEET POSITION (EPOCH 2010) AND VERTICAL CONTROL (NAVD88) IS AN OPUS SOLUTION FROM NGS STATIONS TBON, TSEA AND ANC2 TO ESTABLISH CP -2. THE ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: N = 2458384.578 E = 1483669.444 ELEV. = 212.690 (NAVD88) 2. SECTION LINES SHOWN ARE COMPUTED FROM MONUMENT TIES ALONG THE NORTH TOWNSHIP LINE OF TOWNSHIP 7N RANGE 9W 3. DATUM TRANSFORMATIONS (NAD83 ASPZ4 TO NAD27 ASPZ4) WERE DONE USING CORPSCON SOFTWARE VERSION 6.0.1. Con5uLting Inc M�LAN� ENGINEERING / MAPPING / SURVEYING / TESTING P.O. BOX 468 SOLDOTNA, AK 99669 VOICE: (907) 283.4218 FAX: (907) 283-3265 EMAIL: SAMCLANE@MCLANECG.COM 11 Ililcorp Alaska, LIX m SCU 42-05Y n ^SCU QA -05 • SCU 13-4"' ,,SCU 42-05X SCU 42B-05 00.0 Iw z J Iz O IU w U) FEL i I SRF 42 - 05 PAD z SCALE 0 200 400 FEET PROJECT HILLCORP ALASKA, LLC SWANSON RIVER FIELD WELL SCU 33-05 AS BUILT SURFACE LOCATION NAD 27 LOCATION SECTION. 05 T07N R09W SEWARD MERIDIAN, ALASKA I� 00 �...10 STAN A. McLANE r : 4637—S 25 FfJ5 14.. ... REVISION: - DATE: 02/025/14 DRAWN BY: ICB SCALE: 1'=2DD' PROJECT NO. 143016 BOOK NO. 13-22,14.08 SHEET 1 GF 1 I -�S-b39 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday, June 16, 2014 9:59 AM To: 'Stan Porhola' Cc: Davies, Stephen F (DOA) Subject: RE: SCU 33-05, PTD 175-039, Location of Well discrepancy Stan, Please provide the most recent surveyor's NAD 27 plat for this well so that the coordinates can be confirmed. Please provide the plat by 6/30/2014. Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 From: Guhl, Meredith D (DOA) Sent: Wednesday, May 28, 2014 12:55 PM To: Stan Porhola Cc: Davies, Stephen F (DOA) Subject: SCU 33-05, PTD 175-039, Location of Well discrepancy Hello Stan, During additional review of the 10-407 form submitted for SCU 33-05 it was noted that the current surface coordinates provided to not match the previously provided surveyor's plat of 8-12-1975. That plat shows coordinates of 1896' FSL and 626' FEL. The 10-407 of 4-22-2014 lists 1957' FSL and 571' FEL. Could you please provide the most recent surveyor's NAD 27 plat for this well so that the coordinates can be confirmed and the plat added to the well history file? If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 / -�6- 039 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Wednesday, May 28, 2014 12:55 PM To: Stan Porhola Cc: Davies, Stephen F (DOA) Subject: SCU 33-05, PTD 175-039, Location of Well discrepancy Hello Stan, During additional review of the 10-407 form submitted for SCU 33-05 it was noted that the current surface coordinates provided to not match the previously provided surveyor's plat of 8-12-1975. That plat shows coordinates of 1896' FSL and 626' FEL. The 10-407 of 4-22-2014 lists 1957' FSL and 571' FEL. Could you please provide the most recent surveyor's NAD 27 plat for this well so that the coordinates can be confirmed and the plat added to the well history file? If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ %I t A 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1 1 b. Well Class: Development ❑ Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 5. Date Comp., Ste., or o l Aband.: 3/19/2014 2. Permit to Drill Number: 175-039 / 314-111 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 6. Date Spudded: 8/25/1975 13. API Number: 50-133-20276-00 4a. Location of Well (Governmental Section): Surface: 195T FSL, 571' FEL. Sec 5, T7N, R9W, SM, AK Top of Productive Horizon: Total Depth: 206T FSL, 1054' FEL, Sec 5, T7N, R9W, SM, AK 7. Date TD Reached: 10/18/1975 14. Well Name and Number: Soldotna Creek Unit (SCU) 33-05 8. KB (ft above MSL): 152 GL (ft above MSL): 17.5 15. Field/Pool(s): Swanson River / Hemlock Oil 9. Plug Back Depth(MD+TVD): 10.827'MD; 10,723'TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 341,744 y- 2,457,910 Zone- 4 TPI: x- y- Zone- Total Depth: x- 342,227 y- 2,458,020 Zone- 4 10. Total Depth (MD + TVD): 10,870'MD; 10,760'TVD 16. Property Designation: FEDA028996 11. SSSV Depth (MD +TVD): N/A; N/A 17. Land Use Permit: N/A 18. Directional Survey: Yes ❑ No ❑� (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MD/T`/D: N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): N/A 22.Re-drill/Lateral Top Window MC/TVD: N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" Surf 44' Surf 44' N/A N/A 10-3/4" 40.5 K-55 Surf 3,372' Surf 3,372' 15" 1,035 sx 7-5/8" 26.4/29.7/ N80/ Surf 10,585' Surf 10,510' 9-7/8" 350 / 545 sx 33.7 S95/P110 20 N-80 10,384' 10,870' 10,347' 10,760' 6-5/8" 100 sx 24. Open to production or injection? Yes ❑ No ❑ If Yes, list each interval open (MD+TVD of Top and Bottom, Perforation Size and Number): ECNc g y; f� APR 2 2 2014 t AlOrICC 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes [-]No 0 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): Not flowing Date of Test: N/A Hours Tested: Production for Test Period -11111. Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 1 Flow Tubing Press. N/A Casing Press: Calculated 24 -Hour Rate --pp. Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. c sem; RBCMS APR 2 2 ZDV ;/, 'Oe_ Y/yliy .� 'AG 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes [�] No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: 31. List of Attachments: Schematic, Well Operations Summary 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email: S po rho Ia hi1cq .ComT Printed Name: Stan Porhola Title: Operations Engineer Signature:,._ J'I',_ � - Phone: 907-777-8412 Date: �f' � Z / INSTRUCTIONS �r General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Hileoru Alaska. LLf. 20", 10-3/4'L ACTUAL SCHEMATIC Ground Elev: 152.0' Above MSL KB -THF = 19.28'/ KB -GL = 17.5' 1 G w 2 CASING DETAIL Soldotna Creek Unit Well SCU 33-05 Suspended: 3/19/2014 PTD: 175-039 API: 50-133-20276-00 Type Size WT Grade Conn ID Top Btm. Conductor 20" 4.312" Bridge Plug (capped w/ 40' of cement) 10,446' Surf 44' Surface 30-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' Production 7-5/8" 26.4 N-80 BTC 6.969" Surf 3,798' 29.7 N-80 BTC 6.875" 3,798' 5,733' 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 10,585' Liner 5-1/2" 20 N-80 LTC -SCC 4.778" 10,384' 1 10,870' TUBING DETAIL Tubing JEWELRY DETAIL NO. Depth ID OD Item 1 9,420' 6.312" Bridge Plug (set for whipstock) 2 10,450' 4.312" Bridge Plug (capped w/ 40' of cement) PERFORATIONS (Open Hole) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Length Date 10,498' 10,510' 10,435' 10,446' 12' 03/27/01 G2 10,530' 10,544' 10,464' 10,477' 14' 03/27/01 10,551' 10,561' 10,483' 10,492' 10' 03/27/01 10,584' 10,590' 10,513' 10,518' 4 6' 07/02/94 H1 10,584' 10,601' 10,513' 10,528' 17 04/02/13 10,595' 10,601' 10,523' 10,528' 4 6' 07/02/94 10,616' 10,634' 10,542' 10,558' 6 18' 04/02/13 H2 10,616' 10,634' 10,542' 10,558' 4 18' 07/02/94 10,646' 10,661' 10,569' 10,582' 6 13' 04/02/13 H3 10,648' 10,661' 10,570' 10,582' 4 13' 10,680 10,712' 10,599' 10,429' 6 32' 04/02/13 H4 10,680' 10,700' 10,599' ,,--'10,617' 4 20' 10,702' 10,712' 10,619' 10,627' 4 10' 09/1970 H5 10,722' 10,747' 10,636' 10,658' 4 25' H7 10,776' 10,805' 10,684' 10,709' 29' 04/02/13 G2 H1 H2 H3 H4 H5 H7Fill tagged w/ 2.0" DD bailer 5-1/2" @ 10,801' 2/22/14 TD = 10,870'/ PBTD = 10,827' Downhole Revised: 3/19/14 Max Dev. 30 degrees Updated by STP 4/10/14 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 33-05 50-133-20276-00 1 175-039 1 3/15/14 3/19/14 Daily Operations: 03/15/2014-Saturday Rig up WO rig. Winterize equipment. Run pump lines. 03/16/2014-Sunday Finish containment. Work on rig. Blow down well to 0. Shoot fluid level, could not get reading. Wait on BOP. Set BPV, ND prod tree. NU adapter flanges, flow cross and her valves. 03/17/2014 - Monday NU BOP and hydril. Perform BOPE test, test all valves to 250 psi low 3000 psi high for 10 mins and chart do draw down test on Koomey. Witness waived by Jim Regg, AOGCC & Justin Miller, BLM. Pressure build during test had to pump 40 bbls of FSW down tubing to remove. Work pipe to release packer, no luck. Release on/off tool. POOH and lay down tubing hanger. RIH, relatch onto packer work pipe get packer to release. POOH, S/B 314 jts 9,961' in derrick, LD 9 jts 2-7/8" EUE 8rd L80 tubing. LD 9 gas lift valves, 1 on/off tool, 15-1/2" x 2-7/8" AS-1 packer with X nipple and WLEG. Start RU wireline. 03/18/2014-Tuesday RU eline. RU lubricater, test to 250 low - 3000psi high. RIH with CIBP 5-1/2" x 20 Ib and set at 10,450' MD. RIH E-line with dump bailer, 2 runs bail 3" x 50', dump bail 33 gallons cement R/D Eline. Break subs off gas lift valves. MU BHA = 1 - 6-1/2" junk mill, 1-bit sub, 1 7-5/8" casing scraper, 1 X0. RIH, BHA & 315 jts 2-7/8" EUE 8rd L80 tubing to 10,002', load hole with FSW while tripping in. Finish loading hole with FSW 310 bbls total. Reverse circulate bottoms up 1x to purge trapped gas. Close safety valve and pressure up well to 2700 psi to test casing, hold and chart for 30 mins - test good. POOH, LD 2-7/8" tubulars and BHA 315 jts. RIH with Eline to tag cement tag low at 10,432' (18' cement). POOH. 03/19/2014-Wednesday RIH with E-Line. Dump bail 32 gallons cement. POOH, wait on cement to set. RIH with bailer. TAG cement at 10.410'. POOH. RIH with 7-5/8" CIBP, set at 9,420' MD. POOH. RDMO Priority E-Line. Test and chart plug at 9,420' to 2500 psi for 30 mins. Set BPV. ND BOP and spool. NU dry hole tree, remove BPV. RD Moncla 405 and equipment. • �� �\\�%// � 11 STATE ;',- ,--",-_,''<---------'71'- ,,,f-P J / 1/ \ '\ /� - :-,74,:-,__ - -- — 333 West Seventh Avenue GOVERNOR SEAN PARNI'.I,I, Anchorage, Alaska 99501 2572 "i .n; Main: 907.279 1433 Stan Porhola O 37 Operations Engineer4 7c-- Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 33-05 Sundry Number: 314-111 SCANNED AUG p 6 2014 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 P4,,, 4,_ Cathy P. oerster Chair DATED this -2-#1A--ay of February, 2014. Encl. RECEIVED STATE OF ALASKA FEB 2)5 U14 ALASKA OIL AND GAS CONSERVATION COMMISSION D7S. 2/AT l ` 9— APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril 2 . Perforate New Pod ❑ Repair Wee Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑✓ Time Extension❑ Operations Shutdowl❑ Re-enter Susp.Wel ❑ Stimulate❑ After Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ 175-039 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20276-00 ` 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B 111Soldotna Creek Unit(SCU)33-05 Will planned perforations require a spacing exception? Yes ❑ No • 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028996 Swanson River/Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,870 10,760 10,827 10,723 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10-3/4" 3,327' 3,32T 3,130psi 1,580psi Intermediate Production 10,585' 7-5/8" 10,585' 10,510' 6,020psi 3,400psi Liner 486' 5-1/2" 10,870' 10,760' 9,190psi 8,830psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic I See Attached Schematic 2-7/8" 6.5#/N-80 10,425' Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): 5-1/2"AS1-X;N/A . 10,424'MD/10,364'TVD;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program [1 BOP Sketch n . Exploratory n Stratigraphicn Development n Service n 14.Estimated Date for 15.Well Status after proposed work: 30) Commencing Operations: 03/04/14 Oil L 1 Gas ❑ WDSPL ❑ Suspended Q 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhda Phone: 907-777-8412 Email soorholaehilcorn.corn Printed Name Stan Porhola Title Operations Engineer 1 . Signature — Phone 907-777-8412 Date 2/"2� /t/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: *# 3 c )J /,S,% ‘0ri -7--es-r---- RBDMS MAY 1 0 2014 Spacing Exception Required? Yes ❑ No12( Subsequent Form Required: l t — 4107 l / APPROVED BY Approved by: , COMMISSIONER THE COMMISSION Date: 2 _2.)_ly Z OC'/V ` ' '�/,�` A� � HI ' I Submit Form and Form 10-403(-,/ised 10/2012) Approve a Rtiirti iliftv�lip4r lanbnths from the date of approval. Attachments in Duplicate Well Prognosis Well: SCU 33-05 Hilcorp Alaska,LL' Date:02/24/2014 Well Name: SCU 33-05 API Number: 50-133-20276-00 Current Status: _ Shut-in Oil Well Leg: N/A Estimated Start Date: _ March 4th,2014 Rig: Moncla 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 175-039 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,200 psi @ 10,523' ND (Static survey conducted May 25, 2012 10,600' MD) Maximum Expected BHP: —2,200 psi @ 10,523' ND (Static survey conducted May 25, 2012 10,600' MD) Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir at 4,809' ND.) Brief Well Summary This well was drilled and completed as an oil well in Hemlock in 1975 as SCU 33-05.A workover performed in 1994 was performed to add the Hemlock H-1 bench. In 2001 the Tyonek G zone was perforated.A workover performed in 2013 was performed to remove the original completion and add the Hemlock H-7 bench.The well has had limited productivity since this workover(approximately 1 bopd on gaslift). The purpose of this work/sundry is to abandon the current perforated interval and prepare the wellbore for re- drilling operations/A drilling permit application will be submitted separately for the sidetrack. rocivOe5 a (— Notes Regarding Wellbore Condition T coAcu v� 10 BO�o • Last tag at 10,801'SLM on 2/22/14 w/2.00" DD bailer. f fP ,�fS 4 a to, fr o' er/. 0 WO Rig Procedure: ,. ,at fate wet/ "" oletb'ne. Vivo 1. MIRU Moncla#405 WO Rig. P pi..'(1 61a401 allay /2i i�"0' °� 2. NU BOPE.Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/1,500 psi High (hold each /(covC�i valve and test for 10-min). Record accumulator pre-charge pressures and chart tests. boot, ( a. Notify AOGCC 24 hrs in advance to witness. b. Notify BLM 48 hrs in advance of BOP test. p. tof 3. Bleed any trapped pressure off tubing and casing. 4. MU landing joint and pull tubing hanger free. / /(09f° 5. Release mechanical packer. a. Have E-line on standby if packer does not pull free. b. Watch for drag/sticking of the packer while pulling thru the 5-1/2" liner. 6. SOOH and rack back 2-7/8" 8RD tubing. Lay down the packer and all jewelry. 7. RU E-line, PT lubricator to 3,000 psi Hi 250 Low. 8. RU 5-1/2"CIBP, RIH and set bridge plug at 10,450' MD. 9. RU 3.5"-4.0" bailer,dump bail 35'of cement on tubing plug(33 gallons of cement)to achieve a cement top at 10,415'. 10. MU 6-1/2" bit w/7-5/8" 33.7#casing scraper and RIH on 2-7/8" 8RD tubing out of derrick. • • Well Prognosis Well: SCU 33-05 Hilcorp Alaska,LL Date:02/24/2014 a. Need XOs for 3-1/2" IF connections on scraper tools to 2-7/8" 8RD tubing. 11. RIH to+/- 10,000' MD. 12. Circulate well clean w/Produced Lease Water. /C-4,-cf- 14. 13. Pressure test casing and cement plug to 2,700 psi for 30 min.POOH. Lay down 2-7/8" tubing, casing scraper and-6-1/2" bit. a. MU 2-7/8" 8RD thread protectors to tubing (330 joints). 15. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. BOPE connection is 11" studded top for lubricator on top of annular. 16. RU 3.5"-4.0" bailer, RIH and tag cement top at 10,415'. 17. RU 7-5/8" 33.7#CIBP and GR/CCL tools. 18. RIH and set top of CIBP at+/-9,290' MD in the 7-5/8" 33.7# P-110 casing (set 3-5 ft above a casing collar). 19. RD E-line. 20. Test casing to 2,500 psi for 30 min and chart. 21. Set BPV. ND BOPE. NU dry hole tree. Pull BPV. 22. RD Moncla #405 WO Rig. 23. Turn well over to production in preparation of moving in the Saxon#169 Drilling Rig. 24. Replace IA x OA pressure gauge if removed (7-5/8" x 10-3/4"). Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic • Soldotna Creek Unit • Well SCU ACTUAL SCHEMATIC Completion Well SCU 33-05te: 04/03/13 PTD: 175-039 Haror„Alaska.HA API: 50-133-20276-00 Ground Elev: 152.0' Above MSL CASING DETAIL KB-THF = 19.28'/ KB-GL= 17.5' Type Size WT Grade Conn ID Top Btm. Conductor 20" Surf 44' 1 Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 26.4 N-80 BTC 6.969" Surf 3,798' 20'L 29.7 N-80 BTC 6.875" 3,798' 5,733' Production 7-5/8" 33.7 5-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" 6,906' 10,585' r---02 Liner 5-1/2" 20 N-80 LTC-SCC 4.778" 10,384' 10,870' TUBING DETAIL Tubing 2-7/8" 6.5 L-80 8RD EUE 2.441" Surf 10,425' 10-3/42 I. 03 JEWELRY DETAIL NO. Depth ID OD Item I 0 4 1 17' - - Tubing Hanger,Shaffer,2-3/8" CIW BPVP 2 2,316' 2.44" 4.75" 2-7/8"GLM SF0-1 Mandrel 3 4,013' 2.44" 4.75" 2-7/8"GLM SF0-1 Mandrel 4 5,331' 2.44" 4.75" 2-7/8"GLM SF0-1 Mandrel r D 5 5 6,427' 2.44" 4.75" 2-7/8"GLM SFO-1 Mandrel 6 7,333' 2.44" 4.75" 2-7/8"GLM SFO-1 Mandrel 7 8,141' 2.44" 4.75" 2-7/8"GLM SFO-1 Mandrel 8 8,885' 2.44" 4.75" 2-7/8"GLM SFO-1 Mandrel 9 9,997' 2.44" 4.75" 2-7/8"GLM SFO-1 Mandrel 06 10 10,375' 2.44" 4.75" 2-7/8"GLM SF0-1 Mandrel-1"Orifice 11 10,423' 2.313" 4.8" On/Off tool 12 10,424' 2.44" 4.8" AS1-X Retrievable Packer 13 10,435' 2.313" 3.5" EUE"X"Landing Nipple 14 10,439' 2.4" 3.5" EUE WLEG 07 B8 PERFORATIONS(Open Hole) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Length Date 10,498' 10,510' 10,435' 10,446' 12' 03/27/01 I^5 9 G2 10,530' 10,544' 10,464' 10,477' 14' 03/27/01 10,551' 10,561' 10,483' 10,492' 10' 03/27/01 10,584' 10,590' 10,513' 10,518' 4 6' 07/02/94 010 H1 10,584' 10,601' 10,513' 10,528' 17 04/02/13 10,595' 10,601' 10,523' 10,528' 4 6' 07/02/94 10,616' 10,634' 10,542' 10,558' 6 18' 04/02/13 7-5/8'L , H2 10,616' 10,634' 10,542' 10,558' 4 18' 07/02/94 • 11H3 10,646' 10,661' 10,569' 10,582' 6 13' 04/02/13 ' 10,648' 10,661' 10,570' 10,582' 4 13' • a 10,680' 10,712' 10,599' 10,629' 6 32' 04/02/13 maiii__- 12 H4 10,680' 10,700' 10,599' 10,617' 4 20' - -- 10,702' 10,712' 10,619' 10,627' 4 10' 09/1970 H5 10,722' 10,747' 10,636' 10,658' 4 25' W 13 H7 10,776' 10,805' 10,684' 10,709' 29' 04/02/13 14 G2 = H1 H2 = Max Dev. 30 degrees H3 - H4 H5 H7 y;,,;r;r;r;r;r;r;r;: Fill tagged w/2.0"DD bailer '7.1.17.~•('•1611.1 1. @ 10,801'2/22/14 r•r•r•r• r•r•r•r• 5-1/2'/, .. TD=10,870'/PBTD= 10,827' Downhole Revised:2/22/14 Updated by STP 2/24/14 Soldotna Creek Unit 11 Well SCU 33-05 Proposed Completion PROPOSED SCHEMATIC PTD: 175-039 Hilcaru Ala+ka.LLC API: 50-133-20276-00 Ground Elev: 152.0'Above MSL CASING DETAIL KB-THF= 19.28'/KB-GL= 17.5' Type Size WT Grade Conn ID Top Btm. Conductor 20" _ Surf 44' Surface 10-3/4" 40.5 K-55 BTC 10.050" Surf 3,372' 26.4 N-80 BTC 6.969" Surf 3,798' 20" 29.7 N-80 BTC 6.875" 3,798' 5,733' Production 7-5/8" 33.7 S-95 BTC 6.765" 5,733' 6,906' 33.7 P-110 BTC 6.765" _ 6,906' 10,585' Liner 5-1/2" 20 N-80 LTC-SCC 4.778" 10,384' 10,870' TUBING DETAIL Tubing 10-3/4'L JEWELRY DETAIL NO. Depth ID OD Item 1 9,290' _ - 6.312" Bridge Plug(set for whipstock) 2 10,450' - 4.312" Bridge Plug(capped w/35'of cement) PERFORATIONS(Open Hole) Zone Top(MD) Btm(MD) Top(ND) Btm(ND) SPF Length Date 10,498' 10,510' 10,435' 10,446' 12' 03/27/01 G2 10,530' 10,544' 10,464' 10,477' 14' 03/27/01 1 10,551' 10,561' 10,483' 10,492' 10' 03/27/01 10,584' 10,590' 10,513' 10,518' 4 6' 07/02/94 H1 10,584' 10,601' 10,513' 10,528' 17 04/02/13 - ON 10,595' 10,601' 10,523' 10,528' 4 6' 07/02/94 10,616' 10,634' 10,542' 10,558' 6 18' 04/02/13 7-5/8'L , H2 10,616' 10,634' 10,542' 10,558' 4 18' _ 07/02/94 H3 10,646' 10,661' 10,569' 10,582' 6 13' 04/02/13 10,648' 10,661' 10,570' 10,582' 4 13' 10,680' 10,712' _ 10,599' 10,629' 6 32' _ 04/02/13 H4 10,680' 10,700' 10,599' 10,617' 4 20' 10,702' 10,712' 10,619' 10,627' 4 10' 09/1970 tt t ,, H5 10,722' 10,747' 10,636' 10,658' 4 25' '4` -�6 ' 2 H7 10,776' 10,805' 10,684' 10,709' 29' 04/02/13 G2 = H1 H2 - Max Dev.30 degrees H3 -A:._-- H H4 - H5 H7 - Fill tagged w/2.0"DD bailer '%2%2'1'?:?i2%:r7.` 5-1/2"Artiy ,s'Ul.,is.- ,`;► @ 10,801'2/22/14 TD=10,870'/PBTD=10,827' Downhole Proposed Updated by STP 2/24/14 • Swanson River Moncla#405 BOP 2/24/2014 Ili cogs %is..kr.1.I.(. 3.98' ° Hydril ' GK 11"-5000 1iI Iil Mgr!ii iii It I I ISI III I•I I I 4.54' C) o U 1 1 H 2 7/8 -5 variables Sit' :, i = .T.ire 11"- 5000 limpona7 H H Blind ...." t li I1 iiln111 2 1/16 5M Choke and Kill Valves i_il I II I I I III 1111: 2.00 , , F :' '; it . • ' : li ; i -, . � II I "% IIIIi111I : : ' DECEIVED STATE OF ALASKA 3 , AL OIL AND GAS CONSERVATION COMMISSION fir 1 °� 201 REPORT OF SUNDRY WELL OPERATIONS OGCC 1. Operations Abandon U Repair Well U Plug Perforations Lf Perforate Lf Other U Reperforate & Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ New Completion Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 • Exploratory ❑ 175 -039 ' 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 50- 133 - 20276 -00' 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028996 Soldotna Creek Unit (SCU) 33 -05 ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Hemlock Oil • 11. Present Well Condition Summary: Total Depth measured 10,870 feet " Plugs measured N/A feet true vertical 10,766 feet Junk measured N/A feet Effective Depth measured 10,722 feet Packer measured 10,424 feet true vertical 10,636 feet true vertical 10,367 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10 -3/4" 3,372' 3,372' 3,130 psi 1,580 psi Intermediate Production 10,585' 7 -5/8" 10,585' 10,514' 6,020 psi 3,400 psi Liner 485' 5 -1/2" 10,870' 10,766' 9,190 psi 8,830 psi Perforation depth Measured depth See Attached Schematic SCANNED MAY $ 0 2013 True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.5# / L -80 10,425' MD 10,368' TVD Packers and SSSV (type, measured and true vertical depth) AS1 -X Ret Pkr 10,424' MD 10,367' TVD N /A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 100 200 Subsequent to operation: 2 10 18 970 185 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development Q • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 , Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -136 Contact Chad Helgeson Email chelaeson @hilcoro.com Printed Name Chad Helgeson Title Operations Manager Signature C//�'Z Phone 907 - 777 -8405 Date 5 RBDMS MAY 17 201 ' Form 10 -404 Revised 10/2012 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 33 -05 50 -133- 20276 -00 175 -039 3/13/13 4/3/13 Daily Operations: 03/13/2013 - Wednesday MIRU Pollard slickline Unit, attempted to clear obstruction from wire -line re -entry guide below first packer. RIH W/ 1 -3/4 "" DD Bailer, tagged @ 10,610' wlm, worked tool, POOH, Full sample of gravel. RIH W/ 1 -3/4" DD Bailer, tagged @ 10,612' wlm, worked tool, POOH, Full sample of gravel. RIH W/ 2" DD Bailer, tagged @ 10,614' wlm, worked tool, POOH, Full sample of sand. RIH W/ 2" DD Bailer, tagged @ 10,615' wim, worked tool, POOH, Full sample of sand and 3 perf disc's. RIH W/ 1 -3/4" DD Bailer, tagged @ 10,615' wlm, worked tool, POOH, Full of sand. RIH W/ 2" DD Bailer, tagged @ 10,615' wlm, worked tool, POOH, 1/2 cup of perf debree. RIH W/ 1 -3/4" DD Bailer, tagged @ 10,615' wlm, worked tool, POOH, no recovery. RIH W/ 1 -3/4" DD Bailer, tagged @ 10,615' wlm, worked tool, POOH, Full of sand and perf debris. SDFN. 03/14/2013 - Thursday RU Pollard slickline Unit and Mast truck. RIH W/ 1 -1/2" Magnet, tagged @ 10,614' wlm, worked tool, POOH, very little sample on magnet. RIH W/ 1 -3/4" hydrostatic Bailer with 2 -1/4" junk basket, tagged fluid at 5,268' wlm, continued in, tagged XN nipple @ 10,437' wlm, POOH. RIH W/ 1 -3/4" hydro- static Bailer, tagged @ 10,614' wlm, worked tool, POOH, had 2 perf disc's and full of sand. RIH W/ 1 -3/4" hydro- static Bailer, tagged @ 10,615' wlm, worked tool, POOH, pin did not shear. RIH W/ 1 -3/4" hydro- static Bailer, tagged @ 10,615' wlm, worked tool, POOH, recovered full of sand. RIH W/ 1- 3/ "4 hydro- static Bailer, tagged @ 10,615' wim, worked tool, POOH, had 1 perf disc and full of sand. RIH W/ 1 -3/4" hydro- static Bailer, tagged @ 10,616' wlm, worked tool, POOH, had 1 perf disc and full of sand. RIH W/ 1 -3/4" hydro- static Bailer, tagged @ 10,616' wlm, worked tool, POOH, bailer full of sand. RDMO Pollard Slickline. 03/21/2013 - Thursday MIRU SL set PX plug in XN nipple at 10,448' and pulled lower GLM. RDMO SL. MIRU Williams WOR, Installed winterization. Circulated well with PW and tested CSG to 2,000 psi for 15 mins and charted. CSG tested good. Set BPV, ND PT and NU 11" BOP Stack. 03/22/2013 - Friday Tested BOPE from 12pm to 11pm with State AOGCC Inspector Jeff Jones (250 low - 3000 high). Pulled BPV out of the tbg hanger. Closed blind rams and made repairs on Koomey Unit per AOGCC Inspector. 03/23/2013 - Saturday Finished repairing the Koomey Unit. Backed lock pins on hanger out and PU to string wieght at 57,000 #. PU string to 67,000# and released seal assembly out of the packer. TOOH and L/D 327 jts of 2 -7/8" IBT TBG, 13 GLM, 2 pup jts and seal assembly. 03/24/2013 - Sunday PU Burn shoe, boot basket, jars and DC. TIH w/ 2 -7/8" PH6 workstring and tag packer at 10,440'. Mix a 50 bbl sweep in coil tank to pump while milling. Broke circulation and started milling for 1 hr. SD due to power swivel not torquing up. Making repairs. 03/25/2013 - Monday SD for four hours to repair power swivel. Started milling on packer, burned thru packer and chased to bottom. Pumped a gel sweep and waited for sweep to come around. L/D power swizel and SOOH with workstring. L/D milling assembly BHA. PU spear. bumper jars, oil jars 6 DC and accel jars. TIH at report time. 03/26/2013 - Tuesday TIH and latched fish at 10,605'. TOOH and L/D fish, packer, 1 jt of 2 -7/8" IBT and a WL re -entry guide. MIRU SL RIH w/ 1.75" magnet and tag 10,644' wlm. POOH w /metal debris. RIH w/1.75" magnet and tag 10,643'. POOH w /metal debris. 03/27/2013 -Wednesday RIH w/ 3" drive down bailer at 10,640' wlm. Made 8 runs and bailed to 10,648'w1m. PU up a 2.5" pump bailer and tag @ 10,648' wlm. Stroked bailer and POOH. No sample. RIH w/2.25" LIB and tag at 10,648' wlm. POOH. Showed metal mark. RIH w/3.5" magnet and tag 10,648' wlm. POOH w /metal pieces. RIH w /same tag at 10.648' wlm. No metal on magnet. RIH w/1.75" Pump bailer and tag at 10,648' wlm. Stroked bailer and POOH with no sample. RIH w/1.75" drive down bailer and tag @ 10,648' wlm. POOH w /no sample. RIH w/2.25" LIB and tag at 10,648' wlm. Showed metal. RIH w/1.75" magnet and tag at 10,648' wlm. POOH with no metal. RIH w /1.5" drive down bailer and tag at 10,648' wlm. Could not make hole. POOH. RDMO SL. PU a 2 -3/8" spear dressed with a 1.995" grapple and TIH w /workstring. 03/28/2013 - Thursay • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 33 -05 50 -133- 20276 -00 175 -039 3/13/13 4/3/13 TOOH with spear, attempted to engage fish at 10,642' with no success. TBG plugged off. MIRU EL. RIH w/ TBG puncher. Punched hole 10,370' wlm. POOH. RDMO EL. SOOH and L/D spear. PU a 4 -5/8" bladed junk mill, boot baskets, jars and 6 DC. Tag Fish and started milling at report time. 03/29/2013 - Friday Milled up 4" off the top of the WL re -entry guide. Circulated bottoms up. TOOH. L/D Junk Mill. MIRU SL, Made 3 runs with a 3.5" magnet and recovered metal debris. RIH w/ 1.75" bailer and tag at 10,644'. Could not get inside fish. POOH. PU a 2.5" LIB and RIH. Tag at 10,644', POOH. LIB showed 2 -3/8" impression. PU a 1.992" grapple, jars and 6 DC and TIH with 165 stands and 1 single. Engaged fish and started jarring. 03/30/2013 - Saturday Engaged the fish @ 10,642'„Continued jarring on fish for 4 hrs. We tried to release one of the CC safety jnts down hole with no success. Released spear from fish. Tried to re- engage but we kept shucking the spear. TOOH. Tested BOPE per AOGCC regulations, 250 psi low - 2,500 psi high. (Witness waived by Jim Regg, AOGCC 3/30/13). PU tapered Tap, Jars and 6 DC and TIH at report time. 03/31/2013 - Sunday TIH w /tapered tap and engaged fish @ 10,642'. Tried to release one of the 2 safety jts with no success. We began jarring on fish. After 1 hr of jarring the fish started coming up the hole. Drug the fish at 20K # over string wieght thru the liner. POOH. L/D all 3 FH packer and a SL toolstring stuck in the bottom of the tailpipe. MIRU SL, RIH w /2" DD bailer and tagged hard at 10,753' wlm. POOH. Did not recover sample. RIH w/4.80' wire brush. Brushed production liner from 10,383' wlm POOH. Fluid level at 1,600'. RDMO SL. PU a 4 -5/8" mill, jars and 6 DC. TIH and tag at 10,650'. RU power swivel and started milling at report time. 04/01/2013 - Monday Drilled 1' and fell through. Pumped a 10 bbl sweep. We tagged again @ 10,745'. We drilled 17' and fell through. We tagged again hard @ 10,832'. Pumped a 40 bbl sweep. Circulated well with 450 bbls of clean PW. RD Power Swivel. POOH and L/D workstring and BHA. 04/02/2013 - Tuesday MIRU EL. RIH w /Gamma Ray and CCL, logged from 10,824' to 3,000'. MU a 3 -3/8" x 29' perf gun and RIH to depth. Perforated (10,779' to 10,808' POOH. MU a 3 -3/8" x 32' perf gun and RIH to depth. Perforated (10,684' to 10,716'). POOH. MU a 3 -3/8" x 15' perf gun and RIH to depth. ,Perforated (10,650' to 10,6651. POOH. MU a 3 -3/8" x 16.5' perf gun and RIH to depth. Perforated (10,620' to 10,636.5'). POOH. MU a 3 -3/8" x 17' perf gun and RIH to depth. Perforated (10,590' to 10,607'). POOH. RDMO EL. PU WLRG, x- nipple, packer and started in hole with completion string at report time. 04/03/2013 - Wednesday TIH w/ 323 jts of 2 -7/8" EUE 8rd tbg, 9 GLM, packer, x- nipple and WLRG. Set packer at 10,423' and landed hander with 9,000# of compression. Drop RHCP plug and tested tbg to 3,000psi and csg to 2,000psi (charted for 30 mins). Set BPV, ND BOP stack, NU PT, Pulled BPV and tested PT to 5,000psi. Started RD WOR. • 0 • Soldotna Creek Unit • Well SCU 33-05 SCHEMATIC Completion Date: 04/03/13 PTD: 175 -039 HiIcoru Alaska, LLC API: 50- 133 - 20276 -00 RKB to TBG Hanger = 19.28' CASING DETAIL Type Size WT Grade Conn ID Top Btm. Conductor 20" Surf 44' 1 Surface 10 -3/4" 40.5 K -55 Surf 3,372' 26.4 N -80 6.969" Surf 3,798' 202. 29.7 N -80 6.875" 3,798' 5,733' Production 7 -5/8" 33.7 5 -95 6.765" 5,733' 6,906' 33.7 P -110 6.765" 6,906' 10,585' I 8 2 Liner 5 -1/2" 20 N -80 4.778" 10,38 10,870' TUBING DETAIL 10 -3/4'/ , I Tubing I 2 -7/8" 6.5 L -80 8RD EUE I 2.441" I Surf 10,425' I 8 3 JEWELRY DETAIL NO. Depth ID OD Item I_ i 4 1 17' - - Tubing Hanger, Shaffer, 2 -3/8" CIW BPVP 2 2,316' 2.44" 4.75" 2 -7/8" GLM SF0 -1 Mandrel 3 4,013' 2.44" 4.75" 2 - 7/8" GLM SFO -1 Mandrel 4 5,331' 2.44" 4.75" 2 - 7/8" GLM SFO -1 Mandrel I 8 5 5 6,427' 2.44" 4.75" 2 -7/8" GLM SFO -1 Mandrel 6 7,333' 2.44" 4.75" 2 -7/8" GLM SFO -1 Mandrel 7 8,141' 2.44" 4.75" 2 - 7/8" GLM SFO -1 Mandrel 8 8,885' 2.44" 4.75" 2 -7/8" GLM SFO -1 Mandrel 9 9,997' 2.44" 4.75" 2 -7/8" GLM SFO -1 Mandrel I j 6 10 10,375' 2.44" 4.75" 2 -7/8" GLM SFO -1 Mandrel - 1" Orifice 11 10,423' 2.313" 4.8" On /Off tool • 12 10,424' 2.44" 4.8" AS1 -X Retrievable Packer 13 10,435' 2.313" 3.5" EUE "X" Landing Nipple 14 10,439' 2.4" 3.5" EUE WLEG I 117 I 8 8 PERFORATIONS (Open Hole) Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Length Date 10,498' 10,510' 10,435' 10,446' 12' 03/27/01 I 8 9 G2 10,530' 10,544' 10,464' 10,477' 14' 03/27/01 10,551' 10,561' 10,483' 10,492' 10' 03/27/01 10,584' 10,590' 10,513' 10,518' 4 6' 07/02/94 I 0 10 H1 10,584' 10,601' 10,513' 10,528' 17 04/02/13 10,595' 10,601' 10,523' 10,528' 4 6' 07/02/94 7 -5/8' H2 10,616' 10,634' 10,542' 10,558' 6 18' 04/02/13 10,616' 10,634' 10,542' 10,558' 4 18' 07/02/94 H3 10,646' 10,661' 10,569' 10,582' 6 13' 04/02/13 V 10,648' 10,661' 10,570' 10,582' 4 13' / 10,680' 10,712' 10,599' 10,629' 6 32' 04/02/13 ✓ H4 10,680' 10,700' 10,599' 10,617' 4 20' f II III 12 10,702' 10,712' 10,619' 10,627' 4 10' 09/1970 E4 13 H5 10,722' 10,747' 10,636' 10,658' 4 25' . H7 10,776' 10,805' 10,684' 10,709' 29' 04/02/13 v G2 - 14 H1 H2 - I Max Dev. 30 degrees I H3 = -H4 H5 H7 5 -1/2 "7 .. , , TD = 10,870' / PBTD = 10,722' Updated by DMA 05/14/13 • s 9 THE STATE Alaska Oil and Gas °f T ,[� i onservaton Commission Ll 1 o GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALASP Anchorage, Alaska 99501 -3572 Main: 907.279.1433 SCANNED MAR 2 1 2013 Fax: 907.276.7542 Chad Helgeson Operations Manager 1 76:—°3/ Hilcorp Alaska, Inc. 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 33 -05 Sundry Number: 313 -136 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Ye Cathy P. oerster Chair DATED this day of March, 2013. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A j CC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Wel❑✓ • ChangeApproved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate © 0 Pull Tubing✓ • Time Extension ❑ Operations Shutdowi ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter Casini0 Other Re- Perforate & new completion 0 2. Operator Name: Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Exploratory ❑ Development 0 • 175-039 4 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number Anchorage, Alaska 99503 50-133-20276-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123A Soldotna Creek Unit (SCU) 33 -05 ■ Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028996 Swanson River Field / Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,870 , 10,766 ' 10,722 10,636 N/A WA Casing Length Size MD WD Burst Collapse Structural Conductor 44' 20" 44' 44' Surface 3,372' 10 -3/4" 3,372' 3,372' 3,130 psi 1,580 psi Intermediate Production 10,585' 7 -5/8" 10,585' 10,514' 6,020 psi 3,400 psi Liner 485' 5 -1/2" 10,870' 10,766' 9,190 psi 8,830 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (It): See Attached Schematic See Attached Schematic 2 -7/8" 6.5# / L-80 10,425 Packers and SSSV Type: Baker FB -1 Pkr Packers and SSSV MD (t) and TVD (ft): 10,440' MD - 10,382' TVD 3 Baker FH Pkrs - N/A 10,640' MD - 10,563'TVD; 10,668'MD - 10,588' TVD; 10,715'MD - 10,630' TVD; N/A 12. Attachments: Description Summary of Proposal 1151 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch n Exploratory ❑ Stratigraphic0 Development n Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 03/22/13 Commencing Operations: Oil Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Phone: 907- 777 -8405 Email chelgeson(d hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature e4 Phone 907- 777 -8405 Date 3 //5y/3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 5r` 510 Plug Integrity ❑ BOP Test IX Mechanical Integrity Test ❑ Location Clearance ❑ h✓ Other: 1- 250 o p 5..:, 6 tL) r LS (— 41 L? p r Ac HAR 21 Z �: ), v l y 1 S p s L An K•3-46.4.. b Spacing Exception Required? Yes ❑ No M Subsequent Form Required: / 0 .- 1 1 0 7 APPROVED BY Approved GRIG by: / COMMISSIONER THE COMMISSION Date: 3 - 2 --0 20 Submit Fon i ane Approved applicatio is valid for 12 months from the date of approval. '� Attachments in Duplicate / � `) / 7% ,� - • • Well Prognosis Well: SCU 33 -5 Hilcorp Alaska, LLB Date: 3/15/2013 Well Name: SCU 33 -5 API Number: 50- 133 -20276 Current Status: Shut in Oil Producer Leg: N/A Estimated Start Date: March 22, 2013 Rig: Williams 405 Reg. Approval Req'd: 403 Date Reg. Approval Rec'd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 175 -039 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Sangier (907) 777 -8378 AFE Number: AFE 1320331 Current Bottom Hole Pressure: — 2,200 psi @ 10,500' TVD Static survey 5 -25 -2012 Maximum Expected BHP: — 2,200 psi @ 10,500' TVD Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir pressure as measured by static pressure survey run 5 -25 -2012. Working fluid (gradient of .442 psi /ft) will balance reservoir pressure at 5622 ft. TVD. Brief Well Summary Soldotna Creek Unit 33 -5 was drilled in 1975 to develop oil reserves in the Hemlock formation with perforations in the H -1 -5 sand lobes. The well originally flowed on test at rates over 1000 BOPD but declined to about 100 BOPD in about 18 months as GORs increased. Asphaltene and or paraffin deposits increased in wellbores as the GOR increased. These deposits were treated mechanically (slick line cutting) and with solvents including hot oil and aromatics, with varying degrees of success. Gas lift operations further increased the GOR in the tubing and reduced flowing bottom hole pressures, which further compounded wax deposits at the completion interval and on through the tubing and flow lines. Production operations continued with gas lift until bottom hole pressures approached 800 psi with producing rates declined to less than 20 bpd with water cut at — 90 %. The well was last produced in 2009. The well was worked over to change out the tubing from 3 -1/2" to 2 -7/8" in 1994 and to change the gas lift design to . increase maximum lift depth from 7,278' to 10,301' MD. Notes Regarding Wellbore Condition Well current well status is shut in oil well. Wellbore deviation across perforated intervals is 26 -30 degrees. OBJECTIVE OF WORKOVER Pull tubing and bottom hole assembly to remediate suspected completion damage due to asphaltene accumulations. These accumulations are thought to be present from the perforation tunnels through completion tubulars installed in 1975 for selective zone isolation. Pre Work over Rig Procedure: 1. Pre pulling unit activities. 2. Close and tag (lock out/ tag out /bleed) pressure sources to wellhead from flow lines and gas lift supply lines. 3. Shoot fluid levels on casing and tubing and report same, and calculate fill volume to fill wellbore. • • Well Prognosis Well: SCU 33 -5 Hilcorp Alaska, LL Date: 3/15/2013 4. RU slick line unit and bail sand /debris from the top of the overshot at 10,633'. 5. Pull bottom GL mandrel at 10,301'. RIH w /PXN plug and prong and set in XN- nipple at 10,460'. 6. Prep location to remove snow and any debris that will effect safe operations. 7. Check and record pressures on casing and tubing. 8. Conduct JSA on rig up operations. Work -Over Rig Procedure 9. MIRU Williams pulling unit. ✓ 10. Rig up circulating manifold and bleed any pressure off tubing through same to working tank. 11. Circulate well with lease produced water (8.5 ppg) filling well down tubing and take returns on casing, circulate until clean fluid is returned. 3� 12. Pressure test casing to 2,000 psi and hold for min. v CM"" (3)i*. 13. Install back pressure valve in tbg hanger. Note: If hanger profile is not test worthy, call out slick line with tubing stop /plug and set at 500'. 14. Set BPV in tubing hanger, ND tree, NU 11" BOPE and test to 250psi low /3,000psi high, annular to 250psi low /1,500psi high (hold each valve and test for 10 -min). Record accumulator pre- charge pressures. a. Notify AOGCC 24hrs in advance to witness test. b. Notify BLM 48 hrs in advance of BOP test. c. Ensure winterization package is installed for the weather conditions. 15. Release test pressure, pull tubing stop or BPV and install 2 -7/8" EUE N 80 handling sub in hanger. 16. Back out tbg hanger, hold down pins and pick up on hanger. 17. With hanger free, record tbg weight while picking up tubing. Do not exceed 40,000 lbs above string weight on tbg head connection to pull locator seal assembly out of FB -1 packer at 10,440 ft. If seals are stuck in packer RU e-line and cut 2 -3/8" tubing 10' above locator seal assembly and fish same with overshot and jars on work string. 18. If seal assembly pulls free, TOOH with tubing and gas lift mandrels. LD tubing 19. PU packer retrieval assembly (burning shoe, wash pipe, bumper sub, jars, drill collars) and 2 -7/8" PH -6 work string. 20. TIH and burn over packer until comes free and push down. 21. Trip work string with overshot (dressed for 2 -3/8" tbg), bumper jars and collars to fish seal assy and packer. 22. RIH w /overshot or spear onto tubing and POOH with tbg and packer. 23. POOH, LD Spear BHA. 24. Clean sand or debris from the top of the scoophead (TSA Overshot w/ reentry guide) with slickline, slimhole circulating sub, or bulldog bailer. 25. RIH w/ fishing assembly for 2 -3/8" 4.6# tubing and fish for scooped head /overshot assy landed on Brown CC safety joint. 26. POOH and lay down scooped head 27. RIH with wash pipe for and wash down to packer at 10,640'. 28. Trip tubing for overshot to latch CC safety joint and release FH packer at 10,637'. Cycle tension on tubing to work packer elements. • Do not exceed the tensile strength of the of the 2 -3/8" 4.6# N -80 tubing in the tubing (104,340 #). s/ 29. If all the packers do not come free, but there was a little movement, rotate off CC safety joint (12 turns to the right). • • Well Prognosis Well: SCU 33 -5 Hilcorp Alaska, LL Date: 3/15/2013 30. POOH with fish, LD fish and determine any completion assy left in the hole. a. If only 1 packer comes with the CC safety joint, RIH with overshot for CC safety joint and pull Baker FH packers, jarring free. b. If necessary rotate 12 turns to the right to release 2 CC safety joint. c. Repeat as necessary until all the fish comes out of the hole. 31. LD workstring. 32. RU slickline line and bumper jars and RIH with bailer and tag bottom in 5 -1/5 "x 20# production liner. 33. Rig up casing brushes for 5 -1/2" production liner and RIH below jars on braided line to scrub walls of production liner. Remove debris with hydrostatic bailer on work string as necessary. 34. Shoot fluid level on casing when all BHA has been recovered. 35. Perforate Hemlock (H -1 to H -5) intervals with deep penetration charges with 3 -3/8" OD carrier 6 spf on 60 deg phase. a. Proposed perfs shown on the proposed schematic � b. Final Perfs tie -in sheet will be provided in the field for exact perf intervals, based on the success of fish removal. Note: Record fluid levels and time of day for each RIH with E -line. 36. RDMO E -line unit. 37. RIH with packer and GLVs per design with new tubing. Set packer at +1- 10,410'. Land tubing hanger with 8 -10K of compression on tubing. 38. Drop RHCP plug in well and test casing to 2,000 psi and tubing to 3,000 psi, chart for 30 min ea. 39. Set BPV, ND BOPs, NU Tree, test tree to 5,000 psi. 40. RDMO workover rig and equipment. 41. Turn well over to production. 42. NU piping and flowlines. 43. Gas lift well, unloading fluid from well, SI well leaving gas lift pressure on well. 44. RU slickline, PT lubricator to 2000 psi Hi 250 low. 45. RIH and pull RHCP prong and plug 46. Start production 47. Notify AOGCC of SSV testing within 5 days of brining well online. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic • • • Well Soldotna SCU Creek 33 5 Unit • SCHEMATIC Completion Date: 10/25/75 Hilcorp Alaska, LLC PTD: 175 -039 API: 50- 133 - 20276 -00 CASING DETAIL RKB = 19.28' Type Size WT Grade Conn ID Top Btm. Conductor 20" Surf 44' 1111 1 Surface 10 -3/4" 40.5 K -55 Surf 3,372' Mk i 26.4 N -80 6.969" Surf 3,798' 29.7 N -80 6.875" 3,798' 5,733' 20" Production 7 -5/8 IR i 33.7 S -95 6.765" 5,733' 6,906' Mg i 33.7 P -110 6.765" 6,906' 10,585' allt ' A Li 5 -1/2" 20 N -80 4.778" 10,384' 10,870' INIMIlk Mb i 10 -3/4 o TUBING DETAIL es f ` !; l I 2 -7/8" I 6.5 I L -80 I Butt. I I Surf I 10,470' 7 - 5/8" aim 41 ' JEWELRY DETAIL +s ' No Depth Item / 1 1,783' #13 Gas Lift Mandrel /� Q��✓� 3,228' #12 Gas Lift Mandrel 2 + O,(f' 4,270' #11 Gas Lift Mandrel 4,995' #10 Gas Lift Mandrel 5,594' #9 Gas Lift Mandrel 6,197' #8 Gas Lift Mandrel 3 A 6,808' #7 Gas Lift Mandrel 7,412' #6 Gas Lift Mandrel = 4 io :, 33 8,019' #5 Gas Lift Mandrel 8,600' #4 Gas Lift Mandrel MI 5 Sa 0-4". 9,209' #3 Gas Lift Mandrel 9,816' #2 Gas Lift Mandrel e 10,301 #1 Gas Lift Mandrel 1 10,440' 5 -1/2" Baker "FB -1" Perm Pkr ® 7 106 40 2 10,460' 2 -7/8" "XN" Nipple 3 10,470' Wireline Re -Entry Guide 4 10,633' Wireline Re -Entry Guide w /TSA Overshot 8 5 10,636' Brown "CC" Safety Joint 2 -3/8" ✓ _ s 6 10,637' Otis "XA" Sleeve 9 7 10,640' Baker "FH" Pkr 8 10,647' Otis "S" Nipple 9 10,648' 2 2 -3/8" Blast Jts. L 10 10 10,664' Brown "CC" Safety Jt. 11 10,665' Otis "XA" Sleeve 11 12 10,668' Baker "FH" Pkr 13 10,675' Otis "5" Nipple 1 III 12 066 Y 14 10,676' 3 2 -3/8" Blast Jts. 15 10,710' Brown "CC" Safety Jt. 13 16 10,712' Otis "XA" Sleeve OMMIP 17 10,715' Baker "FH" Pkr 14 18 10,721' Otis "S" Nipple = 19 10,722' 2 2 -3/8" Blast Jts. 15 20 10,743' Camco "D" Nipple 21 10,744' 2 -3/8" Blast Jts. 16 D 1l PERFORATIONS (Open Hole) ■ ®; 17 I i Zon Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Length Date 18 10,498' 10,510' 10,435' 10,446' 12' 3/27/01 mom G2 10,530' 10,544' 10,464' 10,477' 14' 3/27/01 19 10,551' 10,561' 10,483' 10,492' 10' 3/27/01 Fill @ 10,722' MI 10,584' 10,590' 10,513' 10,518' 4 6' 7/2/1994 6/87 20 H1 10,595' 10,601' 10,523' 10,528' 4 6' 7/2/1994 to onium H2 10,616' 10,634' 10,542' 10,558' 4 18' 7/2/1994 21 H3 10,648' 10,661' 10,570' 10,582' 4 13' H4 10,680' 10,700' 10,599' 10,617' 4 20' c. 10,702' 10,712' 10,619' 10,627' 4 10' 9/70 5 - 1/2" H5 10,722' 10,747' 10,636' 10,658' 4 25' TD @ 10,870' PBTD @ 10,722' Updated by DMA 03/15/13 14 • S Swanson River Field PROPOSED Well # SCU 33 -5 Hilcorp Alaska, LLC Date 3 -15 -13 RKB to TBG Hanger = 19.28' CASING DETAIL Type Size WT Grade Conn ID Top Btm. Conductor 20" Surf 44' 1 L Surface 10 -3/4" 40.5 K -55 Surf 3,372' 26.4 N -80 6.969" Surf 3,798' Production 7_5/8" 29.7 N-80 6.875" 3,798' 5,733' 20 33.7 S -95 6.765" 5,733' 6,906' 33.7 P -110 6.765" 6,906' 10,585' Liner 5 -1/2" 20 N -80 4.778" 10,384' 10,870' NE 2 TUBING DETAIL T ubing I 2 -7/8" I 6.5 L -80 18R EUE I 2.441 I Surf I 10,425' 10 -3/4 L , IR 13 I JEWELRY DETAIL NO. Depth ID OD Item IR 4 1 17' - - Tubing Hanger, Shaffer, 2 -3/8 CIW BPVP I 2 3 ±2,300' 2.44 4.75 GLM 8rd, SFO 1 Mandrel ±4,000' 2.44 4.75 GLM 8rd, SFO -1 Mandrel 4 ±5,300' 2.44 4.75 GLM 8rd, SFO -1 Mandrel 5 ±6,401' 2.44 4.75 GLM 8rd, SFO -1 Mandrel Illa 15 1 6 ±7,302' 2.44 4.75 GLM 8rd, SFO -1 Mandrel 7 ±8,109' 2.44 4.75 GLM 8rd, SFO -1 Mandrel 8 ±8,865' 2.44 4.75 GLM 8rd, SFO -1 Mandrel 9 ±9,970' 2.44 4.75 GLM 8rd, SFO -1 Mandrel 4101 i 6 10 ±10,360' 2.44 4.75 GLM 8rd, SFO -1 Mandrel- orifice • 11 12 ±10,400' 2.313 4.8 On /off tool w/ x- nipple ±10,410' 2.44 4.8 Arrowset mechanical packer 13 ±10,420' 2.313 3.5 X- Nipple 14 ±10,425' 2.4 3.5 WLREG al 7 I ' -8 i 9 5 PERFORATIONS (Open Hole) IR It54 1 10 Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Length Date 10,498' 10,510' 10,435' 10,446' 12' 3/27/01 7 5/8 G2 10,530' 10,544' 10,464' 10,477' 14' 3/27/01 10,551' 10,561' 10,483' 10,492' 10' 3/27/01 H1 10,582' 10,602' 10,511' 10,529' 6 20' Future • 7/2/1994 H1 10,584' 10,590' 10,513' 10,518' 4 6' 10,595' 10,601' 10,523' 10,528' 4 6' 7/2/1994 . F.. '�. . 1 1 H2 10,616' 10,634' 10,542' 10,558' 6 18' Future 674 1 3 H2 10,616' 10,634' 10,542' 10,558' 4 18' 7/2/1994 H3 10,648' 10,661' 10,570' 10,582' 6 13' Future • H3 10,648' 10,661' 10,570' 10,582' 4 13' H H4 10,680' 10,712' 10,599' 10,629' 6 32' Future ' H4 10,680' 10,700' 10,599' 10,617' 4 20' 10,702' 10,712' 10,619' 10,627' 4 10' 9/70 H5 10,722' 10,742' 10,636' 10,656' 6 20' Future H5 10,722' 10,747' 10,636' 10,658' 4 25' = Max Dev. 30 deg 5-1 PBTD = 10,722' TD = 10,870' Revised By CAH 3/15/2013 r • • Soldotna Creek Unit Well SCU 33 -5 Completion Date: 10/25/75 PTD: 175 -039 Ihk.,.p %Ia471.1.Ix. API: 50- 133 - 20276 -00 Swanson River Williams BOP 2013 • • I i l I Ill lfillaIllililllllil f 3.46' Shaffer 11" 5M lir III ill !h is gi Shaffer LWS ® 1 -er. 2.75' _I it 5M 2 1/16 1OM Choke and Kill `ilIMIl■ Valves - - _ .. Iii 111111 111 Ill -i4f*: I 2.00' Iii 111 Iil 111 Iii -4 4 Lr^ 1 Z o f ' 1 I.= i4t.,: I I .1._-; .-. I . 4 .• 1 .. i i •(•.. i Bp . .. { •►:! ,.. ,,_ ... 1 I . .... , id ■ 0 - �; 4411 1 _ Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALI Dan Williamson Drilling Manager September 12, 2001 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn' Mr. Tom Maunder Subject: Soldotna Creek Unit Well SCU 33-5 APl No. 50-133-20276-00 10-404 Perforate G-Zone Dear Mr. Maunder: Please find enclosed in duplicate Form 10-404 for the perforation of the G-Zone in well SCU 33-5. The following intervals were perforated on 3/27/01' Bench Top Bottom Feet G 10,500 10,512 12 G 10,532 10,546 14 G 10,553 10,563 10 If you have any questions, please contact Ralph Holman at 263-7838. Dan Williamson Drilling Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X KB: 170' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Soldotna Creek Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 ' Service: 4. Location of well at surface 8. Well number 1896' N and 626' W from the SE Cor., Sec. 5, T7N, R9W, SM SCU 33-5 At top of productive interval ~). Permit number/approval number 61' N and 356' W of surface location 75-39/93-319 At effective depth 10. APl number 110'N and 468' W of surface location 50-133-20276-00 At total depth i 1. Field/Pool 110' N and 468' W of surface location Swanson RivedHemlock & G-Zone 12. Present well condition summary Total depth: measured 10870 feet Plugs (measured) true vertical 10766 feet Effective depth: measured 10722 feet Junk (measured) true vertical 10635 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 44' 20" No 44' 44' Surface 3372' 10-3/4" 1035 sx 3372' 3372' Intermediate Production 10585' 7-518" 645 sx 10585' 10509' Liner 485' 5-1/2" 100 sx 10384'-10870' 10326'-10759' Perforation depth: measured 10500-10512, 10532-10546, 10553-10563, 10584-10590, 10595-10601, 10616-10634, 10648-10661, 10680-10700, 10702-10712, 10722-10747 true vertical 10437-10448, 10466-10479, 10485-10494, 10513-10518, 10523-10528, 10541-10557, 10570-10581, 10598-10616, 10618-10627, 10635-10657 Tubing (size, grade, and measured depth) 2-7/8", 6.5~, N-80 from surface to 10470'; 2-3/8" & 2-3/4" with blast joints from 10633'-10744' Packers and SSSV (type and measured depth) Baker FB-1 pkr. @ 10440', Baker FH pkr. @ 10640', 10668' & 10715' 1"3. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure i4. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 9 1 9 750 220 Prior to well operation 9 92 7 795 205 Subsequent to operation 15o Attachments: 16. Status of well classification as: , Copies of Logs and Surveys run: ~{~il ~.,.: i! Daily Report of Well Operations: Oil: X Gas: Suspended: §~ice:~,~;, i~'~- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signe ., Title: ( Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE"~ Unocal North Amer''~'-' Oil & Gas Divison Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL Alaska Region Friday, August 05, 1994 Dear Mr. Douglas, This notice covers the perforating work that was vebally approved on June 30, 1994. They are the intervals that were included in the workover Sundry submitted in April, 1994. Ralph P. Holman ORIGINAL RECF.. V£D AUG A~;~ska Oit & Gas Cons. Commission --~ STATE OF ALASKA ~--- ALASK ,IL AND GAS CONSERVATION C( ~IISSION REPORT OF SUNDRY WELL OP -RATIONS 1. Operations performed: Operation shutdown m Stimulate Pull tubing Alter casing 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Plugging __ Perforate X_ Repair well Pull tubing Other m 5. Type of Well: Development X_ Exploratory ~ Stratigraphio __ Location of well at surface 1896' N and 626' W from the SE Cor., Sec. 5, 'ITN, R9W, SM At top of productive interval 61' N and 356' W of Surface Location At effective depth 110' N and 468' W of Surface Location At total depth 110' N and 468' W of Surface Location O tGINAL 6. Datum eleva~n (DF or KB) KB: 170' feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 33-5 9. Permit number/approval number 75-39/93-319 10. APl number 50-133-20276-00 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total depth: measured true vertical 10870 feet 10766 feet Plugs (measured) Effective depth: measured 10722 true vertical 10635 Casing Length Structural Conductor 44' Surface 3372' Intermediate Production 10585' Uner 485' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) feet Junk (measured) feet Size Cemented Measured depth True vertical depth 20' No 44' 44' 10-3~' 1035 sx 3372' 3372' 7-5~' 645 sx 10585' 10509' 5-1/~ 100ax 10384'-10870' 10326'-10759' 10584-10590,10595-10601,10616-10634,10648-10661,10680-10700,10702-10712, 10711-10747 10513-10518,10523-10528,10541-10557,10570-10581,10598-10616,10618-10627, 10635-10657 See Schemmic See ~hematic RECEIVED 13. Stimulation or cement squeeze summary AUG 1 0 1994 Intervals treated (measured) Treatment description including volumes used and final pressure Ai~ska 0il & Gas Cons. C0mmi,, Anch0raji~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 105 795 I 5O0 116 770 2 500 Tubing Pressure 500 250 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Senate sion Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE SWANSON RIVERFIELD SGU ACTUAL 3/10/94 10 3/4" 40.5# @3372' TOP OF LINER @10,:384' 7 5/8" a6.4# 29.7# 33.7# @10,585' PERFS FROM I0,616-10,639'~ 1 $ ? 1! 17 PERFS FROM 10,648-10 PERFS FROM 10,680-10 PERFS FROM 10,722-10,747': ETD @11,010' 5 tiff' 20# ~-so @10,870' GAS LIFT MANDREI~ AS DETAILED A) 2 7/8" 6.5# N-80 BUTT TBG 1) 5 l/g' BkI<ER "FB-I" PERM PKR @10,440' 2) 10' SEAL BORE EXT. @10,442' 3) 8'2 7/8' 6.5# N-BO BUTT PUP @10,452' 4) ~ ?/~' 'xs" ~IP?~ ~)10.4~0' ~'2 v/ii' ~.~# N-~O Btn7 ~UI:' e~0,4S~' 5) WIRELINE RE-ENTRY GUIDE @10,470' POTENTIAL PERFS @10,585-10,590' / 10,595-i0,610' 7) WlRELLNE RE-ENTRY GUIDE.W/TSA OVERSHOT @10,6: 8) BROWN "CC" SAFETY JOINT @10,636' 9) OTIS "XA' SLEEVE @10,637' 10) BAKER 'FIT' PER @10,640' ll) 0TIS 'S" NIPPLE @10,647' 12) 2 2 3/4" BLAST JTS. @10,648' 13) BROWN "CC" JNT. @10,664' 14) OTIS ' XA' SLEEVE O i 0,665' 15) BAKER 'FI~ PER e10,668' 16) 0TIS '* S' NIPPLE @ 10,675' 17) 3 2 3/8" BLAST JTS @10,676' 18) BROWN "CC" JOINT @10,710' 19) 0TIS "X~* SLEEVE @10,712' 20) BAKER "FH* PER @10,715' 21) 0TIS "S" NIPPLE @10,721' 22) 2 2 3/8' BLAST JTS. @10,722 23) CAMCO "D" NIPPLE @10,743' 24) 2 3/8" BLAST JTS. @10,744' PB TD O10,722' STATE OF ALASKA -- ALA~ , OIL AND GAS CONSERVATION COMM, iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Pull tubing _ _ Alter casing 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 4. Location of well at surface __ Plugging _ _ Perforate _ _ Repair well X_X_._ Pull tubing __ Other_ _ 5. Type of Well: Development X_ Exploratory __ Stratigraphic__ Service __ 6. Datum elevation (DF or KB) 170' KB 7. Unit or Property name Soldotna Creek Unit 8. Well number 1896' North and 626' West from the SE Corner, Section 5, '[TN, R9W. SB&M At top of productive interval 61' North and 356' West of surface location At effective depth 110' North and 468' West of surface location At total depth 110' North and 468' West of surface location ORIGINAL SCU 33-5 9. Permit number/approval number 75 -39/93 -319 10. APl number 50-133 -20276 11. Field/Pool Swanson River-Hemlock feet 12. Present well condition summary Total depth: measured true vertical 10,870' feet Plugs (measured) 10,759' feet Effective depth: measured 10,722' feet Junk (measured) true vertical 10,722' feet Casing Length Size Cemented Measured depth Structural Conductor 44' 20" No 44' Surface 3372' 10-3/4" 1035 sx 3372' Intermediate Production 10585' 7-5/8" 100 sx & 545 sx 10585' Liner 485' 5-1/2" 100 sx 10384'- 10870' True vertical depth 44' 3372' 10509' 103 26'- 10759' Perforation depth: measured 10616'-10634'; 10648'-10661 '; 10680'-10700'; 10702'-10712'; 10722'-10747' true vertical 10537'-10552'; 10565'-10576'; 10593'-10611 '; 10613'-10622'; 10631'-10652' Tubing (size, grade, and measured depth) See Schematic Packers and SSSV (type and measured depth) See Schematic R E ¢ E IV E D 13. Stimulation or cement squeeze summary Intervals treated (measured) None Treatment description including volumes used and final pressure None AP~ I 1 1994 Ata3k3 U~t & 6as Cons. Commission A.~chorage 14. Prior to well operation SubseqUent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Shut-in Not available Tubing Pressure 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations x__ 16. Status of well classification as: Oil x.x__ Gas __ Suspended _ _ Service 17. I her~/c~~rue and correct to the best of my knowledge. Signed G. Russell Schmidt Title Drilling Manager Form 10-404 Rev 06/15/88 Date 04/04/94 SUBMIT IN DUPLICATE SWANSON RIVER FIELD SGU ACTUAL 3/10/94 10 3/4" 40.5# @3372' GAS LIFT MANDRELS AS DETAILED TOP OF LINER @10,384' 7 5la" ~.?# 910,585' PERFS FROM 10,616-10,639'1 PERFS FROM 10,648-10,661' PERFS FROM 10,680-10,712' PERFS FROM 10,722-10,747'= ETD 911,010' ac# 910,870' A) 2 7/8" 6.5# N-80 BUTT TBG 7 8 9 I0 11 12 13 14 I§ 16 17 18 19 20 21 2t 2t 2i I) 5 1/2" BAKER "FB-I" PERM PKR 910,440' 2) 10' SEAL BORE EXT. 910,442' 3) 8'2 7/8" 6.5# N-80 BUTT PUP @10,452' 4) 2 7/8" "XN' NIPPLE @10,460' 5) 8' 2 7/8" 6.5# N-80 BUTT PUP @10,462' 5) WIRELINE RE-ENTRY GUIDE @10,470' POTENTIAL PERFS 910,585-10,590' / 10,595-10,610' 7) WIRELINE RE-ENTRY GUIDE W/TSA OVERSHOT 9i0,633' 8) BROWN "CC" SAFETY JOINT 910,636' 9) OTIS "XA" SLEEVE 910,637' 10) BAKER "Fff' PKR 910,640' 11) OTIS "g' NIPPLE 910,647' 12) 2 2 3/4" BLAST JTS. @10,648' 13) BROWN "CC" JNT. 910,664' 14) OTIS 'XA' SLEEVE 910,665' 15) BAKER "FI-[' PKR @10,668' i6) OTIS 'g' NIPPLE @i0,675' 17) 3 2 3/8" BLAST JTS 910,676' 18) BROWN "CC" JOINT 910,710' 19) OTIS "XA" SLEEVE 910,712' 20) BAKER "Fff' PKR @10,715' 21) OTIS "g' NIPPLE 910,72i' 22) 2 2 3/8" BLAST JTS. 910,722 23) CAMCO "D" NIPPLE @10,743' 24) 2 3/8" BLAST JTS. 910,744' PB TD 910,722' RECEIVED Anchorage "on SCU 33-5 DAY 1-2 (02/26-27/94) 10-3/4" @ 3372' 7-5/8" @ 10,585' 5-1/2" LINER 10,384'-10,870' LEASE WATER 8.5 PPG COMMENCED OPERATIONS ON SCU 33-5 AT 16:30 HRS ON 2-26-94. MOVE RIG FROM SCU 41-33 TO SCU 33-5. R/U RIG. CIRCULATE WELL CLEAN. DAY 3 (02/28/94) 10-3/4"@ 3372' 7-5/8"@ 10,585' 5-1/2" LINER 10,384'-10,870' LEASE WATER 8.5 PPG MADE CHEMICAL CUT IN 2-3/8" TUBING AT 10,493'. SET PLUG IN TUBING AT 505'. N/D TREE. N/U BOP TEST SAME. DAY 4 (03/01/94) 10-3/4"@ 3372' 7-5/8"@ 10,585' 5-1/2" LINER 10,384'-10,870' LEASE WATER 8.5 PPG RECOVERED PLUG AT 505'. UNSET HANGER CBU. POOH L/D 15 JTS. P/U RTTS STORM PACKER SET AT 95'. TEST TO 1500 PSI. N/D BOP'S & TUBING SPOOL CHANGE OUT 'X' BUSHING SEAL. N/U TUBING SPOOL TEST TO 2200 PSI. N/U BOP TEST SAME. RETRIEVE RTTS. POOH L/D TUBING. DAY 5 (03/02/94) 10-3/4" @ 3372' 7-5/8" @ 10,585' 5-1/2" LINER 10,384'-10,870' LEASE WATER 8.5 PPG POOH. L/D REMAINDER OF TUBING. CHANGE TOP RAMS TO 2-7/8" AND TEST. TESTED CASING AT 1500 PSI-OK. RIH W/OVER-SHOT FISHING ASSY. RECEIVED APR 1 1 oil & Gas Cons. Commission Anchorage DAY 6 (03/03/94) 10-3/4"@ 3372' 7-5/8"@ 10,585' 5-1/2" LINER 10,384'-10,870' LEASE WATER 8.5 PPG ENGAGED TOF AT 10,468' DPM. ATTEMPTED TO RELEASE PACKER- OVERSHOT SLIPPED OFF AND UNABLE TO RE-ENGAGE. POH & L/D OVERSHOT. P/U HYD CU'I-I'ER, AND WASH PIPE. RIH ON 3-1/2" DP. W/O FISH TO 10,565', COULDN'T GET DEEPER. DAY 7-9 (03/04-06/94) 10-3/4"@ 3372' 7-5/8"@ 10,585' 5-1/2" LINER 10,384'-10,870' LEASE WATER 8.5 PPG CUT TUBING W/OUTSIDE CU'I-I'ER AT 10,565'. POOH RECOVER 97' OF TUBING FISH. RIH W/1-1/2" GRAPPLE ON OVERSHOT. LATCH WIRELINE FISH AT 10545'. PULLWIRELINE FISH FREE. POOH. RECOVER ENTIRE W.L. FISH. RIH W/2 JTS OF WASH PIPE WASH FROM 10,564' TO 10,601 '. TOP OF PACKER. RECOVER ASPHALTINES AND SAND. POOH. RIH W/4-1/8" O.S. LATCH FISH AT 10,564'. UNSET PACK AND RELEASE 'CC,' SAFETY JOINT. POOH RECOVER SAME. DAY 10 (03/07/94) 10-3/4"@ 3372' 7-5/8"@ 10,585' 5-1/2" LINER 10,384'-10,870' LEASE WATER 8.5 PPG M/U "CC;" RE-ENTRY GUIDE. RIH A'I-rEMPT SCREW INTO "CC" PIN AT 10637'. ROTATE 6 TURNS PULL 10K TO SHEAR OUT RE-ENTRY GUIDE. POOH. L/D. DRILL PIPE FOUND RE-RNTRY GUIDE HAD NOT SHEAR OFF AS PLANNED. DAY 11 (03/08/94) 10-3/4"@ 3372' 7-5/8"@ 10,585' 5-1/2" LINER 10,384'-10,870' LEASE WATER 8.5 PPG P/U WASH SHOE FOR CLEAN OUT TRIP. RIH. P/U 3-1/2" TUBING. WASH F/10,636'-10,642'. POH, INC. RECEIVED APR 1 '1 199q Aiasi~a 0[1 & Gas Cons. Commission Anchorage DAY 12 (03/09/94) 10-3/4"@ 3372' 7-5/8" @ 10,585' 5-1/2" LINER 10,384'-10,870' LEASE WATER 8.5 PPG FINISH POH. L/D JARS & WASH PIPE. P/U OVERSHOT W/SCOOPHEAD. RIH. SET OVERSHOT & SHEAR SCOOPHEAD ONTO "CC". POH L/D DC'S. RIH & SET PKR ON WIRELINE @ 10,440'. POH, INC. DAY 13 (03/10/94) 10-3/4" @ 3372' 7-5/8" @ 10,585' 5-1/2" LINER 10,384'-10,870' LEASE WATER 8.5 PPG FOH W/WIRELINE SE'rTING TOOL. L/D KELLY. RIH W/SEAL ASSEMBLY & GLM ON 2-7/8" TBG. M/U HANGER & LAND TBG. SET "N" PLUG IN "XN" NIPPLE. TEST TBG TO 3000 PSI & ANNULUS TO 1500 PSI. PULL "N" PLUG & SET 2 WAY CHECK. DAY 14 (03/11/94) 10-3/4" @ 3372' 7-5/8" @ 10,585' 5-1/2" LINER 10,384'-10,870' LEASE WATER 8.5 PPG N/D BOP. N/U TREE. TEST SAME CLEAN UP LOCATION RELEASE RIG AT 12:00 HRS ON MARCH 11, 1994. FINAL REPORT. RECEIVED & Gas (Sans. Commission Anchorage .... STATE OF ALASKA -- ALASKA .,,L AND GAS CONSERVATION CC JlSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon __ Suspend __ Operations shutdown__ Re-enter suspended well__ Alter casing__ Repair well X Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing _ _ Variance __ Perforate_ _ Other__ 6. Datum elevation (DF or KB) 2. Name of Operator Union Oil Company of California dba Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 5. Type of Well: Development Exploratory Strafigraphio 4. Location of well at surface 1,896' North and 626' West form the Southeast Corner of Section 5, T-7N, R-9W, SB&M 170' K.B. 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 33-5 At top of productive interval 61' North and 356' West of Surface Location At effective depth 110' North and 468' West of Surface Location At total depth 110' North and 468' West of Surface Location 12. Present well condition summary Total depth: measured 10,870' true vertical 10,759' Effective depth: measured 10,722' true vertical 10,-7-22~- Casing Length Structural Conductor 44' Surface 3,372' Intermediate Production 10,585' 485' Liner Perforation depth: measured /,%~;;~3 ~ii & ~$ Cnn~. Commission feet feet Junk (measured) feet 9. Permit number 10. APl number 50-133-20276 11. Field/Pool Swanson River - Hemlock Tubing Fish - 10,564'MD110,462' TV Size Cemented Measured depth True vertical depth 20' No 44' 44' 10-3/4 1,035 SKS 3,372' 3372' 7-5/8" 100 SX & 545 SX 10,585' 10,509' 5-1/2" 100 SX 10,384'-10,870' 10,326'-10,759' 10,616'-10,634', 10,648'-10,661', 10,680-10,700', 10,702'-10,712', 10,722-10,747' true vertical 10,537'-10,552', 10,565'-10,576', 10,593-10,611', 10,613'-10,622', 10,631-10,652' Tubing (size, grade, and measured depth) See Schematic Packers and SSSV (type and measured depth) See Schematic 13. Attachments Description summary of proposal X Detailed operations program__ BOP sketch X feet 14. Estimated date for commencing operation December 23, 1993 16. If proposal was verbally approved Name of approver Date approved 5. Status of well classification as: Oil X__ Gas __ Suspended __ Service 17., here~ ceT~f~~and.. · correct to t.h~.e best of my knowledge. Signed /d,. , ~ Title P~l. CLi.~q [~&t~C~P_. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Test~ Subsequent form required 10- Approved by the order of the Commission dngmal Signed By David W. Johnston I Appr°val ,~';~ .--,:~// ,-~pproved Copy Returned CommissiOner Date '-~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Swanson River Field SCU 33-~ Workover Procedure II II Ilfll 1. Rig up electric line and jet cut tubing @ 10,550'. 2. Set plug @ 1,000. 3. MIRU. Pull plug and kill well. 4. Nipple down tree and nipple up B.O.P. Test B.O.P. to 5,000 psi. 5. POOH with tubing and fLsh top packer. 6. RHt with wireline and perforate the casing at 10,585'-10,590' and 10,595'-10,601.' 7. RIH with completion string 8. Pressure test tubing/casing annulus to 1,500 psi. 9. In,aH BPV; nipple down B.O.P. Nipple up tree; pressure test to 5,000 psi. 10. Release Rig. RECEIVED & G~s Cons. C:~mmission Anchorage Swanson River Field SCU 33-5 Proposed 11/16/93 10 3/4' 40.5~ K-55 @ 3372' 5-1/2' 20# N-80 Liner top ~ 10,384' Lift Mond~ as Specified 2 7/8' #6.4 N-BO Butl~ess to 10,510' 7 5/8' 26.4/29.7/33.7 # N-80 ~10585 Downhole Jewelry 1. Baker/~odel F-1 Packer O 10,510' 2. Seal Bore Ext. 3. 10', 2 3/8' Pup Joint 4. X-NIpple 5. 10', 2 3/8' Pup Joint 6. Wirellne ReEntry Guide Perforations From 10,616'- 10,639' Perforations From 10,64 8'- 10,661' Perforations From 10,680'- 10,700' 10,702'- 10712' Perforations From 10,722'- 10,747' 5-1/2'20# N-80 @ 10,870'(TD) 7. New Perforat)ons @ 10,585- 10,590' @ 10,595- 10,601' 8. Wirellne ReEntry Guide 9. CC Safety Joint ~ 10,636' 10. Otis XA sleeve ~ 10,637' 11. Baker FH Packer ~ 10,640' 12. Otis S nipple ~} 10,647' 13. Two 2 3/8' Blast Joints 14. Brown CC Safety Joint ~ 10,664' 15. Otis XA Sleeve ~ 10,665' 16. Baker FH Packer ~ 10,668' 17. Otis S nipple ~ 10,675' 18. Three 2 3/8" Blast Joints 19. Brown CC Safety Joint O 10,710' 20. Otis XA Sleeve ~ 10,712' 21. Baker FH Packer ~ 10,715' 22. Otis S nipple ~} 10,721' 23. 2 3/8' Blast Joint 24. Camco 2 3/8' D nipple ~ 10,743' 25. 2 3/8" Blast Joint TubingTa,1010,754' RECEIVED /:'-~,~::;:xa 0il & Gas Cons. Commission Anchorage ." , ._An~ Alaska Inc. - swanson r~ver r~eK~ ,.,~- SCU 33-5 ~API#: 50-133-30356-00 '- Well Type:Producer Spud Date: 8/25/75 Completion Date: 10/25/7~,Last Workover: Original RKB: 19.28' Hanger Type: Camron Hanger: Camron Top of Hemlock:10616'MD Max. Hole Angle: 30° Angle @ Hemlock' 27° All Depths are RKB MD to Top of Equipment. 12 17 19 21 22 Jewelry 1 2146' 2 3284' 3 4008' 4 4667' 9 10,283' lo ~ 11 10,598' 12 10,604' 13 10,636' 14 10,637' 15 10,640' 16 10,647' 17 10,664' 18 10,665' 19 10,668' 20 10,675' 21 10,710' 22 10,712' 23 10,715' 24 10,721' 25 10,743' Dummy GLM 5 5360' DummyGLM 6 6053' Oummy Cd.M 7 6692' DUmmyGLM 8 7279' X. Ove~ 3 1/2' X 2 3/8' Otis 'XA" Sleeve 2 3/8' 1 8last Joint 2 3/8. 4.7# Baker 'Fl-I' Packer 2 3/8' x 5 1/2' Otis 'S' Nipple 2 3/8'E.~ 2 Blast Joints 2 3/8' 4.7# (10.01', 20.18') Brown CC Safety Joint 2 3/8' Otis 'XA' Sleeve 2 3/8' Baker 'EH' Packer 2 3/8' x 5 1/2' Ofl~ "S* Nipple, Position 4_ 2 8last Joints 2 3/8' 4.7# (6.00', 10.02') Brown 'CC" Safety Jr. Otis 'XA' Sleeve 2 3/8' Baker 'EH' Packer 2 3/r x 5 1/2- otis · s' Nipple 3 Blast Joinl$ v 3/8' (4.00',10.06'.20.30') Brown "CC' Safety Jr. Dummy GLM 0ummyGLM 0ummyGLM Dummy GLM otis "A" Sleeve 2 3/r' Ot~ 'S' NlPl~e ~ 1 [~la~ joinl ~ ~" (10.~3 ~:: ';:~ ;~:~i & Gsa Cons. Commission Anchorage Casing and Tubing $1/2" 10,384" 10,870' Uner'- ~-:~ 0 10.283' Tubing '. 2 3/8" 10,283' 10,754' Tdbing'-' ' 20' 0 44'- Conduct~ Pipe 0-314" 40.5# K-$$ 0 3372' $~lace Ca,trig ~" 26,~ N~ 0 3798' P~n'--Ca~ ~.7 1 N~0 3798' 5733' 33.7~ 8-95 S733' ~006' 83.7/ P-110 8g08' ~0,S8S* 20l N~0 9.3~ 4.7l Perforation Data 10616-10639 H2 23 10648-10881 H3 13 10680-10700 H4 20 10702-10712 10 10722-10747 H5 25 SPF 9/70: Perfed tbg.' PBTD · 10722' TO'- 10670' Well 8CU33-5 JIB. 9112/~ Con[rac[ OPTION I Exhibi[ E FILL-UP KILL LINE / FLOW ANNULAR BOP 10" 3000 psi iPIPE RAMS 10" 5000 psi ' BLIND RAMS 10" 5000 psi ~ S?OOL L~~_~'-mL~O" 5000 5000 psi I I 3" 5000 I [ PIPE RAMS/ 10" 5000 psi CHONE LINE--UP> psi BOP STACK 10" 5000 psi RECEIVED ". -..,., Oil & G~s Cons. Commission Anchorage Alaska Region Unocal North America,---. Oil & Gas Division Unocal Corporation P.O. Box 190247 C-OMM-- Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 :~--~MM COMM 'RES UNOI:AL o0.,;-p~,~r.~- ,. iS-~, ENG · ~_ ~,,~ 4. ¢,,d,,,~-.I ENG--AssT-' ~ I SR GEOL----T- / ,,_,.,J~l .--r_.~'~'o,,~ J'~ ~ [~T'TECH[ ~ FILE Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in Swanson .RiverFielct Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same format as submitted last year by ARCO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Two wells, SCU 243-8 and SCU 21-8 were added to the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. RECEIVED MAR 2,5 199 Alaska 0ii & Gas Cons. 6omm~sstOO Anchorage Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. Yours very truly, Petroleum Engineer DLG:sr Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company RECEIVED MAR 2 ,,5 ~99~ Alaska Oil & Gas Cons. f.;ommissio~ Anchorage Form 3160-5 (June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. 6. If Indian, Allottee or Tribe Name Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals SUBMIT IN TRIPLICATE 1. Type of Well ['X Oil Gas W cll [~ [--'] Other Well 2. Name of Operator Union 0il Company of California (dba Unocal) 3. Address and Telephone No. P. 0. Box 196247, Anchorage, Alaska 99519 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit 17 wells Soldotna Creek Unit ........... 14 wells (907) 276-7600 12. TYPE OF SUBMISSION TYPE OF ACTION 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Fi eld I1. County or Parish, State Kenai, Alaska CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA -X] Notice of Intent ]]Subsequent Report --]Final Abandonment Notice ]]]Abandonment '-I Recompletion --]Plugging Back --']Casing Repair '-']Altering Casing [~] Omer Temporarily Abandon ---]Change of Plans C-]New Construction F--] Non-Routine Fracturing '--]Water Shut-Off C-]Conversion to Injection --]Dispose Water (Nole: Report results of multiple completion on Well Completion or Recompletmn Report and t.og form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1, 1993 to March 31, 1994: Swanson River Unit Swanson River Unit SCU 21-3 SCU 21-8*/ SRU 212-10 ~ SRU 23-22'" 23B-3~/ SCU 243-8~ SRU 14-15' SRU 23-27~ SCU SCU 13-4 / SCU 341-8'~ SRU 23-15/ SRU 212-27~ SCU 21A-4 SCU 13-9/ SRU 34-15 SRU 331-27 SCU 34-4'" SCU 24A-9~ SRU 41A-15~ SRU 34-28~ / SCU 43A-4' SCU 34-9'~ SRU 43A-15 SRU 43-28 ~ SRU 14-22' SRU 24-33~ SRU 32-33WD ~' ~AR ~ Alaska 0il & Gas G0ns. G0 * High G0R wells that may be produced intermittently. Anchor~ga '4. ' bereby certify that~/foregoing/~e~co>ect. ~ s~g~ ,,4.y~/.~ '~ ,Y,~ ~n-',-¢-.--- Tree Petroleum Engineer Date Approved by Title Date Conditions of approval, if any: Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the Unitod States any false, fictitious or fraudulent statements *See Instruction on Referee Side Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1, 1993 to March 31, 1994 Shut-in Wells under Evaluation for Shut-in Wells until the Field Blowdown Rate Potential P & A(~) Shallow Gas Potential and 'Hemlock Only' P & A Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-§*' SRU 341-8 SRU 34-28 SRU 43-28 SCU 32-33WD SCU 243-8 SCU 21-3 SRU 212-10 SRU 23-15 SRU 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SCU 14-34 SRU 23-27 SRU 14A-33 SCU 21-8" SCU 13-9 SCU 24A-9 SCU 34-9" SCU 23B-3' SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 SRU 24-3312~ 11 Wells 7 Wells 3 Wells 5 Wells 5 Wells Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 Scheduled 'Hemlock Only' P & A in March-April, 1993. High GOR wells that may be produced intermittently. ,RECEIVED Oil & 6~s ~o~. Oommission ~l~ct]0rage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27, 1991) Additions to 1993 Temporarily Abandoned Status · SCU 243-8: Shallow gas producer (Tyonek). Shut-in due to mechanical problems. Workover candidate. · SCU 21-3: Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned Status · SRU 21-22: Returned to production after flowline repair. · SRU 12A-4: Returned to full time production in 1992. · SRU 211-15 Scheduled for full P & A March-April, 1993. Waiting on personnel and rig. RECEIVED MAR ~ 5 1999 Anchorage Form 3150-S (November 1983) (Formerly 9.331) UNITED STATES .uaMZT ,. m,P,-ZcAm. (Ot~er l~st~aeLloae oa DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON ~LLS not ~ this for. for p~ls to drUl or to d~u or plug back to A ~emut rmrvolr. UM -~p~CATION FOR pERMIT--" ~or such ~~) ~ c~a ~ NAIdl O# Oll)8I&?OI ARCO Alas]ca, Inc. 3. &DDa~I o~ P.O.Box 100360 Anchorage, AK 99510 · S. t, OCATIO]I OS~ ~ gLt. (Report loestrin clearly and tn Accordance. with any State re~ulrementL· See also spac~ 17 l)~iow.) Swanson River Unit 19wells Soldotna Creek Unit 13 wells j16..~YA~ONS (S~w wb~er D~. Form approved. Budget Bureau No. t004--0135 l[xptre$ AulGtat 31. 1985 Soldotna Creek/Swanson Rv ~, fABM OB LIAII NAMI ~. W~LL BO. 10. ~lI~ AHD /~OGL) 01 WILDCAT Swanson River Field IUAVBT OIAR, B& Kenai Alaska 16. Check Appropr, ate Box To Indicate Nature oF Notice, Report, or C)th~ Data ~T OI ACID~ ABAN~NO (Other) Temporary Abandon FtA~RB ~ATMINT ~BIMG C~lWO SHYING OB ACID~ING ABAN~NMB~e (OCher) (No~I: Report results of multiple eompletMm om Well Completion or R~compleUon bi)oK and Z,o~r form.) 17. ot;scafag J'ROPOSlCD OI CO.~It'LETED OPERATIO.~S (Clearly irate ~11 p~rtlnp,t details, and =lye pertinent ditto, lneludln~ eettmated date of itaz~n~ any prolx~ed work. Ir well ia directiona41~ drilled, five s~'t~ ioe~Jons and meashred and true vertical dept~ for nil m~tkere and MBa psettt- nent to %his work.) · · As decribed in the atmched memo, ARCO Alaska, Inc. requests that the following wells have a temporarily abandoned status: ~ld~ma Creek Urat SCU 23B-3 SCU 21-8 * Swanson River Unit SRU 212-10 SRU 21-22 SCU 12A~ SCU 341~ SRU 14-15 SCU 1~4 ~U I~9 SRU ~]5 SCU 21A-~ SCU 24A-9 SRU 34-15 SCU 34-4 SCU 34-9 SRU 211-15 SCU 43A-4 SCU 14-34 SRU 41A-15 SCU 33-5 SRU 43A-~5 SRU 432-15 SRU 14-22 SRU 23-22 SRU 23-27 SRU 212-27 SRU 331-27 SRU 34-28 SRU 43-28 SRU 14A-33 SRU 24-33 SRU 32-33WD * -High GOR wells that may be produced intermittently. 18. I hereby ce.L-~F-~at-~he ri, re,olaf la Ct, re and ¢or~ RECEIVED DEC 3 7 1991 Alaska Oil a Gas Cons. CommJs Anr, h .... T,TLE Actinq Reqional En_qineer ~ (TItl spice for Feder&i or 8tmte o~ce APPROVED BT CONDITION8 01~ APPROVAl,. I~' TITLE D&~ Attachment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total 32 Wells Shut-in Wells under Evaluation for III I IIII III II I II I Shallow Gas Potential Rate Potential P & A and 'Hemlock :i:i:~:i:i:i:i:i:i:i:i:i:i:i:i:~:i:i:i:i:i:i:i:i:i:i:~:i:i:!::.:i:i:i:i:i:i:i:i:i:i:i~!:i:~:i:!:!:i:i:~:~:i~i:i:i:!:i:i:!:i:i:i:~:!:i:i:!:~:i:!:i:i:i:!:i:i:~:i:i:~:i:i:i:i:!:~:~:i:~:i:i:i:i:~:i:i:i:i:i:~:~:i:i:!:i:~:i:i:i:i:i:i:i:i:i:i:i:i:~:i:i:i:!:i:i:i:~..i:i:i:!:~:i..i:i:~:~:i:i:~:i:i:!.i:i:~:i:~:!:i..~:i SCU 12A-4 SRU 212-10 SCU 13-4 SRU 211-15 SCU 21A-4 SRU 23-15 SCU 34-4 SRU 41A-15 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRU 21-22 SRU 331-27 SRU 34-28 SRU 24-33 SRU 43-28 ~- SRU 32-33WD ~ SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 9 Well~ 3 Wells Shut-in Wells until the Field Blowdown Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned i:::::i:i:i:i:i:::i:::i:!:i:::::i:::i:::i:::~:i:~:!:::~:::i:i:::~:~:::~:i:i:~:i:~:::~:i:i:::::::::i:::~:i:::~:::::i:::::i:i:~:::i:i:::i:~:~:i:::::i:i:i:~:!:::i:i:::i:::i:::::i:i:::i:::i:~:i:i:i:i:::i:i:::::i:i:i:i:i:i:i:::::i:i:i:!:~::::::::::::::::::::::::::::::::::::::::::::::::::: SCU 21-8 * SCU 13-9 SCU 24A-9 SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. Fon Temporarily Abandonment Sundry 12/27/91. Attachment, 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) RECEIVED DEC 5 1 199! Alaska Oil & Gas Cons. Commissi Anchorage Added to 1992 Temporarily Abandoned Status: · SCU 23B-3 & · SCU 21-8: High GOR wells, may be produced intermittently, otherwise shut-in until blowdown. · SCU 12A-4: High GOR well, may be produce intermittently, This well is 'also being considered as a workover candidate. · SCU 43A-4: Shut-in due to mechanical problems. Also being considered as a workover candidate for shallow gas. · SCU 13-9: High GOR well, shut-in until field blowdown. · SRU 212-10 & · SRU 212-27: High water rate shallow fuel gas well, currently not economic to produce based on current fuel gas needs. · SRU 21-22: Well currently shut-in due to problems with the flowline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily. Abandoned Status · SRU 21-15 & · SRU 314-27: Wells are scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU 14-15, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the TA List for 1992. Attachment 3 Swanson River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming · SRU 21-15 & · SRU 314-27: work: Wells are scheduled for P & A in first quarter 1992. Wells that are used seasonally · SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. RECEIVED DEC 5 1 t991 Alaska 0ii & (~as (;OHS. burnmissio~, Anchoraae ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 27, 1991 Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue Post Office Box 13 Anchorage, AK 99513-7599 Subject:. !992 Sundry. Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected 'to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: . rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only abandonment. RECEIVED DEC 1 199t Alaska 0il & Gas Cons. CommiSSiOn Anchorage Mr. J. A. Dy gas Page 2 December 27, 1991 Shut-in wells until field blowdown,, including:. 4. Hemlock producers, and 5. wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last ye,ar's TA list were moved into this' category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned List (Ref: our letter of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, SCU 23B-3, SCU 43A-4, SCU 13-9, SRU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4107. Sincerely, J. C. w inn Acting Regional Engineer JTZ:jlg:0025 Attachment L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation Alaska Oil & GaS Cons. Anchora~ ARCO Alaska, Inc. Post n ,'~ ~ ...f,~,,,e Box ,00360 A.~chorage. ~i~ska 995; 0-G360 New ke .... ;," ~ :: E~§:,~ee~:~g December 29, 1989 Mr. J. A. Dygas, Branch Chief Division of Minerals Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 Dear Mr. Dygas: Attached is a Sundry Notice requesting approval to temporarily abandon 31 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.3-4, paragraph C of the Bureau of Land Management Regulations. All 31 wells are expected to be shut-in for a period of at least 30 days. The wells are separated into four categories: 1. Under evaluation for rate potential. 2. Under evaluation for P&A or future utility. 3. Inefficient producers. 4. Shut-in until blowdown. Several other items have been attached for your information. Brief explanations are given for each well that has been added or deleted from the temporarily abandoned status (Ref: your letters of 3/1/89 (3160 (984)) and 3/30/89 (3180 (984)) and our letter 12/28/88). In addition, a list of currently shut-in wells which have planned upcoming work that will enable their return to production is attached. If you have any questions concerning this Sundry Notice request, please call Stacy Strickland at 263-4914. Sincerely, Tom Wellman TW:SLS:jt:0016 Attachment CC: C. V. Chatterton, Chairman AOGCC A. R. Kulda, Marathon Oil Company $.W. Ohnimus, UNOCAL Corporation RECEIVED DEC 2 91989 Alasle 0il & Gas Cons. 6ommissi~ Anchorage ~-s b., I'I'ED STATES ~983) ~-~) D~ARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTI(~ AND REPOR~ ON not ~ thM to~ for p~Mta to d~l or to d~n oF pig[ ~e~ ~ Um ..~p~ON ~R PERM~" for s~ I. NAbfta OF oPRmATom ARCO Alaska, Inc. 3. ADDmtBil o~' o~s~&1'oa Post Offfce Box 100360 Anchroage, AK 99510 4. ~C&TION 0F %t'SC~ (Re.ri lo~tton cietrly nad tn accordance ~tt~ 8ny S~ S~ ~1~ spa~ IT ~low.} At au~l~ Soldotna Creek Unit- 11 wells Swanson River Unit - 20 wells [4. PBRMIT HO. iIS. st,sv&r~oNs ($1M~ whet.~r DP, .., ~1. ~m.) Form approved. 13~diRt flu~uau No. t004--0135 Ex, ti'es Aurar 31. ~o~al dotna~Cr eek/ nson ~!ver Units 8. FLBM oa ~B&aa NAndB 9. Wuff-r- ao. 10. I'~t.~ &rid fOOL si WILD~AT Kenai Alaska 16. Geck Ao~om~me l~ox To Indicate Nature of Notice, Reoon, or Ot4~tr ~ 8R~T OI ACXD~ AlAN~N~ REPAIR WBL~ CHANGB PLAN8 IT. U~.SCRIflE ?'ROI'OSED OK COMPLETED OPtRATrO.~ (Clearly state all ~rtlnpuc detatl~, and ~lve ~rtlnent ht~ tnelud~ m~at~ date or I~ ~y ;ro~=~ wor~ If w~ ~ di~o~y d~fl~ sive ~~ ~uns and meilur~ ~nd t~e vtrtl~ dep~ f~ ~ marten ud ~nm ~- nefl~ ~o ~ia ~rL) · As described in the attached memo, ARCO Alaska, Inc. requests that the following wells have a temporarily abandoned status: Soldotna Creek Unit Swanson River Unit SCU 13-3 SCU 13-4 SCU 21A-4 SCU 34-4 SCU 24-5 SCU 33-5 SCU 33-8 SCU 341-8 SCU 34-9 SCU 3 lA-16 SCU 14-34 SRU 34-10 SRU 23-22 SRU 14-15 SRU 312-22 SRU 21-15 SRU 23-27 SRU 211-15 SRU 314-27 SRU 331-27 SRU 31-15 SRU 34-28 SRU 34-15 SRU 43-28 SRU 41A-15 SRU 14A-33 SRU 43A-15 SRU 24-33 SRU 32-33WD SRU 432-15 SRU 12-34 RECEiVEE 2 91 89 Alaska O, & Gas Cons. Anchorage 18. [ bereOy ~ert~fy t.b~t the foregoing ts Cz'de and eorrt~t TI?f.E Cook ! n let Eng i nerr ing Manag~ (This ap&ce for Feder~t or Smt~ omee ~) APPROVED BY CONDITIONS OF APPROVAL. LB* A~T: TITLE DATa ~ InductJom on Re,me Sid~ Title tS U.S.C. Section tOOt, makes Lt a Crime for any person knowingly and willfully to make to any department or aKency of the fJnttec~ States any false, f~ct&ttous or frauduJent statements or represeflta~ons as to any matter within tis jurisdiction. TEMPORARILY ABANDONED WELLS IN SRF Wells under Evaluation Rate Po.t,en,[ial Wells being evaluated for P&A/Future Utility Wells SI for Inefficient Production Wells SI until Blowdown 13-4 34-4 24-5 33-8 341-8 34-9 41A-15 23-22 23-27 13-3 14-15 21-15 211-15 31-15 34-15 432-15 31A-16 312-22 34-28 14A-33 32-33WD 12-34 14-34 21A-4 33-5 34-10 43-28 24-33 43A-15 314-27 331-27 For: Temporarily Abandonment of 12/29/89 SWANSON RIVER FIELD Wells having Changed Temporarily Abandoned Status Added to Temoorarilv Abandoned Status: SCU 21A-4: Well is temporarily abandoned due to inefficient production (high GOR). SRU 32-33 W D' Well is temporarily abandoned due to annulus communication problems. Removed from Temt~orarilv Abandoned Status: -- _ SCU 243-8' This shallow sands gas well has been returned production. SCU 13-9: A workover is planned for this well which will enable this well to be returned to an active status. SRU 212-10,- This shallow sands gas well has been returned to production. SRU 23-15' This gas-lifted well has been returned to production. SRU 21-34: A sidetrack is planned which will enable this well to be returned to an active status. RECEIVED DEC 2 ? ],..98,9 Alaska 0il & Gas Cons. C0mmissJ0r,' Anchorage For: Temporary Abandonment Sundry of 12/29/89 SWANSON RIVER FIELD WELL STATUS UPDATE Shut-in Wells with Planned Upcoming Work* SCU 32A-9' When on-line, this SI well produces gravel. A sidetrack is planned to return this well to active status. *Will not be placed, on temporarily abandoned statd~~EJVEo ~c ~ 91£89 gl~l~l Oil ~ Ga~ Cons. For: Temporary Abandonment Sundry of 12/29/89 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12!5 Cook Inlet/New Ventures Engineering August 19, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage, Alaska 99523 Dear Joseph: Attached is a Sundry Notice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories: 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in - inefficient production 4. Shut in - save for blowdown Wells in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, H. F. Blacker Regional Engineer Cook Inlet/New Ventures HFB:jWR:ch:O006 Attachment cc: C.V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission Form 3160--5 (November 1983) (Formerly 9--331) UNITED STATES ST~B,,IT m ra..,.zci~. (Other lastr~etioni: on ~ DEPARTMENT OF THE INTERIOR ,,,-~.~ BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not ~se this form for proposali: to drUI or to deepen or plug back to a ~llle~nt rmrvolr. U~e "APPLICATIOH FOR PERMIT--" for such proposML) W I:l,L WaLL OTHER NAMB or OPBIATOI ARCO Alaska, Inc. Soldotne P. O. Box 100360 Anchora~m. AK ·99510-0360 LOCATION OF WgLL (Report location clearly and ffi a6cordance with any [irate [equlrements.· Se~ also space 17 below.) At 8u. rfiee Soldotna Creek Unit - 15 Swanson River Unit - 22 wells 14. PBRMIT NO. 15. R'~'-VATIONS (Show whether Dr, rr, o~, etc.) Form approved. Budget Elureau No. 1004--0135 Expires August 31, 1985 §. Llgill DEIIO,~A?ION AND IiILIL 0. Ir INDIAN, ALLGi---~BB Omi T~IBB NAME UNIT AOIBBMBNT NA,MN CreekTSwanson River Unit 8. l'imM OR LEASE NAMI 0. WBL& MO, 10. rlBLD AND FOOL, Omi WILDCAT Swanson River Field 11. IBC., T., I., if., Omi BLI:, IURVN! OR 12. eon,,, OB ,~-,,e] 18. Kenai[ Alaska 16. Check Appropr,ate Box To Indicate Nature oF Notice, Report, or Ot~er Dais N(YTICB Or INTEN~'ION TO: FRACTURE TREAT IlULTIPLE COMPI,ETE 8HOOT Ob ACIDIZN ABANDONe R[iPAIR WELL CHANGE PLAN~ (Other) Temporarily abandon IUIIlitUIlff If'OB! 01: raaeTvua TRI&TMBNT . ALTIINING e<NO SHOOTING OR ACIDIIglNO ABANDONMBNT® (Other) (NoTB: Report rea:alta of multlplo eompletlon on Well Completion or Recompletlon Report and Log form.) 17. v~s('stu£ vnoPos~o OR COMPLETED OPERATIONS (Clearly state all pertlne,t details, and give pertinent dates. Including ~timated date of starting rainy proposed work..If well is direction~lb- drilled, give subsurface loe~tions and mess, red and true vertical depths for all smirkers and son~s peril- nent to this work.) ' As described in the attached memo, ARCO Alaska, Inc. requests the status of the following wells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SWANSONRIVER UNIT SCU 13-3 SCU243-8 SRU212-10 SCU12A-4 SCU 13-9 SRU 34-10 SCU 13-4 SCU12A-IO SRU 14-15 SCU323-4 SCU343-33 SRU 21-15 SCU43A-4 SCU 14-34 SRU 31-15 SCU 24-5 SCU 14-3 SRU 432-15 SCU 33-5 SCU23B-3 SRU 34-15 SCU341-8 SCU 34-4 SRU41A-15 SCU21A-4 SRU43A-15 SRU312-22 SRU 21-22 SRU 23-22 SRU 22-23WD SRU212-27 SRU314-27 SRU 23-27 SRU331-27 SRU 34-28 SRU14A-33 SRU 24-33 SRU 12-34 SRU 21-34 18. I hereby cert~y._tll.at the fort, going i~/t~rue and correct TITLE (This space for Federal or State of Bee use) APPROVED BI* CONDITIONS OF APPROVAL, LF Alq~: TITLE *~e Instructions on Reverse Side Title 18 U.S.C. Section 100l, makes it a crime for any person knowingly and willfully to make to an}' department or agency of the .... , · ,- - , _,__s: TABLE Wells under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future UtilitS 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 343-33 SUBMIT IN DUi L,CATE* STATE OF ALASKA OIL AND GAS ~OMSERVATION COMMITTEE i i i i II i WELL COMPLETION OR RECOMPLETION REPORT AND LOG WELL ~J WELL ~ DRY~ Other b. TYPE OF COMPLE~ON: WELI. ~ OVER ~ EN ~ BACK RESVR. Other ~ 2, NAME OF OPERATOR Standard Oil Company of California, Western Operations, Inc. 2. ADDRESS OF OPERATOR P. O. Box 7-839, Anchoraqe, Alaska 99510 4, t.oc^'riox or wELL (Report location clearly and in accordance with a~y State requirements)* ~t su~ce 1871' North and 615' West from the Southeast Corner of Sec. 5, T-7N, R-9W, SB&M At top prod. interval reported below 61' North and 356' West of surface location. it tots dept~ 110' North and 468' West of surface location. 17. DATE SPUDDED 114. DATE T.D. RF_,ACFIED 8-25-75 I 10-17-75 ]8. I'OTAL DEPTH, 5iD & TVD 15. DATE CONIP SUSP Oil ABA,N-D. 10-25-75 i 16/ ELEVATIONS~DF, I<KI3, 169' KB ~19. PLUG, BACK MD & TVD~20, IF MULTIPLE COMPL., ! 21. /10827'M~ [ ~ow~¥* [ ~0~^~ ~OOLS 10870'MD 10758'TVD ]10724' D 0-10870' 22. PiiODUCINO INTERVAL(S), OF THIS CO,MPLETIO~--TO,P, BOSOM, NA~E (MD AND Top 10616' MD 10537' ~D Hemlock Bottom 10747' MD 10653' T~ 24. TYPE ELECTRIC AND OTtlEi~ LOGS RUN 0 I51NA[ 5. AP1 NUI~LI~H/CAL CODE 50-133-20276 6, LEASI'~ DF-,SIGNATiON A_ND SEt~IAL NO. A-028996 7. iF IND1A~N, A.LLOTTEE Olt 'I'll[BE N2G~IE 8. UNIT,FARiVI OH LEA.~E NAME So]dotna creak 9. %VELL NO. scu 33-5 10. FIELD A~qD POOL, O1{ WILDC&T ~qwan~qon Rivar H~mlock SEC.. T.. R., .M., (BOTTOM HOLE O)3,J E(CI'IV E ) Sec.5, T-7N, R-9W, SB&M 12. PEIt~5IT NO. 75-39 , I~'F. (JR, E'rc)*]]?. ELEV. CAS1NGitEAD ! INTER%'AI,~ I)RII,I,ED BY CABI,E TOI) I M 23. WAS DIRECTIONAL N(J/~VEY MADE ¥e$ I DIL, BCS, FDC-CNL, BCL ~i ' CASING ~ECdRD (RePort an strings set in well) ....... DEPTH $¢,T (~ID) [ HOLE SIZE ] CEMENTING II.ECOILD ~ AMOUNT PULLED 2 0" None 10 3/4" 40'5' I K-SS 337¢' i is" l z03s sks. "G" ~t... ~, None 7 5/8" ' · '~-~0 10585' ~ 9 7/8" ~Shoe with 100 sks,"G"~t.~_ .None v S4s s s. '"' SIZ~ [ 1)EP'FI-I SET (3.~iD} ~ ],~CI;E[~ SET 10616-10634 ' D~T21 IN'!~VAL (MD; A2, I'OUN i' AND I',AND 0[" RI,%'iE/iIAL USED 10648-10661' Four 1/2" jet holes 10680-10700' Per Foot 10702-10712 ' 10722-10747 ' 30. P~ODUCT!ON [.~¢~ [;;J f~ fi i~ qq ..... I i I~ '~ ~ ~.: ~;"~ - - 10-30-75 [ Gas Lift [[~A/;4'f ~' '7~' ,Pi. Produ6~in~:J~,~-~, ~1-, ~f ~--- .,,q ...... INo ~ PRESSURE GAS--MCF. r'~~,~B5. ! O1L GRAVITY-~I (CORR.) 0 psi ] 900 psi ] ~ 1273 I 1231 [ 3 ;.~ ~,~[;",;,'a :/j,J~'.,'u. !a9 L~. ~mposmuo~ 0r ~,s (Sera, Use~ 7~r]uei, Cente~, etc.) ,'~"a~'~t, ,Y t Injected back into field 32. LIST OF ATTACHMENTS atton is complete and correct as determined from all-available ri,curds in,ley '/i ~/Y~ SIGNED R. M. McK TITLE Area En neer *(See Instructions and Spaces for Additional Data on Reverse Side) COMPLETION REPORT - New We±l ~ ' " ° INC. STANDAPJ) OIL COMPA/,7Y OF CALIFORNIA., WESTEt~ O].ER~].IONo, ;HLE~A: S~0~z~a$on River Kemai Peninsula Almmka LJJ~D OFFICE: Anchorage PROPER%~': Soldotna Creek Unit LEASE NO: A-028996 WELL NO: £CU 33-5 API NO: LOCATION Jf£ SUP~ACE: 1896' North and 626' West from SE Corner Section 5, T.7N.,R. 9W. Seward B & M LOCATIOR AiT DEPTH: 110' North and 468' West of Surface ELEVATION: 152~ GL 169.5' K.B. DATE- October 29, 19 75 Area Engineer DRILLED l~f: Kenai Drilling Company of Alaska, Rig #2 DATE CO~CED DRILLING: August 25, 1975 RIG RELEASE: October 25, 1975 DATE OF ~I~ITIAL PRODUCTION: October 30, 1975 SUM}[~RY TOTAL DE,H: 10,870' PLUGS: 10,870' - 10,827' EFFECTIVE DEPTH: 10,827' CASING: ~'~" Conductor at 44' 1~ 3/4" Cemented at 3372' ~ 5/8" Cemented at 10,585' PERFORATIONS:: ' 10,722'~- 10,747' 10,702' - 10,712' 10,680' - 10,700' 10,648'- 10,66].' · '-10,616' - 10,639' LOGS: S ch lumlo erger Dual Induction Bore-Hole Compensated Sonic Compensated Neutron Formation Density Formation Density Continious Dipmeter , Saraband W.L.S. Dipmeter, Dip & Azimuth Display (Ail PKKS) Dipmeter, Quality Control Plot Go-International Cement Bond Log 3,375' - 10,857' 2 Runs 10,582' - 10,86]_' 1 " 10,585' - 10,864' 1 " 10,585' - 10,864' 1 " 3,380' - 10,583' 1 " 10,600' - TD 1 " 41000' - 10,570' 11 __, '511 2" - 5"' 5I' 5I' 5" 5!1 '5" - 2" ~1975 Rigged up and spud at 12:00 noon. Drilled 15" hole to 60'. Repaired flow linle and drilled to 90'. Set 20" casing at 44' and continued drilling to 203'. Circulated and continued drilling. 72 pcf mud A__~gUS .t .2_6, 1_975 Drilled 15" hole 203' - 1030' (827') 79 pcf mud A_u_gust _27_ 1975 ! Drilled 15" hole 1030' - 1864' (834') 85-88 pcf mud ~t 28~ 1975 Drilled 15" hole 1864' - 2830' (1034') 85 pcf mud Drilled 15" hole 2830' - 3400' (590') 82 pcf mud ~st 30__ 19 75 Ran 3372' of 10 3/4", K-55 40.5~! buttress casing. Circulated and conditioned mud. 84 pcf mud A_~Eust 3]_~ 1975 Cemented 10 3/4" casing at 3372' with class "G" cement and recovered 17.4~ of 20" conductor. Cut off and recovered 22' of 10 3/4" casing. 85 pcf mud Se_~~e~_er ~!, !975 Installed 10 3/4" SOW x 5000 psi casing head and tested to 2500 psi, OK. Nipple up B.O.P.E. · S_$~ptember 2~ 1975 Tested surface lines to 5000 psi and B.O.P.E. to 2500 psi.. Retested 10 3/4" casing head to 2500 psi, test OK. Made up 9 7/8" bit and prepared to drill ahead. S_~pt~mber 3., 1975 Drilled 9 7/8" hole 3423' - 3845~ (423') 76 pcf mud S_~tember 4. _ ~t__1975 Drilled 9 7/8" hole 3845' - 4310' (465') 75 pcf mud S_~ptember 5~ 1975 Drilled 9 7/8" hole 4310' - 4815~ (505') 76 pcf mud S__eptember 6 ~ 1975 Drilled 9 7/8" hole to 4~940' and checked B.O~P~E. for operation. Continued drilling to 5,280~ total (340'). 76 pcf mud ~mber 7~,_J97_5 Drilled 9 7/8" hole 5280~ - 5727' (447') 76 pef mud s__e_pt emb er 8 ~_1975 Drilled 9 7/8" hole 5727' - 6190' (463') 76 pcf mud S_~ptember 9 ~ 1975 Drilled 9 7/8" hole 6190~ - 6539' (349') 77 pcf mud ~e_ptember !0, 1975 Drilled 9 7/8" hole 6539' - 6968' (479') .76 pcf mud ~~r !1~ 1975 Drilled 9 7/8" hole 6968' - 7167' S__ejptember 12. 1975 Drilled 9 7/8" hole 7167' - 7398' S_~tember 13z 1975 Drilled 9 7/8" hole 7398' - 7764' reamed S_e~tember 14 ~ 1975 Drilled 9 7/8" hole 7764' - 8034' Drilled 9 7/8" hole 8034' - 8216' S_~ptember 16, 1975 Drilled 9 7/8" hole 8216' - 8375' S__e~ptember !7~ 1975 Drilled 9 7/8" hole 8375' - 8441' ~tember 18, 19 75 Drilled 9 7/8" hole 8441' - 8623' Check B.O.P.E. .September 19 ~ 1975 Drilled 9 7/8" hole 8623' - 8804' (199 ' ) (231') (366') (270 ' ) (182 ' ) (159') (66 ' ) (182 ' ) \ (181') 81.5 p cf mud 80.5 pcf mud 82 pcf mud 85 pcf mud 84 pcf mud 85 pcf mud 84 pcf mud 84 pcf mud 86 pcf mud S_~tember 20_, 1975 Drilled 9 7/8" hole 8804' - 9014' S_~ptember 212 1975 Drilled 9 7/8" hole 9014' - 9136' S_~pte~er 222 ].975 Drilled 9 7/8" hole 9136' - 9296' ~tember 23~ Drilled 9 7/8" bole 9296~ -~- 9433' S_e~ptember 24.~ 1975 Drilled 9 7/8" hole 9433' - 9556' September 25, 1975 Drilled 9 7/8" hole 9556' - 9687' S__~pte~er 26~ 1975 Drilled 9 7/8''' hole 9687' - 9816' S_~j~tember 27, 1975 Drilled 9 7/8" hole 9816' - 9955' September 28, 1975 Dyna drilled 9 7/8" hole 9955' - 9992' (210') (122') (160') (137') (123') (131') (129') (139') (37 ' ) 87 pcf mud 88 pcf mud 88 pcf mud 88 pcf mud 89 pcf mud 89 pcf mud 93 pcf mud 93 pcf mud 93 Pcf mud September 29~ 1975 Drilled 9 7/8" hole 9992' - 10,007' September 30~ 1975 Drilled 9 7/8" hole 10,007' - 10,037' (15') 93 pcf mud (30') 93 pcf mud October lm ].975 Drilled 9 7/8" hole 10,037' - 10,183~ (146') 93 pcf mud October 2~ 1975 Pulled and. checked B.O.P.E. Ran in hole and jars parted leaving 212' of fish in hole. Made up overshot, grapple and. jars x--.over landed on fish at 9~993' and recovered. October 3~ 1975 Ran in hole and reamed from 10,150' to 10,205' drilling to 10,273'. 93 pcf mud October 4~ 1975 Drilled 9 7/8" hole (oriented.) 10,273' - 10,304' (31') 93 pcf mud Oct.ober 5~,. 19.75_ Drilled 9 7/8" hole 10,304' - 10~376' (72') 93 pcf mud October 6, 1975 D~illed 9 7/8" hole (checked B.O.P.E.) 10,376' - 10,438' (62') 93 pcf mud October 7~ 1975 Drilled 9 7/8" hole (checked B.O.P.E.) 10,438' - 10,499' (61') 93 pcf mud octob.e..~. 8~ .1975 Drilling 9 7/8" hole 10,4.99' - 10,585' (86') 93 pc/ mud October 9~ 1975 Rigged up to r~m 'Schlumberger logs. Ran Dual Induction from 3375' to 10,583'. Ram continuous Dipmeter 3380' - 10,583'. Circulated and condition ~. 94 pc/ mud October 10 ~ 1975 Changed rams to 7 5/8" casing rams. Rigged up an ran 150 joints of 7 5/8" casing. 93 pc/ mud. October 11~ 1975 Completed 7 5/g" .casing run with a total of 255 joints, shoe at 10,585', float c~llar at .10,500', stage collar at 7925'. Circulated and mixed 500 bbls. 92 pc/ mud. Cemented through shoe with 250 sacks class "G" cement, with 2.1% gel in mix water, followed by 100 sacks of clams "G" neat cement, with 75% CFR-2 slur~*y weights 99-102 and 115-117 pc/. Displaced cement with 2747 cubic. 'feet , 92 pc/ mud. Lom~ circulation during cement job. 7 5/8" Casing Detail Ab ove K. B. 14. ~ ' Top 93 joints 7 5/8", 26.4~ Buttress N-80 3811o86 cut and recovered 36.95 ' Next 43 joints 7 5/8", 29.7# Buttress N-80 28 joints 7 5/8", 33.7f~ Buttress S-95 1 Landing Joint 7 5/8", 33.7f~ BT P-110 23 Joints 7 5/8", 33.. 7f~ Buttress P-1i0 Stage collar at 7925' 63 Joints 7 5/8", 33.7# Buttress P-Il0 Float Collar 2 Joints ? 5/8'~, 33.7~! Buttress P-il0 Shoe Total Less K.B. 7 578" casing landed at 1935.34' 1173.68' 43.07' 977.00' 1.85' 2572.68' 1.85' 80.30' 2.35' 10599.9 8' 14.98' 10585.00' October 12~ 19 75 Circulated and cemented through stage collar with 545 sacks of class "G" cement, 2.1% gel in mixing water. Displaced cement with 213]. cubic feet. 97 pc/ mud to close stage collar with 2500 psi. Regained circulation throngh-out job. Installed tubing head and tested to 5000 psi, OK. Imstalled Class (3) B.O.P. and tested all equipment. October 13, 1975~ Tested blind and rams to 5000 psi and Hydrill to 2500 psi. Ran in hole to pick up 3 1/2'~ drill pipe. Made up 6 5/8" drilling assembly. October 14~ 1975 Measured and pick up 3 1/2" drill pipe. Drilled out stage collar at 7925'. Ran in and located cement at 10,359 and drilled out hard cement from 10,359~ to 10,501' top of float collar, float collars at t0~501' and 10,575'. Pulled and rigged up Go-International to run Cement Bond log 4000' to 10,570'. October 15_, 1975 Completed Cement Bond log run. Ran in hole ~d drilled out cement and shoe at 10,585'. Continued drilling to 10,610'. 73 pcf mud October 16~ 1975 Continued drilling 6 5/8" hole. 10,610' - 10,670' (94') 73 pcf mud October 17~ 1975 Drilled 6 5/8" hole. 10,670' - 10,870' (166') 75 pcf mud October 18~, 1975 Circulated out to run logs. Ran Schlumberger logs: Dual Induction 10,582' - 10,857', Formation Density 10,585' - 10,864' and Compensated Neutron Formation Density 10,585' - 10,864'. Rigged up and ran 12 joints of 5 1/2", 20 LT&C, N-80 casing with turned down collars. Casing equipped with Baker Float Shoe, Baker Float Collar one joint above shoe and Burns fluted liner hanger. 74 p cf mud October 19~ 1975 Completed liner run and cemented one foot off bottom with 100 sacks Class "G" cement mixed to 117 pcf slurry weight. Displaced with 478 cu/ft of drilling fluid. Bump plug with 3000 psi cement in place at 8:25 P.M. Pulled and re-entered with 6 5/8" bit. Found top of cement at 10,128 and drilled out cement to top of liner at 10,383'. Pulled out of hole. 74 pcf mud October 20, 19 75 ~ Ran in hole and drilled out-four feet of cement in. top of liner. Continued down hole to 10,827', circulated. Pulled up to liner ].ap and pressure tested to 2400 psi for fifteen minutes, OK. Pulled out and rig up to run'Go International logs, Cement Bond log 10,817' - ~ 10,300'. 74 p cf mud -. · October 212 1975 . Prepared Go International for perforations. Perforated four 1/2" holes per foot 10,722' - 10,747' first attempt failed. Continued perforations at 10,702' - 10,~712' 10 680' - l0 700' 10,648' - 10~661 and 10,6!.6' - 10,634'. Nipple down lubricator, and installed flow nipple. Scraped and circulated out. 74 pcf mud October 22, 197_ 5 Commence running 3 1/2" and 2 3/8" tubing as programed. 74 pcf mud October 23~ 1975 Continued tubing run and could not obtain x-over at proper depth. Pulled out of hole and adjusted ~!G mandrel to 7278'. Re-ran tubing string to 8606'~. 74 pcf mud October 24~ 1975 Completed r~nnin~ tubing to a depth of 10,753'. Rigged up and ran Go International Neutron log to locate packers. Layed do~ Kelly and swivel and installed x-mas tree. 74 pcf mud October 25,_ 1975 Changed 74 pcf drilling fluid to lease crude. Closed sleeves at 10,719' to 10~668', 10,640' and 10,566'. Set blanking plug below bottom packer. Set packers (see tubing detail attached) and rigged down, circulating Clean. Released rig at 6:00 A.M. J. W. Wilson ELEV. 16~,5 K.B. K.B. TO TUBING HANGER 5798 5733 6906 44' -- 2,~6o13'- ,o%'- ~,~?~' .... 3,283.60'- 4,OO8.16' - > 4,667.1~' -,~ 5,360.46 ' -- 6,053.05' --~ 6,691.71' - 7,278.84' -- · ~10'283o27' - TOP 5~¢!0.384" TUBING HANGER - 2 PUP JTS. 3~' 9.3# N-80 35 JTS. 3~' 9°3# N-80 BUTTRESS DSS x BUTTRESS X-OVER 32 JTS. 3~'' 9.3# ATLAS BRADFORD DSS DUMMY MANDREL 35 JTS. 3~ 9.3# A.B. DSS N-80 TUBING DUMMY MANDREL 22; JTS. 3~" 9°3# A.B. DSS 'NE80 TUBING DUMMY MANDREL 20 JTS. 3~" 9.3# A.B. DSS N-80 TUBING · DUMMY MANDREL '~' 21 JTSo 3~' 9°3 # ADB. DSS N-UO TUBING DUMflvIY ;~NDREL 21 JTS, 3~' P,3 #A°B. DSS N-80 TUBING DUMMY MANDREL 19 JTS. 3~'' 9o3~ A.B. DSS N-80 TUBING DU~4Y MANDREL 18 JTS° 3~' 9.3# A.B. DSS N-80 TUBING DUMMY ¥~ANDRE L 92 JTS. 3~' 9.3# A.B° DSS N-80 TUBING 3~' x 2~, X-OVER 9 JTS. 2~" h.7# EUE 8rd N-80 TUBING ~ lO,563.93, -~ OTIS "XA" 'SLEd, YE ~-- 10,598.18' -~ 1 BLAST~'~' J~,. 2~" .~'10,604.39' % 2~' BAKE~ "Fl{" PACKER OTIS "S" NIPPLE, Position i,'j-,,_10,636.o5' 2 BLAST JTS° 2~"'-2o7# t I -- 10,637.47' % BROWN "CC" oAFETY Jr, ~- lO,6~o.~?, ~> OTIS "XA" S~VE OTIS "S" NIPPI~ Poa:Lt:i. on 2 BLAST JTS. 2~" 4.7// (6o00', 10002' ) ~,o~,'~o,6~5o49, % OTIS "X^" S~£VE ~,o~o~iO,674°60' ? OTIS "S" NIPPLE, Position #3 ~,o?oo' ~ 3 BLAST JTS. 2~' (4~OO',1OoO6', 20.30') :~o?oz'10,71Oo43' -~ BROJN "CC" SAFETY JT. ~ .10,711.85' -~ OTIS "XA"' SLEEVE ~ 10,720°96' i'°?zz, ~ OTIS "S" NIPP. LE, Position //2 ~~? C~cO ''D'' NIPP~ ~ ,o?~?10,743oO8,' 1 BLAST JTo 2~" 4°7# 2~s' BLAST JT.' 10.OO~ ~ - '"- S.C.U. 33- 5 ' -- TOP OF PLU¢ -- T.D. 10,870' loOO' lOTh .31' 1043 o 05 ' 1137.~7' 9.18' 715o38 ' 9,15' 9o32' 6~o00' ~o22' 683.37 ' P.15' 619.23 ' 9.17 ' 586.82 ' 9~18' 2995.25' 280.02' 2.90' 31o3~' 6o21' 1o47' 3Oo19' 1~2' 2.90' 6.21' 1.47' 16002' lo42' 2090' 6o21' 1047' 34o36' 1.}~2' 2.90' 6.21' 1o97' 20.15' .90' CASING & TUBING DETAIL SECTION 5 T. YN.,R. 9W. SM STANDAHD OIL COMPANY OF CALIF. GR[AT LA D DIR[CTIONAL DRILLING INC. REPORT OF SUB*SURFACE DIRECTIONAL SURVEY STANDARD OYL COIv~PA_NY COMPANY scu WELL NAME SWANSON RIVER FIEI~ LOCATION ALg?5-D~O JOB NUMBER SINGLE SHOT TYPE SURVEY ~o-Po-?5 DATE THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confidence. Additional copies of your survey report can be made from the original by any bluepr ~,~,::",:"~"l !At. U~FTHOD OF COvp[JTATIONS AC',"~'T~C S~,~GL_E SHOT 5LJ~VEY .... ~':'tJrr'['', FOR GREAT LAt',~D DIRECTIONAL DR ' LL I a. lG IUC, SOLDOTNA CREEK_ UNIT._33-5_ DECLINATION .... 25._DEG, EAST KB ELEVATION 170. FT. ....................................................... ~1' F, M, LINDSEY.AND_ASSO¢, ALL CALCtJL. ATIONS RECOR5 OF P F. RFORh~,ED BY Y ELECTRONIC COMPUIER T q L, tF DE PT H SEA 0,00 .-170,00 ,tO4, . <: ~mT, 9n ~7.98 o]n e~ 7~0,98 'L'22, '77 I052,97 ].SOq.aA 1329,05 ~lO?.a9 1039,97 o, ]. 6 V, :': 'l 7 g?7, e 1 .. /,.751, q' ,i9a],~i ~771,51 5"2] ,/,~ ~051 ,42 ~'72a, 2o 955a,28 5~0~,22 r, 7~a 22 DR I F T DIREC DEG, .W- E E E 6 E E E E E. E E .. E E E E TOTAL 0.00 1,97 2 , 75 2.06 1.81 1,63 2,1F _. 1o6~ 1,6'3 . 5.7a 12,~3 COOED INAT. E5 .. .... DOG ._.LEG ..... C_L.O S U R E S ....... SEVERITY.. SECTiUN ................... DIS.TANCE ........ ANGLE ......... D BG/_LOQF_I .............. DI STANCE ......................... D lu S ............. O,O0._.W ................... 0.00 S _.0 1,65 W ..... 2,57 N 39 2,77 W ....... 3,90 N ~5 4.,.O./...W ........... 5,04 N 54. 1,61_ W ........ 2,42 N al 0 ...... O__.w.~O_,O00 .......... 59 59 W ............ 0,169 11 14 W ....... 0,085 0 ....... 51 W .... -__0.,037_ ...... 39 .31W .......... 0,238... 0,30 E ...... 0,36 N 56 al 9 E .......... 0,045 2,3.1._E .......... 2.,.73_5.8Z_.3~ ..... ~,07 E ..... ~,53 N 63 52 16 E .......... 0,191 .. 5,40 E ....... 5,64 N 73 6 56 E ........... 0,158 6,50 E ........ 6,85..N__TZ__40__Z7._E _ 0.,..051_ ...... 7,35 E .... 7,37 S 86 26 8 E ......... 0,.186 7,82 E ...... 7,87 S 83 9 28 9,61. E .............. 9,79...S 78 .52_~ E__-O.,l~8 ...... 3,78 E 13,91 ~.83 E 18,89 S 85 20 15 E _ 0,089 £,7.8 8,75 2,84 2 E .............. 22,83 .S 85 .... 58- 13 --E O.i&B ....... 2 E 29,~2 S 86 52 23 E ....... 0,100- 3 E ._ 38,75 S 89 3~ 30 E .... 0,109 4 ..E ........ 42,8.~_N_ 89 .31_.__2._.5__0,25~ a9,~9_ E .49,61._N 86 0 .8 E ...... 0,163 .... 53,88 E 54,19_N..83.51 46 E_ 0,0~1... 59,73._E ............ 60,~5__N_81 8_2~__F------~O83 62,97 E 6~,18.__N_78._4~..~8 _E .... 0,232 .... O.O0 2.06 3,u.~ 4. 1 -0,2b -2,'72 -3,50 -4,8a -7,~.: -1 ~! , -22.5- -37,~ -~7.37 -51,Ii -56,00 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY ! B ~'-~ ELECTRONIC COMPUTER T RUE DRIFT VERTICAl. )EPTH ANGLE DEPTH D H SUB DR ! FT SEA DIREC DEG. 6203 ! 45 6202,08 6032,08 N 35 E 6968 3 0 6966,17 6796,I7 N 39 E 7[67 3 0 7164,90 6994,90 N 39 E 73.98 ~ 0 7395,58 7225,58 N 39 E 7764 2 t5 7761,~0 7591,30 N 32 E 80~ Z 15 809t,09 7861,09 N ~0 E 8216 2 !5 8212,95 80~2.95 N 16 E 8375 2 0 8~71,85 8201.85 N ~.2 E 8664 2 45 8460,75 8290,75 $ 66 W 8526 3 30 8522.63 8352,63 $ 65 W 8604 3 ~5 8600,~? 8~30.~7 $ 67 W 8683 ~ 30 8679.22 8509.21 $ 79 W 87~4 5 ~5 8739.97 8569.97 5 83 W 8776 5 45 8771.8! 8601.~ 5 85 W 8871 b 30 8866.20 8696.20 N 86 W 896~ 7 45 8958,35 8788,35 N 81 W 905S 8 15 9051,37 8881,37 N 76 W 9118 9 15 9110.59 8940,59 N 74 W 921~ 9 0 9205,~1 9035.~1 S 71W 9306 10 15 9295.9~ 9125,94 $ 60 W 9371 ~! 15 9359.69 9189,69 $ 59 W 9a33 11 30 9420.45 9250.~5 $ 61W 95~7 12 15 9512,31 9342,31 5 62 W 9582 12 30 9566,01 9396.01 S 62 W 9653 12 45 9635.25 9465,25 5 64 W 9729 13 30 9709.15 9539.15 $ 68 W 9816 14 30 9793,38 9623.38 $ 69 W 9869 15 0 984~.58 967~,58 $ 70 W TOTAL COORDINATES 20,09 N 68.33 E 31,~8 N 77.55 E 48.93 N 91.68 E 57,02 N 98.24 E 66,42 N 105,84 E 78,60 N 113.~6 E 87,78 N 118.76 E 94,20 N ~21,89 E 98,91 N 12~,83 E 97,17 N 120,93 E 95e57 N 1~7,50 E 93~58 N ZlZ,80 E 92~0 N 106.72 E 91,72 N 101,18 E 9~,4~ N 97.99 E 92,19 N 87,26 E 94,15 N 7~.87 E 97,41 N 61,78 E 100,07 N 52.51 E 95.18 N 38.31 E 87.00 N 2%.14 E 80.46 N 13.27 E 74.66 N 2.35 E 65.30 N 15.25 W 59.71 N 25.76 W 52.8~ N 39.84 W 45.19 N 56.29 W 38,39 a 76.63 W 33,70 N 89.52 W DOG LEG C L 0 $ U R E $ SEVER!TY DISTANCE ANGLE DEG/IOOFT 71.22 N 73 36 52 E 83.70 N 67 5~ 22 E 103.92 N 61 5~ ~3 E 113,59 N 59 51 58 E 124,96 N 57 53 29 E 138,03 N 55 17 10 E 147,68 N 53 31 45 E 154,05 N 52 i8 3 E i59,27 N 51 36 30 i 155,1~ N 51 12 59 E 151,46 N 50 52 31E 146,57 N 50 19 17 E 141.16 N 49 6 50 E 136.56 N 47 ~8 30 E 134.02 a 46 58 47 E 126,94 N 43 25 35 E 120,29 N 38 29 36 E 115,36 N 32 23 7 E 113.01 N 27 41 21 E 102.60 N 21 55 39 E 90.28 N 15 30 28 E 81.55 N 9 21 52 E 74,70 N 1 48 28 E 67.06 N 13 8 50 W 65,03 N 23 20 16 W 66.18 N 37 I 4 W 72.82 N 50 37 36 W 85,71N 63 23 22 W 95.65 N 69 22 15 W 0.130 0.227 0.117 0.000 0.000 0.222 0,029 0.086 0,210 5,110 1.213 0~359 1.443 1,349 1.280 1.499 0,911 1.742 5.700 2,411 1.565 1.036 0.798 0.455 0.709 1.549 1-183 1.059 SECTION. O I $TANCE '61,90 -68.26 '78,01 -82,54 -87.79 -97,03 -98,81 -95,42 -92,44 -88.33 -82,68. -77.44 -74,40 -63.79 -51.28 -37.79 -28.16 -15.46 -3,5~ 5.54 1~.83 29.82 38,77 50,90 65,39 83,39 94,86 RECORD OF SURVEY ALL CALCULATION5 PERFORHED BY ! B !q ELECTRONIC CO~.PUTER VERTICAL SUB DR ! F T TOTAL COORDINATES [0007 19 0 9976.3! 9806.3i $ 69 W I018) 21 0 10141.49 9'971.~9 S 90 W 1027~ 22 ~0 1022~.72 1005~.72 N 89 W tO~?2 22 30 1031~.10 ~01~6,I0 ~ 76 U I0~99 24 0 10~32.36 10~6~.~6 N 70 ~ 10585 26 0 10509,65 10~9,65 a 67 ~ 1.0670 26 45 10~85.5~ 10415,56 N 71 ~ ~0870 DO 0 107~9.79 ~0589.79 N 65 ~ 25.86 N 112.27 19,79 N 128,08 16.11 ~ 222,49 25,37 N 259,62 3~.93 N 284,50 42.42 N ~07,8Z ~7,15 N 3~2,52 69,6~ ~l 378,69 79.43 N 401,84 ~0.28 N ~68,00 BOTTO~ HOLE CLOSURE &80.B2 FEET AT a 76 4~ 23 W DISTANCE ANGL. E 115,2I N 77 I ~ W 1Z9,60 N 8t 12 4~ W 159.§8 N 84 17 1i W I~9.07 N 45 i7 Si W 223.07 m 85 ~1 28 W 286,52 N B~ 11 ~0 ~ 310,73 N 82 9 9 W 3~7.26 N 80 31 35 W ~8~.04 N 79 35 3 W 409.62 N ?8 ~9 5 W ~80.82 N 76 44 23 W SEVERITY DEG/IOOFT 1.48'7 1.736 4.966 1,052 2,75~ 2,269 3~863 SECTION DISTANCE 186.97 284.70 3~6,50 ~09,35 480.82 INTERPOLATED TRUE VERTICAL DEPTHS. COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE ~IEASURED VERT ! CAL NAME DEPTH DEP TH TOTAL COORDINATES CLOSURE DISTANCE ANGLE D )vi ,SUB SEA D-:I. E E-10 H-2. H-3 H-4 PT TD 5765 576~.26 10.0) N 60.~8 6880 6878,29 ~5.D5 N 88.78 825~ 82~9.g3 95,30 N 122.57 10573 !0498,87 55.10 N ~37.68 10617 I0'5~8e2~ 61.84 N 356e14 [065i 10568.59 66.82 N 370.6! 10778 10680,11 90,84 N 426.~1 10870 10759.79 t10.28 N ~68.00 W 61.~1 N 80 34 40 E 559~,26 99.70 N 62 56 ~2 E 6708.29 155.26 N 52 8 8 E 8079.9~ ~42,1~ N 80 ~9 57 W 10~28,87 ~61-~7 N 80 8 55 W 10565,23 ~76,59 N 79 ~6 42 W 10398,59 ~89,58 N 79 ~6 6 W 10~24.41 ~20,79 N 78 26 38 W 1048~,26 4~5,88 N 77 58 1~ W 10510.11 480.82 N 76 ~ 2~ W 10589.79 190 FFr:l' V E P,,, T i C/~ L () F SUB SEA-DEPTH, ........................................... I 0 (') , 200, 390, aO0, 509, '7 0 ('), ? 0 ,r,,, ]. OCO, ], ],20~ 1300, 15OO, 1,600, ]700, 1800, ] gOO, 2300, ?ar}O, 2 5O3, 310(~. 0 O O 0 O s. () 0 0 0 0 0 0 0 0 0 0 0 0 0 · . 0 0 0 ,-~ o. o o 0 0,63 5 ?,52_E .............. 0,gg S 7.83_F 1,35 S .... a,60_E ................... 1,76 s ....... 9,37..E ......................... 1,88.5 .......... 10,52._E. 1,88 $ .. il,83. E '... 1,88 5 13,i~ .... E ,'4 "~ 7I', /, ,'.,. '79 ,', f'., '? r ', r'.F, 7 1 .,. :.', V V 1 /,r~? "' ,'i -7 ~ .. ? '? , .? ,, ~ /!': .... !"[C,~l. ,SU7 !.', It [? T .~.~ S E A : ~ , .. , _ 500 ?: '"'", ? 700 Z~ 5 '7 r, a a 70. a 500 a 7 '70. a 6 D 0 . , ,, ,. 5 ] '7"'. :~000 .... , , 5100, . ,.. , ~ , ,~ ~' ~ ,, , .~ , . ,., 5 ': ~ ", ,5 ~CO r:,~-;(,, 5600 :," 'z':,, ~ 700 ~. .. .. ~.: ~ """::', ~7'"0.. :.'7'?" , 660C ,. f:: 0 I't E \/E r{Y f'p,.-TVD. .. r2 ~ F r l"; R E N C S. 100 FEET OF ..SUB SEA_ DEP.TH, .......................................................... : VEqT I CAL ................. COPI~KCTION ....... TOTAL...COORDINATE-$ .............................................. 0 0 0 0 0 0 0 0 0 o o 0 3 rl 0 0 '2 0 ,_ ? o 1,82.5 la,67 ..... IS ................................. ..... 1.:70 .5 16,~1 ....E ...................................... .......................... 1_,.58 .... 5 ........... 18 ,.1 . 1.,55 S ._ 20,16 .... F. ..................................... .................... 1,.5.9 $ ........... 22,35 ....E ................................... ................................. 1.. 50...5 ............ 24 j.B.8__E ....... ............ 1,60 S . .. 27*50 .... E ............................. ............. 1,48 S ............... 30.23 ....E ............................ .................................. 1.,_05_. S ....... 33.,2 6_E.__ . ........... 0.63. 0,22 - ......................... 0,11 0.67 1,78 . . 2,88 ~,05 5,28 36.28 ....E ............................ .. 39,15..E ............................... ........... 41., ~ 0_E. 43,52 .E ................................. 45,e9 .E ............................... .... z+8,26._E ' 50,61._ E ................................ 52,92_5 ......................... .......... 7,57 N 8.70 N ._ _ .................. 10,1~+ N 11.96 N ._ la. 28 ~',1 .... 6,45. N .......... 5~,9.7_E 56,84 F_ ...................................... 58,71 .E ............................... . .. 60,59__E _ 62,47 .,E ................... 64,26__E ........................... 16.78 N ............ 66,0 l_E 19.28 N 57,.77-_E ............ . 22.39 N 70,19_E ...................... ............25.79 N ....... 320.9~_E -. 29,18 N 75,69-5 ............................ ....... 32,79 N 78,6%_E .......................... ................ 35,86 N ........ .... ~0,9~ N .. 8502.1-E ..... ~5,01 N 88,51...E ................... _. 49,08 N ....... 91,8i_.E 53,15 N . _95,11 ....E ................. 57.23 N ....... 980~0 E .......................... ) V ^ I.. L.~?. 7. 1.1 r" C' (" r:'!, ET OF x~EA~- J ,, at.~E D DEPTH. ......................................................................... OT,~L COORDINATES .......... 2,53 1 ,21 /"q 0,33 S 1,5/' 1 .CO "' 50,22 ~,1 92, r~n. 53 r.: 1,18, gS.z,O ~,: 59, 20,01 M 125, 37 W 51 ...... E .................... 31 E 67 E 22..E .................................. 77 E ..................................................................................... 7~ E Or-) .. E ~.5 E HORIZONTAL VIEW SCALE !"=100' STANDARD OIL COMPANY OF CALIFORNIA SOLDOTNA CREEK UNIT 33-5 TANGENTIAL METHOD TV D = 10,760'- TMD = 10,870' SURE · I ALL DEPTHS SHOWN 1 I ARE TVD. t VERTICAL SECTION ' -_ ....... SCALE -1": I000:~ STANDARD OIL COMPANY' Of CALiFORNiA` SOLDOTNA CREEK UNIT 33-5 : TANGENTIAL-- METHOD ..... ' 2400 ......... o 5200 .... · . ALL DEPTHS SHOWN ,~oo- ARE TVD. ~o,..~x9 ,-~ ...................... I , 92C)C~ i 0,00~ -? ! ') ,, n A T A ~ V F t4 100 FFET. OF SWB sEA DEPTH, .................................................... VE?T iCA. L .............................................................................................. CJC:'?,PF. CFION TOTAL. COORDINATES 7200. 7600. 770 C). 7800. 7900. 8000, aloo. ~200, ~500, .~ 500, ~700, 8800. 8900, ~nOO. 9!00, C2OO. "TOn 3300, 1¢a0~ . A 1 1 1 1 2 2 · 12_ 61,30... N .............. 101,70 E ........................ : ........ ..... 65,37..N ................. 105,00 E ................................... .................. 6.8-,..90-.-N ....... LO:t.,.39_E 72.23.. N ........... 109.48 E .......... 75.5 6... N ........ 11.1..55 .... E .7 R,_90__N Z13., 6 3 _:. E 82.30..N ........ 115,59 ...... E 85,70.,_ N ......... Z17..55 E .......... 92.69 N .............. ~21.1~ ....E ...... :95,89.N ..............Z22,95. E .......... g~.~5..N ....... 98,17 .E ........... 92,27_ N ......... 86~75 _E ........................ 9~. 5 5__ N ....... 73 .... 98.. 25..N .......... 58.87 E ...... 97.0~ N .... ~3.52 E ............ 89.34_N 28.20-.E .......... 79.&8 N ........... 11.&2 E ..... 6g.61 N .......... 7.~ W ........... 59..31...N 26.57 .... W ..... ~9.72 N ............~7.58 W 4~,56 N ...... ~0.98 W .................... ............... 3 ~ ..2 B._.N ..... 96.52__W .... 2~.5~_ N ......... ~2~.~5 W ................... 1~,~1 N ........ 160,99..W ......................... ............. 15,22_ N ..... 20_0,2~_W. 20.~5 N ...... 2~1.09. W ............................ 3g.99 N ....... 2~1.?~_W ........ :_ .............. ........... ~ 9. ~ 9 N ..... 32.~ 6~.~5 N ...... 37.1.2~ ....W ......................... LOCATED IN THE APPENDIX UI WFL [~ IPR LOG [221 CALIPER SURVEY [21 VOLAN [21 CURVE DATA UI 'STRATIGRAPHIC HIGH RESOLUTION DIPMETER 4~-OTHER: TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF MATERIAL - (ALASKA) 'Mr. T.R. TO:__ state c,f DEPT.: -300! f'~:t'-cui?:~_ne PLACE: -- THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. ' ....; ' COMPANY -'~'~ ,., ............73 SCALE XEROX SEPIA BLUELINE RUNS · ? I 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. CDM - POLYWOG PLOT CEMENT BOND LOG CASING COLLAR LOG - Perf. Rec. COMPENSATED FORMATION DEN. COMPENSATED NEUTRON FORMATION ANALYSIS LOG FORMATION DENSITY LOG F F FORMATION TESTER FORMATION FACTOR F ~F GAMMA RAY GAMMA RAY - NEUTRON GAMMA RAY COLLAR LOG MICRO LOG MI CROLATEROLOG MUD LOG NEUTRON LOG PROXIMITY MICROLOG RWA COMPARISON PLOT SANDSTONE ANALYSIS SARABAND SIDEWALL NEUTRON POROSITY SONIC TEMPERATURE LOG I I I00 200 COMPLETION REPORT DIRECTIONAL SURVEY CORE DATA SARABAND TABULAR LISTING Received and checked by: Fi"~ -. TO: DEPT.: PLACE: TIIAN[;141'..J'T/~t, ANI) A¢",I~ROWI,EJ)Ct:,i,fl,~NT OI; RECF~'J.P'J' OF~A']'I,;I<iAL - (AI,ASKA) iL". T,ll. Narsha!l. State of ~ '~"' Di'~,u[sicn of OJ! & G~s 300! Pc',rcupii. Te Drive tmchor,sge, Llaska 99504 TilE FOLLOWING IS A LIST OF 1-[&TERIAL gl{CLOSED 'ttEREIN. PLEASE CIIECK AN1) ADVIl;It II.ll.iEJ)I/ffELY. RECEIVED 1REV, $- 1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT O'F DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICA'I~ 1. W~LL W~.LL OTHER 2. NA/~E OF OP~IR.~TOR Standard.Oil Company of California AD~RESS OF OPE/{ATOR P. O. Box 7-839, Anchorager Alaska 99510 4. LOCA~ON OF WELL 1871' North and 615' West from the Southeast corner of Sec. 5, T-7N, R-9W 8. ~mlT,F.~'4JVl OR LEASE lq.'~ME Sgldotna Creek SCU 33-5 10. FIE~ ~ND P~L. OR WILDC~ _. ~wan~nn Rivar o~~ Sec. 5; T-7N~ R-9~, 12. PERMIT NO. 75-39 13. REPORT TOTAL DE2~TH AT END OF MONTH, CHA.NGES IN HOLE SIZE, CASING AND CL-MENTING JOBS INCLUDING DEPTH SET AN'D VOLLqVI]~ USED, PERFO~TIONS. 'rF_.STS ANT) R.ESULTS. FISHING JOBS. JUNK LN HOLE A_ND SIDE-TRACKED HOLE AND A.NY O'T/~ER SIGNIFICA.NT C'qiANGF~S IAI HOL~ CONT)ITIONS. October 1975 Drilled 9 7/8" hole from 10,037 - 10585'. Lost and recovered 212' of D~P. fish while drillirgat 10,183'. Ran D1L log and dipmeter. Cemented 7 5/8", 26.4, 29.7, and 33.7#, N-80, S-95, and p-ll0 casing at 10585' with 100 sks. of class "G" cement, and through stage cOllar at 7925' with 545 sacks of class "G" cement. Reinstalled class III BOPE and tested ok under 5000 psig. D.O. stage collar at 7925', c.o. to 10359 and D.O.C. to 10575'. Ran cement bond log. D.O.C. 10575 to 10585' and drilled to 10870' Ran D1L, BCS, CNL-FDC logs. Cemented 486' to 5 1/2", 20~, N-80 liner at 10869', top at 10383', with 100 sks of class "G" cement. D.O.C. 10128 to 10387', cleaned out to 10827'. Pressure tested 5 1/2" x 7 5/8" splice at 10383' ok under 2400 psig s~c pressure. Ran cement bond log. Perforated 5 1/2" liner with four 1/2" jet holes per foot 10616 - 10634' 10648 - 10661', 10680 - 10700', 10702 - 10712' and 10722 - 10747'. Ran tubing. Installed x-mas tree. Set packers at 10604', 10647', 10675', and 10721'. Crew released at 6:00 AM 10/25/75. 14.S, IGNEDI hereby certify~./'~,that P/C/~/~)/~---- C~'the foregoing, is true~///~/~T ,1~. 'a~~/'~ z// /~ ~'e ~3 '~'--,F) ?/,;? ~' ,~,. //~ D A"I~ ~/f~/'/. [ ~ , ~ NOTE --Re~ort on thi~ form is required for ~ac~calendar ~nth~ regardless of t~e status of operations, and must ~ flied in duplicate with t~ e oil end gas conservotlon commi~ee bythe 15~ of the succ~ding month, unle~ Otherwise directed. ~ No. 1:'--4 RlgV. 3-1-70 STATE OF ALASKA S~B~rr ~ mr~UCAT~ OIL AND GAS CONSERVATION COMMITTEE .~. ~PI NU.MER/CAL CODE 50-133-20276 6 LEASE DESIGNATION AND SERIAL NO MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS A-028996 · 1. 7 IF INDIAN[, ALOTTEE OR TRIBE NANIE W~:LL wELL OTHER 2. NA2~E OF OP~I{ATOR 8. t,~IT FA/tM OR LEASE NAME standard Oil Company of California, WOI Soldotna Creek , 3. ADDRESS OF OPERATOR 9 WELL NO P. O. BOX 7-839, Anchorage, Alaska 99510 33-5 4. LOCA~ON OF WELL 1871' North and 615' West from SE corner of Sec. 5; T7N, R9W, SB&M 10. FIELD AND POOL, OR WILDCAT Swanson River 11. SEC., T., R., M.. ~O~TOM HOLE OBJECTWFD Sec. 5; TVN, R9W, SB&M 12. PERMIT NO. 75-39 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-L~'~GES IN HOLE SIZE. CASING AArD C~-MENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED, PEi~FO~TIONS. TESTS ;~XrD t{ESULTS. FISHING JaCkS. JU/~K LN HOLE A3qD SIDE-TR3%CKED ttOLE AND AaNY OTHER SIGNIFICANT CH-A/~GF~ IN HOLI~ CONDITIONS. August and September 1975 Drove 20" conductor pipe to 44'. August 25, 1975, commenced operations. Drilled 15" hole from 44; to 3422'. Cemented 10 3/4" 40.5#, K-55, buttress thread casing at 3372' with 1035 sacks of class "G" cement. Installed class III BOPE. September 1975, tested B.O.P.E. ok ~n~e_r 2500 psig. Drilled out cement and cleaned out to 3422'. Drilled 9 7/8" -hole from 3422' to 10,037'. ,: ..... CONFER: F~LE: 14. I hereby certi£y that the foregoing SIG~ NOTE --Report on this form is required for each calendar month~ regardless of the status of operations, and must be filed In duplicate with th · oil and gas coneervafion committee by the 15th of the succNding month, unle,S otherwise directed. IRAN,_H].i IAL A~4.~) ACKNOWIA,iDGEMENT OF RECEIPT OF :~'I'ERI AL (AI.,ASKA) TO: DEPT.: Mr, T. FL Marshall ~ ~tate et Alaska Division of OII & Gas 3001 Porcupine Drive ?LACE: Anchorage, Alaska 99504 ]:I)- Folded R - Rol].e.d S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF }IATERIAL ENCLOSED HEREIN. PLEASE CItECK AN]) ADVISE IHHEDIATELY. COMPANY WELL _ % ...... ~.-~ ..... HISTORY RECEIVED BY R EM ARK S'4N OTIiE R SIDE, TttlS SIqEET Wr£LL NO., SCU 33-5 .e£¢TION MO. 5 AT¥ OF .,TOWN$1t I P 71"] '~ELL SURVEY Pro-312 -- KENAI ti', ~F rX-i $.B.B, & 14. r-1 N.D.B. & N. TI~ACT NO. · ~ PROPOSED I:iI PRELININARY : ~ FINAL LOT NO. RANGE 9W LOCATION FIELD Swanson River 626' ft. westerly at riqht.a, nflle from east boundary, of Section 5, and 1896 ft. northerly at right angles frcmsouth boundary of Section 5, T7N, Rgw, S.H. ELEVATION: GROUND CONCRETE NAT DERRICK FLOOR ' "A L T E R #''A'T E O R ' ~ U R V E Y E D L 0 C A T I O'N .... LOCA~ I ON ...... DES I GNAT I ON LOCATION COORD I NATES HOVE lEI'lARKS Final ,, N 22,092,339.66 .... .E.. 2,0'1.9, 08,.0.48 .......... . , ..... ,, , .,. ., · · · , ,, , . , , ..... ,, , N,ORTH , .... *+---*t'*, --+ t I ;' I i I '*," I I .... I / I mi SOUTH BEE~ HARK IS: Top of meta Location is to center of 20" O.D. Conductor in bottom of cellar. rim of well cellar, west rim elevation 152.07 ft. ' $1'A~ION " BEARING DISTANC£ s,.e CosINE .orr. '~OUt. EAST VESt DIV, [NGR. FILE 'SURVEYOR Drasky NAINT. FRHN. NAINT. SUPT ........ DATE August 127, 1975 DATE DATE I~'tll ti t Il PRO. 312 (2500.CD.I-58) July 29, tg75 Re: ~ldotna Creek 33-5 Standard Oil Company of California 75-39 Mr. O. Rowland Area Engineer S~ndard Oil Company of ~lifornla P. O. Box 7-83 ~chorage, Alaska 99510 Dear Sir: Enclosed is the approved appli~tton for permit to drill the above referenced well at a location in Section =5, Township 7N, Range 9W, SM. Well samples, core chips, and a ~d log are not required. A directional survey is ~i~d. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject ~ AS 16.50.870 and the regulations promulgated there- under {Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the t~abi~t Coordinator's office, Department of Fish and Gm~e. Pollution of any wa~rs of the State is prohibited by AS 46, Chapter 03, Article 7 and the ~ulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal ~ater Pollution Control Act, as amended, Prior ~ commencing operations you may be contacted by a ~pres~tative of the Depar~nt of Environmental Conservation. After the !0-3/4" casing has been set, all blowout prevention equipment shall be tested ~ 5000 psig working pressure. J. Rowland O. K. Gilbreth, Jr. Page 2 July 29, 1975 In the event of suspension or abandonment please give this office adequate advance notification so that we may have a witness present. Very ~ru]~y yours, Chairman Alaska Oil and Gas Conservation Committee OK :~. be Enc]osure cc: Depar~nt of Fish and Ganm, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Department of Labor, Supervisor, Labor Law Compliance Division w/o encl. T't'P~ OF STA'I[=.' OF AL/'-',SKA OiL ~,'~D OAS (Other ;r,!;[ru,: t!oF: DEEPEN Dx.~L ~x] b. ~'~ 03' 2 N~%i~ OF' Sfiandard Oil Company of California, WOI 3. ADDR~%S CY'? OPE~{ATOt{ P. 0. Box 7-839, ~nchorager ~laska 99510 70 N K t ._.t LOCATION OF WELL A% si. ir face 1871' North & 615' West from SE corner of Sect. 5 At prolx)sed prod. zone Approximately 2000' North & 1150' West from SE corner os Sec 5 13. 1DI$'I'ANCE 1N ~51LE$ AND DIN. ECTIO:'? F}{O>,! NEAREST Tt)'J,'N OH. FOS'F C)FPI'C~? 15 miles approximately APl# 50-1 33-20276 A-028996 L,'NJ'I'~i,'AI',M OJ[ l,F,'xNi; Soldotna Creek 9. W].;/,I, 33-5 10. FINi.i~ AN'I) NOt ,! , (~I{ YeihIIC'AT Swanson River Il..qf.',l.' , T.. i{. 31, }{ogl~] ()l_i,j'l~]Cq'I \'J,], Sec. 5, T7N, R9W, SBM INFORMATION: - -. .' · Statewide #451636 ~,yezNationwides~,.~,,c .... ~o. SL6205862 15. F;igTANCE ??,O%1 PROPOS~ZD~ LOCATION' TO NE t~-RE-'ST P}tOPERTY OR LKAS]'; !,i:':l~, 18 DISTANCE FRO:;i PYiOPOSED 1.OCAI10};' TO NEAREST WEI,L, fDIiihLiNG, CO%IPLETOTD. ON APPLIi?D FOR. b~'. 21. NI.;5;VATIONS i57',o,^' wt.,ether DF, Ii'F, CR, eic.~ $100,000 ff~n:'unt 150 ~. 000 !iK ,%-%';5~'~ :5i ,17 ,i~s; ,~ :ill T ............................ TO Tlli~; V,'Ehh 80 (approx.) Rotary 153' G. L. 23 -~ ~:'r{OPOS~D CASiIqC; AND CEMEiNFIN(} PNOC~ P. } q!ZF; C'F CASi'N'G ~ V/NIC:NTM ~ET{ ~'r~OT C~'A.D~ ~ S!7. E *We propose to drill a new oil producing well per attached program. Administrative approval has been obtained by letter dated 6/16/i~J, Ifil 'vt.;ica! cieptS~s, Ci'.'e blost'o~% T~FOVOiIiel' 9FOgl'~]'rl. July 24, 1975 Area Engineer o-~, :~.~===,.~.?,~: ' .................... SEE TRANSMITTAL LETTER ~:'m.z Chairman ~,.~..?~ July 29, 1975 Field: swanson River pROPOSAL FOR WELL OPERATIONS PRO 316-1 WELL SCU 33-5 SRF · 1,'fo Property and Well: Soldotna Creek unit 33-5 k,~k~.,.,~,... ~.i~'t.~,~?'%?'-h"~ (~.~i'i ~urface Location: Approximately 1871' north and 615' west from SE corner - · of Section 5, TTN,' R9W (or 31' N and 20' W of well 43-5).... . Bottom Hole Location: At H4 target point of -10,500' ss, approximately · 2000' north and 1150' west from the SE corner of · Section 5, T7N, R9W. Elevation: 153'+ G.L. Blowout Prevention Consideration: 1. ~ Portential Problems: A. Gas an~ .Water Entries: Gas sands may be encountered at any depth below shoe of surface pipe, although none were present in 32-5 and 43-5. Care must be' exercised not to swab well during ' trips. High pressure water entries have been detected in many areas of the SCU. No water entries were reported in 42-5, 32-5, -- 43-5, and 12A-4 while drilling with 96-98 pcf mud. A 10 barrel water entry was reported at 9524' in 32A-5 while drilling with 88-89 pcf mud. Well 43A-4, about a mile east of this proposed location, had water entries at 9000'+ with 93-96 pcf' mud. Well 43B-5 is-currently being redrilled and experienced lost circu- lation at 10,125 while drilling with 97 pcf mud. This was compounded with water entries when the mud weight was decreased to 92 Pcf.- The potential entry zones in 33-5 will be below 9300'. The Programmed mud weight of 96 pcf will overbalance the estimated H~mlock pressure by 2600 psi. The mud system should be continually monitored to avoid water entries. · B.- Lost Circulation: The Hemlock zone was originally drilled in · _ . most surrounding wells with 96-98 pcf mud without lost circu- lation except 43B-5, as discussed above, and~ 42-5, which had losses with 98 pcf mud while drilling the H5 at 10,965. This resulted in stuck pipe, and the hole was sidetracked below 5844'. Lost circulation can .occur while drilling the Hemlock because reservoir pressure now is approximately 1400 psi lower than original pressure. LCM should be readily available at all times. C. Precautions: Any kicks should be handled by our normal proce- dures, and drilling crews should be made aware of these methods. The hole must be kept full at all times, and the mud system should be monitored continually. ' App~R©vEO PROGRAM Proposal for Wei~ Operations PRO 316-1 Well SCU 33-5 SRF Drilling Program 2. Maximum Anticipated Formation Pressure: H.igh Pressure Water Zones at 9300'+ = 6200 psi "G" Sand Above Hemlock at = 5500 psi Hemlock at -10,300 ss = 4200 psi 3. Maximum Surface Pressure: 3600 psi 4. BOPE: A. As per Operating Instructions D-17 10" 5000 psi B. Class III, - Est/mated Depths and Correlations: Marker Measured Depth* Vertical Depth** Subsea Depth K.O.P.* (est.) Top Hemlock H4 Point (Target) Total Depth 7, 170 ' -7,000 10,510 -10,340 10,660 -10,490 10,760 -10,600 *Final KOP, directional plat,' and measured depths to be furnished by Drilling at a later date. **Based on K.B. elevation of 170' (Kenai rig). PROGRAM 1. Drive 18" conductor pipe to +80' or as deep as possible during rig uP. · 2. Drill 15" hole to 3400'+.. Maintain drilling fluid per the attached 'drilling fluid program. o. 3. Cenkent°10 3/4", 40.5#/foot, K-55, buttress casing at 3400'. a. Use float shoe and stab in duplex collar one joint up. b. Lock bottom~-i~e joints of casing. c. Centralize the casing above the shoe. d. Cement through the shoe in one stage as follows: 1)' Use sufficient Class "G" cement premixed with 2.4% gel by weight of water to obtain cement returns to surface PROG~,,,~, v\ Proposal for We'~ Operations PRO 316-1 Well SCU 33-5 SRF . Drilling Program Basis: Yield of Class "G" + 2.4% gel by weight of water = · 1.86 ft3/sk. 2) If cement returns are not received at the surface, do a top job. e. Have stage collar on location in case lost circulation occurs while drilling top hole. 4. Cut off 10 3/4", 40.5~/ft., K-55, casing below the top of the cellar (ground level) to allow the top flange of the tubing head to be above ground level after completion. 5. Install 10" - 5000 psi, 10 3/4", SOW casing head. Test welded lap to 2500 psi +. 6. Install Class III, 10" - 5000 psi, BOPE as per the attached BOPE design. Test BOPE, kill line, blow line, and manifold to 2500 psi per "Operating Instructions D-17." 7. Drill out the cement in the 10 3/4" casing with a 9 7/8" bit to within 10' of the shoe. PressUre test the 10 3/4" casing to not over 2500 psi. If test is okay, drill out the 10 3/4" shoe. 8. Drill a 9 7/8" hole to a true vertical depth of 10,510', estimated 10,554 MD, estimated top of the Itemlock sands as follows: al Follow mud specifications per the attached mud program. b. Take single sh surveys to the estimated KOP at a minimum of every 480'. Should conditions warrant, reduce the survey interval to every 240' or less~ Always take a survey on a dull bit. c. Beginning at approximately 7000' KOP build 2°/100' to 19° .- .L~ad well for a 10~ right-hand turn. Along coUrse of N76°W, ,.section is approximately 620'. Target is the base of the Hemlock No. 5 sand at a location approximately 1150' west and 2000' north of the southeast corner of Section 5, T7N, R9W. 9. At effective depth, condition hole for logs. Take a 1/2 gallon sample of mud prior to pulling for logs. Run the following.Schlumberger logs: a. Dual Induction - Laterolog from drilled depth to the shoe of the 10 3/4" casing. Use linear scale for the 2"=100' and logarithmic scale for the 5"=100'. Use 10+MVdPscale and 0-50 ,,, ohm-meters for the linear resistivity scale. PROGRA/ · , · C.N. S::~I~c,,' Proposal for' Wel. Operations PRO 316-1 Well SCU 33-5 SRF Drilling Pro, ram Have Sonic and CNL-FDC logs on the location. Drill ahead as indicated by log run to set 7 5/8" casing shoe at the top of the Hemlock (H-l). Cement 7 5/8" casing at the top of the Hemlock as follows: "a. Bottom Next Next Next -Top - -Total: · 3;520' 33.79 1,200' 33.79 1,900' 29.79 3,854' 26.49 80' 33.7~ 10,554 ' _ P-110 Buttress $-95 Buttress N-80 Buttress N-80 Buttress P-110 Buttress NOTE: For deeper TD add 26.4#, N-80 buttress as required. Casing program based on pipe availability, which exceeds design criteria. b. Run differential fill-up shoe and collar. c. Run stage collar at approximately 7900'. Have triplex shoe on the location in case it is necessary to set the 7 5/8" casing above the drilled depth. - ~ e. Centralize the bottom 700' and above and below the stage collar at 7900'. . . - .. f. Cement in two stages using Class "G" cement mixed with 2.1% gel by weight of water as follows: Sh6e Job '- Use sufficient cement-gel mix followed by 100 _ sacks of neat cement to reach 8700'+. .2} Stage Collar - Use sufficient cement-gel mix through collar at 7900' to reach 4500'+. . . Remove BoPE and land the 7 5/8" casing. Install a 10" - 5000 psi bottom flange x 10" - 5000 psi top flange tubing head. Test secondary ~ackoff to 5000 psi. Install 10" - 5000 psi BOPE. Test BOPE to 300. 0 .psi per-"Operating Instructions D-17." .~ ~ 13. Drill out cement and stage collar and clean out to within 10' of the 7 5/8" shoe. 14. Run Variable Density-Cement Bond Log from the effective depth to above the top of the cement from the stage collar job. PROGRAM , .. C. ix.I. S.~r~n.,'~r .. · 'Proposal for We: ~ Operations PRO 316-1 Well SCU 33-5 SRI~ Drilling Program 15. Based on CBL, squeeze for WSO above the Hemlock as required. 16. Pressure test the 7 5/8" casing to 3000 psi. 17. Condition mud weight to 72-74 pcf. (72 pcf mud provides a hydro- static pressure of 5250 psi at 10,554' MD versus 4200 psi estimated reservoir pressure). 18. Drill a 6 5/8" hole to true vertical depth of 10,760', estimated 10,810' MD. (Total depth is projected 110' below the base of the Hemlock 5 sand). 19. Condition hole for logs. Take a 1/2 gallon sample of mud prior to pulling for logs. Run and tape the following Schlumberger logs: a. Dual Induction - Laterolog from TD to the shoe of the 7 5/8" casing. Use same scales as before. b. SP-BHC Sonic from TD to the shoe of the 7 5/8" casing. c. Microlog from TD to the shoe of the 7 5/8" casing. d. Compensated Neutron-Density Log. 20. Condition hole for 5 1/2", 209, N-80 Buttress liner. 21. Cement approximately 600' of 5 1/2", 20#, N-80 Buttress at TD as follows: a. Run float shoe and float collar. Do not use centralizers. b. Allow for approximately 200' of special clearance P-110 couplings in lap below the liner hanger. ¢. Use sufficient Class "G" cement treated with 3/4% CFR-2 to reach to above the top of the liner., Mix a heavy slurry to 118-222 . p6f. 22. Clean out cement to the top of the float collar. Run Variable · Density Cement Bond Log from effective depth to above top of the liner hanger. 23. Pressure test the 7 5/8" casing, 5 1/2" liner, 7 5/8" x 5 1/2" lap to 3000+ psi using the rig pumps. 24. Based on log evaluation, consider testing basal Hemlock 5 sand. .. . 25. Jet perforate selected Hemlock 1-5 sand intervals for production }~ii~::~ ~'I~ .,,%~'\~ ~.~:,. 3~,!.i t.~!~:~i;i'~/8" OD carrier guns loaded with four 1/2" holes per foot. APPROVED PROGRAM ' C. Fl. Sc, c,,, "r Proposal for Wel± Operations PRO 316-1 Well SCU 33-5 SRF Drilling Program .. . '26. Run tandem casing scrapers and scrape the entire 5 '1/2" liner. 27. Run and hydrotest to 5000 psi, approximately 10,800' of 3 1/2" x 2 3/8" tubing and gas lift mandrels. Run 2 3/8" OD tubing and Jewelry in the 5 1/2" liner. A detailed completion program will be provided after TD logs have been run. 28. Remove BOPE and install x-mas tree. Pressure test tree to 5000 psi. Displace-the drilling fluid down the annulus and up the tubing string %lsing'lease crude oil. 29. Set the production packers and release the rig. Place the well on . production as directed by the Production Foreman. · B. A. Dakessian -.o/s o/s Area Engineer Area ~. / ! APPROVED PROGRAM f. C. N. Segnar 10'/5 BASIC D~LLING FLUID SYSTEM Lightly treated lignosulfonate mudl OPTIMUM DRILLING FLUID PROPERTIES NEW WELL NO. SCU 33-5 DRILLING FLUID PROGRAM swANSON RIVER FIELD Mud Properties (Vertical Depths) (1) .. 0 - 3,400' Weight- pcf - Viscosity- sec/qt., API Fluid Loss - CC, API Plastic Vsicosity - CPS Yield Point - lb./100 ft.2 Gel - lb./100 ft.2 - 10 min. pH Calcium- PPM Solids Content - % Vol Diesel Oil - % Vol Max. 755 pcf As Required (2) (3) (4) 10 3/4" Shoe - 6500' - 7 5/8" 7 5/8" Shoe- 6500' . .Casin9 Point T.D. 72 - 80 88 - 100 72 - 74 40- 70 40 - 70 40- 70 15 max. 15 max. 7 max. 22 max. 30 max. 22 max. 10- 20 5 - 20 10- 20 5 - 15 8 max. 5 - 15 8.5 - 10.8 8.5 - 10.8 9.2 - 9.8 80 max. 80 max. 50 max. 18 max. 25 max. 16 max. 5-7 5-7 5-7 1. Drill top hole to 3,400'+ with salvaged mud, if available. 2. Convert top hole mud to gel mud while drilling from 3,400' to 6,500'. At 6,500', start to increase weight and have mud properties as listed in Column No. 3 at 7,000'. 3. Use lightly treated lignosulfonate mud below 6,500'. 4. Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. . . 5. Maintain an adequa%e supply of lost circulation material at the rig. 6. Make a high pressure - high temperature fluid loss determination while drilling Hemlock. Make fluid loss tests at estimated bottom hole temperature 170°F. APPROVED PROGRAM C. N. Segnar PROPOSAL'FOR WELL OPERATIOPJS PRO-31G-A (TO BE USED AS A G0-111) CASING [ .QUIREMENTS AND PRODUCIr- EQUIPMENT WELL/LOCATION NO. $CU 33-5 ' DATE May 30, 1975 FIELD Swanson River ESTIMATED SPUD DATE __July 1, 1975 TOTAL DEPTH 1Oo 810 METHOD OF PRODUCTION Gas Lift MAX. ESTIMATED SURF. PRESSURE 3800 ESTIMATED O/W/G1500/ - /225Q EQUIP. FOR STEAM CASING Gross Footage APl Size . Weight Conductor 80 ' 18" 104 Surface 3400' 10 3/4" 40.5 Grade B K-55 IN,. PRODUCER X Threads Coupling Computer Design For: ~ine Pipe 0. 562" Wall This Well Standard Design For Field Buttress Well No. Requires: Float shoe, stab-in duplex collar, and stage collar with Max. Drift Angle buttress threads; 15-10 3/4" x 15" centralizers, 2-10 3/4" stop rings, Baker loc. 1Nater String: Design based on mud density__ 95 lbs./cu, ft. and above max. surf. pressure '· 3600 7 5/8" 33.7 P-110 Buttress 4 X-overs 1200 7 5/8" 33.7 S-95 Buttress 25 9 7/8" x 7 5/8' centralizers 1900 7 5/8" 29.7 N-80 Buttress 25 stop rings Total: 10554 3854 7 5/8".. 26.4 N-80 Buttress Cementin§ Accessories 7 5/8" x 33.7#'P-110 Model G differential fill-up shoe and collar; stage collar and plugs for stage cementing .. . liner 200' 5 1/2" 20 - P-110 Special clearance coupling - 400' 5 1/2" 20 N-80 Buttress Hanger 5 1/2" 20# Buttress x 7 5/8", 33.7#, P-110 BUrns plain liner hanger grooved for cementing float shoe, collar, plugs. - Perforated' ' . to · ,, CAS! NG } UNITIZED HEAD: 5000 CASING SPOOL ', Mesh, Rows, Slots, Centers, PSl CWP. Bottom Conn. 10 3/4 SOW, Type Y,D Top Conn. 10" 5000 RJ flange 2 x 2 ,,, screwed out%~ Fittings... i - screwed 3000 psi WOG valve, bull plug on other side TUBING HEAD TUB ! N G Feet 5-000 PS! CWP. Bottom Cenn. 10" 5000 psi P~7 flanqe, type 59L Top Conn. ] 0" 5000~ RJ Flanqe ", Type Suspension .Shaffer 59L 3 1/2" Buttress up and down full bore, bored for 3 1/: Cosasco APl Size weight Grade Threads Type Remarks Bottom 650' 2 3/8" 4.7 N-80 Next 10,150' 3 1/2" 9.3 N-80 10,800' 9 - 3 1/2" Camco' MMG Mandrels w/ R-20 valves '4 - 5 1/2" Baker FH Packers (20~) Total 3- 2 3/_8" Otis llX~" sleeves 3 2 3/8" Otis. "S" Nipples, Pos #2, 3 & 4 Tubing Catcher. . ." ° type. Csg. Size . ". Packer "x .. " Type with with # wt.' Other Fittings XMAS TREE 3 - 2 Arm. PSI CWP. Dwg. No. (Cross*overs, etc.) 8RD EUE. 2 3/8" EUE x 3 1/2" Bur's. Buttress (both N-80) 3 '- 2 3/8" Brown CC Joints 1 2 3/8-" Camco "D" Nipple 1 2 3/8" Shear-out sub 100' - 2 3/8" Baker Blast Joint 3.062" Wt. Install at "stroke at AP-C-174-0 and AP-C-175-0 Tubing Beans " Header '° Ann Stuffing Box " PUMP: "x ' RODS: Grade , .__'of PUMPING UNIT. APl Size Type Engine Motor Type -1-3 " 5000 psi Willis Type 1 Bean PSI CWP. Dwg. No. Type. Polished Rod "x Type at P[cparcd By BAD 5/30/75 .-.-_ .... of .... of Max. Stroke "Set at HP Remarks Area Supervisor .... Sr. Drlg. Engineer. Approved by ~ ' ' Drlg. Supt. ~J %-~ ' ~ ~ Ty' ' Lo "Stroke and -- PROGT~-- SF t, -Cf N. ' -------P Fl O-31 G- A (CD-1.7 Prl~tud In U.:;.A. · · . · __ . * t. * .. ~ ~ . . '~ ". R -'.. ¢ · -. "~'· , J~ ~ I'.'"'.." } .'. · ' ~-~' - .......... '.. ..! .: !1~.. t1: I! II ,1t .~ .. '..,: .... .' .. · ... ~ ~.~ . . -'_' ... - ~.=, ,,~ ~ ~,. ~. ~ ...... ~ .."' · . · ,___ . ... ~ ,..-. .~-- ' " " !{' -. V~,.,,?~-~:,r: ~~,--~ - '-~, ~ . ~. . . .... · ~. . , . . . ~ -.. -~ . " . ~"' ' ..... . ' , : ~ -. · ,. ...... .. . ........... .._ . . ' " · .'" .... e. . :- · -.~-. '-, ~ '.- '. ---. . - .... ~ . ~.~ .. {~ ~. ~ -~ ....... ~ ~ . . . . .. :~:; ~ . ~. I~ ~ P' - ....... "~ .*~--~ ~/c ~ ' ........... , ................... ~.~-.-. :)~ ................... · ~..:: ~~L~.7 , 2" x 3" 5~ ADAPTOR ~' ~t,' S~k~R KD S.O.W. CSG. ~. 10" 5OOO~ TOP F~. '~ .. 8 (4) 3" 5OO0~ VALVES - ~'O EACH S~E ~D "X" or T with TJO SCD. O.L. " ~ .BHAPFBR HYDRAULIC ~PE ~IS 10" 5CCO,~ BBL. 2 ~.~c~'~n=~,~ ~;~n~-" ' 10 ~DRIL TYPE "GK" lC" 500v,~ BLOWCUT PP~V~,T~. ~ 2'2~H x 4" ~G S~IEJED 2" 3~O# VALVE WITH PULL PLUG. . ~-. L S:-{AZF"~. TUBi:;S HEAD with T~O STUDDED OUTLETS, 5000~ -UP ~-i:~. t,.;o ~,' s;o. ou'rz'~s. " SWANSON RIVE,', FIELD , · '~ _,~ ,,~ ~ ~'~ · . i i i ! i ii i ii i il . .... i . S.C.U.i K,.' ~ _ I ' STANDARD OIL COMPANY OF CALIFORNIA [.....~.....Y...,(?..4'.~'~.....~...~. .... C,/'~',,~:~/O-~.../T'KL'~,,"~,,~c'. ~~ ' . ...... "/ ~ ~ WESTERN OPERATIONS. INC ~ ~CALE~~ · ~ ~ ._ DAT[~/~'~'~ L ............................ r ........ . ................... t .... t'"J'-/''~t'~ .......... ~ h~%",'?ZP-'t /"'°-~~1 , · ' - iii fill ~ /~ ~ ~ I ~~ ~"~z ~ooo= ~ N~CH ~ ~OR~ ~,~-~ ~ ~/.'G~ ~ ~ ~ ~- 00~ ~~ ~ ........................................... ............... ,, _ , ~ _ ~. . ~ ~ /~- ~u~ / ~ ~//~b' ~0~ ~ ~/~ H~ ~ . . ~,.~ ................................ ~ .......... ~ .... ~,~. ..... L~ ..................... '~': ~ ' ~ ..... . ~.~.~.'~_~ ~ ~"~ '~~.'~'~'~-,s~uE'" ~ ~ ~ ~,~.~c ~HRI~TH~S TREE _. Iii ~-~--- ~'~'~'-~L': L- ~'~ '~'~-~~ ~ .......... pROPOSAL FOR WELL OPERATIONS PRO 316-1 WELL SCU 33-5 SRF DRILLING PROGRAM Field: Swanson River Property and Well: Soldotna Creek unit 33-5 Surface Location: Approximately 1871' north and 615' west from SE corner of Section 5, T7N,' R9W (or 31' N and 20' W of well 43-5) .. Bottom Hole Location: At H4 target point of -10,500' ss, approximately 2000' north and 1150' west from the SE corner of Section 5, T7N, R9W. Elevation: 153'+ G.i. Blowout Prevention Consideration: 1. Portential Problems: A. Gas andlWater Entries: Gas sands may be encountered at any depth below shoe of surface pipe, although none were present in 32-5 and 43-5. Care must be'exercised not to swab well during trips. High pressure water entries have been detected in many areas of the SCU. No water entries were reported in 42-5, 32-5, 43-5, and 12A-4 while drilling with 96-98 pcf mud. A 10 barrel water entry was reported at 9524' in 32A-5 while drilling with 88-89 pcf mud. Well 43A-4, about a mile east of this proposed location, had water entries at 9000'+ with 93-96 pcf'mud. Well 43B-5 is 'currently being redrilled and experienced lost circu- lation at 10,125 while drilling with 97 pcf mud. This was compounded with water entries when the mud weight was decreased to 92 pcf. The potential entry zones in 33-5 will be below 9300'. The programmed mud weight of 96 pcf will overbalance the estimated Hemlock pressure by 2600 psi. The mud system should be continually monitored to avoid water entries. Lost .Circulation: The Hemlock zone was originally drilled in ]host surrounding wells With 96-98 pcf mud without lost circu- lation except 43B-5, as discussed above, and' 42-5, which had losses with 98 pcf mud while drilling the H5 at 10,965. This resulted in stuck pipe, and the hole was sidetracked below 5844'. Lost circulation can .occur while drilling the Hemlock because reservoir pressure now is approximately 1400 psi lower than original pressure. LCM should be readily available at all times. Precautions: Any kicks should be handled by our normal prose- dures~ and drilling crews should be made aware of these methods. The hole must be kept full at all times, and the mud system should be monitored continually. ~D PROGRAM Proposal for Wex_ Operations PRO 316-1 Well SCU 33-5 SRF Drilling Program ]~aximum Anticipated Formation Pressure: High Pressure Water Zones at 9300'+ = 6200 psi "G" Sand Above Hemlock at = 5500 psi Hemlock at -10,300 ss = 4200 psi 3. ~4aximum Surface Pressure: 3600 psi . 4. BOPE: " A. As per Operating Instructions D-17 · 10" - 5000 psi B Class III, Estimated Depths and Correlations: F~arker Measured Depth* Vertical Depth** Subsea Depth K.O.P.* (est.) Top Hemlock H4 Point (Target) Total Depth 7,170 -7,000 10,510 -10,340 10,660 -10,490 10,760 -10,600 *Final KOP, directional plat,' and measured depths to be furnished by Drilling at a later date. **Based on K.B. elevation of 170' (Kenai rig) PROGRAM 1. Drive 18" conductor pipe to +80' or as deep as possible during rig up. 2. Drill 15"' hole to 3400'+.. Maintain drilling fluid per the attached ~rilling fluid program. 3. Cem~nt°10 3/4", 40.5~/foot, K-55, buttress casing at 3400'. Use float shoe and stab in duplex collar one joint up. Lock bottom ~ joints of casing. Centralize the casing above the shoe. Cement through the shoe in one stage as follows: 'Use sufficient Class cement premixed' with 2 4% gel by weight of water to obtain cement returns to surface . . . ,, . PROGRAM Proposal for We Operations PRO 316-1 Well SCU 33-5 SRF Drilling Program ' . Basis': Yield of Class "G" + 2.4% gel by weight of water = .1.86 ft3/sk. 2) If cement returns are not received at the surface, do a top job. " e. Have stage collar on location in case lost circulation occurs while drilling top hole. 4. Cut off 10 3/4", 40.5~/ft., K-55, casing below the top of the cellar (ground level) to allow the top flange of the tubing head to be above ground level after completion. 5. Install 10"' - 5000 psi, 10 3/4", SOW casing head. Test welded lap to 2500 psi +. i 10" 5000 psi, BOPE as per the attached BOPE 6. Install Class III, - design. Test BOPE, kill line, blow line, and manifold to 2500 psi .... per "Operating Instructions D-17." 7. DrilI out the cement in the 10 3/4" casing with a 9 7/8" bit to within 10' of the shoe. Pressure test the 10 3/4" casing to not over 25.00 psi. If test is okay, drill out the 10 3/4" shoe. 8. Drill a 9 7/8" hole to a true vertical depth of 10,510', estimated 10,554 MD, estimated top of the Hemlock sands as follows: Follow mud Specifications per the attached mud program. b. Take single sh surveys to the estimated KOP at a minimum of every 480'. Should conditions warrant, reduce the survey interval to every 240' or less. Always take a survey on a dull bit. '. C. Beginning at approximately 7000' KOP build 2°/100' to 19° _-~ L~ad well for a 10°~ right-hand turn. Along course of N76°W, ~ section is approximately 620'. Target is the base of the Hemlock No. 5 sand at a location approximately 1150' west and 2000' north of the southeast corner of Section 5, T7N, R9W. 9. At effective depth, condition hole for logs. Take a 1/2 gallon sample 6f mud prior to pulling for logs. Run the following .Schlumberger logs: . a. Dual Induction - Laterolog from drilled depth to the shoe of the 10 3/4" casing. Use linear scale for the 2"=100' and logarithmic scale for the 5"=100'. Use 10+~Pscale and 0-50 ohm-meters for the linear resistivity scale. APPRO PROGRA/,.,I Proposal for 'Wel Dperations PRO 316-1 Well SCU 33-5 SRF Drilling Pro, ram Sonic and CNL-FDC logs on the location. 10. Drill ahead as indicated by log run to set 7 5/8" casing shoe at the top of the Hemlock (H-i). .~1. Cement 7 5/8" casing at the top of the Hemlock as follows: a. Bottom Next Next Next Top -Total: 3;520' 33.79 1,200 ' 33.79 1,900' 29.79 3,854 ' 26.49 80' 33,79 10,554 ' P-110 Buttress S-95 Buttress N-80 Buttress N-80 Buttress P-il0 Buttress NOTE: For deeper TD add 26.4#, N-80 buttress as required. Casing program based on pipe availability, which exceeds design criteria. b. Run differential fill-up shoe and collar. Run stage collar at approximately 7900'. d. -Have triplex shoe on the location in case it is necessary to set the 7 5/8" casing above the drilled depth. . e. 'Centralize the botto~ 700' and above and below the stage collar at 7900'. .. . .. · · f. Cement in-two stages using Class "G" cement mixed with 2.1% gel by weight of water as follows: 1) Shde Job '- Use sufficient cement-gel mix followed by i00 . sacks of neat cement to reach 8700'+. .2) Stage Collar - Use sufficient cement-gel mix through collar at 7900' to reach 4500'+. · 12. Remove' BoPE and land the 7 5/8" casing. Install a 10" - 5000 psi bottom flange x 10" - 5000 psi top flange tubing head. Test secondary packoff to 5000 psi. Install 10" - 5000 psi BOPE. Test BOPE to 3000 _psi per "OperatLng Instructions D-17." 13. Drill out cement and stage collar and clean out to within 10' of the 7 5/8" shoe. above the top of the cement from the stage collar job. 14. Run Variable Density-Cement Bond Log from the effective depth to PROGRAM ! , . C. N. Sef. rnr'.,r Proposal for We/ Operations PRO 316-1 Well SCU 33-5 SF~'' Drilling Program 15. ~ased on CBL, squeeze for WSO above the Hemlock as required. 16. Pressure test the 7 5/8" casing to 3000 psi. · 17. Condition mud weight to 72-74 pcf. (72 pcf mud provides a hydro- static pressure of 5250 psi at 10,554' MD versus 4200 psi estimated ~eservoir pressure). . 18. ~lrill a 6 5/8" hole' to true vertical depth of 10,760', estimated 10,810' MD. (Total depth is projected 110' below the base of the Hemlock 5 sand). 19. ~Dondition hole for logs. Take a 1/2 gallon sample of mud prior to ~lling for logs. Run and tape the following Schlumberger logs: a. Dual Induction - Laterolog from TD to the shoe of the 7 5/8" casing. Use same scales as before. b. SP-BHC Sonic from TD to the shoe of the 7 5/8" casing. ¢. Microlog from TD to the shoe of the 7 5/8" casing. Compensated Neutron-Density Log. 20. (Dondition hole for 5 1/2", 209, N-80 Buttress liner. 21. Cement approximately 600' of 5 1/2", 205, N-80 Buttress at TD as follows: ~a. Run float shoe and float collar. Do not use centralizers. Allow for approximately 200' of special clearance P-110 couplings in lap below the liner hanger. c. L Use sufficient Class "G" cement treated with 3/4% CFR-2 to reach to above the top of the liner.. Mix a heavy slurry to 118-222 · p6f. 22. ~ean out cement to the top of the float collar. Run Variable · ~ensity Cement Bond Log from effective depth to above top of the liner hanger. " 23. P~ressure test the 7 5/8" casing, 5 1/2" liner, 7 5/8" x 5 1/2" lap to 3000+ psi using the rig pumps. 24. Based on log evaluation, consider testing basal Hemlock 5 sand. . · 25. ,Jet perforate 'selected Hemlock 1-5 sand intorvals for production -ll~e 3 3/8" OD carrier guns loaded with four 1/2" holes per foot. PROGRAM Proposal for Well Operations PRO 316-1 Well SCU 33-5 SRF Drilling Program 26. Run tand~.m casing scrapers and scrape the entire 5 1/2" liner. 27. Run and hydr-otest to 5000 psi, approximately 10,800' of 3 1/2" x 2.3/8" tubing and gas lift mandrels. Run 2 3/8" OD tubing and · jewelry in the 5 1/2" liner. A detailed completion program will be .. provided after TD logs have been run. 28. Remove BOPE and install x-mas tree. Pressure test tree to 5000 psi. 'Displace the drilling fluid down the annulus and up the tubing string using'lease crude oil. 29. Set the production packers and release the rig. Place the well on production as directed by the Production Foreman. B. A. Dakessian .o/s O/S Area Engineer Area S6per{,isor ' / APPROV~ED PROGRAM C. N. Segnar BASIC DRILLING FLUID SYSTEM Lightly treated lignosulfonate mud. OPTIMUM DRILLING FLUID PROPERTIES NEW WELL NO. SCU 33-5 DRILLING FLUID PROGRAM SWANSON RIVER FIELD Mud Properties (Vertical Depths) (1) 0 - 3,400' (2) (3) 10 3/4" Shoe - 6500' - 7 5/8" 6500' . casin~ Point (4) 7 5/8" Shoe- T.D. Weight - pcf Viscosity - sec/qt., API Fluid Loss - CC, API Plastic Vsicosity - CPS Yield Point - lb./100 ft.2 Gel - lb./100 ft.2 - 10 min. pH Calcium - PPM Solids Content - % Vol Diesel Oil - % Vol Max. 75# pcf As Required 72 - 80 88 - 100 40 - 70 40 - 70 15 max. 15 max. 22 max. 30 max. 10 - 2O 5 - 20 5 - 15 8 max. 8.5 - 10.8 8.5 - 10.8 80 max. 80 max. 18 max. 25 max. 5-7 5-7 72 - 74 40- 70 7 max. 22 max. 10- 20 5 - 15 9.2 - 9.8 50 max. 16 max. 5- 7 1.- Drill top hole to 3,400'+ with salvaged mud, if available. .-- 2. Convert top hole mud to gel mud while drilling from 3,400' to 6,500'. At 6,500' , start to increase weight and have mud properties as listed in Column No. 3 at 7,000'. 3. Use lightly treated lignosulfonate mud below 6,500'. 4. Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. 5. Maintain an adequa'te supply of lost circulation material at the rig. 6. Make a high pressure - high temperature fluid loss determination while drilling Hemlock. }lake fluid loss tests at estimated bottom hole temperature 170°F. APPROVED PROGRAM C. N. Sognar PROPOSAL'FOR WELL OPERATIOPJS PRO-31G-A (TO BE USED AS A G0-111) CASING' :QUIREMENTSANDPFi0DUCi[ EQUIPMENT WELL/LOCATION NO. SCU 33-5 ' DATE May 30, 1975 FIELD Swanson River ESTIMATED SPUD DATE __July 1, 1975 TOTAL DEPTH 10,810 METHOD OF PRODUCTION Gas Lift MAX. ESTIMATED SURF. PRESSURE __3800 ESTIMATED O/W/Gl..500/ - /22.50.. EQUIP. FOR STEAM INJ. PRODUCER X CASING Gross Footaqe APl Size Weight Grade Threads Coupling Computer Design For' Conductor 80' 18" 104 " B Line Pipe 0.562" Wall This Well ' ' Standard Design For Field Surface 3400' 10 3/4" 40.5 K-55 Buttress Well No. Requires: Float shoe, stab-in duplex collar, and stage collar with Max. Drift Angle buttress threads; 15-10 3/4" x 15" 'centralizers, 2-10 3/4" stop rings, Baker loc. Water String: Design based on mud density__ 95 lbs./cu, ft. and above max. surf. pressure 3600 7 5/8" 33.7 P-110 Buttress 4 X-overs 1200 7 5/8" 33.7 S-95 Buttress 25 9 7/8" x 7 5/8' centralizers .' 1900 7 5/8" 29.7 N-80 Buttress 25 stop rings Total: 10554 3854 7 5/8" · 26.4 N-80 Buttress Cementing Accessories 7 5/8" x 33.7#'P-110 Model G differential fill-up shoe and collar; stage collar and plugs for stage cementing .. · Liner 200' 5 1/2" 20' P-Il0 Special clearance coupling 400' 5 1/2" 20 N-80 Buttress Hanger 5 1/2" 20~ Buttress x 7 5/8", 33.7#, p-110 Burns plain liner hanger grooved for cementing float shoe, collar, plugs. Perforated' ', t° ', Mesh, Rows, SI ets, Centers, .CASING } UNITIZED HEAD: 5000 PSI CWP. Bottom Conn. 10 3/4 SOW, Type KD 10" 5000 RJ flange 2 x 2 "0 screwed 1 - screwed 3000 psi WOG valve, bull plug on other side CASING SPOOL MC Top Conn. Fittings TUBING HEAD TUBING Feet Bottom 650' Next 1 O, 150 ' 10,800' 9 - 3 1/2" Camco' MMG Mandrels w/ R-20 valves '4 - 5 1/2" Baker FH Packers (20~) ~ota! 3- 2 3/_8" Otis ">D~" sleeves 3- 23/8" Otis "S" Nipples, Pos #2, 3 & 4 ~OOO PS! CWP. Bottom Conn. 10" 5000 psi RJ flange, type 59L Top Conn. ] 0" 5000~ RJ Flange ", T¥~eSuspension Chaffer 59L 3 1/2" Buttress up and down full bore, bored for 3 1/2 Cosasco APl Size Weight Grade Threads Type Remarks (Cross-overs, etc.) 2 3/8" 4.7 N-80 8RD EUE. 2 3/8" EUE x 3 1/2" Butt 3 1/2" 9.3 N-80 Buttress (both N-80) 3 - 2 3/.8" Brown CC Joints 1 2 3/8" Camco "D" Nipple 1 2 3/8" Shear-out Sub 100' - 2 3/8" Baker Blast Joint 3.062" Tubing Catcher " Packer "x with XMAS TREE.. 3 ,, 2 Arm. Tubing Beans " Header " Stuffing Box PUMP: "x RODS: Grade , __' of PUMPING UNIT. APl Size type. Csg. Size " Wt. Install at " Type with "stroke at ~ wt.' Other Fittings Arm Type PSI CWP. Dw9. No. AP-C-174-0 and AP-C-175-0 Type -1-3 " 5000 psi Willis Type 1 Bean PS! CWP. Dwg. No. · Type. Polished Rod "x -. Type at ' of .... of , Max. Stroke "Set at Sr. Drlg, Engineer., T¥' · Lo~ "Stroke and ! APPROVED' ,, C. N. Segnar SF -- '~RO-31G-A (CD-1.7 Prh~iod In · % , '-i - , ~_' i-0~" SH~R KD S.O.W. CSG. HD. lO" 5000# ~07 FLG. with TJO SCD. O.L. , 7 : 2" x 3" 5~G~ ADAPTOR _ · (4)-3" 5000# VALVES - T~O EACH S~E ~D "X~ or ~ 2 SCOTCH ~;!PPLS · R .BHAFFER HYDRAULIC ~'PE DiS 10,, 5CCO~ BBL. ~=~" ........ T ..... o ~.D with T~O STUDDED OUtLeTS, 50~ i-, ,':U: QtC*~ ~lth lO" SO00// F~NOS TOP E BOTTOM, ELL ltEAD ItOOK'UP CLASS. I!1 B.O.R E · .4 & ~ ~,'~ ~l ~' '.'~'~ '" ~ ' , , ,,, , . SWAN° .. ,.eLL He,,~ ,tCO~-JP CLASS ~ g.O.P.E. . . q (~ tl :;_:,; .- ~ S.C.U.. 5 5' I ' STANDARD OIL. ¢OHPANY OF CALIFORNIA j. ,7')"/t:D/~"~,'~'~. t~,/7"/z~/,,5'7/.--///-''5'tO'''. 7-,"~'~' ...... ~'.~ i".5'.l ] ' ,o~..,o~, ' l ......................... / ............... ; ......................... ,,--{~ 't "1 ' ' ' I ..4~;,4,.s',~'A ~/o"z-A:' c"Z' .... "% 't.{ sc~t~_.~.~t.r_.¢" _~_ D^t;...~_//--/--'-e/ ; .......... 5 .... ) ............... -'" ............ ." i l'-I~" '.-~.-,~ ......~" ...........~'"~"'~'~..~-=' ...... '...,~I .... - ..... '~~ ........... o. Chevren Standard Oil Company of California, Western Operations, Inc. 'P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 J. L. Rowland Area Supervisor Producing Department June 11, 1975 Administrative Approval Well SCU 33-5 SwanSon River Field Mr. Thomas R. Marshall, Jr. Alaska Oil & Gas Conservation Committee Department of'Natural Resources 3001 pOrcupine Drive Anchorage', Alaska 99501 CONFER: FILE: Dear Mr. Marshall:- Standard Oil Company of California, as operator of the Swanson River Field, proposes to drill a new development well, eCU 33-5, in the SE 1/4 of Section 5, T7N, R9W, SB&M. The well is to be completed in the Hemlock 1-5-sand intervals. It will increase the number of completions in the quarter section from two.to three, but it will be the only H1-5 producer. The justification for the proposal is an estimated 583,000 STB of reserves. By provisions of Conservation Order No. 123, we request your approval to drill SCU 33-5. Very truly yours, J. L. · Rowland BAD :raj s CC: Mr. J. P. Johnson, ARCo Mr. E. F. Griffin,. Union Mr. B. G. Howard, Marathon- Mr. R. A. Smith, USGS CHECK LIST FOR NEW WELL PERMITS Company " Yes No Remarks' 1.Is the permit' fee attached ..................... Lease & Well 2. Is well to be' located in a defined pool ............... 3. Is a registered survey plat attached ................ 4. Is well located proper distance from property line ......... ~A-:~< , 5. Is well located proper distance from other wells .......... 6. Is sufficient undedicated acreage available in this pool ...... 7. Is welt to be deviated ....................... ~:.~' 8, Is operator the only affected party ................ 9. Can permit be approved before ten-day wait 10. Does operator have a bond in force ................. ~K l l, Is a conservation order needed ...... - ........... ~ . ~z~~ 12. Is administrative approval needed 13. Is conductor string provided 14. Is enough cement used to circulate on conductor and surface 15, Will cement tie in surface and intermediate or production strings !6, Will cement cover all known productive horizons 17. Will surface casing protect fresh water zones 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating ............. Additional Requirements: Approval Recommended :. Geo 1 ogy, Engi nee ri n g: TRM " HWK ~mk~ OKG HHH JAL LCS JCM Revised 1/15/75 Well History File APPENDIX Information of detailed natu~f4~at is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX,' No special'effort has been made to chronologically organize this category of information. $5 AA AA 55 AA AA S~ AA AA 5b AA AA $&$6S~ AA AA ~85S$~ AA AA ~ AAAAAAAAAA 5~ AAAAAAAAAA ~5 AA AA $5 AA AA $~$5555~ AA AA RRRRRRRR RR RR RR RR Rk ~R RR RR RRRRRRRR RRRRRRRR RR RR ~R CCCCCC¢C Uff~ CCCCCCCC qU UU CC UO CC OU CC UU CC CC CC OU CC UU CC CC UU CC CCCCCCCC CCCCCCCC 000000 000000 O0 O0 OO O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 0000 O0 0000 O0 OO O0 O0 O0 O0 O0 O0 O0 000000 000000 000000 000000 I1 I1 1111 1111 11 11 11 I1 11 11 I1 11 1111 1111 11 11 11 11 1111 1111 11 11 11 11 Iillii 11 11 1111 11{1 I1 11 11 11 11 11 11 II 11 1111 111111 21 77 77 6bbbb6 44 44 6bbbb6 44 44 ..... b& 44 44 66 44 44 66 44 44 b6 44 44 66666666 44444444 6666b~66 44444444 66 66 44 66 66 44 bb 6b 44 66 66 44 6b~666 44 666666 4~ 44 44 :12) RUNNING ON LPTO -OCT-75 08: 38: 04 001{!3750,1~421) CREATED: 09:20:23 iTIARROW /FILE :FORT TO <057> PROTECTION 5555555555 5555555555 55 . 55 555555 555555 55 55 55 55 55 55 55 55 555555 555555 222222 2~2222 22 22 22 22 22 22 2Z 222g222222 2222222222 ~0 uC r-75 ICOPiE6: 3 000000 o00000 oo OO oO O0 oo o000 oo o00o oo O0 O0 Oo oo oo o0o0 oo ~000 oo oo O0 O0 OO o0o000 o00000 11 11 1111 1111 11 11 il 1.1 1I 11 11 111111 111111 20:531'00 <157> /$PACINt;: 1 /blMIT:ISb COMP.A~ [IOUNT¥ ~ A [~ A ~ A N D DA?~; 2 0 OT- 7 5 TAPF, iDgNT. 13750~,Ib42! 5fA DARD uIL, CO, UF CAI,~.;.C.U J3-b~,SwAN,StJN AIVEA COMPANY STATE ~ A {~ A B A N L) A 6ANL)$TUNE ANAL,~E~ILi STANDARD OIb COMPANY $ObDOTNA CREEK UNiT 6WANfiON RIVER K~;NA I Ab AMKA OF CAI~IFORN IA TAPE IDENT, I~750,ib421 STANDAI~D ()Ih C{.!. b,,.'3 L,D [,m LXO L,SN LIL,~ LILD LSP L, GiRL, CAL 15 14 11 0 70 7I 66 6 19 114 C~SP ARRAY 58. 67. 47. O. RW ARRAY 0.I~0 O.ISO 0.800 0.000 AT DEBt 10842. 107'I5. ID610. AT TEMP 0. O. 0. 0 TOP D~PI{~ 107'15, 10610, O, 0, OF CAf~,,q.C.tI.~I3-b~,~';WAN,SO.N {q,l, VElq 0, O, 0, 0. O,000 0,000 0,000 0,000 O, 0, O, 0, O, O, 0. 0, O. O. O. O, ROG ARRAY 2,u5 0,00 0.00 0.00 )TMA ARRAY 55,5 0,0 0,0 0.0 ~N~A ARRAY O.O00 O.O00 O.000 O.000 T 0 TOP OEP 'N O' O, O, · 0.00 0.00 0.00 0,00 0,0 0,0 0.0 0,0 0,000 0.000 0.000 0,000 O. O. O. O. 00010010 iNPUT PARAMi;TE[i5 Fi!OM 10842° TU 10590, ~MI}D XblT OITSZ BHT, BiiTDEP 5UVT R~tF RtiFT Rt'J~4F,S Pttl~F,~ DASI[..~ 9,8 0o50 6,53 165, 10a63, 50, 1,57 ~, 1,00I 0,995 O.bO0 O, O, 2,84 0.20 10842. 10590, O,O00 1,00 0,000 1~,60 20,00 0.2 V{HY PHILEV BR $t.,I~.t A~i PK $~ 8Tt)P£~ PHIiqAX PHINCL PHIDCb ,200 0,000 ,lO 0,~0 62500. 0.0 2,0 O, 0,240 0.400 0,050 0,280 124, ,029 O, O, O, O, lbo. 150, 0°75 ,1.30 EDIAM PNI, I~4 PDLIM 0.00 0,43 0,~! RLi[4 GRLIM VARHC CU~ST RtJP VA.~I,It4 10,O 1000,O O,07 0,~33 0,70 0.20 0,50 RES_[$TIVITY fiTATI~TIC~ U ~.R ~:NTIRE I~TERVAi... SONIC ~'ATI~TIC,5 OVER ~NTIRE COEFF, FROM ~TAT DET[,RMI ATIO~ IL" c;6' ~0° 60 ' OT° '! 6~'1. ~c;'L q~'L 00'0 0~'0 ~l~V3AH ' WCl2) ~O'qI 6L'gT 00'0 O0 '0 Z~*Og Oq'Og LO'OZ Lfz O~ Lg .,'q~¢flqO^ .8°0 9'0 T9 l~ O0 6~ T6 O0 96 Off 6[7 L[ OOl OOT OOT 00! ~'~l 6*L ~'OT fi*ti L 6 *ET L'ZT ['-'L L 0 1,'oT 6*gT L 8'6 6'~T ~'trT O'~T T*Ol % ~ £ ! ~OHOd 0'0 0'0 0°0 *0 0'0 ~°0 9 L fi OT OT OK O~ L°O T'O 0'~890T I o* 0'0 I 0'600.0I 0 OT o 0 0'6~qOl O'tTOOT O'OTqOl O'q6qOI '69"6 L6'6 l.g '0I Oq°OI Ot'OI 6 ~" 0 I tO'Il LI "gT gq'fi Lf'~I LO"~I L6'~t q~ q~ 'FI T~ *~'0 *8'0 ~8'0 +8'0 ~'0 ~e'O *~'0 ~'0 Oi~ f~ O~ L~ 6[ O0 E6 6[ O~ Of~ O~ 6f 9[ L[ O~ £'L 6'! {z'OT L"gT O'ql ~'Oi g'gT g'ql O"gl ~'qT l"fT 9'gT o[ 8 L Ol O! 9' o 0'0 o"o OI o 1; o1: OT OT OT O~ OT L Ol O~ Og O~ O~ Og Og OI L L L O'~LOT O't~LOI O~6TLOI O'L~LOI O'[iLOI 0. 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