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Home My WebLink About174-042PLUGGIN~ & LOCATION CLEAk~NCE REPORT State of Alaska .ALASt~. 0IL & GAS CONSERVATION COM~SSION · ~_:, ~o. 7q- ooq ~_ =: 'Il lbO, Note casing size, wt, depth, cmtTol, & nrocedur~. Review the well file, and-comment on plugging, well head sZatus,Aand location clear~ncD - orovide loc. clear, cod~. Well head cut off: · Harker oos~ or plate: Location Clearance: Code Date STATE OF ALASKA ALASKA OIL, ND GAS CONSERVATION C .4MISSION WELL COMPLETION OR RECOMPLETION REPORT 1. Status of Well Classification of Service W~l~''~ ~' ~' ~''; ~' ¢'' OIL: GAS: SUSPENDED: ABANDONED: X SERVICE: ...ii.!i'J '~ 2. Name of Operator 7. Permit Number Union Oil Company Of Califonia (UNOCAL) 74-42 . ,*~)~.ska fill 8, Gas Cons. C01 "'3. Address 8. APl Number rdi(,h0, P.O. Box 196247, Anchorage, AK 99519 50-133-20267 4. Location of well at surface Conductor No.2 Leg 3 Grayling Platform 9. Unit or Lease Name 1802'FSL, 1415' FEL,Sec 29,T9N, R13W,SM ~ Trading Bay Unit At Top Producing Interval :., ; 10. Well Number 410' FNL, 1865' FWL, Sec 29, T9N, R13W,SM . G-21 At Total Depth ~ .:: '11. Field and Pool ........ ~ 1082' FNL, 2110' FWL, Sec ~T9N, R13W, SM McArthur River/Middle Kenai "G" Zone 5. Elevation in feet (indi~,ate KB, DF, etc.) I 6. Lease Designation and Serial No. 99' KB above MSLI ADL-18730 12. Date Spudded 13. Date T.D. Reached ! 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 11/19/74 1/3/75I 5/14/98 (Abandoned)I 99' RT feet MSLI Abandoned 17. TotalDepth (MD+TVD)18. Plug BackDepth (MD+TVD)11,160, MDI9711,TVD 7873' MD/ 6920' TVD 19'Directi°nalSurveY I 20' Depth where SSSV set I21 Thickness °fPermafr°stYes: X No: feetMD N/A 22. Type Electric or Other Logs Run N/A "'2'3." CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 26" Drive Pipe 42.5 356' Driven 0 20" 94 H-90 42.5 822' 26" 779 sx 0 13-3/8" 61/68 K-55 42.5 5201' 17-1/2" 1550 sx 0 9-5/8" 40/47 N-80/P-110 42.5 11,160' 12-1/4" 2000 sx ' ' 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ,, 2-7/8" 7,896' 7,876' See Attached 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MDi I . AMOUNT & KIND OF MATERIAL USED G zones(5-8-96) and Hemlock (1/10/75) previouSly squeezed. Existing G isolated by EZSV set at 7876'. Unable to establish injection ,,, rate and received verbal variance from Blair Wiondzell 12 May 1998 (See attachment) I , 27. PRODUCTION TEST Date First Production IMethOd Of OperatiOn {FlOwing' gas lift' etc') BUPLi CATE Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD --,> Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co'r) Press. 24-HOUR RATE => 28.' CORE DATA Brief description of lithoiogy, porosity, fractures, apparen( dips and presence of oil, gas or water. Submit Core chips. ,, 310~i Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ' 30. -- GEOLOGIC MARKERS FORI~. ON TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAs. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Description of Activities Grayling G-21 Abandonment Operations commenced on Grayling G-21 on 11 May 1998. The landing joint was screwed into the tubing hangar and wireline was rigged up to effect a tubing cut above the annular top of cement. The tubing was subsequently recovered from a cut at 7,896' and a 7" EZSV retainer was set directly above the tubing stub at 7,876'. It had been intended to squeeze cement through the retainer to isolate the open G-2, G-3, G-4 and G-5 intervals. A formation integrity test was run prior to running the retainer. A test pressure of 2500 psi was placed on the open perforations and a bleed off of only 400 psi in ten (10) minutes occurred. Based on the unlikely event of being able to squeeze cement into the open perforations, it was decided that perhaps the best course of action was to install a second packer mounted on the lower portion of the whipstock to be used for subsequent sidetracking operations, directly above the retainer and rely on the 300' cemented liner lap to provide the required well isolation. (See Schematic) (Blair Wondzell with AOGCC was contacted on 12 May regarding this course of action and verbal approval to proceed was given with the stipulation that a clear drawing detailing the final condition of the well would be included with the 407 submittal) The well was subsequently sidetracked without incident and 308' of cement coverage was obtained above the whipstock packer. Whipstock Packer (5000 psi EZSV at 7876' SIZE 26" 20" 13- 3/8" 9-5/8" Tubing: 2-7/8" NO. 1.-4 5. 6. 7. 8. 9. Tubing top at 7896' Trading Bay Unit, Grayling Platform Well G-21 (Abandoned Status Pre-Redrill) 5/98 WT GRADE TOP BTM 94-g 61168# 40/47# Surf 356' H-40 Surf 822' J-55 Surf 5201' N-80/P- 110 Surf 11,160' Depth 10,361' 10,371' 10,377' 10,417' 10,451' N-80 Butt 7896' 10,428' JEWELRY DETAIL Item 2-7/8" MACCO GLM's OTIS XA (2.313" ID) OTIS BWT) Permanent Packer (4" ID) Seal Bore Extension (7.7') OTIS "X" nipple profile (2.313") OTIS WLREG (2.44") 10,870' CMT. RET. 11,004' Baker F Packer TD = 11,160' Max angle = 38° @ 10,10W G Perfs TOP HB-1 HB-2 Iq:B-3 HB-4 9902 9994 10042 10105 10228 10958 10904 10882 11042 10930 10810 10770 11060 10755 10735 10660 10540 10605 10730 10540 10478 10477 10729 Perforation Record BTM ZONE SPF DATE COMMENTS 9939 G-2 3HPF 4~98 abandoned 10034 G-3 3HPF 4~98 abandoned 10081 G4 3HPF 4~98 abandoned 10125 G4 3HPF 4/98 abandoned 10252 G-5 3HPF 4/98 abandoned 10987 HB-5 1/75 abandoned 10930 HB-5 1/75 abandoned 10900 HB-5 1/75 abandoned 11084 HB-6 3HPF 1/75 abandoned 10980 HB-5 9/89 abandoned 10850 HB-4 abandoned 10800 HB4 abandoned 11080 liB-6 9/89 abandoned 10800 HB4 abandoned 10745 HB4 abandoned 10690 HB-3 4HPF 5/75 squeezed 10590 I-t]3-2 2/80 squeezed 10635 HB-2 5/75 squeezed 10840 HB-4 4HPF 2~80 abandoned 10580 HB-2 squeezed 10506 HB- 1 4HPF 2~80 abandoned 10505 HB-1 abandoned 10859 HB4 abandoned CompletionG-21 tffter abandonment (State).rtf REVISED: 6/4/98 DRAWN BY: DNIvl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Plugback for Sidetrack WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil ~] Gas [] Suspended [] Abandoned [] Service , 2'. Name of Operator ...................... 7. Permit Number ..... ARCO Alaska Inc. 83-21 397-234 3'." Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20324-01 4. Location of well at surface , ,~--,,.,,,,.,~ 9. Unit or Lease Name 2171' NSL, 31' WEE, SEC. 14, T10N, R14E, UM ~i: Prudhoe Bay Unit At top of productive interval ~ ~1~1~_ 10. Well Number 4389' NSL, 1814' EWE, SEC. 13, T10N, R14E, UMi~~,~,- 13-02A At total depth 4544' NSL, 2120' EWE, SEC. 13, T10N, R14E, UM .~! 1 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay 51'" Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool RKB = 86'I ADL 028315 i";). Date Spudded. 2/4/83 I13.Dat~.~.D.~eached~14.Da.t.eC~.mp.~Susp.~r^ban~.[15.Wat~r~epth~`f~sh~e~1.6.N~.~fC~mp~et`~s~ 2/16/83 1/10/98 .... N/A M.SL, Zero 17. Total Depth (MD'~TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Deptl~' where SSSV set 121. Thickness of Permafrost 10300 9251 FT] 10001 9026 FT] []Yes []No! N/A MDI. 1900' (Approx.) 22. Type Electric or Other Logs Run CBL, DIE / BHCS / GR / SP, EDT / CNL / GR, Cai, Dia-Log Cs9 Profile, ETT, CBL, CRT , 2..,.3,'. CASING, LINER AND CEMENTING RECORD CASING SE'FI-lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 127' 24" 167 sx Arcticset II ,, 13-3/8" 72# N-80 Surface 2741' 1 -~'~1/2';' 760'0 s~"ArctiCset II ,,, 9-5/8" 47# N-80 Surface 9194' 12~1/4" 1000 sx Class 'G' 7" 29# L-80 3460' 10298' 8-1/2" 1272 sx Class 'G' .............. , .............. 24. perforations open to Production (MD+TVD of Top an(J' 25. TUBING RECORD ,,, Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 3_1/2,,, 913#, i3Cr~8© 9450' 9619' 9490' MD TVD MD TVD ... .... 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9513' P&A, 33 Bbls of Class 'G' 9185' Set EZSV & Whipstoc[< 3419' Set Bridge Plug & 2nd Whipstock ...... 27. ' ..... pRoDUcTION TEST .... ....... Date First Production I Method of Operation (Flowing, gas lift, etc.) Not on Production I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE-IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing PresSUre CALCULATED 0iL-BEE GAs-MCF WATER-BEE OIL GRAVITY-APl (CORE) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or Water. Submit core chips. DUPLICATE .: ,,, Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests ..... Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GQR, and time of each phase. Top of Sadlerochit 9782' 8863' O/W Contact 10120' 9115' :~1. List of Attachments Summary of Daily Drilling Reports ?~e and correct i° the best of my knowledge 3~'2. I hereby certify that the foregoing is~, "" Signed ~:~--------------~----- ~,~ ~--~- '"---~:-- ... Dan Stone ....... Title Engine..ering Supervisor .... Date ...... 13-02A 83-21 397-234 Prepared By Name/Number: Terrie Hubble, 564-4628 _ Well Number Permit No. / Approval No. ............ ~NSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other ~paces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,. Shut.~-!n, Other-explain. ITEM 28: if no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 .~' 13-02A DESCRIPTION OF WORK COMPLETED PRE RIG SIDETRACK CEMENT PLUG & ABANDONMENT 1/10/98: A CTU Cement Plug was pumped to Plug & Abandon the lower wellbore prior to Rig Sidetracking as follows: MIRU CTU & PT equipment to 4000 psi. RIH w/nozzle & loaded wellbore w/KCI Water, Meth Water, & Crude. Tagged PBTD at 9873' CTM. Spotted 13 bbls of 15.8 ppg Neat Class G Cement to plug & abandon the open perforation intervals located at: 9659 - 9679' MD (Sag) 9840- 9860' MD (Z4) 9870- 9900' MD (Z4) Ref. Log: BHCS 2/18/83. Pumped an additional 2 bbls of Neat Class G Cement, followed by 7 bbls Class G Cement w/aggregate, followed by 11 bbls of Neat Class G Cement, and placed a total of 15 bbls of cement behind pipe at 1500 psi max squeeze pressure. Contaminated cement w/biozan & jetted contaminated cement from wellbore to 9525' MD. POOH w/CT. Left 500 psi on wellhead. RD. 1/11/98: RIH & tagged TOC at 9513' MD. 1/12/98: RIH w/cutter & cut tubing at 9450' MD. Left the lower wellbore Plugged & Abandoned w/cut tubing for Rig Sidetrack to 13-02B. Facility PB DS 13 Progress Report Well 13-02B Page ! Rig Doyon 14 Date 06 May 98 Date/Time 19 Jan 98 20 Jan 98 21 Jan 98 22 Jan 98 23 Jan 98 00:01-00:30 00:30-02:00 02:00-04:00 04:00-06:00 06:00-08:00 08:00-12:00 12:00-12:30 12:30-13:30 13:30-18:00 18:00-21:30 21:30-02:00 02:00-03:00 03:00-05:30 05:30-06:00 06:00-09:30 09:30-11:00 1 I:00-12:00 12:00-12:30 12:30-14:30 14:30-14:45 14:45-17:00 17:00-18:00 18:00-19:00 19:00-20:00 20:00-22:30 22:30-00:00 00:00-03:00 03:00-04:30 04:30-06:00 06:00-13:30 13:30-14:30 14:30-15:30 15:30-16:00 16:00-19:30 19:30-21:30 21:30-22:30 22:30-00:00 00:00-01:00 01:00-01:30 01:30-06:00 06:00-07:00 07:00-08:00 08:00-08:30 08:30-09:30 09:30-16:00 16:00-16:30 16:30-17:00 17:00-19:30 19:30-22:00 22:00-22:15 22:15-23:00 23:00-01:30 01:30-02:00 02:00-03:00 Duration 1/4 hr 1-1/2 hr 2 hr 2 hr 2 hr 4 hr 1/2 hr 1 hr 4-1/2 hr 3-1/2 hr 4-1/2 hr I hr 2-1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1 hr 1/2 hr 2 hr 1/4 hr 2-1/4 hr I hr 1 hr 1 hr 2-1/2 hr 1-1/2 hr 3 hr 1-1/2 hr 1-1/2 hr 7-1/2 hr 1 hr 1 hr 1/2 hr 3-1/2 hr 2 hr 1 hr I-1/2 hr 1 hr 1/2 hr 4-1/2 hr 1 hr 1 hr 1/2 hr 1 hr 6-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 1/4 hr 3/4 hr 2-1/2 hr 1/2 hr I hr Activity Held safety meeting Rigged down High pressure lines Rig moved 15.00 % Rig moved 40.00 % Rig moved 65.00 % Rig moved 85.00 % Held safety meeting Rig moved 100.00 % Rigged up Lines / Cables Removed Accessories Circulated at 9450.0 ft Installed Accessories Removed Xmas tree Rigged up BOP stack Rigged up BOP stack Rigged up Pipe ram Rigged up Bell nipple Held safety meeting Tested Choke manifold Tested Blind ram Tested Top ram Retrieved Accessories Retrieved Accessories Installed Well control Installed Tubing retrieval string Laid down 80.0 ft of Tubing Retrieved Seal assembly Removed BOP stack Removed Seal assembly Rigged down Seal assembly Installed Seal assembly Rigged up BOP stack Tested Seal assembly Tested BOP stack Injected packing Tested BOP stack Rigged down sub-surface equipment - Other sub-surface equipment Rigged up Tubing handling equipment Circulated at 9370.0 ft Laid down 2200.0 ft of Tubing Rigged down sub-surface equipment - Other sub-surface equipment Laid down 1129.0 ft of Tubing Rigged up Tubing handling equipment Serviced Block line Laid down 6094.0 ft of Tubing Removed Tubing handling equipment Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Removed Logging/braided cable equipment Tested Casing Rigged up Top ram Installed BOP test plug assembly Tested Top ram Facility PB DS 13 Progress Report Well 13-02B Rig Doyon 14 Page 2 Date 06 May 98 Date£Fime 24 Jan 98 25 Jan 98 26 Jan 98 27 Jan 98 03:00-03:30 03:30-06:00 06:00-07:30 07:30-10:00 10:00-10:30 10:30-16:00 16:00-18:00 18:00-19:00 19:00-00:00 00:00-01:30 01:30-04:00 04:00-06:00 06:00-08:30 08:30-11:00 11:00-11:30 11:30-16:30 16:30-17:00 17:00-06:00 06:00-14:30 14:30-16:00 16:00-18:00 18:00-19:30 19:30-20:30 20:30-23:00 23:00-00:00 00:00-0I :30 01:30-02:30 02:30-02:45 02:45-03:00 03:00-06:00 06:00-06:30 06:30-16:30 16:30-17:00 17:00-18:30 18:30-21:00 21:00-22:00 22:00-01:00 01:00-02:30 02:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:00 08:00-09:00 09:00-11:00 11:00-14:00 14:00-14:30 14:30-16:00 16:00-19:00 19:00-20:00 20:00-20:30 20:30-21:30 21:30-22:30 Duration 1/2 hr 2-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 5-1/2 hr 2 hr I hr 5 hr 1-1/2 hr 2-1/2 hr 2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 5 hr 1/2 hr 13 hr 8-1/2 hr 1-1/2 hr 2 hr 1-1/2 hr 1 hr 2-1/2 hr 1 hr I-1/2 hr 1 hr 1/4 hr 1/4 hr 3 hr 1/2 hr 10 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1 hr 3 hr 1-1/2 hr 2-1/2 hr I hr 1/2 hr 1/2 hr 1/2 hr I/2 hr I hr 2 hr 3 hr I/2 hr 1-I/2 hr 3 hr I hr 1/2 hr I hr 1 hr Activity Serviced BOP test plug assembly Made up BHA no. 1 Made up BHA no. 1 R.I.H. to 3470.0 fi Circulated at 3470.0 fi R.I.H. to 9100.0 fl Circulated at 9185.0 fl Circulated at 9163.0 fi Drilled to 9192.0 ft Circulated at 9192.0 ft Pulled out of hole to 912.7 ft Pulled BHA Made up BHA no. 2 R.I.H. to 9177.0 fi Reamed to 9192.0 ft Drilled to 9264.0 ft Took MWD survey at 9225.0 fi Drilled to 9430.0 ft Drilled to 9521.0 ft Circulated at 9521.0 ft Pulled out of hole to 1093.0 fl Pulled BHA Made up BHA no. 3 R.I.H. to 9408.0 ft Reamed to 9521.0 fi Pulled out of hole to 9100.0 fi Circulated at 9100.0 ft Laid down 256.0 ft of 3-1/2in OD drill pipe R.I.H. to 9200.0 ft Reamed to 9459.0 ft Set tool face Drilled to 9649.0 ft Took MWD survey at 9649.0 ft Circulated at 9649.0 ft Pulled out of hole to 1049.0 ft Pulled BHA Tested BOP stack Made up BHA no. 4 R.I.H. to 8794.0 ft Serviced Block line Circulated at 9163.0 ft R.I.H. to 9286.0 ft Reamed to 9390.0 ft R.I.H. to 9598.0 ft Washed to 9649.0 ft Set tool face Pulled out of hole to 1091.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 9350.0 fl Reamed to 9488.0 fl R.I.H. to 9598.0 ft Washed to 9649.0 ft Circulated at 9649.0 ft · Nell Megee · PO Box 196347 ~78 10ffl~ 263-78~. To: Blair Wondzeil Fax.. 276.7542 AOGCC From= Dan Willlamson/Neil Magee Date: 5/12/98 Union O11 Company Grayling G-21 RD Page; 3 including this cover shee! CC: Uq~ent For Fbview Please Com~ pleaae Reply Pleaae Ftecycle Blair, attached is the original proposed abarx~nrnent of G-21 and well as the proposed revision. The revised proposal is due to out our inability to effectively ~ueeze the "G" zone per[orations below the retainer. We attempted establish an injection rate and we had no pressure bleed off at 2500 psi. (Clear water was in the hole at the time) What we are proposhg to do is to set an EZSV approximately 20' abow the lublng stub at 7896' (the tubing has annular cement up to approximately 8046' based on a free mint which was performed yesterday, Fellowlng this we will be setting a whipstock approximately 35' atx)ve the EZSV which Incorporates a packer element desil~ed to withstand 5000 psi differential pressure, Once the open hole section of the well has been drilled we will cement back the liner allowing at least a 300' cement lap from the base of the whipstock to the top o~ the liner, It is desired to set 1he whipslock as deep as possible due to a series of coal stringers shallower in the well which will hamper.our re-drill efforts,'.~ R ~ ~'~ ~ V E We will call you later this morning to discuss the details of our plan, Dan wilramson/Nell M~gee .5'/~ ~/"~8 ~iaska 0ii & Gas G0ns~ 263-7677 or 263-7671 Rnch0rage i! i il i, i' ,:.' ?'..' """ · · · · · i · · · · · · · · · · · · ~ ~ ~i ,L , NfiRq'o~J , ~Nq qwqn~ln i^lw~n, n i (~cR F_.ZSV at 9~00' 10,870' CMT. l~ET. 11,004' Baker F Packer TD = 11,160' Max arkie = 38° ~ 10,200' III~IIIU. ............................ Tubin8 top at 9550' Trading Bay Unit, Grayling Platform Well G-21 (Proposed Abandoned Status Pre-Redrtll) 5/98 ....... LL3~ i iii _ _~ .............. 11,,1 · _ ~iT.J~ .......... WT GRAD_~ ..... TOP.,., BT~ 26" Surf 356' 20" 94~ H~ S~ 822' 13-3/8" , 61/~8~ J-55 S~ 5201' 9.5/8" ~/47~ N-80~- 110 S~ 11,160' Tubing: 2-7/8" d.4~ N-80 BuI~ 9950' 10,428' NO. I.-2 3. 4.. 5. 10,361' 10,371' 10,377' 10,417' I0,451' JEWELRY DETAIL Item 2-7/8" MACCO GLM's OTIS XA (2.313" ID) OTIS BWD P~r~ Packer (4" ID) Seal Bore Extension (7.7') OTIS "~' nipple profile (2.313"~) £ ¢ E I V E D P..grforaflon Record G Peffs TOP BTM__ ZONE 9902 9939 O.2 3HPF 9994 10034 O-3 3HPF 10042 10081 0-4 3HPF 10105 10125 0-4 3HYF 10228 10252 0-5 3HPF HB,1 10958 10987 HB-5 10904 10930 I-IB-$ HB-2 10882 10900 HB-5 HB-3 II042 11084 HB-6 3HPF 10930 10980 HB-5 HB.4 10810 10850 HB-4 10770 10800 HB-4 11060 11080 HB-6 10755 108OO HB-4 I-~-5 10735 10745 I-[B-4 10660 10690 I-IB-3 4HPF 10540 10590 I-[B-2 10605 10635 HB-2 HB-6 10730 10840 H]B-4 4HPF 10540 10580 HB-2 10478 10506 HB-I 4I-~F 10477 10505 I-.IB- 1 10729 10859 HB.4 12 1998 Anchorage SPF ....... I),ATE COMMEN~ 4198 abaudoued 4t98 abandoned 4/98 abandoued 4/98 abandoned 4/98 abaa~ed 1175 abandoned 1/75 abandoned 1/75 abandoned 1/75 abandoned 9/89 abandoned abandoned abandoned 9/89 abandoned abandoned abandoned 5/'75 squeezed ~80 squeezed · 5/75 squeezed ~80 abandoned squeezed ' 2/80 abandoned abandoned aN~doned CompledonG-21 after abandonment.rtI' REVIgED: 5/6/08 DRAWN BY: DNM Whipstock Aad Packet ($000 psi ratin BF3V at 7876' 7" liner vdth 300' overlap SIZE 20" 13-3/8" 9-5/8" Tubing: 2-7~8" Trading Bny Unit, Grayling Platform Well G-21 (Proposed Abandoned Status Pre. Redrill) 5/98 .......... . ...... '- III . Illll I ...... IIIII III _W..T ....... GRADE TOP BTM Surf 356' 94g H-40 Surf 822' 61/68# J-55 Surf 5201' 40/47# N-80/P- 110 Surf 11,160' 6,4~ N-80 Butt 9950' 10,428' NO. Depth 1.-4 5, 10,361' 6. 10,371' 7, 10,377' 8. 10,417' 9. 10,451' JEWELRY DETAIL Item 2-7/8" MACCO 'GLM'S OTIS XA (2.313" ID) OTIS BWD Permanent Packe~ (4" ID) Seal Bore Extension (7,7') OTIS "X" nipple profile (2.313") OTIS WLREG (2.44") 10,870' CMT. RET. 11,004' Baker F Packer Tubing tOp at 7896' ~ ~ -3 q~ ~' Perfo .m_t~gn R~ord O ~fs ~ TOP BTM ZQNE' sPF ___DATE COMMENTS 9902 9939 (I-2 3HPF 4/98 abandoned 9994 10034 G-3 3HPF 4/98 abandoned 6 ~ [0~2 '/I 10042 10081 04 3HPF 4198 abandoned 10105 10125 0-4 3HPF 4~98 abandoned 10228 10252 G-5 3}iPF 4~98 abandoned HB.1 10958 10987 HB-5 1/75 abandoned 10904 10930 HB-5 1/75 abandoned I-lB.2 10882 10900 1-13-5 1/75 abandoned I4It-3 11042 11084 I-IB-6 3I-tPF 1/75 abandoned 10930 10980 HB-5 9/89 abandoned HB-4 10810 10850 I-IB4 abandoned 10770 10800 HB-4 abandoned 11060 11080 I-lB-6 9~89 abandoned 10755 10800 HB-4 abandoned HB-5 10735 10745 12111-4 abandoned 10660 10690 HB-3 4I-tPF 5/75 squeez~l 10540 10590 . ttB-2 2/80 squeezed 10605 10635 HB-2 5/75 squeezed ItB-6 10730 10840 I.~..4 4HPF 2/80 abandoned 10540 10580 HB-2 squeezed 10478 10506 HB-I 4HPF 2/80 abandoned 10477 10505 ItB-1 abandoned 10729 10859 ItB-4 abandoned TD = 11,160' Max angle ,~, 38° ti~ 10,100' CompletionO.21 after abandonment (State).rff REVISED: :5/12198 DRAWN BY: DNM -. STATE OF ALASKA ALASKA OIL, ,ND GAS CONSERVATION MMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator · 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 99' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Anchorage, AK 99519 Stratigraphic: Trading Bay Unit Service: 4. Location of well at surface Conductor No.2, Leg 3 Grayling Platform 8. Well number 1802' FEL, 1415' FEL, Sec 29, T9N, R13W, SM G-21 At top of productive interval 9. Permit number 410' FNL, 1865' FWL, Sec 29, T9N, R13W, SM ,~.,..,.~ 74-42 At effective depth~1~11~ 1'~1;~~ 10. APl number 707' FNL, 1978' FWL, Sec 29, T9N, R13W, SM 50-133-20267 At total depth 11. Field/Pool 1082' FNL, 2110' FWL, Sec 29, T9N, R13W, SM Mc. Arthur River/Middle Kenai "G" Zone 12. Present well condition summary Total depth: measured 11,160' feet Plugs (measured) Cement Retainer at 10,870' (9-5/8" casing) true vertical 9,711' feet Cement Retainer at 7,750' (9-5/8" casing) Effective depth: measured 10,257' feet Junk (measured) Baker H-1 retainer set at 10,257' (2-7/8" tbg) true vertical 8,958' feet Multiple Wireline Fish at 10,091' (2-7/8" tbg) Casing Length Size Cemented Measured depth True vertical depth Structural 356' 26" Driven 356' 356' Conductor 822' 20" 779 sx 822' 715' Surface 5,201' 13-3/8" 1,550 sx 5,201' 4,524' Intermediate Production 11,160' 9-5~8" 2,000 sx 11,160' 9,711' Liner Perforation depth: measured G-2 (9902'-9939'), G-3 (9994'-10034'), G-4 (10042'-10081',10105'-10125'), G-5(10228'-10252') true vertical G-2 (8677'-8707), G-3 (8750'-8782'), G.4 (8789'-8821', 8836'-8852'), G-5 (8934'-8954') Tubing (size, grade, and measured depth) 2-7/8" 6.41btff, N-80Buttress@10,452' IF)LimiL,/_, IrlT . Packers and SSSV (type and measured depth) Otis "BWD" Permanent packer set at 10,372' Otis SSSV at 312' ~"';~:":'; ':~ :" .' ,'.' . '.i:.",;¢J~ !~::'~!;:. ':~ 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 4/14/1998 16. If proposal well verbally approved: Oil: X' Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approvah Notify Commission so represe,n~,ative may witness IApproval N,~.~ ~,~)..., Plug integrity BOP Test ~' Location clearance Mechanical Integrity Test Subsequent form required 10- '-/~ '~ Original Signed Approved by order of the Commissioner ~ W. Johnston Commissioner Date · Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Grayling Well G-21 Summary of Proposal The existing completion in Grayling G-21 will be abandoned to allow for the sidetracking and re-drilling of the well to allow for access to additional "G" zone interval and Hemlock formation. This Application for Sundry Approval covers the preliminary abandonment operations. Based on pressure data fresh water will be suffiCient for'use as the abandonment fluid however there will be LCM available onboard to combat fluid losses to the formation should they be encountered. The existing completion will be squeezed off entirely from a depth of 7,750' through to the existing "G" zone perforation intervals. The Hemlock perforations have been previously abandoned as per the attached well schematic. The future re-drill work will entail sidetracking the well from approximately 7,000'. Grayling Well G-21 Proposed Abandonment Hazards: Lost Circulation Zones: None Low Pressure Zones: None Over Pressure Zones: None Time Estimate Cumulative Preliminary Procedure Time 2.0 2.0 Skid Rig 10.0 12.0 Rig Up (Well Previously Killed) 2.0 14.0 Check for tubing pressure and set BPV 8.0 22.0 N/U and test BOP's 4.0 26.0 P/U landing joint and screw into hangar 2.0 28.0 Pull tubing loose from cut at 8,000' 6.0 34.0 Displace tubing/well annulus with FIW 16.0 40.0 POOH laying down tubing 18.0 58.0 RIH and set EZSV at 7,750' ~t ,9 ~" c~jr 4.0 62.0 Squeeze "G" perforations and fill annulus with cmt. 4.0 66.0 POOH with EZSV setting tool .Prepare for sidetrack operations Trading Bay Unit, Grayling Platform Well G-gl Current Completion, 2/98 SIZE WT GRADE TOP BTM 26" Surf 356' 20" 94# H-40 Surf 822' 13-3/8" 61/68# J-55 Surl' 5201' 9-5/8" 40/47# N-80/1)~ 110 Surf 11~ 160' TO( ¢*> 7,700'?' "tSsh' Gun Assr 10,870' CMT, RIT. 11,004' Baker i: Packer DV at 2,595' 19-5/8'~ TOC (w 9700' G Peri','; 16 17 HB-I itB-2 HB-3 [ lB -4 t1B-6 TD = 11,160* Max angle = 38° ~* 10,1110' Tubing: 2-7/8" 6.4# 4.4/2" 12.6# N-80 Bult 82.4 I' l (L428' N-g0 Butt Tbg. Hangar. 82.41' JEWELRY DETAIL Item NO. r~e_~_m 1. 42.7' 2. 82.4~ 3. 4. 311.7' 5.-14. 15. 10,361' 16. 10,371' 17. 10,377' 18. 10417' 19. 10,451' Pedbration Record 4-1/2" EUE x BTC TBG Hangar 4-i/2" i2,6 lb/Il Butt Tbg (l joint) 2-7/8" 6.4 lb/ft Burl Tbg Otis XXO SSSV. (No valve ilxqlalled) 2-7/8" MACCO GLM~s OTIS XA 12.313" 1D) OFfS BWD Permanenf Packer (4" Il)) Seal Bore Exlensk)n 17,7') OTIS "X" nipple profile 12,313 ') OTIS WLREG TOP BTM ZONE SPF DATE COMMENTS 9902 9939 9994 10034 10042 10t18 l 10105 10125 10228 10252 10958 10987 10904 10930 10882 10900 11042 11084 10930 10980 10810 10850 10770 10800 11060 11080 10755 10800 10735 10745 10660 10690 10540 10590 10605 10635 10731/ 10840 11t540 10580 I(~78 10506 1134.77 10505 10729 10859 (3-2 3IIPF 4/96 open (}-3 31fPF 4/96 open G-4 3ilPF 4/96 open G4 311P1;' 4/96 open G-5 3HPF 4/96 open liB-5 1/75 abandoned HB-5 1/75 abandoned HB-5 1/75 abandoned lfB~6 3HPF 1/75 abandtmcd ~-5 9/89 abandoned tlB~4 abandoned I ~-4 abandoned HB-6 9/89 abandoned HB-,4 abandoned HB-4 abandoned HB-3 4HPF 5/75 squeezed HB-2 2/80 squeezed ItB-2 5/75 squeezed HB-4 4HPF 2/80 abandoned ltB-2 squeezed HB-1 4HPI: 2/80 abandoned HB- i abm~doned HBo4 abandm~ed CompletionG~21 .rtf. rtl REVISED: 3/4/98 DRAWN BY: DNM 5" KILL. L~NE WITH TWO 3" 5.~ VALVES l ;I", ;i/, KiLL LINE FROM MUD PMF &: CEMENT' UNIT NIPPLE '~3-5/8" riO00 Psi ANNULAR i rq_OWLINE L PiPE RAMS BL[NO RAMS 1 I PIPE RAMS 13-5/8" 5,k{ FLANGE 00UBLE GATE 5M 13-5/8" 5W FLANGE ~," CHOKE LINE WITH ONE REMOTE & I ,~NUAL 4" 5M VALVE (,!?' ] CONNECT-'~ TO CHOKE MANIFOLO (SEE MANFOLD DRAWING) i3-5/8" 5M FLANGE SINGLE GATE 5M L ,,, t t3-5/8" 5M FLANCE RISER ,1 10" 5M x 15-5/8" ADAPTER CAMERON 5M SPOOL ~5-5/a" soPE 5M STACK gRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) r' '©RAWN: OAC; SCALE: NONE TO GAS FIUSTE1R /\ CHOKE 'FO WELL CLEAN TANK AUT0,UATIC CHOKE FROM CHOKE LINE VALVES UPSTREAM OF CHOKES ARE 10,000 PSf GATE TYPE VALVES 0CFC/N~~.U OF CHOKES ARE .5,000 PSi GATE TYPE CHOKE NtANIFOLD GRAYLING PLATFORM UNION OIL CONtPANY OF CALIFORNIA (dba UNOCAL) DRAWN: OAC APF:'D' CS8 SCALE: NONE oxrz: 11/~/~ MIXIN~ PIT ~ 0 BBLS MIXIN0 LEVEL ACTIVE PIT IS A ONE BELOW THE SYSTEM TRIP 4-5 TANK BBLS 'I' 185 BBLS VOLUME PIT 185 BBLS SUCTION PIT 125 BBLS 3EGASSER! 67 BBLS ! DESILTER ! 24-0 BBLS SI-lAKER SHAKER i .............. tc,-m-r~,z RESERVE PiT ¢75 BBLS HOTE: THE SYSTEM WILL BE EQUIPPED WITH A DRILLING PIT LEVEL AUDIO ,a,4: VISUAL WARNING DEVICES. INDICATOR WITH EQUIPMENT LIST 1) RESERVE PIT 2) DEGASSER 3) (2) S~KERS 4) PIT LEVEL INDICATOR (VIStIAL ~ AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PIT AGITATORS a) DESlLTER fl) CENTRIFUGE 10) MIXING PIT UNOCAL GRAYLING MUD PiT DRAWN BY: DAC APP'D: GSEI SCALE: NONE DATE: 1 SCHEMATIC Unocal Energy Resources DJ: 909 West 9th, P.O. BOX 1962,., Anchorage, AK .9951,9-6247 TeJephone (909) 276-7600 Fax (907) 233-7828 Debra Childers Clerk · DATA TRANSMITTAL '96-i3 June 6,1996 Howard Oakland AnChOrage, AK 99501 ..... From: "' Debra Childers 909 W. 9th Avenue I Anchorage, AK 99519-6247 ,. tUnocal ...... Transmitting the following items. Gran'ite R°in.'.t / Ann. a-21 fi1¢¢I~ blacklin, e"' Completion Record ..... 4/01/96 Granite P.0int / Anna-26 f'fl'm / blackline ~Tubing Packer Setting Record 4/20/9.6 .... Granite Point/Anna-36f~' "~/blacktine/ Comple!ion'Record 5/20/96 Granit 'Point/42-23 RD f~m/blaCkline;*''' Perforati~ng Depth Control 2/17/96 Trading Bay Unit K-26 RD" film,,/,blackline,,,, Main Pass (Collar Locator) 3/23/96.. Trading Bay Unit .M-.5 ¢if;m / bla~l~li'ne,..,r Completion Record .... 2./.14/96 T.radiqg Bay Unit...M-.2. 5 ~ / blackline'-"~Completion Record 4/24/96 Trading Bay.Unit..M-25 ~'1~'/blackline~--Completion Record 4/30/96 Trading Bay Unit G-21 ¢ilm~,~blackline'~' CCL/Gamma Ray 4/03/96 Trading Bay Unit. G-21 fi~--f blackline..," Cemer~t Retainer '4/08/96 Trading.Bay Unit G-2'~ " .~'rr~ / blackline'"' Completion Record 4/13/96 Trad!.ng Bay Unit G-21 ~'/blacklinet,-- Completion Record 4/18/96 Trading Bay Unit G:2.1 . ~ / bla'cklin~--'! Completion Record I 4/2'2/96 ' .Trading. Bay Unit G-21 ¢fflm / bla.ckline..~--! Com~oletio'n Record ! 4/25/96 , , .... Trading Bay Unit G-21 iCi-t~,m / b~o.'~- ~-~--~i, , ......... , C-.~m~:~:..n'-"~ ,.,~.~,.~,~. ~ .... ~"~ i/3 Energet '~'"~F I ~ "~ 5/96 '"1' t i Trading Sa)/Unit G-21 ~ / blackline,-- G.amma Ra~,~T.e.mperature ..... 4/10/96 Tradi.ng Bay..unit G-21 ' ~ / btacklin~''' Tubing Cutter 4/08/96 -'-"~-' '-'7 '--'*'/S C t~ ~,,.{l -"H ¢fl'm / bla~kline ! Completion Record 5/17/96 .............. . ............... ..... " 't ,,, ,, ,, J,,, , ,, ,, ,, ,, , , , , , , , , RECEIVED to (907) 263-7828 . STATE OF ALASKA ALASKA O,-AND GAS CONSERVATION L, OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Name of Operator 7.~mber 3. Address 8. APl Number P. O. BOX 19-2647 ANCHORAGE, AK 99519-2647 50- 733-20267-00 4. Location of well at surface 1802' N & 1415' W of SE Corner, Sec. 29, T9N, R13W, SM At Top Producing Interval At Total Depth 5. Elevation in feet (indicate KB, DF, etc.) 103' 6. Lease Designation and Serial No. 9. Unit or Lease Name Trading Bay Unit 10. Well Number G-21 11. Field and Pool McArthur River/Hemlock 12. Date Spudded I 13' Date T'D' Reached I 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °fish°re I 16' N°' °f C°mpleti°ns4/8/1996 4/25/1996 feet MSL None 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11160' MD 9711' TVDI 10257' MD 8956' TVD Yes: No: I 312 feet MD NA 22. Type Electric or Other Logs Run GR/CCL 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. 26" 13-3/8" 9-5/8" 3-1/2" 9.2 GRADE N-80 SETTING DEPTH MD TOP 1 6BOTTOM35 1822 15201 111160 ~10351 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) All previous casing perforations are cemented. The new"G" Zone through tbg. perforation intervals were shot at 3HPFand are located at: 9902 - 9939; 9994 - 10034; 10042 - 10081; 10105 - 10125; 10228 - 10252' MD & 8676 - 8705; 8749 - 8780; 8787- 8817; 8836 - 8852; 8933 - 8952' TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED Driven None None 24" 779 sx None 17-1/2" 1550 sx None 12-1/4" 2000 sx None NA 225 sx None 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 10351 None 3-1/2" 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) II AMOUNT & KIND Of MATERIAL USED 10434' - 10844' Plug #1 31 Bbls Cmt. 9700' - 10257' Plug #2 46 Bbls Cmt. Tbg/Csg Annulus 10257' - 10351' Plug #2 Tbg Annulus & Csg Annulus 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Gas Lift Date of Test 4/26/96 Hours Tested 20 PRODUCTION FOR TEST PERIOD --> OIL-BBL 249 GAS-MCF 163 WATER-BBL 247 CHOKE SIZE I GAS-OIL RATIO 14/64"I 653 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 90 1005 24-HOUR RATE => 299 195 296 3.18 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL RECEIYEO Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. RECEIVED MA, Y 5 0 1996 Alaska 0it & Bas Con{. c0mmismi0n Anchorage 31. LIST OF A'I-I'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .~-'b~_ ~'~I~ TitleiSt. ~~ Date_' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 TRADING BAY UNIT G-21 DAY 01-03 (3/30-4/1/96) ~ RU HALLIBURTON SLICKLINE TO DRIFT TUBING. PUMP 250 BBLS. FIW DOWN TUBING. MADE 2 RUNS W/2.4" WIRE SCRATCHER TO EOT @ 10,451'. RIH W/2.25" DRIVE DN BAILER. UNABLE TO GO DEEPER THAN 10,290'. RIH AND LATCH VALVE FROM MANDREL @ 9606' RKB. CIRCULATE FIW VIA MANDREL. RIH W/ 2.16 GAUGE RING TO 10,325'. RIH W/5'X 1.875" BAR ON TOOL STRING TO 10,451'. RD HALLIBURTON. DAY 04 (4/3/96) RU SCHLUMBERGER. ATTEMPT GR/CCL RUN TO TD. UNABLE TO PASS 10,270'. RECONFIGURE TOOL AND SUCCESSFULLY RUN TO TD @ 10,844'. RUN CORRELATION PASSES. EOT 23' SHALLOW TO COMPLETION SCHEMATIC. PU TUBING PUNCHER. RIH, UNABLE TO PASS 10,367'. RECONFIGURE PUNCHER STRING WITHOUT SUCCESS. DAY 05 (4/4/96) CIRCULATE FIW TO COOL TUBING STRING. REATTEMPT TO RUN MODIFIED TUBING PUNCHER STRING, WITHOUT SUCCESS. CONTACT AOGCC AND SECURE APPROVAL TO OMIT PERFORATING TAILPIPE. OFFLOAD DOWELL CTU EQUIPMENT AND SPOT SAME. DAY 06 (4/5/96) RU 1-1/2" CTU EQUIPMENT. CUT COIL AND PRESSURE TEST BOP TO UNOCAL SPECIFICATIONS. AOGCC WAIVED WITNESSING TEST. RIH W/1-1/2' NOZZLE PUMPING AT 1/4 BPM. NO RETURNS. UNABLE TO PASS GLM @ 9,547' CTM. POOH. DAY 07 (4/6/96) RU HALLIBURTON SLICKLINE AND INSTALL VALVE IN GLM. RDSLICKLINE. RU CTU. CHANGE NOZZLE TO 1-3/4". PRESSURE TEST STACK AND RISER. RIH PUMPING @ 1 BPM W/80- 90% RETURNS. TAG BOTTOM @ 10,821' CTM. PU TO 10,811 CTM. BATCH MIX 31 BBLS/190 SX (USABLE) CLASS G CEMENT W/.21 GPS D-80, .54 GPS D-159, AND .025 GPS D-47 @ 15.8 PPG. -~ PERFORM FLUID LOSS TEST, OK. PUMP CEMENT TO COIL END AND PLACE CEMENT IN CASING. PUMPED CONTAMINANT IN DISPLACEMENT TO ELIMINATE ANY CEMENT IN TUBING. CIP 2200. POOH RD CT. MAY 5 0 1996 Anehor~le DAY 08 (4/7/96) WOC FOR 18 HOURS AND PRESSURE TEST TUBING AND ANNULUS TO1500 PSI FOR 30 MINUTES. RU HALLIBURTON. RIH AND TAG CEMENT @ 10,434' SLM. TOC ABOUT 6' BELOW TUBING TAIL AND 50' ABOVE TOP PERFORATION. CONTACT AOGCC AND SECURE APPROVAL TO PROCEED WITH WORK. CHANGE TOOLS AND RIH W/2.126" TOOL STRING TO 10,434'. POOH, RD SLiCKLINE. RU SCHLUMBERGER. DAY 09 (4/8/96) RIH W/2-1/16" TUBING CUTTER ASSY. MAKE CORROLATION PASS AND FIRE CUTTER @ 10,351' (ELM). GOOD INDICATION OF DETONATION. POOH, CUTTER EXPENDED, RD SOS. RU & PUMP 120 BBLS 90 DEG F WATER DOWN TUBING. REVERSE 200 BBL WATER INTO ANNULUS. PUMP 400 BBLS 90 DEG WATER INTO TUBING. RU SLICKLINE & RIH W/2.25" GAUGE RING. STOP @ 10,265' SLM. POOH. RU SOS & RIH W/2.25" BAKER MODEL H RETAINER. UNABLE TO PASS 10,261' ELM. PU AND SET RETAINER @ 10257' ELM. POOH, RD SOS. RU DOWELL AND RIH W/CEMENT STINGER. DAY 10 (4/9/96) RIH & STAB INTO RETAINER @ 10,234' CTM (10,257' ELM). BATCH MIX 46 BBLS/280 SX (USABLE) CLASS G CEMENT W/.21 GPS D-80, .54 GPS D-159, AND .025 GPS D-47 @ 15.8 PPG. PERFORM FLUID LOSS TEST, OK. PUMP 10 BBL FRESH WATER, 46 BBL CEMENT THROUGH RETAINER TO CEMENT TUBING IN PLACE. FOLLOWED CEMENT WITH 10 BBL FRESH WATER AND BARAZAN CONTAMINATED WATER. ClP 0530 4/9/96. UNSTING AND CIRCULATE BARAZAN FLUID. SD AND OBSERVE WELL. CT x TUBING ANNULUS STILL FLOWING. CONTINUE CIRCULATION. BOTTOMS UP CEMENT CONTAMINATED. POOH W/CTU. CEMENT OBSERVED ON LAST 100' OF CT. WOC 8 HOURS. RIH W/2.25" BIT, 1-11/16" BAKER MOTOR, AND HYDRAULIC DISCONNECT. DID NOT ENCOUNTER ANY CEMENT IN TUBING. CIRCULATE BOTTOMS UP. POOH. RD CTU. PLAN TO SHIP EQUIPMENT TO BEACH TOMORROW. 4/10-25/96 PERFORATE "G' ZONE 3HPF THROUGH TUBING: ZONE INTERVAL FEET G-2 9902- 9939' 37' G-3 9994-10034' 40' G-4 10042-10081' 39' G-4 10105-10125' 20' G-5 10228-10252' 24' Total 160' *Gun stuck were shot. RIH W/Halliburton's smaller explosive cutter. No Indication cutter fired. RIH W/Halliburton's larger explosive cutter and cut wire. Left 4 1/2' of wire and gun in hole. RIH W/2 1/8" Enerjet gun and perforated. Gun stuck were shot. Top of Fishing head at 10091.6' and bottom of gun at 10125.8'. **Tie in and shoot 10,228' - 10,252'. Gun stuck where shot after shooting. NOTE:Tool string is 39.4' long overall and the top of the head is at 10,213'. Oil & Ql~!i Can,t. Cc~mmis~ior~ An~hor~ige /~rl JU- 1 JJ-/U/O/-UU 'Grayling Platform Leg 5, Conduc[or-I b-Zl Trading Bay Un t McArthur River Field K~U LleV, i U,~ It IL :ad Fins Depth 42,7 Fi Mi8 Perf Deviation 20.6 Deg. 9700.0 - 10257.0' CEMENf 4/8/96 Plugged 10257.0- 10551.0' CEMENf PLUG 4/8/96 71.6-10584.4' PACKER Otis BWD Pkr. (7/19/95 Pkr. Noi Holding) 10454.0 - 10844.0' CEMENf PLUG 4/7/96 5t Bbls Cml. -10505.0' ABANDONED PERFS HB-1, 8HPF, 2/24/80 & 10/5/89 10540.0- 10590.0' SQUEEZE PERFS HB-2, 5/20/75&2/24/80 10605.0- 10655.0' SQUEEZE PERFS HB-2, 5/20/75 7.0- 10658.7' 9.625" OD &6BI" ID 47.00t/fi P-110 PROD CSG 10660.0 - 10690.0' SQUEEZE PERFS HB-5, 4HPF, 5/19/75 ' ~ANDONED PERFS HB-4, 12HPF, 5/18/75, 2/2~/80&10/5/89 10844.0- 10847.0' FILL 4/3/96 E-Line T~g 1084.7.0-10870.0' FILL 2/6/94. Tagged W/2 1/4" Scr. .0-10987.0' ABANDONED PERFS HB-5, 4HPF, 1/1/75&5/10/75 10870.0 - 11160.0' CEMENI PLUG IRE FISH 6/50/95 Locoted Tools & 20' Of Wire @ Boiiom Roi Hole O"ABANDONED PERFS HB-6, 12HPF, 2/50/74, I/2/75&5/14/75 10870.0-10870.0' RLL-[AINER 658.7- 11160.0' 9.625" OD 8.681" ID 47.00t/fl S-95 PROD CSG 11004.0 - 11015.0' PACKER Baker, Mod. F-l, Abd. t0/5/89 KB EL~: 99' PBTD: ID: 11160' 42.8-I0551.0' 2.875" OD 2.44" ID 6.40t/It N-80 iBO 10/7/89 - ,u~zo.u 2.875" OD 2.44" ID 9606.1 - 9612.9' 4.75" OD 2.44" ID OASLIFT//ALVE t9 kI~,CCO GLM 9902.0 - 99,39.0' PERFS 4/25/96, 3HPF, Tbs. 9902.0 - 9959.0' PERFS,.,¢-9,_, 4/zw96, 3HP,, 37, 2 I/o Enerie[ Guns, 0 Phase 10042.0- ]0081.0'vL,',rjn""~'-¢ 4/18/96, .3MPg, lb9. 9994.0- 10054.0' PERFS 0-5, 4/22/96, 5hpf, 40', 2]/8" Eneriet Guns, 0 Phase I0042.0 - 10081.0' PERFS 0-4, 4/18/96, 5HPF, 59', 2 i,/8" Enerjet Guns, 0 Ph(]s IOl05.0- I0125.0' PERFS 0-4, 4/15/96, 5HPF, 20', 2 i/8" Eneriet Guns, O Phas 9994.0- t0154.0' PERFS 4/22/96, 5HPF, fb9. 10105.0- 10125.0' PERFS 4/15/96, 5MPg, Po9. 10228.0 -10252.0' 10228.0 -10252.0' 10091.6 -10125:8' 10215.0 -10252.0' 10257.0 -10257.5' 10257.5-10551.0' 10557.1 -t0643,8' 103~7,7-10~41.2' 10351,0 -i0551.2' 10~5~.5 -10~6`3.8' 10393.8-10`395.1' PERFS O-5, 4/t2/96, `3HPF, 2.4', 2 I/8" Eneriet Guns, O Phas PERFS 4/12/96, `3HPF, PoS. GUN FISH 4/15/96, ,39.4' Lon9 W/Wt, eCL, etc, &20' of gneri GUN FISH 4/12/96, ,39.4' Long W/Wt,'CCI, Ere, ~ 24' gE Enerj RE'[AINER 4./8/96 Boter Model U-I CEMENf PLUG 4/8/96 Tb9. 4..75" OD 2.44." ID GASLIFT VALVE IlO MACCO GLM 5,75" OD 2.515" ID SLEEVE Otis XA PARI 4/8/96 Cut l~g. 4.04" OD 2.97" ID gEALS Offs Sir Slot Seal Assembly 5.24." OD 2.51`3" ID LANDING NIPPLE Ods X 10427.5 10428.0' 5.$" OD - z.~ ID MULESHOE Otis WL Re-Entry Guide Oil Well Plugged Bock 4/8/96 Losl Perf'd 4/25/96 Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL ) G. Russell Schrnidt Drilling Manager Monday, January 29, 1996 Dear Mr. Johnston: Mr. David Johnston Commissioner Alaska O&G Cons. Commissioner 3001 Porcupine Drive Anchorage, AK. 99501-3192 Please find enclosed an application for SUNDRY APPROVAL to abandon the Hemlock formation and recomplete the G-Zone (Form 10-403) in Grayling Platform well #21. The timing to commence the work is early February, 1996. If yOu should have any questions regarding this permit, please contact Steven S. Lambe, assigned to this project, at 263-7642. Thank you for your attention to these matters. Sincerely, ,, G. Russell Schmidt Drilling Manager enclosure AL ...... STATE OF ALASKA A OIL AND GAS CONSERVATION CON ,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend Alter casing Repair well Change approved program Operations shutdown Re-enter suspended well Plugging Time extension Stimulate ~ Pull tubing Variance Perforate Other X~ 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 I 5. Type ~ Well: Development Exploratory Stratigraphic Service Location of well at surface Grayling Platform, Leg #3, Conductor #2 1802' N & 1415' W of SE Corner, Sec. 29, T9N, R13W, S.M. At top of productive interval ORIGINAL 584' S & 1989' E of NW Corner, Sec. 33, T9N, R13W, S.M. At effective depth 12. At total depth 921' S & 2211' E of NW corner, Sec. 33, T9N, R13W, S.M. Present well condition summary Total depth: measured 11,160' true vertical 9,970' feet Plugs (measured) feet 6. Datum elevation (DF or KB) '103' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number G-21 9. Permit number 74-42 10. APl number 50-133-20267 11. Field/Pool McArthur River Hemlock Effective depth: measured 10,860' true vertical 9,452' Casing Length Size Structural 356' 26" feet Junk (measured) feet Cemented Driven Cement Retainer Measured depth 356' True vertical depth 356' Conductor 822' 20" 779 sxs 822' 715' Surface 5,201' 13-3/8" 1,550 sxs 5,201' 4,524' Intermediate Prod uction 11,160' 9-5/8" 2,000 sxs 11,160' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Upper most 10,447' See attachment Lower most 10,859' Upper most 9,114' Lower most 9,451' 2-7/8", 6.4~, N-80, Buttress I~ 10,452' Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal FEB 02 19 G OTIS "BWD" Permanent Packer set @ 10,372' AHchorage OTIS TRBV "BXE" SCSSV ~ 312' X Detailed operations program X BOP sketch X feet 14. Estimated date for commencing operation February 15, 1996 16. If proposal was verbally approved Oil x Name of approver Date approved Sen/lee 17. I hereby certify that the foregoin~g,~tr~ )~'s tr nd cor ~ to ~ I:{est~ ,-° knowledge. ~ '" FOR COMMISSION USE ONLY 15. Status of well classification as: (~as Suspended Date Conditions of approval: Notify Com,m.,j~on so representative may witness Plug Integrity,, BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by the order of the Commission Form 10-403 Rev 06/15/68 Approved Copy Ret, urn(Id Commissioner Date SUBMIT IN TRIPLICATE Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL G. Russell Schmidt Drilling Manager Monday, January 29, 1996 Dear Mr. Johnston' Mr. David Johnston Commissioner Alaska O&G Cons. Commissioner 3001 Porcupine Drive Anchorage, AK. 99501-3192 Please find enclosed an application for SUNDRY APPROVAL to abandon the Hemlock formation and recomplete the G-Zone (Form 10-403) in Grayling Platform well #21. The timing to commence the work is early February, 1996. If you should have any questions regarding this permit, please contact Steven S. Lambe, assigned to this project, at 263-7642. Thank you for your attention to these matters. Sincerely, ,., ~ .-~., .r~ G. Russell Schmidt Drilling Manager enclosure Grayling Platform Well it 21 Abandon Hemlock producing intervals and complete in the G-zone By: S.S. Lambe Date: JanuaD' 24, 1996 Objective: Well G-21 is currently a shut in Henflock production well with benches I & 3 open. In 1989 the well was worked over and a new 2-7/8" completion run in the 9-5/8" casing. The permanent packer was set between the G-zone and Hemlock benches at 10,372' measured depth. Based on slickline reports, the 2-7/8" tubing is cork screwed below 9,700'. Tube move calculations predict 43 inches movement downwards from static to flowing conditions. The majority of the movement is from thermal effects. The procedure details: · Abandonment of the Hemlock formation · Relief of the compressional buckling load on the 2-7/8" completion string by cutting the tubing above the permanent packer · Displacement of cement in the annulus across the G-zone interval to provide zonal isolation * Completion of the G-zone interval behind pipe. HEMLOCK ABANDONMENT: Orient each crew to overall project scope and hold tailgate safe~, meeting at every operational changeover. Kill well and prell for Coil Tubing: 1) Rig up hard line to pump FIW down tubing from the water flood manifold. Bullhead 90 bbls into formation at I BPM to kill well and reduce thermal buckling ,-fffect. Do not exceed 2500 psi. 2) Bleed pressure from casing and fill annulus with FIW. 3) Rig up slickline umt, lubricator and BOPs. Pressure test to 2500 psi against swab valve. Bleed pressure and drain liquids. MU 2.25" gauge ring on tool string of equal dimensions as E-line perforating gun noted in step #5. 4) RIH with gauge ring and tag fill. Note any excessive drag while POOH. POOH with gauge ring and RD slickline. NOTE: Prior to arming explosives and until explosives are 500' in hole, establish all SCHLUMBERGER safeguards for handling explosives. Re-establish safeguards when POOH with explosives in the event of a misfire. 5) Ensure well has no pressure on tubing. Bleed any pressure from well prior to RU E-Line unit. RU E-Line umt, lubricator, and BOPs. Pressure test to 2500 psi. Bleed pressure and drain liquids. Tie a strong weak point expecting extra drag from corkscrewed tubing. MU 1-11/16" CCL and 2' of robing perforating gun dressed for 2-7/8", 6.4 # tnbing. Keep length to a minimum by using minimal weight bars. 6) RIH with assembly and tag bottom. Log up and locate jewelry of BHA (See attached completion guide). Perforate top of tubing joint above X nipple at~ POOH with perforating gun. Ensure all shots fired and rig down E-line unit. Coil Tubing Cement Placement: NOTE: Prior to pumping any non produced fluids, notif.v Trading Bay Production Facility of intent to pump FIW and possible FR26CL (Halliburtons "Slickum"). Fill out non produced fluids form and receive confirmation of acceptance. Noti~ TBPF when job is completed. 7) RU 1-1/2" coil tubing unit. RU hard lines from both low pressure FIW source and suction line from 250 BBL tank. RU injector, BOPs, and lubricator. Pressure test all surface lines to 4500 psi. Pressure test coil and lubricator to 4500 psi. Function and pressure test BOP's. 8) Fill deck mud pits with FIW and start heating with steam lines. 9) MU 2-1/8" cementing nozzle, 4' mandrel bypass tool, and coil connector to the 1.5" coil. RIH with assembly circulating cold FIW at 1/2 BPM. Perform weight checks at 5,000', 8,000', 9,000', followed by checks every 500' while in tubing. Expect increased drag below 9,700' due to cork screwed tubing. Pump a concentrated pill of Halliburtons FR26CL and let soak in the tubing below 9,000' if excessive drag is encountered. RIH and tag bottom. Correlate depth to DIL as noted from E-Line tag in step #6. PU coil 20'. lO) Ensure 2-7/8" X 9-5/8" annulus is full and positive returns from 1-1/2" coil by 2-7/8" tubing annulus. Il) Batch mix 36 barrels class "G" cement with additives for a 4 hour set time, fluid loss not exceeding 80 mi per 30 minutes, and compressive strength of 4000 psi in 12 hours. Field test fluid loss prior to pumping. Pump 10 BBL fresh water preflush followed by the 36 BBLs of cement down coil at I BPM holding 500 psi back pressure. Allow I BBL cement out coil and then PU at a 1:1 laying in balance plug. POOH placing cement at I bpm to the tubing tail as noted in step #6. Reduce pump rate to 1/2 bpm. Displace balance of cement with coil positioned at tubing tail. With I BBL cement left, POOH slowly to cement top at 10,388'. PU coil 500' and start pumping down coil at maximum rate holding 1,000 psi back pressure on choke. RIH circulating to 10,380'. Circulate bottoms up and POOH circulating. 13) 14) Close out all billing for cost tracking purposes. G-ZONE COMPLETION: Relieve Compression in Buckled Tubing: NOTE: Shut in well and leave 1,000 psi on tubing. Rig down coil tubing. WOC 12 hours. Pressure tubing and casing to 1,500 psi and monitor for leak off. Pressure tubing to 2500 psi and test cement plug. Note any pressure communication to the casing annulus. Alaska Oi! Prior to arming explosives and until explosives are 500' in hole, establish all SCHLUMBERGER safeguards for handling explosives. Re-establish safeguards xvhen POOH with explosives in the event of a misfire. 15) RU E-Line unit, lubricator, and BOPs. Pressure test to 2500 psi. Bleed pressure and drain liquids. Tie a strong weak point expecting extra drag from corkscrewed tubing. MU 1-11/16" CCL and jet cutter dressed for 2-7/8", 6.4 # tubing. Keep length to a minimum by using minimal weight bars. 16) RIH with jet cutter and tag TOC. Correlate depth and locate the two pup joints below the sliding sleeve at 10,362'. Position jet cutter below tubing joint of first pup joint at 10,366'. Pressure tubing to 1,500 psi and open annular valve. Fire jet cutter and note pressure loss indicating pipe has parted. POOH with E-line and rig down. 17) Rig up hard-line to pump down tubing taking returns out annular valve. Pump 100 bbls hot water down tubing to clear any residual oil from casing. Reverse circulate 500 bbls hot water down casing taking returns from tubing. Lay in Annular Cement Plug: 18) Rig up slickline unit, lubricator and BOPs. Pressure test to 2500 psi against swab valve. Bleed pressure and drain liquids. MU 2.25" gauge ring on stiff tool string to check corkscrew of tubing. RIH to sliding sleeve at 10,362'. POOH. 19) MU pulling tool dressed to pull live valve from gas lift mandrel # I at 10,337'. RIH and recover valve. MU dummy valve on kick over tool and RIH. Set dummy valve in mandrel #1. POOH and ensure valve is set. MU LIB on kick over tool and RIH. Take impression of valve in GLM #1. POOH. Confirm valve is inside pocket. 20) MU check valve assembly on OTIS X-lock. RIH and set in sliding sleeve profile at 10,362'. POOH. MU check set tool for X-lock. RIH and verify X-lock is securely set in sliding sleeve profile. POOH with slickline and rig down unit. 21) RU 1-1/2" coil tubing unit. RU hard lines from both low pressure FIW source and suction line from 250 BBL tank. RU injector, BOPs, and lubricator. Pressure test all surface lines to 4500 psi. Pressure test coil and lubricator to 4500 psi. Function and pressure test BOP's. 22) MU cementing stinger and coil connector. RIH circulating hot water at minimum rate. Shut down pumps and stab stinger into the check valve assembly's PBR set in sliding sleeve at 10,362'. Set down 5,000 #. Pressure 2-7/8" X 1-1/2" coil annulus to 800 psi to ensure seals are holding. 23) Batch mix 48 barrels class "G" cement with additives for a 4 hour set time, fluid loss not exceeding 80 mi per 30 minutes, and compressive strength of 4,000 psi in 12 hours. Field test fluid loss prior to pumping. Pump 15 BBL fresh water preflush and cement down coil at I BPM taking returns up 2-7/8" X 9-5/8" annulus. 24) With all cement displaced from the coil, shut down pumping and ensure check valves are holding. Unsting from assembly and circulate hot water down coil to clear any residual cement in the coil. POOH circulating at 1/2 BPM. Shut in tubing and rig down coil. WOC 12 hours. 25) Rig up slickline trait, lubricator and BOPs. Pressure test to 2500 psi against swab valve. Bleed pressure and drain liquids. MU 2.25" gauge ring and RIH and tag top of check valve assembly at 10,362' and ensure check valves held the cement in the annulus. POOH with slickline and rig down. 26) Release coil tubing trait from platform. 27) Unload 440 BBLs from the tubing and casing (GLM # 7) to production not exceeding I BPM to prevent fluid cutting of gas lift valves. Perforate G-Zone: NOTE: Prior to arming explosives and until explosives are 500' in hole, establish all company safeguards for handling explosives. Re-establish safeguards when POOH with explosives in the event of a misfire. 28) RU E-Line unit, lubricator, and BOPs. Pressure test to 2500 psi. Bleed pressure and drain liquids. MU 1-11/16" CCL and perforating guns noted below. Keep length to a minimum by using minimal weight bars. Shoot the following intervals underbalance. Flow test each bench a minimum of 24 hours into the test separator obtaining water cuts every 4 hours. Bench # 5 10,265' - 10,285' 20' 2-1/8" EJ III, 3 spf, O-phase 10,245' -10,265' 20' 2-1/8" EJ III, 3 spf, O-phase 10,225' - 10,245' 20' 2-1/8" EJ III, 3 spf, O-phase 10,205' - 10,225' 20' 2-1/8" EJ III, 3 spf, O-phase Bench # 4 10,105' - 10,125' 20' 2-1/8" EJ III, 3 spf, O-phase 10,085' - 10,105' 20' 2-1/8" EJ III, 3 spf, O-phase 10,065' - 10,085' 20' 2-1/8" EJ III, 3 spf, O-phase 10,045' - 10,065' 20' 2-1/8" EJ III, 3 spf, O-phase Bench # 3 10,014' - 10,034' 20' 2-1/8" EJ III, 3 spf, O-phase 9,994' - 10,014' 20' 2-1/8" EJ III, 3 spf, O-phase Bench # 2 9,919' - 9,939' 20' 2-1/8" EJ III, 3 spf, O-phase 9,902' - 9,919' 17' 2-1/8" EJ III, 3 spf, O-phase NOTE: Casing fill up rates from perforating debris for selected guns correlated to the 2-7/8", 6.4 # tubing. The overall fill height is subject to actual compacting and should only be used as a comparative indicator. Retrievable Strips: 2-1/8" EJ III, 6 spf, O-phase 2-I/8" EJ III, 4 spf, O-phase 0.201' (debris per foot shot) 0.139' (debris per foot shot) Expendable Strips: 2-1/8" EJ III, 6 spf, +/- 45-phase 0.622' (debris per foot shot) 2-1/8" EJ III, 4 spf, +/- 45-phase 0.415' (debris per foot shot) 20"@ ] 822'/_J @ 5201, 9-5/8" e 11160' A 1 2 O 3 O 4 O 5 O 6 O 7 O 8 0-9 O 10 O 11 O 12 XA 1,3 X 14- CEMENT == CEMENT B ~SING ~D ~N~ D~AIL ~Y B~SR2~G AT 0.00' B) C~ERON TUBING ~NGER AT C) 20', 94~, B-40 CASING AT D) 13-3/8', 61~ & 68~, K-55 ~SING AT 5201' E) CE~ R~AIN~ AT ~0860' DIL F] BAKER ~ODEL F-1 PKR AT 11004' (AB~NED IN P~CE) E) 9-5/8', 40~ & 4~%, USS-95 CASING AT 11160' TUBING DETAIL 2-7/8'' 6.4%, N-80, BUTTRESS, SC CPLGS .CAMERON TBG HANGER AT 42.75' 1) 4-1/2'x 2-7/8° X-OVER AT 82.41' 2)-2-7/8° OTIS BALL VALVE AT 311.7U' 31 2-7/8' MACCO GL~ %1 AT 2098.72' 4) 2-7/8' MACCO GL~ ~2 AT 3715.$7' 5) 2-7/8' MACCO GL~ ~3 AT 5053.51' 2-7/8° ~IACCO GL~ 94 AT 5966.95' 7) 2-7/8' ~IACCO G~ #$ AT 6698.08' - 8)-' 2-7/8' ~ACCO G~ t6 AT 7432.09~ 9) 2-7/8' MACCO GL~ %7 AT 8165.40' 10) 2-7/8° ~IACCO GL~ %8 AT 8888.16~ 11) 2-7/8' MACCO GL~ #9 AT 9606.13' 12) 2-7/8' MACCO GL~ ~10 AT 10337.09' 16 13)~ 2-7/8' OTIS 'XA' SLEEVE AT 10361.53~ 14) 2-7/8' OTIS 'X' NIPPLE AT 10417.58' · ' 15). 2-7/8' OTIS WIRELI'fl~ REENTRY GUIDE BOTTOH AT 10451.81' 16) OTIS NODEL 'BWD' PERMA-DRILL PACKER AT 10371.62~ DPH A) B) OTIS SEAL BORE EXTENSION FRO~!~1-0376.70' TO 10384.40' DP~ OTIS SEAL ASSY WITH STRAIGHT "J" LOCATOR FROM 10377.26' TO 10387.56' T~ E PERFORATION RECORD 2/30/74 11063'-12084' 2/31/74 11042'-12063' 1/1/75 10958~-10987~ 10904'-10930~ 20882~-~0900~ 1/2/75 11042~-11084~ 5/10/75 10930~-10980~ 5/14/75 11060~-11080' 11042~-12062 5/18/75 108~0~-10850 10755~-10800 10735'-10745 5/19/75 10660'-10690 5/20/75 10540~-10590 10605'-~0635 2/24/80 ~07~0'-10840' 10~40'-10580' 10478e-~0506~ 10/5/89 10477e-~0505' 10729~-10859~ ABANDONED ABANDONED ABANDONED ABANDONED ABanDONED ABANDONED ABANDONED ABANDONED ABANDONED PROD - OPEN PROD - OPEN PROD - OP~N SQUEEZED SQUEEZED SQUEEZED PROD - SQUEEZED PROD - OPEN PROD - OPEN PROD - OPEN WELL TBUS G-2 1 COMPLETION ( 10-8-89 ) UNION OIL COMPANY OF CALIFORNIA (dbe UNOCAL) DRAWN' DAC SCALE' NONE DATE: 10- 17-89 PAGE NO. LEASE TRADING BAY WELL NO. TBUS G-21 FIELD MCARTHUR LOCATION: CO~ID~CTO~ 1415'W OF PERMIT NO. 74-42 SERIAL NO. TD 11160' TVD~ DEVIATION (BHL) 9~'$, 2211' E OF NW Corl~er Sec. $$, TgN, R13W S.M. CO~LPANY ENGINEER CHLTDANOV, HA~$S, GP~J~A~ & MCALLISTER SPUD DATE 9/11/8~ COMP. DATE 10/8/89 CONTRACTOR POOL ARCTIC RIG NO. ~4 TYPE UNIT Na~£onal 1~0 DRILL PIPE DESCRIPTIC~ 5". 19.5~ E&$ ELEVATIONS~ WATER DEPTH %~' RT TO OCEAN FLOO~ 228' RT ~O MMm RT TO DRILL DECK RT TO PRODUCTION DECK 46,~' APPROVED cASiNG & TI}BING R~CORD SI$~ ,W~G~T THREAD G~ADE DEPTH RF.~ARKS 26" %/~", WALL ~§' DRIVEN 20' , 94~ BUA'TRESS H-40 822' . C~'D W/779 SX$ i~-~/8" 6~ ~ 68# - ~-s$ ~;9~' - - 155osxs 9-s/$- 40~..% 47~ . ." uss-95, P-11Q 11160' ' "2000sxs PERFORATING ,~]~ORD , DATE , INT~R~A~ , E.T.D- ~ON .... ~ ~NDXTI~ 2-)0-74 %~0~3'-~084' lll2O'Fq PR~U~QN ~N~p 9Z23/89 . 2-32-74 2~04~'-~2063' ~2~20' P~U~ION ~~0 9/23/89 1-01~75 10958'-10987' llllO' ' ~~O 9/23/89 10904'-1Qg~Q' ii110' ' ~~D 9/23/8~ 10~2'~10~00'. 11110' ' ~~O 9/23/89 1-02-7~ 11042'-11084' 11110' ' ~~D 9/23/89 5-14-75 11060'-11010!. 11091' ' ~~D 9/23/89 11042'-11062' 11~91' 5-18-75 10810'-105~0' 11091' " 10770'-i0800',,' 11091' . 10755'-10770' 11091' ~o~s'-~0~4s' ~o9~' - I~ITIAL PRODUCTION , · ~AT.E INTERVAL NET OIL CUT GRAV. C.P. T.P. CItOKE ~ GOR . .._REMARKS TYpE~ CA~RO~. , ~ ~ma, p ASS~mLY CASING HRAD= WF, 12" 3QQO# x 13-3/8' SOMo W/2 EA. 2" 5000# flanaed outlets CASING HANGER: 12' 3000~ w/ CA 12" x 9-5/e" OD slid & sea1 assr. , TUBING HEAD~ ~C~ TUBING HANGER: Single DC-FBB 10" nominal w/ 4-1/2" EUE 8RD (TOPi ~.,.,4-1/2' 9Uti [BOTTOM) TUBING HEAD TOP, 1~'.5000~ ~ASTER VALVZS~ 4-1/~' TYP~ CHRISTMAS TREE TOP CORNs 4-1/~' ~ $ RD . NO. LEASE TRADING BAY WELL NO. T~US G-21 FIELD MCARTHUR RIVER LOCATION: CONDUCTOR 2, LEG ~f 1802' N, 1415'W OF SE CORNER, SEC. 29, T9N, R13W, SM PERMIT NO. 74-4~ SERIAL NO. · D 11~60' TVD DEVIATION (BHL) 921'S, 22%~.' ~ OF NW .Corner ~c. 33, TgN, R~)w S.~. C~uNY ENGINF~ER CI~JD~NOV, F~SS, Gl~ & MCALLISTER SPUD DATE ,9/11/89 COMP. DATE CONTRACTOR POOL ARCTIC,. RIG NO. 54 TYPE UNIT National 1320 DRILL PIPE DESCRIPTION 5', 19.5~ ELEVATIONSt WATER DEPTH ~' RT TO OCEAN FLOOR . RT TO MLLW aT TO DRILL DECK ~.~' BT TO PRODUCTION DECK 46~§' APPROVED DATE INTERVAL 5-19-75 10660'-10690' 5-20-75 10540'-10590' 10605'-10635' 2-24-80 10730'-10840' 10540'-10580' 10478'-10506' 10-05-89 10477'~10505' E.T.D. 11091 ' 11091' 11091' 11091' 11091' 11091' i0860' ~'~l' ~I~T 10729'-108~9' ~05§0' p$1~FORATING REASON PRODUCTION PRODUCTION PRODUCTION P~ODUCTION PRODUCTION PRODU~I~ PROD~I~ PI~S~E~T (~)NIDITION $OUEEZED 9127189 SOUEEZED 9129189 SO~S~SD ~/28/89 .. OPeN SOUER~ 9/29/89 OPeN , OPEN OPEN NAME: G-21 LOO~IC~: Grayling Platfc=m- F~mai, Alaska 9-5/8" 47 ppf N-80 2-7/8" 6.4 ppf ]3.tttress HO N~: 43!/1010/03/89 October 7, 1989 (907) 283-7531 ~ I.D. O.D. 10 1. K.B. 11 4-1/2" ]3~ X 4-1/2" B'IC 3. ~ (1) Joint 4-1/2" 3.95" 5.2" -- 12 12.6 ppf SIC Tubir~ 4. Swac3~ - 4-1/2" .BTC x 2-7/8# 2.44" 4.5" 5. Pup Joint. 2.44" 3.5" 15 6. Pup Joint 2.44" 3.5" 7. Seva~ (7) Joints of Tubing 2.44" 3.5" 16 8. ~ %/4" Stainless Steel .25" 17 ~ ~ .049" ',,{all (~,,'N 22 sxx 33.05o) 18 9. Otis "XXD" Safety Valve 3.25" (P/N 3.1. :XXD 23:Ll0) 3.85" --].9 Z0. Fi.f'W-Zi.gt~ (58) Joints of 2.44" 3.5" 20 .1/. Gas IJ. ft Mandrel #10 2.44" 4.';5" 21 12. ~ Joir~c 2.44" 3.5" 2:2. 3.3. Pup Joint 2.44" 3.5" 3.4. ~ (52) Joints of 2.44" 3.5" -- 23 Tubing 2l, 15. Gas Lift Mandrel 19 2.44" 4.'/5" 16. Pup Joint 2.44" 3.5" 25 3.7. n=L-7~ (43) Joints cZ' 2.44" 3.5" 26 ~,,bire :tS. Gas Lift Mandrel ~8 2.44" 4.75" 27 3.9. ~ Joint 2.44" 3.5" 28 20. Pup Joint 2.44" 3.5" 21. ~-Nine (29) Joints of 2.44" 3.5" 29 Tubing 22. Gas ~ Marziz-ml #7 2.44" 4.';5" 23. Pup Jo.tnt. 2.44" 3.5" 2.313" 42.75' 38.93' 5.35' 8.05' 215.29' 2.49' 1784.53' 6.76' 4.10' 9.42' 1596.57' 6.78' 10.30' 1320.86' 6.77' 8.21' 5.0' 893.46' 6.76' 5.11' -0- 42.75' 43.48' 82.41' 83.01' 88.36' 96.41' 311.70' 314.19' 2,098.72' 2,105.48' 2,109.58' 2,119.00' 3,715.57' 3,722.35' 3,732.65' 5,053.51' 5,060.28' 5,068.49' 5,073.49' 5,966.95' 5,973.71' 39 ~3 -A &9 24. ~ (23) Join'cs of 2.44" 3.5" 719.26' 25. Gas Lift ~ ~6 2.44" 4.75" 6.78' 26. la~ Joit~ 2.44" 3.5~ ~.63' 27. ~ (~) Jo~ of 2.~" 3.5~ 28. ~ ~ ~ %5 2.~" 4.75" 6.80' 29. ~ Jo~ 2.~w 3.5" ~.95' 30. ~ (~) Jo~ of 2.~" 3.5" 7~.~' 31. ~ ~ ~ ~ 2.~" 4.75" 6.80; 32. ~ J~ 2.~" 3.5" 3.~' 33. ~ Jo~ 2.~" 3.5" 3.49' 34. ~ (~) Jo~ of 2.~" 3.5" 35. ~ ~ ~ ~3 2.~" 4.75" 6.81' 36. ~ J~ 2.~" 3.5" 37. ~~ (~) Jo~ of 2.~" 3.5" 38. ~ ~ ~ ~2 2.~w 4.75w 6.79' 39. ~ Jo~ 2.~" 3.5" 4.10' 40. ~ Jo~ 2.~" 3.5" 6.~' 41. ~ Jo~ 2.~" 3.5" 42. ~ (~) Jo~ of 2.~" 3.5" 43. ~ ~ ~ ~1 2.~" 4.75" 6.76' 44. ~ J~ 2.~" 3.5" 45. ~ ~" Sl~ S~ ~ 2.3~" 3.75" 3.~' ~~/=~ 46. ~ ~ 2-~m ~.5" 6.~0' 47. ~ ~0~ 2.~' ~.5~ ~. ~ ~. S~ ~ a. ~. Sl~ ~~ 2.~" 4.47" (1.~') (~ 2~ s ~) b, ~ ~y 2.97" 4.~" (1.01') ~ 2u ~ 4~) c. ~~ 2.97" 3.~" (2.01') (~ 2u x ~) d. ~ ~~ 2.97" 4.~" (1.01') e. ~ 2.97" 3.~" (2.01') (P~ 2u x ~) f. ~ ~~ 2.97" 4.~" (1.01~) (~ 2u ~ ~~) g. ~ ~y 2.97" 4.N" (Lot') (~ 2u ~ ~) h. ~~ - 3-~- ~ 2.~" 3.~" (.4') PA~2 5,978.82' 6,698.0~' 6,704.86' 6,716.49' 7,432.09' 7,438.89' 7,452.1M' 8,165.40' 8,172.20' 8,175.35' 8,178.84' 8,888.16' 8,894.~7' 8,922.74' 9,606.13' 9,612.92' 9,617.02' 9,623.20' 9,629.2~' 10,337.09' 10,343.8~' 10,361 · 53 ~ 10,364.97' 10,371.07' 10,377.26' (~ 1'13:431/1010/03/89 [PI1/E: ~ 7, 1989 49. Cna (1) ,,To/.,~c of '1%~J.r~ 2.44" 3.5" 30.02' 50. O'c/s "X~ SeZecl:/&'e ~ 2.3~" 3.24" 1.29' N~e (P~ ~ X 231~) 51. ~ (1) 3o~ of ~ 2.44" 3.5" 32.20~ 52. ~ ~e ~ ~~ 2.~" 3.5" .74' (P~ 2= ~ 3) 10,387.56' 10,417.5~' lO,418.r/' 10,451.0'/' A. Or./s "El4']" ~ 4. O" 8.12" 9-5/8" 36-54.9 LB (9/Z~ 2~2 ~ 95400-,X) B. Ok.is Seal Bore Exkensi.c~ 4.0" 5.03" C~/t; 22 c ?o6o) 5.08- 7.70' 10,371.62'* 10,376.70' 10.384.40~ 0TIS 9-5/8" · &" "BWH" PERMA DRILL PACKER WELL: G-21 COMPLETED: OCTOBER 7, 1989 2.32'I J 3~35' .35' .7~' ! &,Ot 7.70' 5 08' 12.78' · Top of Packer: 10,371.62' Drill Pipe Measurement Stud-Up Flange Top Connection,~ Pressure Port Blind-Ram Equalizing Valve Manual Lock Handle Side Port (Kill Port) Blind Rams (Ram No. 1 ) Shear Rams (Ram No. 2) Slip Rams (Ram No. 3) Pipe Rams (RamNo. 4) Pipe-Ram Equalizing Valve Bottom Pin and Collar Connection Hydraulic Actuator with Ram Position Indicator Bottom Flange Connection Unocal North American ..... Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region October 25, 1993 AOGCC 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ms. Miller: Attn: Joan Miller TRADING BAY AOGCC FORMS Further to your letter of July 14, 1993 Unocal is attempting to comply with the Regulations and supply the appropriate paperwork. To that end please find the completed 10-404 forms enclosed, in triplicate, for the following wells; a) G21 b) K9 c)~_ K2RD operations to the end of 1990 As we complete the paperwork on the outstanding wells, we will in turn submit those to you. If you have any questions or comments please contact the undersigned at 263-7676. Sincerely, G. Russell Schmidt Drilling Manager GRS / 1 eg RECEIVED N 0V -- 'J 199 Alaska 0il & Gas Cons. Corn Anchorage -- STATE OF ALASKA -- ALA, , OIL AND GAS CONSERVATION COMIV, ,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing Alter casing Stimulate __ Plugging _ Perforate Repair well Pull tubing __ 5. Type of We~: 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 4. Location of well at su'face 1802' N & 1415'W of SE corner, Sec. 29, T9N, R13W, SM At top of productive interval 584' S & 1989 E of NW corner, Sec. 33, T9N, R13E, SM At effective depth At total depth 921' S & 2211' E of NW corner, Sec. 33, T9N, R13W, SM Development X_ Exploratory __ Stratigraphic__ Sen/ice __ Trading Bay Unit 8. Well number G-21 9. ~,?rmit number/approval number 7~-42J93-154 10. APl number 50-133 -20267 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured true vertical 11,160' 9,711' feet feet Plugs (measured) Effective depth: measured 11,110' true vertical 9,668' feet feet Junk (measured) 10278' Casing Length Size Structural 356' 26" Conductor 822' 20" Surface 520 1' 13-3/8" Intermediate Production 11160' 9-5/8" Liner PerforaUon depth: measured Uppermost perf. 10478' Lowermost perf. 10859' true vertical Uppermost perf. 9115' Lowermost perf. 9524' Tubing (size, grade, and measured depth) Cemented Driven 779 sx 1550 sx an~l 425 sx Class G 2000 sx 2-7/8", 6.4#/ft, N-80 @ 10452' Measured depth 356' 822' 5201' True vertical depth 356' 715' 4524' 11160' 9711' Alaska Oil & Gas Cons. Anchorag8 Packers and SSSV (type and measured depth) Otis ball valve @ 312'. Otis BWD per @ 10372' type 303.29' Baker F-1 pkr ~ 11004' abandoned in place. 13. Stimulation or cement squeeze summary Intervals treated (measured) Used coiled tbg to jet wash gas lift mandrels and tbg clean. No fish was encounted in the tubing Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water- Bbl Casing Pressure Shut-in Tubing Pressure Subsequent to operation Shut-in pending reperforation of Hemlock Bench 1. 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run__ Daily Report of Well Operations x _ Oil x _ Gas __ Suspended _ _ 17. I herel~er~ t~~e and correct to the best of my knowledge. Signed G. Russell Schmidt Title Drilling Manager Form 10-404 Rev 06/15/88 Sen/ice -- Date 09/30/93 SUBMIT IN DUPLICATE ~,~ ~ ~ ..... STATE OF ALASKA ALASK~ _ AND GAS CONSERVATION CO ISSION APPLICA.! ION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend Operations shutdown' Re-enter suspended well '/'//~ I Alter casin~'-__ Repair w-~ __ Plugging __ ~m. exten.ion __ Stlmulat~- Change approved program Pull tubing Variance Perforate X Other '2. Name of Operator -- 15. T~e of Well: -- 6.-D-atum eleva--~n (DF or KB) Unocal I ~nt X_ RKB 103' above MSL J ~to./ feb1 3. Address J S~ag~phic --- ~ ~ ~ P.O. Box 196247 Anchorage, Alaska 99519-6247 j s~wic~ ~ Trading Bay Unit 4. Location of well at surface 1802' N & 1415' WofSE cot., Sec. 29, T9N, R13W, SM At top of productive interval 584' S & 1989' E of NW Cor., Sec. 33, T9N, R13W, SM At effective depth 8. Well number G-21 9. Permit number 74 -42 10. APl number 50 -733-20267-00 At total depth 921' S & 2211' E of NW Cor., Sec. 33, T9N, R13W, SM 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured 11160 true vertical 9711 feet feet Plugs(measured) 10860 Effective depth: measured 11110 feet Junk (measured) true vertical 9668 Casing Length Structural 356' Conductor 822' Surface 5201' Intermediate Production Uner Perforation depth: measured feet Size Cemented Measured depth True vertical depth 26" Driven 356' 356' 20" 779 sx 822' 715' 13-3/8' 1550 sx 5201' 4524' 11160' 9-5/8" 2000 SX 11160' 10477' - 10506', 10729' - 10859' true vertical 9142' - 9166', 9351' - 9459' Tubing (size, grade, and measured depth) 2-7/8", 6.4#, N-80 @ 10,452' 9711' RECEJVEC Packers and SSSV (type and measured depth) Otis ball valve @ 312', Otis BWD pkr. @ 10372' 13. Attachments Description summary of proposal Detailed operations progran~__ BOP sketch __ 14. Estimated date for commencing operation 10/25/93 16. If proposal was verbally approved Name of approver Date approved 5. Status of well classir,:ation as: Oil X Gas Suspended__ Service 17., he,by ~ t~thr~e and correct ,o ~bes, of my k~wledge. ...Signed F~,.. !L~JV"~)v...~ Title ~.D~LLL.~,~C_,. ~1~ &~~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test_ Location clearance _ Mechanical Integrity Test__ Subsequent form required 10- Original Signed By Approved by the order of the Commission Da vid W. Johnston Form 10-403 Rev06/15/88,..~-~ ~~ Date JApproval N/~ _ ~ Commissioner ........ Date t ~ / 'z. Z./"~ ~ /,~.~/_~.~,_~ SUBMIT IN TRIPUCATE ~ OCT 1 9 199;5 Alaska Oil & (Jas Cons. Com~ Anchorage October 14, 1993 ~Gravlin.(3, Well G-21 perforating procedure 1. Hold safety meeting. 2. RU electric line unit. 3. Pressure test lubricator to 2500 psi for five minutes. 4. Shut down all welding and radio transmissions. 5. RIH and perforate intervals as instructed by Unocal (When gun is 200' below surface, welding and radio transmissions may resume.) 6. POOH. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: NOTE: A pump-in sub must be installed on lubricator. BENCH MEASURED TOTAL FEET HB1 10,477'-10,505' 28' TOTAL: 28' OCT ~ 9 799;5 Alaska OJJ & Cas Co/is. Commissar,, Anchorage ALASKA OIL AND GAS CONSERVATION CO~IMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 14, 1993 Mr. G. Russell Schmidt Ddlling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. $chmidt, . In conducting an audit of well files I have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. , · To be in compliance with AS 20 AAC 25.280(d) of the Regulations, the Form 10-404 is required to be filed within 30 days following completion of work. In previous telephone conversations concerning the subject, it had been._explained to me that either ARCO or Marathon had been the~operator on the majodty of the work proposed; hoWever, it is the feeling of the Commission that if the work was completed, it is UNOCAL's responsibility to see that the appropriate paperwork be filed in a timely manner inasmuch as UNOCAL is the operator of the field and UNOCAL personnel signed the Application-of Sundry Approval forms. Your assistance in supplying us with the appropriate forms and in helping resolve this problem.in the future will be appreciated. We would also appreciate notification of any canceled Work so that the corresponding Application on file can-be marked accordingly. Sincerely, · ,, Statistical Technician (~ p,inled on ~,ecy~led paper · . Well Permit No. No. D-4 82-41 D-5RD 80-65 D-26 74-9 D-27 75-24 D-40 82-83 D-42 83-53 D-46 89-61 Approval Date & No. 3-1-91, 91-060 5-31-91, 91-163 7-2-91, 91-188 11-22-91, 91-353 9-2-91, 91-189 9-20-91, 91-284 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 5-31-91, 91-160 7-2-91, 91-190 5-31-91, 91-162 12-11-91, 91-387 Trading Bay Unit J Description Perforate 2-91 Perforate 5-91 Workover 4~91 Perforate 11-91 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&$4 10-3-91 Perf 5-91 Scale Cleanout 6-20-91 Perf 5-91 Reperf HB-2 11-91 10-403 Signed By G. Bush G. Bush G. Bush G. Bush G. Bush' G. Bush G. Bush G. Bush G. Bush G. Bush G-5 67-71 G-6 82-33 3/15-91, 91-086 10-30-91, 91-325 4-21-92, 92-093 Short & long inj. profile (If work was completed the 10-403 required a 10-407, Completion, Recompletion report for this well.. Perf. 10-19-91 Perf 4-92 G. Bush G. Bush G. Bush G-17 78-3 G-19 69-17 G-21 ~-42 G-27 78-70 G-31 69-72 K-1 67-65 K-2RD 78-38 K-3 80-144 K-9 68-38 11-1-91, 91'331 11-10-92, 92-238 4-21-92, 92-094 6-17-93, 93-154 4-21-92, 92-95 1-6-93, 92-203 ., · 3-21-91, 91-95 2-9-90, 90-082 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 2-9-90, 90-081 11-14-89, 9-987 Perforate Temp. log 10-15-92 Perf 4-92 Coil tubing cleanout Perforate Convert to inj. Production profile Perforate 2/90 Perf., cement squeeze Stim, p. tubing, perf. 6-90 Perforate 6-91 Perforate 2/90 Repair well, p. tubing, stimulate, perforate G. Bush G. Bush G. Bush R." S chraidt _.G~i~Bush R S chm/dt G. Bush R. Roberts R. Roberts G. Bush G. Bush R. Roberts R. Roberts .... STATE OF ALASKA ALA ~ OIL AND GAS CONSERVATION COMIV, ,ION APPLICATION FOR SUNDRY APPROVALS --- Susp----~.~-- ~ Re-ent'----'-~r suspended wel---I .... Repair well Plugging Time extension Stimulate Pull tubing Variance Perforate Other X -- T~e of Well: -- 6.-~-atum eleva-~;n (DF or KB) - 1. Type of request: Abandon Alter casing Change approved program 2. Name of Operator J5. Development X Exploratory -- Stratig raphic Service -- UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 4..Location of well at surface 1802' N & 1415' W of SE corner, Sec. 29, R9N, R13W, SM At top of productive interval Top of Hemlock 584'S, 1989' E, NW corner, Sec. 33, T9N, R13W, SM At effective depth At tolal depth 921 'S,2211' E of NW corner, Sec. 33, T9N, R13W, SM 99 RKB above MSL feet 7. Unit or Property name TRADING BAY UNIT 8. Well number G-21 9. Permit number 10. APl number ~-'- 50-133 -20267 11. Field/Pool MCARTHUR RIVER/HEMLOCK 12. Present well condition summary Total depth: measured true vertical 11,160' 9,711' feet feet Plugs (measured) Effective depth: measured true vertical 11,110' 9,668' feet feet Junk (measured) 10,278' Casing Length Structural 356' Conductor 822' Surface 5201' Intermediate Production 11160' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented 26" Driven 20" 779 sx 13-3/8" 1550 sx 9-5/8" 2000 sx Uppermost perf: 10,478' Lowermost perf: 10,859' Uppermost perf: 9115' Lowermost Perf: 9524' 2-7/8", 6.4#/[t, N-80 ~ 10,452' Measured depth True vertical depth 356' 356' 822' +715' 5201 ' +4524' 11160' R ECEIVL~i~' J UN 1 4 199, Alaska Oil & Gas Cons. Commissio[~ ;~nchorage Packers and SSSV (type and measured depth) Otis Ball valve # 312' Otis BWD per @ 10,372'type 303.29' Baker F-1 pkr ~ 11,004' abandoned in place 13. Attachments Description summary of proposal X_ Detailed operations programX___ BOP sketch X 14. Estimated date for commencing operation 16. If proposal was verbally approved Oil X Gas Name of approver Date approved Service 17. I hereb~ert? thai !~0or~)~(i~~ and correct to the best of my knowledge. Signed G. Russell Schmidt Title Drilling Manager FOR COMMISSION USE ONLY 5. Status of well classification as: Suspended Date June2, 1993 Conditions of approval: Notify Commission so representative may witness Plug Integrity m BOP Test Location clearance Mechanical Integrity Testm Subsequent form required 10- Approved by the order of the Commission Form 10-403 Rev 06/15/88 Original ;Signed By David W. Johnston Approval No. ,x~,pprovod Copy Rc'[umed Commissioner Date qUBMIT IN TRIPLICATE 20" @ 822' //i @ 520 1' 9-5/8" 11160' ! I'-'" ! × 14 __ ...~_ CEMENT =: CEMENT L 1) 2; 3) 4) G CASING AKD ABANDONMENT DETAIL A) KELLY BUSHING AT 0.00' B) CAMERON TUBING HANGER AT 42.75' C) 20", 94#, H-40 CASING AT 822' D) 13-3/8", 61% & 68#, K-55 CASING AT 5201' E) CEME~ RETAINER AT 10860' DIL BAKER MODEL F-1 PKR AT 11004' (ABANDONED IN PLACE) £) 9-5/8", 40# & 47#, USS-95 CASING AT 11160' TUBING DETAIL CAMERON TBG HANGER AT 42.75' 4-1/2"x 2-7/8" X-OVER AT 82.41' 2-7/8" OTIS BALL VALVE AT 311.70' 2-7/8' MACCO GLM .1 AT 2098.72' JUN 2-7/8" MACCO GLM #2 AT 3715.57' :-7/o- ~cco c~ . ,T 5966. as Oil.& Gas Cons. 2-7/8" MACCO Gk~ #5 AT 6698.08' 2-7/8" MACCO GLM #7 AT 8165.40' 2-7/8" MACCO OLM #8 AT 8588.16' 2-7/8" MACCO 6LM ¢9 AT 9606.13' 2-7/8" MACCO 6LM #10 AT 10337.09' 2-7/8" OTIS "XA" SLEEVE AT 20361.53' 2-7/8" OTIS "X" NI~LE AT 10417.58' 15) 2-7/8" OTIS WIRELINE REEN'I'R¥ 6UIDE '-.' BOTTOM AT 10451.81' -- 16) OTIS MODE~ "BWD' PERMA-DRILL PACKER AT 10371.62' DPM A) OTIS SEAL BORE EXTENSION FROM L0376.70' TO 10384.40' DPM B) OTIS SEA~ ASS~ WITR STRAIGHT "J" LOCA~OR FROM 10377.26' T~ 10387.56' TM PERFORATION RECORD 2/30/74 11063'-11084' 2/31/74 11042'-11063' 1/1/75 10958'-10987' 10904'-10930' 10882'-10900' 112175 11042'-11084 5/10175 10930'-10980 5/14/75 11060'-11080 11042'-11062 5/1B/75 108X0'-10850 10755'-10800 ~0735'-10745' 5/19/75 10660'-10690' 5/20/75 10540'-10590' 10605'-10635' 2/24/80 10730'-10840' 10540'-10580' 10478'-10506' 10/5/89 10477'-10505' 10729'-10859' ABANDONED ABANDONED ABANDONED ABANDONED ABANDONED ABANDONED ABANDONED ABANDONED ABANDONED PROD - OPEN PROD - OPEN PROD - OPEN SQUEEZED SQUEEZED SQUEEZED PROD - OPEN SQUEEZED PROD - OPEN PROD - OPEN PROD - OPF.~ WELL TB U S G- 2 1 COMPLETION ( 10-8-89 ) UNION OIL COMPANY OF CALIFORNIA (db(] UNOCAL) DRAWN' DAC SCALE' NONE DATE' 10- 17-89 D ;}remission General Work Procedure Coil Tubing Cleanout G-21 1. RU & test 1-1/2" coil tubing unit ( maximum depth 10,451'). , RIH w/jet nozzle & wash 2-7/8" 6.4# tubing to top of slickline fish at 10,303'. Trip out for motor & mill if required for heavy scale deposits. Maintain gas lift during entire operation to assist in lifting scale debris and reduce risk of covering fish with scale. o Tag slickline fish. POOH. RD unit & turn over to production for slickline fishing operations. RE ,EIVED JUN Alaska 0il & 6as Cons. 00remission'.'- Anchorage ,.' -~ECOIL Arctic Recoil, Inc. (~07) 283-1~80 P.O. BOX 2595 Kenai, Alaska g~611 JUN 1 4 199~ Alaska OJJ & Gas Cons, Oommissio~'~ ;~nchorago ALASKA OJL AND ~{,,~'(~C~I~I~I~'~/-,~,~'I'ON COMMISSION ApPLIC,A. ON FOR SUNDRY AP :IOVALt j;j 1. Type of request: Abandonm Suspend m Operatiom shutdown m Re-enter suspended wellm Alter casing __ Repair well ~ Plugging ~ Time extension ~ Stimulate __ Change approved program Pull tubing __ Vartanoe __ Perforate X_ Oth®r~ 2. Name of Operator ~5. Type of Well: 6. Datum elevation (DF or KB) Union O11 Company of California (UNOCAL) ! ~ X_ 103' KB above MSL 3. Address Stmtigraphk~ ~ 7. Unit or Property name P.O. Box 196247, Anchorage, Alaska 99519-6247 sense ~ Trading Bay Unit 4. Location of well at surface Grayling Platform Leg ,,'3, cond. ,f'2, 8. Well number 1802' N & 1415'W of SE Cor, Sec. 29, T9N, R13W, SM G-21 At top of productive interval 9. Permit number 584' S & 1989' E of NW Cor, Sec. 33, T9N, R13W, SM 74-42 At effective depth 10. APl number At total depth 11. Field/Pool 921' S & 2211' E of NW Cot, Sec. 33, T9N, R13W, SM McArthur River/Hemlock feet 12. Present well condition summary Total depth: measured 11,160 feet true vertical 9711 feet Plugs (measured) Effective depth: measured 10,860 feet true vertical 9452 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size 356' 26" 822' 20" 5201' 13-3/8' Cemented Driven 799 sx 1550 sx Measured depth 356' 822' 5201' 11,160' 9-5/8' 2000 sx 11,160' 10,477 - 10,506; 10,729 - 10,859 9142-9166, 9350 - 9459 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 True vertical depth 356' 715' 4524' 9711' RECEIV Alaska Oit & Cas Cons. Com~'s'''°'-~ ~'~ · '~nchorag8 Packers and SSSV (type and measured depth) Otis ball Valve (iD 316', Baker "F-l" pkr. @ 10,380' Baker 'SAB pkr. (~ 10,864', Baker "F-1" pkr. @ 11,004' 13. Attachments Description summary of proposal ~ Detatled operations prograrnX__ BOP sketch 14. Estimated date for commencing operation J15. 4/24/92 / 16. If proposal was verbally approved Oil X_ Gas Name of approver Date approved Sen/ice 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~o_-._~ ~'. (~¢'~~'~ Title ~,e. cx~ ~ '~'~, FOR COMMISSielN USE ONLY Conditions of app'relVal:'R'olJfy Commission so representative may witness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Test_ S'-~bsequent form required 1-'~- /¢0/-¢ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Status of well classification as: Suspended Date SIGNED BY SN]ITH JApproval No. .... "Commissioner Oat. ~' '"',:~/'"'~',,~ SUBMIT IN TRIPLICATE April 3, 1992 Grayling, Well G-21 perforating procedure 1. Hold safety meeting. 2. RU electric line unit. 3. Pressure test lubricator to 2500 psi for five minutes. 4. Shut down all welding and radio transmissions. 0 6. · RIH and perforate intervals as instructed by Unocal (When gun is 200' below surface, welding and radio transmissions may resume. ) POOH. (When gun is 200' below surface, shut down all welding and radio transmissions. ) Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH HB1 HB4 M~ASURED 10,478'-10,506' 10,730'-10,840' TRUE VERTICAL TOTAL FEET 9143'-9166' 9351'-9443' 28' 1~0' TOTAL 138' RECEIVED Alaska Oil & Gas Cons. Gomm'~ss'~o~ 'Anchora~l~ 20"@ 822' 5-5/8" @ 520 1' 9-5/8" @ 11160' ' i I 0 12 . × 14 CEMENT : : CEMENT IB CASING AKD AflANDONHF.]~ DKTAII, A) KELLY BOSHING AT 0.00' CA.~.,RO~ TUBING HANGER AT C) 20°, 94#, H-40 CASXNG AT 822' D) 13-3/8°, 61# & 68#, K-SS CASING AT 5201' CEP',ENT RETAINER AT 10860 BAKER MODEL F-! PKR AT 11004' (ABANDONED IN PLACE) £) 9-5/8°. 40# & 47#, 055-95 CASING AT ~60' 2-7/8'* 6.4#, N-80, SUTTR~SS. SC CPLGS · R[C[I 3) 2-7/8' I4ACCO GLI, I t1 AT 2098.72' 4) 2-7/8* ~CCO G~ J2 AT 37~5,57t 6)- 2-7/8' ~C~ G~ ~4 AT 5966.95' -,; ~ 7) 2-7/8' ~C~ O~ J5 AT 6698.08* 8)" 2-7/8' ~C~ G~ J6 AT 9) 2-7/8' ~C~ Om 07 AT 8165.40' Ataska 0il & Gas Cot ~0) 2-7/8' ~c~ G~ 08 Af 8088.16' XX) 2-7/8' ~c~ G~ 89 AT 9606.X2' Aflcho[a [2) 207/~' ~C~ G~ ~[0 AT [0337.09* 1~ [2). 2-~/~' ~s 'n' s~E~ AT [026[.S2' [4) 2-7/S' ~S '~' .~PP~ AT 15) 2-7/8' ~XS NXR~XNE R~ GUXDB · -. ~ AT 1045X,81° ~6) ~ZS ~D~ "B~° PE~oDRZ~ PACI~ AT ~0371.62' D~ ~0384.40' D~ PERIt~itATXOff RECORD 2/30/74 XX063'oXX064' 2/31/74 11042'-11063' ABANDO#F,O X/X/TS 10958'-10987' A~~ 10904'-~0930' 20882'-10900' x/2/7S xxo42*-llo84* 5/10/75 X0930*-10980' 5/14/75 ~060'-1~080' A~~ 1X042'-11062' 5/10/75 ~08~0'-10850' P~ - OP~ ~0755'-10800' P~ - OP~ 5/19/75 10660'010690' 5/20/75 10540'-X0590* ~0605'-~0635' SQUEEZ~ 2/~4/80 Z0730'-~0840' P~ - OP~ 10540'0X0580' ~0478'-~050~* ~ - OP~ WELL TBUS G-2 1 COMPLETION ( 10-8-89 ) UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' DAC SCALE' NONE DATE' 10- 17-89 /ED s. CommissiOn Unoc31 North Ame Oil & Gas Division ' LJnocnl Corporation P.G. ~ox 19024;' Anchorage. Alaska 99519-024;' Teie~none (90~ 276-;'600 Alas~<a Recj~o n April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, RGegional Drilling Manager GSB/lew GRAYLING DISTANCE &~DIRECTIONS FROM SE CORNER SEC. 29,. TgN, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL_ LEG ~/3: LAT = 60050' 22.569" LONG =151°36' 46.519" 2,502,352.30 212,272.70 1804 1 2 3 4 5 6 7 8 9 lO 11 12 2,502,346.65 212,269.32 G-22 1789 2,502,350.14 212,266.48 G-21 1802 2,502,354.64 212,266.55 . G-26 1806 2,502,358.05 212,269.49 G-25 lB10 2,502,358.77 21 2,273.94' G-24 1810 2,502,356.46 212,277.80 G-20 1808 2,502,352.20 212,279.28 1804 2,502,347.99 21 2,277.68 G- 36 1800 2,502,345,80 212,273.75 G-34 & RD 1798 2,502,350.83 212,270.89 G-23 & RD 1803 2,502,354.60 212,272.33 G- 33 1806 2,502,351.47 212,274.88 G-27 & 28 1803 LEG #4: LAT = 60050' 22.832" LONG =151036' 48.042" 2,502,380.80 212,197.90 1831 13 14 15 16 17 18 19 20 21 22 23 24 2,502,374.34; 212,196.66 G-1 4A 1825 2,502,376.65' 212,192.79 G-19 1827 2,502,380.90 212,191.32 G-1 3 1831 2,502,385.11 212,192.92 G-15 1835 2,502,387.30 21 2,196.85 G- 5 1 838 2,502,386.45 212,201.28 1837 2,502,382.96 212,204.12 G-3 1833 2,502,378.46 212,204.05 G-2 1829 2,502,375.05 212,201.11 G-11 1825 2,502,378.50 212,198.27 G-lO 1829 2,502,381.63 212,195.72 G-17 & RD 1832 2,502,382.27 212,199.71 G-7 1832 LEG #l: 2,502,455.60 · LAT = 60050' 23.575" LONG =151°36' 4Z. 505" ' 212,226.40 1906 (Reserved for Compressors) LEG #2: LAT = 60050' 23. 313" LONG =151°36' 45. 982" 2,502,427. l0 212,301.20 1880 37 38 39 40 41 4 47 48 2,502,421.45 2,502,424.94 2.502,429.45 2,502,432.85 2,502,433.57 2,502,431.26 2. 502,427.00 2,502,422.80 21 2~'502,420.60 ............ 21 2,502,425.63 21 2,502,429.40 21 2,502,426.27 21 212,297.82 G-12, RD & 2 1874 212,294.98 G-31 1878 212,295.05 G-4 1882 212,297.99 G-1 1886 212,302.44 G-9 1886 212,306.31 G-18 1884 212,307.78 G-14 1880 2,306.18 G.-30 ............ 1876 2',302.25 ................. G-8 & RD 1874 2,299.39 G-6 1879 2,300.83 G-32 1882 2,303.38 G-16 1879 FEL 1409 1413 1415 1415 1412 1408 1404 1402 1'404 1408 1411 1409 1407 1486 1487 1491 1493 1491 1487 1483 1480 1480 1486 1483 1488 1484 1458 1383 1386 1389 1389 1386 1382 .~/o 1376 __1378 1382 1 385 1 383 1381 'f STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMIS$,Or'0 I REPORT OF SUNDRY WELL OPERATIONS Plugging 1. Operations performed: Operation shutdown __ Stimulate __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator '--'----~ LTY)pe of Well: Development C Exploratory 3. Addr~ Stratigraphic Perforate __ Other 6. Datum elevation (DF or KB) Service __ Grayling Platform, Leg 3, Conductor #2 W of SE Corner, Sec. 29, T9N, R13W, $.M. 4, Location of well at surface 1802' N & 1415' At top of productive interval 584' S & 1989' At effective depth E of NW Corner, Sec. 33, T9N, R13W, S.M. Attotatdepth 921' S & 2211' E of NW Corner, Sec 33, T9N, R13W, S.M. 7. Unit or Property name 8. Well number// 9. Permit number/approval number 74-42 10. APl number 50-- 133-20267 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured true vertical Effec.tive depth: measured true vertical Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: ~ngth 356' 822' 5201' measured true vertical 11160' 11160' feet Plugs(measured) 9711' feet 10860' feet Junk (measured) 9452 ' feet Cmt Retainer Size Cemented Measureddepth ~ueverticaldepth 26" Driven 356' 356' 20" 779 sxs 822' 715' 13-3/8" 1550 sxs 5201' 4524' 9-5/8" 2000 sxs Uppermost 10,447' Lowermost 10,859' Uppermost 9,114' Lowermost 9,451' 111~60;'.~ 9711 ' Tubing (size, grade, andmeasureddepth)2-7/8,', 6.4#, N-80, Buttress @ Otis "B~D" 2erm par @ 10,372'. Packers and SSSV (type and measured depth) 10,452' otis Type "BXE" SSSV @ 312'. 13. Stimulation or cement squeeze summary Intervalstreated (measured) See attached "cement squeeze" summary See a~ta.ched "Abandon" summary Treatment description including volumes usedano f~nal pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 122 702 2054 1060 psi (gas 76 546 592 1140 psi (gas ~bingPressure lift) 100 psi lift) 100 psi 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil .~ Gas __ Suspended 17. I hereby certify that the foreg0,ing is true and correct to the best of my knowledge. ned ~ ' /~roy...) b. Robe itle r .t.~~_/f¢ Environmental Engineer Service SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 UNOCAL WELL RECORD PAGE NO. LEASE TRADING BAY FIELD MCARTHUR RIVER WELL NO. TBUS G-21 LOCATION: CONDUCTOR 2, LEG ~3, 1802' N, 1415'W OF SE CORNER~ SEC. 29, T9N, R13W, SM PERMIT NO. 74-42 SERIAL NO. TD 11160' TVD 9711' DEVIATION (BHL) .... 921'S, 2211' E OF NW Corner Sec. 33, T9N, R13W S.M. COMPANY ENGINEER ~CHUDANOV~ HARNESS, GRAHAM & MCALLISTER SPUD DATE 9/11/89 COMP. DATE 10/8/89. CONTRACTOR POOL ARCTIC RIG NO. 54 TYPE UNIT National 1320 DRILL PIPE DESCRIPTION 5", 19..5~ E&S ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO MLLW RT TO DRILL DECK 125' 228 ' 103' 23.3' 46.6' RT TO PRODUCTION DECK APPROVED CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 26" 1/2" WALL 356' DRIVEN 20" 94~ BUTTRESS H-40 822' CMT'D W/779 SXS 13-3/8" 61~ & 68~ " K-55 5201 ..... 1550SXS 9-5/8" 40~ & 47~ " USS-95, P-110 11160 ..... 2000SXS & N-80 PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 2-30-74 11063'-11084' llll0'FC PRODUCTION ABANDONED 9/23/89 ABANDONED 9./23/89 ABANDONED 9/23/89 ABANDONED 9/23/89 2-31-74 11042'-11063' 11110' PRODUCTION 1-01-75 10958'-10987' 11110' " 10904'-10930' 11110' " 10882'-10900' 11110' " 1-02-75 11042'-11084' 11110' " 5-10-75 10930'-10980' ll091'JUNK " 5-14-75 11060'-11080' 11091' " 11042'-11062' 11091' " 5-18-75 10810'-10850' 11091' " ABANDONED 9/23/89 ABANDONED 9/23/89 ABANDONED 9/23/89 ABANDQNED 9/23/89 ABANDONED 9/23/89 OPEN 10770'-10800' 11091' " OPEN 10755'-10770' 11091' " OPEN 10735'-10745' 11091' " OPEN INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS TYPE: CAMERON WELL HEAD ASSEMBLY CASING HEAD: WF, 12" 3000# x 13-3/8" SOW, W/2 EA. 2" 5000# flanqed outlets CASING HANGER: 12' 3000~ w/ CA 12" x 9-5/8" OD slip & seal assv. TUBING HEAD: DCB 12" 3000~ x 10" 5000~ w! 2 ea 2" 5000~ flanged outlets TUBING HANGER: Sinqle DC-FBB 10" nominal w/ 4-1/2" EUE 8RD (TOP) x 4-1/2" Butt (BOTTOM) TUBING HEAD TOP: 10" 5000~ MASTER VALVES: 4-1/8" Type F CHRISTMAS TREE TOP CONN: 4-1/2" EUE 8 RD UNOCAL WELL RECORD PAGE NO. LEASE TRADING BAY WELL NO. TBUS G-21 FIELD MCARTHUR RIVER LOCATION: CONDUCTOR 2, LEG ~3, 1802' N, 1415'W OF SE CORNER, SEC. 29~ T9Nr R13Wt SM PERMIT NO. 74-42 SERIAL NO. TD 11160' TVD 9711' DEVIATION (BHL) 921'S, 2211' E OF NW Corner Sec. 33, T9N, R13W S.M. COMPANY ENGINEER CHUDANOVt HARNESS~ GRAHAM & MCALLISTER SPUD DATE 9/11/8~. COMP. DATE 10/8/89 CONTRACTOR POOL ARCTIC RIG NO. 54 TYPE UNIT National 1320 DRILL PIPE DESCRIPTION 5"r 19.5~ E&S ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO MLLW RT TO DRILL DECK 125' 228' 103' 23.3' 46.6' RT TO PRODUCTION DECK APPROVED PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 5-19-75 10660'-10690' 11091' PRODUCTION 5-20-75 10540'-10590' 11091' PRODUCTION 10605'-10635' 11091' PRODUCTION 2-24-80 10730'-10840' 11091' PRODUCTION SQUEEZED 9/27/89 SQUEEZED 9/29/89 SQUEEZED 9/28/89 OPEN 10540'-10580' 11091' PRODUCTION 10478'-10506' 11091' PRODUCTION 10-05-89 10477'-10505' 10860'CMT RET PRODUCTION OPEN 10729'-10859' 10860' PRODUCTION OPEN SQUEEZED 9/29/89 OPEN LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 1 of WELL NO. G-21 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 9/11/89 11091' COMMENCED OPERATIONS ON WELL G-21 AT 0000 HOURS, 9/11/89. Rig'up on well G-21, slot #2, leg #3. Spot suction tank and pipe rack on drill deck. Center rig over G-21. Hook up lines on mud pits. Spot reserve tank and second pipe rack section on drill deck. Install lines and grating on mud tanks. Install floor plates in pipe racks. 9/12/89 11091' Continued installing floor plates and hand rails on pipe racks. Refit boards around rotary table. Hooked up degaser and set V-door. Set rat hole and moved Kelly hose to south stand pipe. Leveled derrick and set mouse hole. Moved choke panel to south side of pits. Start building slides for shakers. Rigged up 4-1/2" lubricator on G-21. Bull headed down tubing 212 BBL FIW at 3.5 BPM. Well on a slight vacuum. 9/13/89 11091' Rigged up Myers wireline and pulled ball valve. Rigged up APRS and ran in with perf gun to shoot circulation holes. Tied into GLM at 10307' and located "XO" sleeve at 10361'. Spotted perforating gun and shot 10 holes from 10357' to 10361'. Tubing went on a vacuum after gun fired. Waited for fluid level to ~ ~ ~ ~i'% equalize and pulled out with perforating gun. i'i~ ~'.~ ~'~ ~ ? ~ Rigged up for circulating and pumped FIW down ~ ..... ii'~[~ '~ tubing. High pressure mud valve to leg ~2 ,~ washed out-replaced seat and paddle. i~!~i~'~ .....~ Circulated well to pipeline. Pumped total of ~.~ 1153 bbls (353 bbls before establishing · ~i~~, '-~ ~ ~ returns to surface). Annulus and tubing on a ~'~~ vacuum at end of displacement. Set BPV and remove production tree. Set in riser and BOPE. Nipple up BOPE. 9/14/89 11091' Continued to nipple up BOPE. Changed pipe rams to 4-1/2". Tested BOPE to Unocal specifications. Adjust drawworks brakes. Pulled BPV. Attempted to pull tubing free with l12K overpull. Well taking 3 to 5 BPM. Mixed and pumped a 50 BBL sized salt pill. Squeezed away pill with 500 psi initial pressure and 2000 psi final pressure. Rig up wireline to make a 3.60" gauge cutter run. 9/15/89 7223' Continued in with 3.60" gauge cutter and set down at 7260' WLM. Trip for 3.25" gauge cutter and ran in to 10395' WLM (bottom of seal assembly). Rigged up APRS, ran in to 10387'TM, pulled 250K on tubing, and set off string shot to jar seals free-no good. Trip wireline for 3.562" je~ cutter. Ran in and cut tubing at 7223' TM. Rigged down wireline. Pulled o~t of hole laying down 4-1/2" tubing (recovered 7126' tbg and 7 GLM's). Set test plug and test CSO rams. wear bushing and made up fishing tool assembly. Ran in picking up 5" drill pipe. Set LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 2 of WELL NO. G-21 FIELD MCARTHUR RIVER DATE E.T.D. 9/16/89 7217' 9/17/89 7217' 9/18/89 10362' 9/19/89 10472' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued running in with fishing tool assembly and tagged top of fish at 7217' DPM. Polished top to 4-1/2" OD. Pulled out of hole and changed top pipe rams to 5" and tested same. Ran in and engauged fish at 7217' DPM. Attempted to jar tubing free-no good. Release from fish and tripped for tool string with ID that will pass a 2.7" jet cutter. Held meeting with all on tour drilling crew and went over station bill for drilling response to alarms. Made up fishing tool assembly and ran in hole. Continued running in with fishing tool assembly and engaged fish at 7217' DPM. Rigged up APRS and ran in with 2.7" OD jet cutter-could not get in top of fish. Pulled out and rigged down APRS wireline. Released from fish and tripped for new fishing assembly. Made up fishing tool assembly and ran in to 7217' DPM. Polished ID of fish with a 3 5/8" mill (total cut on ID of tubing = 7"). Trip for fishing tool assembly. Ran in hole and engaged fish at 7217' DPM. Rigged up APRS and ran in with 2.7" OD jet cutter to 10359' TM. Fired cutter with 200 K overpull-did not get a cut. Ran freepoint and found pipe free to top of packer. Rigged up APRS for coiled shot. Ran in and set shot at collar located 2 joints above bottom GLM (shot @ 10243' TM). Pulled 120K overpull and fired shot. Tubing did not pull free. Tripped out of hole with wireline. Worked pipe jarring with 170K overpull and tubing came free. Pulled out of hole standing back 5" drill pipe. Released overshot and layed down fishing tools. Pulled out laying down 4-1/2" tubing and GLM's (recovered a total of 3153' including 10 GLM's and "XO" sleeve). Tubing parted at 2.7" jet cut at 10362'. Pulled wear bushing and set test plug. Changed lower pipe rams to 5" and pressure tested same to 250 psi (low) and 3000 psi (high). Pulled test plug and reset wear bushing. Made up F/T assembly and ran in to 1000'. Cut drilling line 79' and worked on drawworks brakes. Continued running in and tagged top of fish 10362' DPM. Dressed top of fish and engaged same. Attempted to jar fish free at 120K overpull-no good. Released from fish. Redressed top of fish. Tripped for packer milling assembly. Continued trip for packer milling assembly. Made up packe~°~ miliing assembly. Ran in and tagged packer at 10374' DPM. Milled packer from 10374' to 10377' DPM. Packer fell away. Chased packer 15' with no tag. Circulated well through choke (had gas bubble to surface on bottoms up). Trip for fishing assembly. Made up fishing assembly. Ran in and engaged fish at 10472' DPM. Fished started moving with hook overpull. Had drag to 80K over for the first 5 stands and then started pulling free. Recovered all of "F-i" permanent packer and stab-through assembly. Made up clean out assembly and ran in hole. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 3 of WELL NO. G-21 FIELD MCARTHUR RIVER DATE E.T.D. 9/20/89 10869' 9/21/89 11004' 9/22/89 11004' 9/23/89 10870' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued in with clean out assembly and tagged fill at 10777' DPM. Cleaned out loose fill 10797' DPM. Cleaned out firm fill to top of packer at 10868' DPM. Circulated well clean (quite a bit of sand across shaker). Trip for clean out assembly. Made up 2 joints of 2-3/8" tubing with saw tooth collar on 5" drillpipe. Ran in and washed through top of packer at 10869' and cleaned out packer tail to 10926' DPM. Circulated well clean. Trip for packer milling assembly. Made up 8-1/2" x 7-1/16" wash over shoe. Ran in and milled on permanent packer at 10869' DPM. Finished milling over permanent packer at 10869' DPM. Fluid losses to hole increased from 1/2 BPH to 45 BPH. Mixed 40 BBL sized salt pill and spotted above packer body. Pulled 7 stands and down squeezed on pill. Held pressure at 400 psi for 30 minutes at completion of the squeeze. Trip for fishing assembly. Had 1-1/2 hours down time due to an electrical problem with the wiring to drawworks "B" motor. Completed trip and laid down burn over shoe. Made up spear with a 4.76 OD grapple. Ran in and engaged fish at 10869' DPM. Pulled seals out of packer at 11004'. Circulated three hole volumes to clear well of migrating gas. Pulled out and recovered entire fish (169.82'). Made up 8-1/2" bit and scraper and ran in hole. Finished running in to packer at 11004' with bit and scraper - no fill. Circulated well clean and pulled out of hole. Rigged up Schlumberger electric line and lubricator. Ran CET/CBT/GR/CCL from 10970' to 7500'. Pulled out and rigged down electric line. Ran in with 9-5/8" RTTS and bypass to 10456' DPM. Set packer and pressure tested casing to 3000 psi for 30 minutes - held OK. Released packer and pulled out of hole. Picked up 10 joints of 3-1/2", 9.2# tubing (cementing tail) and ran in on 5" drill pipe. Continued in with open ended pipe to 11087' and circulated out fill to 11091' ETD. Circulated well clean and hung open ended pipe at 11089'. Equalized in 70 sx Class "G" cement with 0.5% Halad 344, 0.2% CFR-3 and 0.15% LWL mixed to a 15.5 ppg slurry weight to abandon lower HB-5 and HB-6 perforations from 10904' to 10987' and 11042' to 11084' DIL. Cement in place at 0528 hours. Pulled out of hole and laid down tubing tail. ~de up bit on 6 ea 6-1/2" drill collars and ran in hole. Tagged cement at i0S84' DPM and cleaned out firm cement to 10900' DPM. Pulled out and laid down junk basket. Set retainer on wireline at 10870' DIL. Pulled out and rigged down electric line. Made up stab-in tool on 5" drill pipe and ran in hole. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 4 of WELL NO. G-21 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 09/24/89 10645' Stabbed into cement retainer at 10870' with stinger on 5" drill pipe. Rigged up and tested surface lines to 6500 psi. Established a formation breakdown at 4700 psi and injected 3/4 BPM at 4750 psi. Mixed and pumped 100 sxs Class "G" cement with 0.5% Halad 344, 0.2% CFR-3, and 0.15% LWL at a 15.5 PPG slurry weight for abandonment of Hemlock Bench 5 perforations from 10882' to 10900' DIL. Displaced cement to 10 BBL above retainer and stabbed in. Displaced 19 sxs below retainer with a final squeeze rate of 1/4 BPM at 5800 psi (2000 psi on backside). Cement in place at 0558 hours. Pulled up and reversed out 81 sxs cement. Pulled out of hole and ran BOPE test. Made up cement retainer with setting tool on 5" drill pipe and ran in hole. Set retainer at 10710' to isolate HB-4 from HB-3. Rigged up and tested surface lines to 6000 psi. Established a HB-4 formation breakdown at 3100 psi and injected 1 BPM at 3500 psi. Good isolation between HB-3 and HB-4. Trip for cement retainer to squeeze HB-3 perforations from 10660' to 10690' DIL. Made up retainer with setting tool on 5" drill pipe and ran in hole. Set retainer between HB-2 and HB-3 at 10645'. Rigged up and tested surface lines to 6800 psi. 09/25/89 10326' Attempted to breakdown HB-3 and well began to circulate with 1000 psi drill pipe pressure. Circulated around retainer for 40 minutes at 3 BPM with 3200 psi to clean channels behind blank pipe. Mixed and pumped 100 sxs "G" cement with 0.5% Halad 344, 0.2% CFR-3, and 0.15% LWL at a 15.5 PPG slurry weight to isolate HB-2 from HB-3. Stabbed in with cement 10 bbl above retainer and displaced 75 sxs cement below the retainer at a final rate of 2.5 BPM with 1700 psi. Cement in place at 0350 hours. Pulled up and reversed out 63 sxs cement. Trip for cement retainer to squeeze lower HB-2 perforations from 10605' to 10635' DIL. Ran in on drill pipe and set retainer at 10598'. Rigged up and tested surface lines to 6500 psi. Stabbed in and established a formation breakdown at 2500 psi and injected 2 BPM at 3100 psi. Mixed and pumped 150 sxs "G" cement with 0.5% Halad 344, 0.2% CFR-3, and 0.95% LWL at a 15.5 ppg slurry weight. Stabbed in with cement 10 bbl above retainer and backed up annulus with 2000 psi. After displacing 7 bbl of cement through the retainer the squeeze job broke ~round to the upper HB-2 perforations. Displaced 126 sxs cement below retainer. Cement in place at 1506 hours. Pulled up and attempted to reverse-pipe plugged. Ran from cement by pulling 6 stands and reversed out at that point. No cement reversed out. Trip for drilling assembly. Ran in and tagged cement at 10326' DPM (276' above retainer). Pulled up to circulate and wait on cement. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 5 of WELL NO. G-21 FIELD MCARTHUR RIVER DATE E.T.D. 9/26/89 10644' 9/27/89 10599' 9/28/89 10596' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued waiting on cement until 0900 hours. Drilled firm cement from 10326' to retainer at 10517'. Drilled retainer and hard cement to 10620', then stringers to 10643'_ Drilled on retainer at 10644' until bit quit. Trip for new bit. Completed trip in with new bit and drilled retainer at 10644'. Drill cement to top of retainer at 10710'. Circulated well clean. Trip for cement retainer. Ran in with retainer to 10643' DPM. Rigged up and tested surface line to 6500 psi. Broke circulation and set retainer at 10643' DPM. Tested drill pipe to 4500 psi and annulus to 2000 psi. Established breakdown on HB-3 perforations (10660'-10690' DIL) with 4400 psi and injected 1 BPM with 4600 psi. Squeezed HB-3 perforations with 150 sxs cement. Maximum squeeze pressure was 5900 psi. Cement in place at 1520 hours. Pulled up and reversed out 42 sxs cement. Trip for cement retainer to squeeze lower HB-2. Ran in with retainer to 10599' DPM. Rigged up and tested surface lines to 6500 psi. Broke circulation and set retainer at 10599' DPM. Tested drill pipe to 4500 psi and annulus to 2000 psi. Established breakdown on lower HB-2 perforations (10605'-10635' DIL) with 5900 psi and injected 3/4 BPM with 5800 psi. Squeezed lower HB-2 perforations with 100 sxs cement. Maximum squeeze pressure was 5600 psi. Cement in place at 0200 hours. Pulled up and reversed out 56 sxs cement. Trip for cement retainer to squeeze upper HB-2. Ran in with retainer to 9000' and cut drilling line 104 ft. Continued in to 10520'. Rigged up and tested surface lines to 6500 psi. Broke circulation and set retainer at 10520' DPM. Tested drill pipe to 4500 psi and annulus to 2000 psi. EstabliShed breakdown on upper HB-2 perforations (10540'-10590' DIL) with 4400 psi and injected 2 BPM with 4600 psi. Squeezed upper HB-2 with 186 sxs cement. Maximum squeeze pressure was 5400 psi. Cement in place at 1340 hours. Pulled up and reversed out 26 sxs cement. Trip for clean out assembly. Ran in hole to 10460' DPM and washed down to 10500' DPM. Cleaned out firm cement to 10518' DPM. Drilled retainer and cleaned out firm cement to 10594' DPM. Washed down to 10596' DPM and tagged retainer. Circulated we]! clean and tripped for RTTS tool. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 6 of WELL NO. G-21 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 9/29/89 10520' Made up RTTS and ran in to 10517' DPM to pressure test squeezed HB-2 perforations from 10540' to 10590' DIL. Rigged up and tested surface lines to 6500 psi. Set RTTS at 10517' DPM and pressured against HB-2 to 4000 psi. Pressured to 5000 psi and had slow bleed to 4400 psi. Repressured and established an injection rate of 1 BPM with 5500 psi. Trip for cement retainer to resqueeze HB-2. Made up retainer and ran in to 10520' DPM. Rigged up and tested surface lines to 6500 psi. Broke circulation and set retainer at 10520' DPM. Tested drill pipe to 4500 psi and annulus to 2000 psi. Established breakdown of upper HB-2 perforations (10540'-10590' DIL) with 4900 psi and injected 1 BPM with 5000 psi. Squeezed upper HB-2 with 29 sxs cement. Cement in place at 1745 hrs. Trip for drilling assembly. 9/30/89 10712' Ran in hole with drilling assembly and tagged cement at 10507' DPM. Cleaned out firm cement to 10520' DPM. Drilled retainer at 10520' DPM and cleaned out hard cement to 10560' DPM. Cleaned out cement stringers to 10597' DPM. Trip for new bit. Drilled retainer at 10597' DPM and cleaned out hard cement to 10639' DPM. Drilled retainer at 10643' DPM and cleaned out hard cement to 10702' DPM. Cleaned out cement stringers and junk to 10712' DPM. Trip for test assembly to drawdown test squeezed HB-2 and HB-3 perforations. 10/01/89 10712' Continued trip for test assembly. Made up drawdown test assembly and ran in hole filling the first 2500' of drill pipe with workover fluid Rigged up and tested surface lines to 3000 psi. Held safety meeting on working with gas cushions. Pressured drill pipe to 1150 psi with gas off the H&H Header. Set packer at 10520' DPM, shot fluid level, and opened hydrospring. Bled off gas cushion to 10 psi. Shot fluid levels every 15 minutes for 1 hour. No fluid rise during drawdown period. Filled drill pipe with fluid and pressured annulus to 1700 psi to open reversing valve. Reversed drill pipe clean. Trip for drilling assembly. 10/02/89 10871' Perform weekly BOPE test. Made up drilling assembly and ran in to 8000'. Cut drilling line and continued running in to 10712' DPM. Drilled retainer at 10712' DPM. Chased. retainer to 10852' DPM. Drilled on retainer junk at 10852' DPM for 1-1/4 hours with no progress. Trip for new bit and strapped out (7 ft correction in measurement). Cleaned out to 10871' DPM. Circulated well with FIW. Trip for casing scraper. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 7 of WELL NO. G-21 FIELD MCARTHUR RIVER DATE E.T.D. 10/03/89 10871' 10/04/89 10871' 10/05/89 10860' DIL ETD 10/06/89 10860' DIL ETD 10/07/89 10860' DIL ETD 10/08/8~ 10860' DIL DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Ran in hole with casing scraper to 10871' DPM. Circulated well with FIW until returns were clean. Cleaned mud pits. Had quite a bit of solids in shaker pit. Mixed and filtered 3% KCL completion fluid. Displaced well with filtered fluid. Circulated and filtered fluid to 20 NTU reading at the flowline. .Trip for perforating assembly. Continued trip for perforating assembly. Made up guns, packer, and test tools. Ran in hole filling the drill pipe with 64.3 pcf fluid for perforating cushion. Rigged up test manifold and fluid level equipment. Rigged up electric line and ran in with correlation log. Ran correlation log and spaced out guns. Tagged ETD ± 8' high. Ran confirmation log. Guns on depth according to RA tag. Filled drill pipe and cycled omni valve open. Reversed one drill pipe volume. Pulled out to re-strap perforating assembly. Continued pulling out with perforating assembly. Strap guns and stand back same. Rig up wireline and ran in with gamma ray/neutron log for depth correlation. Tagged ETD at 10860' DIL (10' high). Made up and ran back in with perforating assembly. Filled drill pipe with 64.3 pcf fluid above omni valve to obtain a 750 psi underbalance. Rigged up surface lines. Ran correlation log. Set packer and reran correlation log-guns 1 ft. high. Test surface lines. Cycle omni valve open and shot perforating gun. Perforate HB-1 from 10477' to 10505' DIL and HB-4 from 10729'-10859' DIL at 4 HPF with 32 gram charges. Performed impulse test. Finished impulse test. Cycle omni valve to reversing position and reversed 2 drill pipe volumes. Cycle omni valve open and released baker test packer. Well taking 16 BBL/hr. Mixed and pumped sized salt pill to control fluid loss. Pulled out and layed down perforating assembly. Made up bit and scraper and ran in to 10866' DPM. Cleaned out fill to 10871' DPM. Made up OTIS "BWD" packer and ran in hole on 5" drill pipe. Space out Otis "BWD" packer, drop ball, and set packer at 10375' DIL. Test back side to 2000 psi. Sheared out with 3300 psi and pulled out of hole. Pulled wear bushing and changed top and bottom rams to 2-7/8". Tested rams to 2000 psi. Rigged up tubing tools and hydrotest. Run 2-7/8" gas lift production string. Hydrotest tubing to 5000 psi. Continue running gas lift production string. Tagged packer at 10375' DIL and stabbed into seal assembly. Test packer. Spaced out tubing, installed hanger, and tested SSSV control line to 5000 psi. Landed tubing and retested packer. Set back pressure valve. Remove BOPE. Install production tree. Test seals and tree to 5000 psi. Turned well over to production. Released riq at 1200 hours on !0/08/89 to TBUS G-24. A 20"@ 822' 3-3/8" @ 5201' / 9-5/8" @ 11160' Z 1 2 O' ,3 0 4 0 5 0 6 ,, O 7 O 8 O 9 O 10 O 11 Q 12 XA 15 X 14 -i -. ii CEMENT :: CEMENT B 16 CASING AND ABANDONMENT DETAIL A) KELLY BUSHING AT 0.00' B) CAMERON TUBING HANGER AT 42.75' C) 20", 94#, B-40 CASING AT 822' D) 13-3/8", 61# & 68#, K-55 CASING AT 5201' E) CEMENT RETAINER AT 10860' F) BAKER MODEL F-1 PKR AT 11004' E) 9-5/8", 40# & 47#, USS-95, P-110 & N-80 CASING AT 11160' F) 7", 29J, N-80 CASING AT 10450' G) CEMENT RETAINER AT 10420' TUBING DETAIL 2-7/8"' 6.4~, N-80, BUTTRESS, SC CPLGS 2)" 3) 4) 5) · 6): 7) 9) 10) 11) 12) · 13)._ 14) .CAMERON TBG BANGER AT 42.75' 1) 4-1/2"x 2-7/8" X-OVER AT 82.41' 2-7/8" OTIS BALL VALVE AT 311.70' 2-7/8" MACCO GLM '1 AT 2098.72 2-7/8" MACCO G~¼ #2 AT 3715.57 2-7/8" MACCO GLM %3 AT 5053.51 2-7/8" MACCO GLM #4 AT 5966.95 2-7/8" MACCO Gk~ #5 AT 6698.08 2-7/8" MACCO GLM %6 AT 7432.09 2-7/8" MACCO G~¼ #7 AT 8165.40 2-7/8" MACCO GLM #8 AT 8888.16 2-7/8" MACCO GLM #9 AT 9606.13 2-7/8" MACCO GLM #10 AT 10337.09' 2-7/8" OTIS "XA" SLEEVE AT 10361.53' 2-7/8" OTIS "X" NIPPLE AT 10417.58' ' ' 15). 2-7/8" OTIS WIRELINE REENTRY GUIDE _.. -:--'-' BOTTOM AT 10451.81' . 16) OTIS MODEL 'BWD" PERMA-DRILL PACKER AT 10371.62' DPM A) OTIS SEAL BORE EXTENSION FROM 10376.70' TO 10384.40' DPM B) OTIS SEAL ASSY WITH STRAIGHT "J" LOCATOR FROM 10377.26' TO 10387.56' TM PERFORATION RECORD ======~==========~ 2/30/74 11063'-11084' 2/31/74 11042'-11063' 1/1/75 10958'-10987' 10904'-10930' 10882'-10900' 1/2/75 11042'-11084' 5/10/75 10930'-10980' 5/14/75 11060'-11080' 11042'-11062' 5/18/75 10810'-10850' 10755'-10800' 10735'-10745 10660 -10690 10540 -10590 10605 -10635 10730 -10840 10540 -10580 10478 -10506 10477 -10505 10729 -10859 5/19/75 5120/75 2/24180 1015189 ABANDONED ABANDONED ABANDONED ABANDONED ABANDONED ABANDONED ABANDONED ABANDONED ABANDONED PROD - OPEN PROD - OPEN PROD - OPEN SQUEEZED SQUEEZED SQUEEZED PROD - OPEN SQUEEZED PROD - OPEN PROD - OPEN PROD - OPEN WELL TBUS G-21 COMPLETION ( 10-8-89 ) UNION OIL COMPANY OF CALIFORNIA (db~ UNOCAL) DRAWN' DAC SCALE' NONE DATE' 10- 17-89 PERFORATIONS CEMENT SUMMARY TBUS G-21 WORKOVER 9/11 THRU 10/8/89 PRE-WORKOVER POST-WORK~ V'~R,~: ~ HB-1 (10478' - 10506') UPPER HB-2 (!0540' - 10590') LOWER HB-2 (10605' - 10635') HB-3 (10660' - 10690') HB-4 (10730' - 10850') UPPER HB-5 (10882' - 10900') LOWER HB-5 (10904' - 10987') HB-6 (11042' - 11084') OPEN OPEN OPEN OPEN OPEN ISO W/PKR ISO W/PKR ISO W/PKR OPEN SQUEEZED SQUEEZED SQUEEZED OPEN ABANDONED ABANDONED ABANDONED HB-5 AND HB-6 ABANDONMENT SUMMARY 9/23/89 9/24/89 TOC @ 10884' SET RET @ 10870' EQUALIZED IN 70 SX CLASS "G" CMT PLU_~ FROM 11091' ETD TO 10884' TO ABANDON LOWER HB-5 AND HB-6 SQZ WITH 100 SX CLASS "G" CMT TO ABANDON UPPER HB-5 HB-2 AND HB-3 SQUEEZE SUMMARY 9/24/89 9/25/89 9/25/89 9/27/89 9/28/89 9/28/'89 9/29/89 SET RET @ 10710' SET RET @ 10645' SET RET @ 10598' SET RET @ !0643' SET RET @ i0599' SET RET @ 10520' SET RET @ 10520' ISOLATION OF HB-3 FROM HB-4 SQZ W/ 100 SX CMT TO ISOLATE BLANK CSG, HAD CIRC AROUND RET SQZ w/ 150 SX CMT TO ISOLATE BLANK CSG, HAD CIRC AROUND RET SQZ HB-3 W/ 150 SX CLASS "G" CMT. MAX SQZ PRESS = 5900 PSI SQZ LOWER HB-2 W/ 100 SX CLASS "G" CMT. MAX SQZ PRESS = 5600 PSI SQZ UPPER HB-2 W/ 186 SX CLASS "G" CMT. MAX SQZ PRESS = 5400 PSI RESQZ UPPER HB-2 W/ 29 SX CLASS "G" CMT. MAX SQZ PRESS 5800 PSI JTS PUP PUP PUP 23 PUP PUP PUP 22 PUP 23 PUP PUP 23 PUP 23 PUP 23 PUP 29 PUP PUP 43 PUP 52 PUP PUP 58 7 PUP PUP X-OVER 1 TUBING DETAIL TBUS G-21 DESCRIPTION LENGTH REENTRY GUIDE SHOE 0.74 2-7/8",6.4#,N-80,BUTT 32.20 OTIS X LANDING NIPPLE 1.29 2-7/8",6.4#,N-80,BUTT 30.02 OTIS SEAL ASSY 10.30 2-7/8",6.4#,N-80,BUTT 6.19 2-7/8",6.4#,N-80,BUTT 6.10 OTIS XA SLIDING SLEEVE 3.44 2-7/8",6.4#,N-80,BUTT 17.68 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 707.81 2-7/8",6.4#,N-80,BUTT 6.08 2-7/8",6.4#,N-80,BUTT 6.18 2-7/8",6.4#,N-80,BUTT 4.10 MACCO GLM 6.79 2-7/8",6.4#,N-80,BUTT 683.39 2-7/8",6.4#,N-80,BUTT 27.77 MACCO GLM 6.81 2-7/8",6.4#,N-80,BUTT 709.32 2-7/8",6.4#,N-80,BUTT 3.49 2-7/8",6.4#,N-80,BUTT 3.15 MACCO GLM 6.80 2-7/8",6.4#,N-80,BUTT 712.56 2-7/8",6.4#,N-80,BUTT 13.95 MACCO GLM 6.80 2-7/8",6.4#,N-80,BUTT 715.60 2-7/8",6.4#,N-80,BUTT 11.63 MACCO GLM 6.78 2-7/8",6.4#,N-80,BUTT 719.26 2-7/8",6.4#,N-80,BUTT 5.11 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 893.46 2-7/8",6.4#,N-80,BUTT 5.00 2-7/8",6.4#,N-80,BUTT 8.21 MACCO GLM 6.77 2-7/8",6.4#,N-80,BUTT 1320.86 2-7/8",6.4#,N-80,BUTT 10.30 MACCO GLM 6.78 2-7/8",6.4#,N-80,BUTT 1596.57 2-7/8",6.4#,N-80,BUTT 9.42 2-7/8",6.4#,N-80,BUTT 4.10 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 1784.53 OTIS SSSV X-PROFILE 2.49 2-7/8",6.4#,N-80,BUTT 215.29 2-7/8",6.4#,N-80,BUTT 8.05 2-7/8",6.4#,N-80,BUTT 5.35 2-7/8" x 4-1/2" BUTT 0.60 4-1/2",12.6#,N-80,BUTT 38.93 CAMERON TBG HANGER 0.73 LANDED BELOW ZERO 42.75 BOTTOM 10451.81 10451.07 10418.87 10417.58 10387.56 10377.26 10371.01 10364.97 10361.53 10343.85 10337.09 9629.28 9623.20 9617.02 9612.92 9606.13 8922.74 8894.97 8888.16 8178.84 8175.35 8172.20 8165.40 7452.84 7438.89 7432.09 6716.49 6704.86 6698.08 5978.82 5973.71 5966.95 5073.49 5068.49 5060.28 5053.51 3732.65 3722.35 3715.57 2119.00 2109.58 2105.48 2098.72 314.19 311.70 96.41 88.36 83.01 82.41 43.48 42.75 TOP 10451.07 10418.87 10417.58 10387.56 10377.26 10371.01 10364.97 10361.53 ].0343.85 10337.09 9629.28 9623.20 9617.02 9612.92 9606.13 8922.74 8894.97 8888.16 8178.84 8175.35 8172.20 8165.40 7452.84 7438.89 7432.09 6716.49 6704.86 6698.08 5978.82 5973.7]_ 5966.95 5073.49 5068.49 5060.28 5053.51 3732.65 3722.35 3715.57 2119.00 2109.58 2105.48 2098.72 314.19 311.70 96.41 88.36 83.01 82.41 43.48 42.75 0.00 1) CAMERON HANGER TOP IS 4-1/2" EUE 8RD THREAD PACKER DETAIL DESCRIPTION LENGTH BOTTOM TOP OTIS "BWD" PERMA-DRILL 12.78 10384.40 DPM 10371.62 DPM OTIS 9-5/8" · 4" "BWH" PERMA DRILL PACKER WELL: G-21 COMPLETED: OCTOBER 7, 1989 2.32 I~± ~'~'~ o, 7.70' 12.78' Top of Packer: 10,371.62' Drill Pipe Measurement BIT RECORD COUNTY Cook Inlet FIELD McArthur River STATE AK SECTION TOWNSHIP RANGE LOCATION WELL NO. G-21 CONTRACTOR Pool Arctic Alaska SPUD REACHED T.D. RIG NO. #54 PUMP NO. 1 OPERATOR Unocal TOOLPUSHER LINER PUMP NO. 2 LINER PUMP POWER TYPE MUD DRILL PIPE TOOL JOINTS Size Type O.D. NUMBER O.D. I.D. LENGTH DRILL COLLARS DRAWWORKS POWER NO. SIZE MAKE TYPE 1 8-1/2 SEC M44N JET ACCUM WT. PUMP SPM 32nd DEPTH DRLG 1000 PUMP OPER- IN SERIAL OUT FEET HOUR FT/HR HRS LBS R P M PRESS PUMP ! ~ BITS 401232 MUD DULL. COND. FORMATIONS WT VIS WL ~ ~ G OTHER REMARKS c/o run 1RR 8-1/2 SEC M44N 401232 c/o run 1RR 8-1/2 SEC M44N 401232 c/o run 1RR 8-1/2 SEC M44N 4012:32 c/o run 1RR 8-1/2 SEC M44N 401232 c/o run 2 8-1/2 SEC M44N 16 380857 8 2 I DRL ret 3 8-1/2 SEC M44N 16 401249 4 8-1/2 SEC H77SG 24 356187 5 8-1/2 SEC M44N 24 402276 1RR 8-1/2 SEC M44N 401232 DRL ret 6 1 I DRL ret 7 1 I DRL ret c/o run BIT RECORD COUNTY FIELD STATE SECTION TOWNSHIP RANGE LOCATION WELL NO. Cook Inlet McArthur River AK G-21 CONTRACTOR RIG NO. OPERATOR TOOLPUSHER Pool Arctic Alaska ~54 Unocal SPUD REACHED T.D. PUMP NO. 1 LINER PUMP NO. 2 LINER PUMP POWER TYPE MUD DRILL PIPE Size Type O.D. NUMBER O.D. TOOL DRILL JOINTS COLLARS I.D. LENGTH DRAWWORKS POWER NO. SIZE MAKE TYPE JET ACCUM WT. PUMP SPM 32nd DEPTH DRLG 1000 PUMP OPER- IN SERIAL OUT FEET HOUR FT/HR HRS LBS R P M PRESS PUMP ! ~ BITS 6 8-1/2 SEC M44NG 24 403789 MUD DULL. COND. FORMATIONS WT VIS WL T B G OTHER 7 1 I REMARKS DRL ret 7 8-1/2 SEC M44NGF 24 403790 6 1 I DRL ret 8 8-1/2 SEC M4NJ 24 5064'76 6 1 I DRL ret 1RR 8-1/2 SEC M44N 401232 Scraper run FU~D NAME: Trading Bay Unit NAME: G-21 ~C~: Graylir~ Platform - Kenai, Alaska CASING: 9-5/8" 47 ppf N-80 TUBING: 2-7/8" 6.4 ppf Buttress N-80 Q[IIfE NO: 431/1010/03/89 Ila~TE: October 7, 1989 (907) 283-7531 E~S(~IPrION I.D. 10 1. K.B. 2. Cameron Tubing Hanger 11 4-1/2" EU x 4-1/2" BTC 3. One (1) Joint 4-1/2" 12 12.6 ppf BTC Tubing (Range 4) 13 4. Swage - 4-1/2" .BTC x 2-7/8" 2.44" 5. P~p Joint 2.44" 15 6. Pup Joint 2.44" 7. Seven (7) Joints of Tubing 2.44" 16 8. Otis 1/4" Stainless Steel -- 17 Control Line .049" Wall (P/N 22 SXX 31050) 18 9. Otis "XXO" Safety Valve Landing Nipple (P/N 11 XXO 23110) 19 10. Fifty-Eight (58) Joints of 2.44" 11. Gas Lift Mandrel #10 2.44" 21 12. Pup Joint 2.44" 22 13. Pup Joint 2.44" 14. Fifty-Two (52) Joints of 2.44" 23 Tubing -- 24 15. Gas Lift Ma~ #9 2.44" 16. Pup Joint 2.44" 25 17. Forty-Three (43) Joirrts of 2.44" 26 18. Gas Lift Mandrel #8 2.44" 27 19. Pup Joint 2.44" 28 20. Pup Joint 2.44" 21. Twenty-Nine (29) Joints of 2.44" 29 Tubing 22. Gas Lift Mandrel #7 2.44" 23. ~ Joint 2.44': 3.95" oom. 42.75' -0- .73' 42.75' 3.95" 5.2" 38.93' 43.48' 4.5" .60' 82.41' 3.5" 5.35' 83.01' 3.5" 8.05' 88.36' 3.5" 215.29' 96.41' .25" 3.25" ECC. 3.85" 2.49' 311.70' 3.5" 1784.53' 314.19' 4 · 75" 3.5" 3 · 5" 3 · 5" 6.76' 2,098.72' 4.10' 2,105.48' 9.42' 2,109.58' 1596.57' 2,119.00' 2.313" 4.75" 6.78' 3,715.57' 3.5" 10.30' 3,722.35' 3.5" 1320.86' 3,732.65~ 4 · 75" 3 · 5" 3.5" 3.5" 4 · 75" 3.5" 6.77' 5,053.51' 8.21' 5,060.28' 5.0' 5,068.49' 893.46' 5,073.49' 6.76' 5,966.95' 5.11' 5,97~.?I' --46 47 48 NO: 431/1010/03/89 October 7, 1989 EES(]~I~TI~ I.D. O.D. 24. TWenty-~%ree (23) Joints of 2.44" 3.5" 25. Gas Lift ~ #6 2.44" 4.75" 26. Pup Joint 2.44" 3.5" 27. Twenty-q]3ree (23) Joints of 2.44" 3.5" 28. Gas Lift Ma/xlrel #5 2.44" 4.75" 29. Pup Joint 2.44" 3.5" 30. Twenty-q/lree (23) Joints of 2.44" 3.5" 31. Gas Lift Mandrel #4 2.44" 4.75" 32. Pup Joint 2.44" 3.5" 33. Pup Joint 2.44" 3.5" 34. TWenty-Shree (23) Joints of 2.44" 3.5" 35. Gas Lift Mandrel #3 2.44" 4.75" 36. Pup Joint 2.44" 3.5" 37° Twenty-Two (22) Joints of 2.44" 3.5" 38. Gas lift Mandrel #2 2.44" 4.75" 39. Pup Joint 2.44" 3.5" 40. Pup Joint 2.44" 3.5" 41. Pup Joint 2.44" 3.5" 42. Twenty-q]%ree (23) Joints of 2.44" 3.5" 43. Gas Lift Mandrel #1 2.44" 4.75" 44. P~p Joint 2.44" 3.5" 45. Otis "XA" Slid/ng Side Door 2.313" 3.75" o~e~p/c~-D~n (P/N 121 XA 17) 46. Pup Joint 2.44" 3.5" 47. Pup Joirfc 2.44" 3.5" 48. Otis Str. Slot Seal Assembly a. Str. Slot Locator 2.44" 4.47" (P/N 212 S 40000-a) b. Seal Assembly 2.97" 4.04" (P/N 212 MSN 40000-a) c. Exter~ion 2.97" 3.96" (P/N 212 X 40000-a) d. Seal Assembly 2.97" 4.04" (P/N 212 MSN 40000-a) e. Extension 2.97" 3.96" (P/N 212 X 40000-A) f. Seal Assembly 2.97" 4.04" (P/N 212 MHN 40000-a) g. Seal Assembly 2.97" 4.04" (P/N 212 MSN 40000-a) h. Adaptor - 3-1/2" NU 2.44" 3.96" x 2-7/8" BTC BxP 719.26' 6.78' 11.63 ' 715.60 ' 6.80' 13.95' 712.56' 6.80' 3.15' 3.49' 709.32 ' 6.81' 27.77 ' 683.39' 6.79' 4.10' 6.18' 6.08' 707.81' 6.76' 17.68' 3.44' 6.10' 6.19' 10.30' (1.84') (1.01') (2.01') (1.01') (2.01') (1.01') (~.01') (.4') PAGE2 5,978.82' 6,698.08' 6,704.86' 6,716.49' 7,432.09' 7,438.89' 7,452.84' 8,165.40' 8,172.20' 8,175.35' 8,178.84' 8,888.16' 8,894.97' 8,922.74' 9,606.13' 9,612.92' 9,617.02' 9,623.20' 9,629.28' 10,337.09' 10,343~85' 10,361.53' 10,364.97' 10,371.07' 10,377.26' QEEY/~/~): 431/1010/03/89 DATE: October 7, 1989 49. 50. 51. 52. One (1) Joint of Tubing otis "~' Sel~ive Landing Nipple (P/N 11 X 23100-A) One (1) Joint of Tubing otis Mule Shoe Wireline (P/N 212 M 3) 2.44" 2.313" 2.44" 2.44" oom. 3.5" 3.24" 3.5" 30.02' 1.29' 32.20' .74' PAGE3 10,387.56' 10,417.58 ' 10,418.87' 10,451.07' 10,451.81' A. otis "5~H" Perma-Drill 4.0" Set on Drill Pipe W/~ydrau~ic .Setting Tool 9-5/8" 36-54.9 LB (P/N 212 ~H 95400-A) B. Otis Seal Bore Extension 4.0" (P/N 212 C 7060) Bottom Of Packer and Seal Seal Bore Extension * Drill Pipe Measurement 5.03" 5.08" 7.70' of Packer 10,371.62'* 10,376.70' 10,384.40' Baroid Drilling Fluids, Inc. October 18, 1989 Mr. Don Chudanov Unocal Oil & Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 Re' Workover Fluids Recap G-21Workover (Grayling) Dear Mr. Chudanov' Attached is the well. The final follows- workover fluids recap for the above reference Baroid cost of $35,744 can be broken down as Litesal Pills - $17,622 KC1 - 4,494 Technical Service - 10,935 Miscellaneous - 2,693 Total - $35,744 Three Litesal pills were required to minimize brine losses during the various stages of the workover. The KC1 was used to achieve a 3% concentration prior to the final completion. If additional information is required, please advise. Very truly yours, BAROID CORPORATION d. G. Rose District Engineer cc: Bush/Neve' File Attachments 2000 West Int'l. Airport Rd., Suite A-10 (99502) · RO. Box 102492 · Anchora?. ,Alaska 99510 (907) 248-3511 · Fax (907) 248-5390 Petroleum Services COMPANy Unocal 0il & Gas Division STATE Alaska CASING PROGRAM 20 Inch at 822 ft. WELL G-21 Workover COUNTY Kenai 13 3/8inch at 5201 ft. CONTRACTOR Grayling Platform LOCATION Cook Inlet SEC ~ TWP ~ RNG ~ 9 5/8inch at11160 ft. STOCKPOINT Rig Tenders Dock DATE BAROID ENGINEER Kerr, Redford TOTAL DEPTH 11,032 ft. DATE DEPTH WEIGHT VISCOSITY Yp GELS FILTRATION RETORT SAND CEC pH FILTRATION ANALYSIS 1989 feet Sec APl PV 10 sec/ mi HTHP Cake Solids Oil Water % Mud Strip ~J Pm Pfl P,IPz CI CA REMARKS AND TREATMENT __°F _°F 10 min APl __°F 32ntis % % % me/mt Meter Q Mf ppm ppm (See Operations Sheet) 1'9'"'i3 10365 PER DEPTI~ - ~O'"Vi)LUME Iq PITS ~ET Buil'head FIW to i'~ kill well -9-14 10361 63+ ~0 VI)LUME Iq PITS lET Nipple up BOP's '9-15 10361 63+ FILTI:~ql~D~I~E~ 0 TR 13000 Spot 50 bbls _itesal pill 9-16' 10380 63+ FILTliRED INLI-'T WATE~ 0 TR 8.5 14000 Pull 7919' of tb ,9-17 10380 63+ FILTI!RED INLI!T WATE]~ 0 TR 8.5 14500(] Polish top of fi !'g---1-8 ' 1-03'80 63+ FILTliRED INLi!T WATE.~ 0 TR 8.5 13500 Jar fish free !9-19 10362 63+ FILTI!RED INLIT WA~i~ 0 TR 8.5 13500 Recover 3153' tb 9-20 10460 63+ FILTliRED INLliT WATE]~ TR TR 8.5 13000 Recover packer 9-21 10869 63+ FILTI!RED INLI!T WATEi~ TR TR 8.5 13500 Ream sand & scal ~,22 10900 63+ FILTI!RED INLI!T WATE]~ TR TR 8.5 14600 Mill packer, spo Litesal 9-23 11004 63+ FILTIRED INL T WATE]~ IR TR 8.5 14000 Scrape & test cs 9-24 10900 63+ FILTIRED INLIT WATE]~ TR TR 8.5 13500 Cmt HB-6 plug .'9-25 10647 63+ FILTIRED INL T WATEi~ TR TR 8.5 13500 Cmt BH-5 squeeze 9-26 10600 63+ FILTIRED INLIT WATEi~ TR TR 9.0 13500 Cmt HB-3circula 19-27 10644 64 FILTIRED INLI!T WATEi~ TR TR 9.5 14000 Drilling cement .'9-28 10643 64 FILTIRED INL T WATEi~ TR TR 10 14500 Squeeze 9-29 10570 63+ FILT!RED INL T WATEi~ TR 11.5 14500 Squeeze ~19-30 10520 63+ FILTIRED INL T WATE]~ TR 11.5 14500 Test perfs COST COST COST MATERIAL AMOUNT $ MATERIAL AMOUNT $ MATERIAL AMOUNT $ Baravis 10 1,355.80 .. Polytec-S 5 956.70 ,-i~L Workover Ad~titives 24,748.98 Ni 4,493.72 . ,~ Servi :e 27 10,935.00 Baroid KC1 154 Tech. , ~,~,~,~ Petroleum Services SDI Defoam 3 283.11 '~ " .i'"'. ~'~- Days @ $405,~Day/Man Salt 83 907.19 :i-~ , .. Kenai Borou,]h Tax Liteplug-F 58 3,772.90 ~ ~., 6 @ $10.00 60.00 Liteplu§-R 82 5,334.10 MUD MATERIALS Li tepl u.q-X 17 1,105.85 Used (Total) Li tesal 70 6 ~064.10 DRILLING MUD RECORD Sapp i 87.77 PAC-L 2 387.74 ~., TOTAL COST 35,743.98 g sh g e t g int Drilling Mud Record Petroleum Services Page 2 COMPANY Unocal 0il & Gas Division WELL G-21Workover CONTRACTOR Grayl i ng P1 atform STATE A1 as ka CASING PROGRAM 20 inch at~822 ft. COUNTY Kenai 13 3/8inch at 5201 ....... ft. LOCATION Cook Inlet SEC ~ TWP ~ RNG 9 5/8inch at 11160 ft. STOCKPOINT Ri9 Tenders Dock DATE BAROID ENGINEER Kerr, Redford TOTALDEPTH 11,032 ft. DATE DEPTH WEIGHT VISCOSITY Yp GELS FILTRATION RETORT SAND CEC pH FILTRATION ANALYSIS Sec APl PV 10 sec/ mi HTHP Cake Solids Oil Water % Mud StripX] Pm P{I P,IPz CI CA REMARKS ANO IR~IMENI 1989 feet P C F __OF _°F 10 rain APl __°F 32nds % % % me/mt Meter Cl Mi ppm ppm (See Operations Sheet) 10-1 1070¢' 63+ FILTERED IINLE' WATER TR 12 14500 ..... Drill retainer 10-2 10707 63+ FILTERED INLET WATER TR 11 14000 Dr,aw down test 10-3 10871 63+ FILTFRED INLE' WATER IR 9.5 14000 Displace w/.FIW ~0-4 10871 64+ 27 0 9.0 25500 Run cs§ scraper Build 3% KCl 10-5 10438 64.~' 27 ' 0 9.0 25500 RIH w/perf guns 10-6 10438 64.: 27 0 9.0 25000 P0H lay down gu i0-7 10874 64..~ 27 TRC 19.0 ..... 27500 Spot 50 bbl Litesal pill 10-8 10871 64.; 28 TRc !9.0 ....27500 Test & Run 2 7/ 10-9 Release ri§ ................. - .,. ,1 , ¢ ' ,, i, ..... Unocal Oil & Gas Division INVENTORY G-21Workover Beginning InventorS Received Used Baravis 30 0 10 Barazan 10 0 0 CaCl 35 0 0 2 Polytec-S 3 4 5 KC1 128 210 154 SDI Defoam 2 2 3 Salt 39 176 83 Li tepl ug-F 22 48 58 Liteplug-R 46 58 82 Liteplug-X 65 0 17 Litesal 15 79 70 Sapp I 0 1 PAC-L 6 0 2 Ending InventorS 20 10 35 2 184 1 132 12 22 48 24 0 4 Order Document Numbers' Charges: Q27093 Q27094 Q27098 Q27100 Q27102 Q27106 Q27119 Q27121 Q27137 Credits' Q27115 Q27117 Q27120 Amount' $ 6,137.80 6,424.34 14,002.07 11,202.09 6,857.73 1,583.82 3,250.00 1,780.86 7,705.00 Total Charges $17,783.46 4,774.41 641.96 Total Credits - $58,943.81 - $23,199.83 Total Well Cost - $35,743.98 OPERATIONS · Unocal Oil & Gas Division G-21Workover 9-12 9-13 9-14 9-15 9-16 9-17 9-18 Depth~ Ft. 11,032 Tour Ri9 up ri9 #54 on platform leg III, test mud lines to 3000 ps- Bullhead 212 bbls filtered inlet water down tubing. Pull ball valve, run .HPRS perf gun and shoot circulating perfs in tubing at 10,361', circ FIW down tubing with returns to production. Hole took approximately 354 bbls to 400 bbls more FIW than we pumped, set back pressure valve nipple down tree, nipple up BOP stack, test valve. Nipple up BOP's, flowline etc., and pressure test BOP's, chokes, valves, etc., work on brakes, pull pack pressure valv~ pull tubing hanger, couldn't pull tubing free from packer, mix and spot 50 bbls Litesal pill to control seepage. Run wireline gauge rings, shoot tubing at 10,380' with APRS under gauge string shot, work tubing, still won't pull free, RIH with tubing cutter and shoot off tubing @ 7223', POH w/wireline, circ 2 hours, POH with 7,192' of 4½" tubing and lay down same, test BOP's, PU Tri-state overshot and BHA RIH, picking up 5" DP, tag fish @ 7247', polish top of fish,. POH with Tri-state tools, change top BOP rams to 5" and test. same, RIH with overshot, bumper sub and jars, engage and work fish, no go, release fish and POH, make up overshot, bumper sub, jars and RIH on 5" drill pipe only (no DC's). Latch fish, run APRS tubing cutter on wireline, but couldn't get past top of fish with cutter, POH with wireline, jar on fish, no go, release fish and POH w/DP and OS lay down overshot, pick up small bull nose, mill and RIH w/DP, mill on (in) top of fish (4½" tubing) at 7,217', circ, POH with mill, PU overshot and est. and RIH w/drill pipe, engage fish, run APRS under gauge tubing cutter on to shoot tbg @ 10,359', rig down APRS, jar on fish, no go, rig up APRS and free point. free to packer, run coil shot and shoot at 10,243', jar fish free, clrc bottoms up, ri9 down APRS. POH and lay down fishing tools (caught fish), lay down 3153' 4½" tubing (it finally parted at the first shot), change bottom BOP ram~ to 5" and test same, OK, slip drilling line Date Depth, F~', Tour 9-18 (continued) 9-19 9-20 9-21 9-22 OPERATIONS · Page 2 Unocal Oil & Gas Division G-21Workover and work on brakes, pick up overshot, bumper sub and oil jars and DC's and RIH to 7579', single in drill pipe to top of fish @ 10,362' DPM, dress and catch fish, could not work it free, release fish and POH with overshot. Lay down overshot, pick up wash pipe and shoe and RIH, mill slips loose on packer at 10,374', circ, POH w/wash pipe, pick up overshot and RIH to 10,370', chase fish from 10,370' down to 10,472', latch fish, circulate hole clean, POH with fish (recovered packer and tubing tail), PU bit and RIH. Ream sand and scale from 10,777' to 10,868', circ hole clean with both pumps (AV at DP of 289 ft/min.), POH w/bit, PU 2 jts of 2 3/8" tubing on drill pipe and RIH to 10,476', single in drill pipe f/10,476' to top of packers @ 10,869', wash out inside 4½" tubing tail f/10,869' to 10,926', circulate hole clean with both pumps, POH and LD tubing stinger, PU 8½" burn shoe, est. and boot baskets and RIH to 10,869', mill over packer slips and circulate. Finish mill over "SAB" packer @ 10,869' (hole started taking. 30 bbls of FIW per hour into perfs below packer), circ btms up while mixing Litesal pill (40 bbls), spot Litesal pill and close annular preventer, bullhead pill 137 strokes until it held 400 psi with bleeding off very fast. Work on draw works motor, POH and LD milling assembly, PU spear assembly and RIH to 10,869', spear "SAB" packer and work free, circulate hole clean (got some Litesal pill back), noticed gas count rising, monitor well and circ thru choke 2 hours, POH with fish, recovered packer and tail pipe (170' long), lay down fishing tools, PU 8½" bit, 9 5/8" casing scrapers and 2 boot baskets and RIH Circ bottoms up, POH w/casing scarper and bit, run Schlumberger CET/CBT/PIL/GR logs, PU bypass sub and RTTS and RIH, set RTTS @ 10,456' and press test csg to 3000 psi, OK, POH w/RTTS, pick up 3½" tubing stinger and RIH on 5" DP. Page 3 Unocal Oil & Gas Division G-21Workover OPERATIONS · Z: Date Depth, FI'. Tour 9-23 W&R from 11,004' (Baker F-1 perm pkr), thru seal bore to 9-24 9-25 11,091', circ hole clean, rig up Haliburton and test lines to 2500 psi, mix and spot 15 bbls of 15.5# cement to abandon Hemlock bench 6 and plug back above "F-I" packer, POH and LD stinger, PU drlg assembly and RIH to tag cement @ 10,894', polish plug off to 10,900', circ bottoms, POH, rig up Schlumberger and run junk basket and gauge ring on wireline, lay down junk basket/gauge ring, pick up and run EZ drill cement, retainer on wire]ine, set @ 10,870', POH with wireline and rig down Schlumberger, P.U. stinger on 5" DP and'"RIH to 10,870'. Rig up HOWCO, circ while mixing HOWCO Chemicals for cmt slurry, test lines to 6500 psi, estimate injection rate of I bbl/min @ 4750 psi, mix and pump 21 bbls of 15.5# cement, reverse circulate DP clean, got back 17 bbls pre cmt slurry, POH w/stinger, test BOP's to 3000 psi, OK, PU EZSV retainer on DP and RIH to 10,712', rig up Howco, test lines to 5000 psi, set EZSV @ 10,712', sting in, est. injection rate, no Communication above EZSV observed, don't have to squeeze zone therefore, rig down Howco, POH w/stinger, RIH with new EZSV and set @ 10,647'. Rig up Howco and test lines to 6500 psi, stab into retainer and estimated injection rate, circ into HB-3 perfs below EZSV with returns communicating back thru perfs above EZSV, pull stinger out of EZSV and circ bottoms up with ~oth pumps immediately above it, mix and pump 100 sx 15.5# cmt, un-sting and reverse circ DP (get back 13.3 bbls cmt), POH w/stinger, P.U. new EZSV retainer and RIH on DP to 10,600', set retainer, break circ, test lines to 6500 psi, estimated injection rate, mix and pump 150 sxs of cement (15.5# slurry) while holding 1200 psi back pressure, couldn't reverse circ or circ foreward, shake pipe free of cement and POH 6 stand, reverse circ, didn't get any cement back, POH and lay down stinger, Pick up 8½" bit and DC"s and RIH to tag cement, lay down extra stands OPERATIONS · Page 4 Unocal Oil & Gas Division G-21Workover Date Depth, Fl'. Tour 9-26 9-27 9-28 9-29 9-30 10-1 10-2 Circ and WOC drill cement from 10,336' to 10,597', drill retainer and cement to 10,643', drill on retainer and POH for N.B. RIH w/bit #3, drill retainer and clean cement to 10,710', CBU nad POH, P/U retainer and RIH and set retainer @ 10,643'. Test lines and run, squeeze w/150 sxs cement, reverse circ and discard 14 bbl cement contaminated FIW, POH and P/U retainer, RIH w/same. Set retainer @ 10,599', run squeeze w/lO0 sx cement, reverse circulation and discard 18 bbls cement and FIW, POH and P/U EZ drill, RIH and set @ 10,520', pump/squeeze 185 sxs (38.5 b~ cement, reverse circ and discard 5½ bbls cement, POH and P/U Drilling assembly, RIH and drill retainer @ 10,520', continue cleaning cement. CBU and POH, P/U RTTS and RIH, test surface equipment and set RTTS @ 10,517', tests-perfs from 10,540' to 10,590', perfs drwon w/5500 psi @ I bbl/min., POH and L/D RTTS, RIH w/retainer, test surface equipment and set retainer @ 10,520'. pump/squeeze 150 sxs (32 bbl) cement, reverse circulation and discard 18 bbl cmt/ fwd, POH and P/U drilling assembly. RIH w/bit #5 and tag cement @ 10,507', drill to 10,520', drill retainer and clean to 10,597', POH and P/U bit #6, RIH and drill retainer and clean cement to 10,639', drill retainer @ 10 639' and clean cmt to 10,702' hole void to retainer @ 10,707' circ hole clean and POH } · P/U Howco test tools, RIH to 10,518', R/U for draw down test, take fluid level shot and test equipment to 3000 psi, take on 1100 psi gas cushion and run draw down test, bleed off cushior periodically, and ta~e fluid levels, complete test, OK, POH. Test BOE, RIH and drill 10,712' to 10,852', trip for new bit and SLM, RIH and drill from 10,854' to 10,871', displace w/fresh FIW, Build 427 bbls 3% KC1/FIW. , Dote Depth, Ft, Tour 10-3 10-4 10-5 10-6 10-7 10-8 OPERATIONS · Page 5 Unocal Oil & Gas Division G-21Workover Test BOP's and hydrill, POH and cut drillinq lines~ TIH and drill from 10,712' to 10,852', circulate, POH, change bit and 'junk baskets,.TIH, drill from 10,854' (new STRAP figure) to 10,871', circulate and displace with fresh FIW until returns clean up, built 427 bbl 3% KC1 FIW and DE filtered NTU-16 POH, pick up csg scraper, RIH, circulate and clean pits, build and circulate 1000 bbls 3% KC1 FIW, DE filtered to NTU, 10.4 shipped 951 bbls of FIW to onshore facility for disposal, failed shean test, circulated 3% KC1 until CC- in was 25,500 and out was 25,500 POH, pick up perf guns, RIH space out packer to 10,438', rig up surface equipment and wireline, RIH for wireline correlatil logs, no correlation, reverse circulate to fill drill pipe, POH strapping out POH, lay down perf guns, rig down Schlumberger, Run logs, Pick up perf gun assembly, RIH, run Schlumberger correlation Logs. Take fluid level shots, cycle omni valve, circulate two DP volumes, monitor hole and rig down, circulate bottoms up, build and spot 50 bbl Litesal pill, pressure up to 200 psi and hold for 10 minutes to squeeze pill in place. POH lay down perf gun assembly, RIH circ at 10,874' 5' of fill, circulate two bottoms up, observe well, POH, pick up Otis packer, RIH Drop bal'l, set packer at 10,375', test to 2K sheet out ball POH, rig up Joes and hydrotest, run 2 7/8" production string, release rig 12'00 noon 10/9/89 ! UN(_,~/l L...c,i kl 'Tcr_.j.t 0 I Z" .~oOo~ STATE OF ALASKA 0 I{ I 6 I ALASKA OIL AND GAS CONSERVATION COMMIbSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repai~well __ Plugging __ Time extension __ Stimulate __ Change approved program -- Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 190247, Anch, Ak., 99519-0247 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at sudace 1802'N & 1415' W of SE Corner Sect. 29, T9N, At top of productive interval Top of Hemlock: 584' S, 1989' E, NW Corner At effective depth T9N, R13W SM 9~gt~l,de~l' E of NW Corner Section 33, T9N, R13W SM Section 33, R13W SM 6. Datum elevation(DForKB) 99' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number G-21 9. Permit number 74-42 10. APl number 50-- 133-20267 11. Field/.Rool Mc~rtnur River/Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,160' feet 9,711' feet 11,110 ' feet 9,668 ' feet Plugs (measured) Junk (measured) Casing Length Structural 356 ' Conductor 822 ' 5201' Sudace Intermediate Production 11,160 ' Liner Perforation depth: measured Size Cemented 26" Driven 20" 779 sxs 13-3/8" 1550 sxs 9-5/8" 2,000 sxs Uppermost Perf: 10,478' Lowermost Perf: 10,980' Measureddepth ~uevedicaldepth 356' 356' 822' +715' 5201' +4524 true vertical Tubing (size, grade, and measured depth) Uppermost Perf: Lowermost Perf: 4-1/2", 12.6 11,160' 9,711' Packers and SSSV (type and measured depth) RECE ¥ED 9,11s, SEP 1 ! ]989 9,640' #, N-80 AJaska 0il & Gas Cons. Commission Anchora_ae Otis Ball Valve @ 316', Baker 'F-i" pkr ~ 10,380', Baker "SAB" Pkr @ 10,864', Baker 'F-i" pkr @ 11,004' 13. Attachments Description summary of proposal ..x_ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: September 11, 1989 16. If proposal was verbally approved Oil x__ Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~R~, ,~/~/; n h/~e Ct ¢.~tz~ Title Environmental Engineer FOR COMMISSION USE ONLY Conditions'~f a~r6val: Notify con'mission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- 4-~ ~ ORIGINAL SIGNED BY LONNIE C. SMITH ARi~r~y)e,.,d)%y~rder of the Commission Form 10-403 Rev 06/15/88 Commissioner Date 9/06/89 [Approval No. Approved Copy Returned Date C~ SUBMIT IN TRIPLICATE i ,, PIP..... RAMS , i m , ", FLOW%JNE DOUBLE GATE 5t,4 13-5/B" 5M FLANGE I:::HDKE LIN~ WITH ON? REMOTE_ MANUAL 4" 51,/ VALVe_ '-' ';J~ ;,J ' '_1 I:::DNNE2TED TD I::HDKE MANIFOLD (_~-.~_ M/,NIFDLD DRAWING) ~5 5/s" 51,4 FLANGE i 5 5/S" 5M F1..ANG-'" '~ g" 5M x 1 5-5/B" 5M ~.~. A,=T:Z_R CAtJ,:'RDN 5M DCB SPOOL ' ~ ":CEI' ":D ~_.' ~ RECEiVEI~'-- v,_ . _ ta.~k~ Oil & Gas Cons. Commission - ! 13-5/B'' BOP- SM-STACK ALL DRILLING OP--'RA~ONS · ,~'.-, UNION OIL COMPANY OF CA~F.DRNIA (;.,~m UN , ri.Ti .. ., DRAWN: DLL A.=, D: DC ~A!_~ NONE WELL PROCEDURE TBUS G-21 1. MOVE RIG t54 OVER TBUS G-21, LEG #3, CONDUCTOR #2. 2. KILL WELL. 3. INSTALL BPV, REMOVE TREE, INSTALL AND TEST BOPE. 4. PULL AND LAY DOWN SINGLE 4-1/2" PRODUCTION STRING. 5. MILL OVER AND RECOVER BAKER "F-i" PACKER SET AT ]0380'. 6. CLEAN OUT FILL FROM 10523' TO THE BAKER "SAB" PACKER SET AT 10864'. 7. MILL OVER AND RECOVER THE BAKER "SAB" PACKER SET AT 10864'. 8. CLEAN OUT TO THE BAKER "F-l" PACKER AT 11004'. 9. RUN A CASED HOLE LOGS. 10. PRESSURE TEST 9-5/8" CASING. 11. ABANDON HEMLOCK BENCH 6; 11042'-11084' DIL. 12. ABANDON HEMLOCK BENCH 5; 10882'-10987' DIL. 13. CEMENT SQUEEZE HEMLOCK BENCHES 2 & 3; 10540'-10635' DIL; 10660'-10690' DIL. 14. CHANGE OVER TO CLEAN COMPLETION FLUID. 15. PERFORATE THE HEMLOCK UNDERBALANCE WITH 6" TUBING CONVEYED GUNS AT 4 SPFo BENCH 1 BENCH 4 10478'-10506' DIL (28') 10730'-10860' DII, (130') 16. CLEAN OUT TO 10870' ETD. 17. RUN AND SET PERMANENT PACKER AT 10350' DIL. 18. RUN 2-7/8" GAS LIFT COMPLETION. 19. REMOVE THE BOPE AND INSTALL SINGLE TREE. 20. RETURN WELL TO PRODUCTION AS A SINGLE HEMLOCK PRODUCER. NOTE: ANTICIPATED SBHP IS 4025 PSI AT 9450' TVD. WORKOVER FLUID IS 3% KCL WITH NACL AS REQUIRED FOR WELL CONTROL. ABANDONMENT PROCEDURE HEMLOCK BENCHES 5 & 6 TBUS G-21 1. MOVE RIG #54 OVER TBUS G-21, LEG #3, CONDUCTOR #2. 2. KILL WELL. 3. INSTALL BPV, REMOVE TREE, INSTALL AND TEST BOPE. 4. PULL AND LAY DOWN SINGLE 4-1/2" PRODUCTION STRING. 5. MILL OVER AND RECOVER BAKER "F-i" PACKER SET AT 10380'. 6. CLEAN OUT FILL FROM 10523' TO THE BAKER "SAB" PACKER SET AT 10864'. 7. MILL OVER AND RECOVER THE BAKER "SAB" PACKER SET AT 10864'. 8. CLEAN OUT TO THE BAKER "F-l" PACKER AT 11004'. 9. RUN A CASED HOLE LOGS. 10. PRESSURE TEST 9-5/8" CASING. 11. CLEAN OUT BELOW BAKER "F-i" PACKER AT ].1004' TO 11091' ETD. 12. ABANDON HEMLOCK BENCHES 5 & 6 AS FOLLOWS: A) ABANDON HEMLOCK BENCH 6 (11042'-11084' DIL) AND LOWER HEMLOCK BENCH 5 (10904'-10987' DIL) BY LAYING A CEMENT PLUG FROM 11091' ETD UP THROUGH THE BAKER "F-i" PERMANENT PACKER SET AT 11004' TO i0900'. SUFFICIENT CEMENT WILL BE USED TO FILL THE ENTIRE WELL BORE OF THE ABANDONED INTERVAL. B) ABANDON UPPER HEMLOCK BENCH 5 (10882'-10900' Dill,) BY SETTING A CEMENT RETAINER AT 10870' AND CEMENT SQUEEZING PERFORATIONS WITH A MINIMUM OF 100 SXS OF CEMENT (10 SXS REQUIRED TO COVER ALL ORATIONS C i NOTE: ANTICIPATED SBHP IS 4025 PSI AT 9450' WORKOVER FLUID IS 3% KCL WITH NACL AS REQUIRED FOR WELL CONTROL. AOGCC TO WITNESS ABANDONMENT. 20" @ 822'/d @ 5201' 9-5/8" e 11160' CEMENT :: CEMENT / __ __ TUBING DETAIL 2-7,/8", 6.4# , N-80 TBG. sssv 2) GLM's 3) XA SLEEVE 4) PERM. PACKER @ 10375' 5) "X" NIPPLE 6) RE-ENTRY GUIDE HB 1 10478'- 10506' HB 2 10540'-10590' SQZ'D HB 2 10605'- 10635' SQZ'B HB 3 10660'- 10690' SQZ'D HB 4 10730'- 10860' CEMENT RETAINER @ 10870' HB 5 10882'- 10987' ABANDONEB BAKER "F-I" PKR @ 11004' HB 6 11042'- 11084' ABANDONED WELL TBUS G- 21 PROPOSED COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN' DAC SCALE: NONE DATE: 8-28-89 j25 WELL TBUS G-21 WORKOVER I ,.-,CASING & ABANDONMENT DETAIL 1.) Rot&fy Table Mealurament at 0.00' IL) 4 1/2' Cameron Tubing Hanger at 38.46' III.) 26' Drive Pil)e at 356' " IV.) 20', 94e, H-40 Casing at 822' V.) 13 3/8°, 61~ · 68~, K-55 Casing at 5201' Vi.) 9 5/8'. 40~ & 47~. USS-g5 Casing at 11.160' ' L' zI 24 29 TUBING DETAIL 4 1/2', 12.6',~, N-80 TUBING 1.) 4 1/2' 2.) 4 1/2' 3.) a, 1/2' 4.) 4 1/2' 5.) 4 1/2' 6.) 4 1/2' 7.) 4 1/2° 8.) 4 1/2' 9.) 4. 1/2' 10.) 4 1/2' 11.) 12.) 14.) 15.) 16.) 17.) 18.) 1~.) 20.) 21.) Otis Ball Valve at 316.59' Camco 'MMG' GLM at 1968.61' Camco 'MMG° GLM at 3440.32' Camco 'MMG° GLM at 4691.01' Camco 'MMG' GLMat 5571.26' Camco 'MMG' GLMat 6201.89' Camco 'MMG' GLM at 6552.79' Camco 'MMG' GL Mat 6932.46' Camco 'MMG' GLM at 7311.00' Camco 'MMG' GLM at 7660.69' 22.) 23.) 24.) 25.) 26.) 27.) 29.) 4 1/2' Camco 'MMG' GLM at 8040.47' 4 1/2' Camco 'MMG' GLM at 8391.11' 112' Camco "MMG' GLM 112' Camco "MMG' GLM 1/2' Camco "MMG° GLM 1/2' Camco "MMG' GLM 1/2' Camco"MMG' GLM at 8770.27' at 9120.25' at 9470.32' at 9759.24' at 10,142.22' 4 1/2' Camco 'MMG' GLM at 10.307.02' 4 112' Otis 'XO' Sleeve at 10,346.04' Baker Locator Sub at 10,$79.32' Baker Model 'F-I' Packer with Baker Model Seal Assembly from 10,380.27' to 10,395.83' 4 1/2' Otis 'X' NiDDie at 10,426.76' Bottom of Mule Shoe at 10,459.87' Baker Model 'SAB' Hydraulic Packer at 10,864.35' Baker Millout Extension at 10,869.38' 6 5/8' x 4 1/2' Crossover at 10,574.73' 4 1/2' Otis 'XO' Sleeve at 10,968.39' Baker Locator Sub at 11,003.05' Baker Model 'F-1° Packer with Baker MOdel Seal Assembly from 11,004.00' to 11,013.00' 30.) 4 1/2' Otis 'X' Nipple at 11,021.02' 31.) Cement Plug at 11,022' '32.) Baker Shear Out Sub at 11,032.59' PERFORATION RECORD DA TE INTERVAL CONDITION 5/10/75 10930'-10980' Closed Sleeve at 10966.39' 5/14/75 11042'-11080' Isolated by plug at 11,022' 5/18/75 10810'-10850' Hemlock Bench ,~4 Production 5/18/75 10755'-10600' Hemlock Bench +4 Production 5/18/75 10733'-10745' Hemlock Bench +4 Production 5/19/75 10660'-10690'. Hemlock Bench ,~3 Production 5/20/75 10540'-10590' Hemlock Bench ~2 Production 5/20/75 10605'-10635' Hemlock Bench +2 Production 2/24/80 10478'-10506' Hemlockrli~e.~ch ~'1 Production 41aska 0ii & C~as Cons. Cornrn, ission Anchorage "' :.WELLTBUSG-21.WORKOVEFI . -" ' WELL SCHEMATIC ,; ......... ) L,'N'ON. OIL COM=),t.,NY "~[",. ~/.LIcC."N[,L ;: ... tv ONE :.,-; .1/ ID/85 .. · . . ,.. · ...... ':!-~ · .: .. · . .. · 'i .. .::.l,. . . _. ".2 .. · .. !'2. ~.;.-.. ..o,.~ · ~ ~ ' .'II~:~...C · .'~:H:[i.:'~ · .., .~. : :.,. 2...: ... .~. ..~ , .:: ":~ · '! CMT TOP AT 1407" CMT TOP AT 3957 COMPLETED 1-3o75 WELL TBUS G-Z1 CASING & CEMENT DETAIL VOLUMES SHOWN ARE (CMT. VOL./HOLE VOL.) 26',1' WALL, DRIVEN TO 356' 20°, 94~ H-40 AT 822' 779 SX AT 1.51 FT3/SK (1176 FTC/680 FT~) CMT RETURNS TO SURF. TESTED OK AT 500 psi 13 3/8' 6!,~ & 6~. K-55 AT 5201' 1550 sx' AT 1.7 f[=/$k (2635 ft~/3879 ft~) CSG TESTED OK AT 2000 psi SEAT AND FORMATION TESTED OK FOR .65 p$1/f CBL SHOWS GOOD BOND TO 1900' 9 5/8', 40+ & 47,~,USS'95, P-110, N-80 AT 11,160' 2000 sx AT 1.15 ft /sk (2300 ft~/3682 ft~) NOTE: ALL CEMENT TOPS ARE THEORETICAL GRAYLING PLATFORM CASING & CEMENT DETAIL UNION OIL COMPANY OF ~ALIFOP. N1/-, AeP'D. sc~£ N 0 N E STATE OF ALASKA 0 R I 6 I N ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AL 1. Type of Request: Abandon ---- Suspend m Operation shutdown __ Re-enter suspended well __ Alter casing ~ Repair well ~ Plugging __ Time extension ~ Zimulat Change approved program ~ Pull tubing ..Z- Variance ~ Pedorate %'-~r __ 2. Name of Operator Union Oil Company of California (UNOCAL 3. Address P.O. Box 190247, Anch, Ak., 99519-0247 5. Type of Welt: Development Exploratory Stratigraphic Service 4. Location of well at sudace 1802'N & 1415' W of SE Corner Sect. 29, T9N, R13W SM At top of productive interval Top of Hemlock: 584' S, 1989' E, NW Corner Section 33, At effective depth T9N, R13W SM ¢~t~tp~leP~%ll' E of NW Corner Section 33, T9N, R13W SM 6. Datum elevation (DF or KB) 99' KB above MSL Unit or Property name Trading Bay Unit 8. Well number G-21 9. Permit number 74-42 10. APl number 50-- 133-20267 feet 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured true vertical 11,160' feet Plugs (measured) 9,711 · feet Effective depth: measured 11,110 · feet Junk (measured) true vertical 9,668 ' feet Casing Length Size Structural 356 ' 26" Conductor 822 ' 20" 5201' 13-3/8" Sudace Intermediate Production 11,160' 9-5/8" Liner Perforation depth: measured Uppermost Lowermost Cemented Measureddepth ~ueverticaldepth Driven 356' 356" 779 sxs 822' ~715' 1550 sxs 5201' ±4524 2,000 sxs Perf: 10,478' Perf: 10,980' 11,160' 9,711' true vertical Uppermost Perf: 9,115' ; ~"'~" Lowermost Perf: 9,640 ' Tubing (size, grade, and measured depth) 4-1/2" , 12.6 #, N-80 @ 10,460&~&Ska 0il & Oas t;0ns~t;oi'rl!lltsslo~ ~ ....... Anchorage Packers and SSSV (type and measured depth) Otis Ball: Valve @ 316', Baker "F-I" pkr @ 10,380', Baker "SAB" Pkr @ 10,864', Baker "F-l" pkr @ 11,004' 13. Attachments Description summary of proposal X"' Detailed operations program __ BOP sketch ,K 14. Estimated date for commencing operation Aug'ust 14, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended Service 17. I hereb~ certify that the foregoing is true and correct to the best of my knowledge. , Signe ~ Title Environmental Enqineer ~'/,-,,, n ~~ FOR COMMISSION USE ONLY Conditions of ~-~lSro~ai: l'~0~i~, ~-o~nission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ~.O~. Ap o d rder R~ ~,,I:}Y~ ~ of the Commission Origlnal $1~jned By David W, Johnston Commissioner Date 7 t 25,/',89.,. -'--~ I Approva, NO. q -- Approved Copy Returned Date ,~ I"~I Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PROCEDURE TBUS G-21 1. MOVE RIG ~54 OVER TBUS G-21, LEG $~3, COND[ICTOR ~ 2. KILL WELL. · , , ST BOPE. 5 INSTALL BPV REMOVE TREE INSTALL AND TE 4. PULL AND LAY DOWN SINGLE 4-1/2" PRODUCTION STRING. 5. MILL OVER AND RECOVER BAKER "F-l" PACKER SET AT 10580 DI L, 6. CLEAN OUT FILL FROM 10~°3'~ TO THE BAKER "SAB" PACKER. SET AT 10864' D!L WITH 8-i/2" BIT AND 9-5/8" CASING SCRAPER. 7. MILL OVER AND RECOVER THE BAKER "SAB .... ~,~ SET AT DIL. 8. CLEAN OUT TO THE BAKER "F-I" PACKER AT i1004~ WITH 8-1/2" BIT AND 9-5/8" CASING SCRAPER. 9. RUN A CASING INSPECTION LOG. ~ 10. PRESSURE TEST THE 9-5/8" CASING. v ii. ABANDON HEMLOCK BENCH 6; l1042'-l1084'DIL. '~-' ~'~" 0' . . 12. CEMENT oQUEEZE THE HEMLOCK BENCIt 5 FROM 108,~,z -1098 DIL 13. CEMENT' SQUEEZE HEMLOCK BENCHES 2 & 3; I0540'-10655'; ~ 10660'-10690' DIL, 14. CHAN,~-~E OVER TO CLEAN COMPLETION FLUID. 15 RE~.ERF3RA~E THE H~MLOCK UNDERBALANCE WITH 7 OD TUBING C, ONVEYED ' c S~ GUN~., AT 4 ~_~.F. BENCH 1 BENCH 4 BENCH 4 10478'-10506' (28') 10733' 10~'~ ,5' ~' - ,:... (12) 10755'-!080C)' (45') 16. CLEAN OUT TO +/-10870" ETD WITH A 8-1/2" BIT AND 9-5/8" CASING SCRAPER. 17. RUN AND SET A 9-5/8" PERMANENT PACKER AT +/-]_0350 i8. RUN AND STAB A 5-1/2" COMPLETION ASSEMBLY THROUGH THE PACKER SET AT +/-i0550r DIL, 19, REMOVE THE BOPE AND INSTALL SINGLE TREE, RETURN WELL TO PRODUCTION DEPARTMENT Ab A 2-1/.,. HEMLOCK PRODUCER, NOTE: ANTICIPATED SBHP IS 41125 PSI AT 9450' TVD WORKOVER FLUID IS 5% KCL WiTH NACL AS REQUIRED FOR WELL CONTROL ABANDONMENT PROCEDURE T ~) HEMLOCK BENCH 6 TBUS G-21 I MOVE RIG ~54 OVER TBUS G-21 LEG 2. KILL WELL. S. INSTALL BPV, REMOVE TREE, INSTALL AND TEST BOPE. 4. PULL AND LAY DOWN SINGLE 4-1/2" PRODUCTION STRING. 5 MILL OVER AND RECJVER BAKER F I PACKER SET AT 10380 DIL. 6. CLEAN C)UT FILL FROM 1052~' TO THE BAKER "SAB" PACKER SET ..... ~,CRArER AT 10864 DIL WITH 8-1/2 BIT AND 9-5/8 CASING ~ ~" . ~ MILL Ow~ .... . ' ..... ~ AND RECOVER THE BAKER SAB PACKER SET AT 10864 DIL. 8. CLEAN OUT TO THE BAKER "F-i" PACKER AT 11004' WITH 8-1/2" BIT AND 9-5/8" CASING SCRAPER. 9. RUN A CASING INSPECTION LOG. 10. PRESSURE TEST THE 9-5/8" CASING. tl. CLEAN ()UT BELOW BAKER "F-I" PACKER AT 11004' TO Ii160~ TD. 12. ABANDON HEMLOCK BENCH 6 BY LAYING A CEMENT PLUG FROM 11160' TO THE BAKER "F-l" PACKER AT 11004". SUFFICIENT CEMENT WILL BE USED TO FILL THE ENTIRE WELL BORE OF THE ABANDONED INTERVAL. BENCH 6 PERFORATIONS ARE FROM 11042' TO 111184' DIL. NC rE ANTICIPATED SBHP IS 4025 PSI AT 9450 TVD WORKOVER FLUID IS .'3% KCL WITH NACL AS REQUIRED FOR WELL CONTRJL o ', ..a=_'..L J NiPP!~'~ I' i ii ii 12" 3DOD PS! ANNULAR , FLOWLINE 2" KILL LIN-" WITH j,,, '!~ , KIL. L LINK r-""RIDM MUD &: CEL;.:'NT UNIT J :BLIND RAMS RAMS L :3-5/B" ;SM FLANCE ADAPTER 5M x 5U ~-5/B" 5M F'LANCE DOUBLE GATE 5M 13-5/B" 5M FLANGE ] 4" 12HDKE LIN.,,... WITH DNF' J ,m 1 MANUAL. 4" 5bi VALVE .] RAMS ] CDNNECT-ZD TO CHDK-" MANIFOLD (S.~ MANIFDLD DRAWING) SINGLE DATE 5M iD-5/B" 5M FLANGE i D" 5M x 13-5/B" 5M ~,~, APTER C,-JJ_,,DN 5M DCB SPOOL 13-5/8" ~OP.-- SM-STACK A~I DRIIt]NG 0"'- " ..... UNION OIL COMPANY OF CA~FDRNIA (dba UNm~'~ '~ DPJ.,WN: A.-'.mP'D: ~'CA! :": NON.,'... 1 9- 5/'B" 11166,' 1 CE I,.{ ENrT' I / TUBINC- E,',ETAIL 3-1/'2", 9.3#, N-BO 'f'BC-. 2'1 C-,LI',/'s .IXA SLEEVE PE,Rk,. P. ACKER ~' +,/- "×' NIPPLE ~I: RE-EIqTRY 8UIDE 1 0;350 HE, 1 1C~78'--1050 HE; 2 l~4-,D'--lOE,,35' HB .3 1 O§ 150' --10 DgO' .~,:;~' D HB 4. 107..'33'--1074..5' HB 4. 107,55'--10,~00" (2~ k{ Et. IT RETAINER '~ 10,~70' HB 5 '10882'--10980' 5QZ.'D EC.,,KE R "f--q" PI<R: ~ '110C~1-' HB 15 1 104-2'--1 1 084/ SCE' D V/ELL TBUS ~-21 PF.:OPO$ E D COMP LETI Ol'.,I UI'.,llOI".,I OIL COMP. ANY OF C,AUFORI',.,II,A (dba LINC, C/.,,L'.) D,,R/,;,,A,'I',.,I: CLL ~CALE.. NONE D,A'FE: 3- 1-Bg II WELL TBUS G-21 WOFIKOVEFI CASING & ABANDONMENT DETAIL l.) Rotary Table Measurement at 0.00' I1.) 4 1/2° Cameron Tubing Hanger at 38.46' II1.) 26' Drive PiDe at 356' " IV.) 20', 94~, H-40 Casing at 822' V.) 13 3/8', 61~ & 68~, K-55 Casing at 5201' VI.) 9 5/8', 40~ & 47~, USS-95 Casing at 11,160' i.) 4 1/2" 2.) 4 1/2' 3.) 4 1/2' 4.) 4 1/2' 5.) 4 1/2" 6.) 4 1/2' 7.) 4 1/2" 8.) 4 1/2' 9.)4 1/2' 10.) 4 1/2' 11.) 4 112' 12.) 4 1/2' 13.) 4 1/2' 14.) 4 1/2' 15.) 4 1/2' 16.) 4 1/2' 17.) 4 1/2' 18.) 4 1/2' 19.) 20.) 21.) 22.) 23.) 24.) 25.) 26.) 27.) 28.) 29.) vij 8~ 30.) TUBING DETAIL 4 1/2', 12.6~, N-80 TUBING Otis Ball Valve at 316.59' Camco 'MMG' GLM at 1968.61' Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco 'MMG' GtM at 3440.32' 'MMG' GLM at 4691.01' 'MMG° GLMat 5571.26' 'MMG' GLMat 6201.B9° 'MMG' GLMat 6552.79' 'MMG' GLMat 6.032.46, 'MMG' GLM at 7311.00' 'MMG' GLM at 7660.69' 'MMG' GLM at 8040.47' 'MMG' GLM at 5391.11' 'MMG' GLMat 8770.27' 'MMG' GLM at 9120.25' 'MMG' GLMat 9470.22' 'MMG' GLM at 9759.24' 'MMG' GLM at 10,142.22' Camco 'MMG" GLM at 10.307.02' 4 1/2" Otis 'XO" Sleeve at 10,346.04' Baker Locator Sub at 10,379.32' Baker Model 'F-I' Packer with Baker Model 'G'. Seal Assembly from 10,380.27' to 10,395.83' 4 112" Otis 'X" Nil)pie at 10,426.76' Bottom of Mule Shoe at 10,459.87' Baker Model 'SAB' Hydraulic Packer at 10,864.35' Baker Millout Extension at 10,B69.3B" 6 5/8' x 4 1/2' Crossover at 10,874.73' 4 1/2' Otis 'XO' Sleeve at 10.968.39' Baker Locator Sub at 11,003.05° Baker Model 'F-I' Packer with Baker MOdel Seal Assembly from 11,004.00' to 11,013.00° 4 1/2' Otis 'X' Nipple at 11,021.02° 31.) Cement Plug at 11,022' '32.) Baker Shear Out Sub at 11,032.59' PERFORATION RECORD DA TE INTERVAL 2,4 5/10/75 10930'-109B0° 5/14/75 11042'-1 1080' 5/18/75 10810°-10850' 5/18/75 10755'-10B00' 5/18/75 10733'-10745' ~,~o~ 5/19/75 10660'-10690'. 5/20/75 10540"-10590° 29 5/20/75 10605°-10635' 2124/80 CONDITION Closed Sleeve at 1096B.39' Isolated by ptug at 11,022' Hemlock Bench ~4 Production Hemlock Bench ,~4 Production Hemlock Bench ~-4 Production Hemlock Bench '~$ Production Hemlock Bench ~'2 Production Hemlock Bench ~-2 Production 10478'-10506' Hemlock Bench ~1 Production "' ji' WELLTBUSG-Z1WORKOVEFI i.- ........... ! WELL SCHEMATIC UN!ON OIL COMPANY OF CALIF-©PN~L ;:,,.~ h'DNE :-'-t .1/ ~0/85 CMT TOP AT 1407' CMT TOP AT 3957' COMPLETED 1-3-75 WELL TBUS CASING & CEMENT DETAIL ., VOLUMES SHOWN ARE (CMT. VOL./HOLE VOL.) 26',1' WALL, DRIVEN TO 356' 20', 94~ H-40 AT 822' 779 SX AT 1.51 FT-~/SK (1176 FT'~/680 F'r~) CMT RETURNS TO SURF. TESTED OK AT 500 psi 13 3/8'. 61~ & 6~.~. K-55 AT 5201' 1550 sx AT 1.7 ff~/sk (2635 ft~/3879 ft~) CSG TESTED OK AT 2000 psi SEAT AND FORMATION TESTED OK FOR .65 psi/f CBL SHOWS GOOD BOND TO 1900' 9 5/8', 40~ & 47~, USS-95, P-110, N-80 AT 11,160' 2000 sx AT 1.15 ft /sk (2300 ft3/3682 ft~) NOTE: ALL CEMENT TOPS ARE THEORETICAL GRAYLING [ LATFORM CASING & CEMENT DETAIL · UNION OIL COMPANY OF CALIFORNIA SC~L£ HONE ,; .. · .. · . . . . . · · . · : · .. STATE OF ALASKA ALASK.. OIL AND GAS CONSERVATION COMM. _SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate I~ Pull tubing Alter Casing [] Other ,~ 2. Name of Operator 5. Datum elevation (DF or KB) Union Oil Company of California dba UNOCAL 99' KB Above MSL Feet 3. Address 6. Unit or Property name P.O. Box 190247· Anchorage· Ak. 99519-0247 Trading Bay Unit 7. Well number G-21 4. Location of well at surface 1802' N, 1415' W f/SE Corner Section 29, T9N, R13W, S.M. At top of productive interval Top of Hemlock: 584' S, 1989' E, NW Corner Sec. 33, At effective depth T9N, R13W, S.M. At totaldepth 921' S, 2211' E f/NW Cor. Sec.33, T9N, T9N, R13W, S.M. 8. Approval number 569 9. APl number 50-- 133-20267 10. Pool ~cArthur River Field/Hemlock 11. Present well condition summary Total depth: measured true vertical 11·160 feet 9·711 feet Plugs (measured) 11,022 Effective depth: measured true vertical 11,110 feet feet 9·668 Junk (measured) Casing Length Size Cemented Structural 356 ' 26" Driven Conductor 822' 20" 779 sx Surface 5201 ' 13-3/8" 1550 sx Intermediate Production 11,160 ' 9-5/8" 2000 sx Liner Perforation depth: measured Upper Most Lower Most Upper Most Lower Most true vertical Tubing (size, grade and measured depth) Measured depth 356' 822' 5201' 11,160' 10,478' 10,980' 9,115' 9,640' 4-1/2", 12.6#, N-80 Packers and SSSV(type and measured depth) Otis Ball Valve @ 316' Baker Hyd. Pkr. @ 10,864' ~ue Verticaldepth 356' +715' -- ~4524' 9711' 1987 · baker ":F-l" pkr @ 10,380' · Baker ":F-i" pkr @ 11,004' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut in prior to work, no data. Subsequent to operation 40 585 360 900 Copies of Logs and Surveys Run Jill my knowledge ~ / /~/'d -~'~ to the best of 14. Attachments Da. ily Report of Well Operations~ 15. I hereby cert'~t hai~ ~rrect Signed ~/~ R~,~ ~e2sil]. Form ¢1~-404 Rev. 12,/f-85 Title Drilling Superintendent Datel 2./'~'1/86 Submit in Duplicate DAILY REPORT OF WELL OPERATIONS 12-9-86 ll,022'ETD 12-10-86 12-11-86 ll,022'ETD 12-15-86 10,850'ETD Commenced oPer~tiqns 0300 hours 12-9-86. Moved rig over G-21. Rigged up C.T.U. Tested surface equipment to 3000 psi. Ran in hole with Otis hydrablast tool and tagged fill at 6540'. Cleaned out intermittent fill from 6540'-10,247'. Could not wash deeper. Pulling out of hole at midnight. Finished pulling out of hole. Ran in hole with 1-3/4" Dyna-drill with 2.7" diamond mill. Tagged fill at 10,249'. Cleaned out to 10,500' (upper tubing tail). Pulled out of hole. Ran in hole with 2-3/8" Dyna-drill with 3.4" mill and tagged scale at 9425'. Cleaned out from 9425' to 10,340'. Dyna-drill locked up. Pulled out of hole. Ran in hole with redressed 2-3/8" Dyna-drill and 3.4" mill to 10,340'. Dyna-drill locked up immediately. Pulled out of hole at midnight. Finished pulling out of hole with locked up Dyna-drill. Ran in hole with redressed 2-3/8" Dyna-drill and 3.4" mill. Tagged fill at 10,349' and cleaned out to 10,499'. Ran in hole to 10,500' (upper tubing tail). Pulled out of hole. Ran in hole with 1-3/4" wash tool and tagged fill at 10,780' (84' fill in 9-5/8" casing). Cleaned out fill with 6% KC1 fluid and high vis sweeps to packer at 10,850' and to 10,940' in isolation tail. Circulated high vis sweep around. Pulled out of hole. .Rigged up wireline and ran 3.75" gauge ring to 1794' and stopped. Pulled out of hole. Ran 3.625" gauge ring to 2736' and stopped. Pulled out of hole and rigged down wireline at midnight. Rigged down wireline. Ran in hole with hydro-blast tool. Cleaned out from 300' to tail at 10,459'. Pulled out of hole. Rigged down and Released rig to G-7 at 2400 hours 12-12-86. Rigged up wireline unit (.092"). Ran in hole with 3.75" gauge ring. Stopped at 1794'. Pulled out of hole. Flowed well for cleanup. Ran in hole with 3.62" gauge ring to 4530' (several small tight spots). Pulled out of hole. Flowed well for cleanup. Ran in hole with 3.62" gauge ring and worked to 7196'. Pulled out of hole. Flowed well. Ran in hole, unable to get past 7196'. NOTE: Maximum I.D. from 7196' to 10,459' is 3.4". --- STATE OF ALASKA ..... ALAS .... OIL AND GAS CONSERVATION COM,...,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order I-] Perforate ['] Other . Name of Operator UNOCAL Corporation Address P. O. Box 190247, Anchorage, ak.~ 99519 Attn' C. Location of well at surface Lockwood 1802' N, 1415' W f/SE Corner Section 29, T9N, R13W, S.M. At top of productive interval Top of Hemlock: 584' S, 1989' E, NW Corner Section 33, At effective depth T9N, R13W, S.M. At total depth 921' S, 2211' E f/NW Corner Section 33, T9N, R13W, S.M. 5. Datum elevation (DF or KB) 99' KB Above MSL 6. Unit or Property name Trading Bay Unit 7. Well number G-21 8. Permit number 74-42 9. APl number 50-- 133-20267 10. Pool Mc~rthur River Field/Hemloc] 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 356 ' Conductor 822 ' Surface 5201 ' Intermediate Production 11,160 ' Liner Perforation depth: measured true vertical 11,160 feet Plugs (measured) 9,711 feet 11,110 feet Junk (measured) 9,668 feet Size Cemented 26" Driven 20" 779 sx 13-3/8" 1550 sx 9-5/8" 2000 sx Upper Most Perf: Lower Most Perf: Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 9115' ) 9640 ' ) ) ) ) )' Measured depth 356' 822' 5201' 11,160' ~ueVerticaldepth 356' ±715' ±4524' 9711' ?',!!:3V ! 3 1986 SEE ATTACHED SCHEMATIC Alaska 0il & O3s Cons. Commission Anch0ra~e 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation November 20, 1986 14. If proposal was verbally approved Name ofa¢/ver ~, ,,,, 15. I hereby~r~j/y~.~t,~~~' ' correct to the best of my knowledge Signed '~_//~~/~;¢~// Tit le Dr il li ng Superintendent it/io/n; "o~ Commission Use Only Co,~ of app al Notify commission so representative may witness I Approval / [] Plug integrity [] BOP Test [] Location clearance I Date approved Date 11-10-86 Approved by Commissioner b~)' order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate G-21 COILED TUBING CLEANOUT PROCEDURE 1. RU slickline and pull ball valve. 2~ Se e MU KCl-polymer workover fluid RU skid pump unit to 1-1/4" coiled tubing unit. Pressure test surface equipment to 3000 psi. Function test coiled tubing unit BOP system. RIH with Otis Hydrablast tool on 1-1/4" coiled tubing to +--500' and break circulation with KCl-polymer fluid. Continue down hole and clean out scale to tubing tail. (Reciprocate and check pick up weight on coiled tubing after every 20' drilled to insure no bridging. If returns are lost during operation turn on gas lift and reestablish circulation. Use nigrogen to provide additional lift if needed.) 7. POH with coiled tubing and RD. Replace ball valve. 8. Return well to production and move over to G-iL. 11-10-86 0173D Ala~<a Oil & Gas Cons. Co~'~niission Iii iv 4 GLMI 5 G LMi 7 8 LMi II ,3 LM ~5 I? VI_ 30 31 TEUS G-21 ASING & ABANDONMENT DETAIL i I.) Rotary Table Measurement at 0.00' II.) 4 1/2' Cameron Tubing Hanger at 38.46' III.) 26' Drive Pipe at 356' " IV.) 20', 94+, H-40 Casing at 822' V.) 13 318', 61~, & 68~,, K-55 Casing at 5201' VI.) 9 5/8'. 40+ & 47+, USS-95 Casing at 11,160' TUBING DETAIL 4 1/2'; 12,6#, N-80 TUBING 1.) 4 1/2" Otis Ball Valve at 316.59' 2.) 4 1/2' Camco 'MMG" GLM at 1968.61' 3.) 4 1/2" Camco 'MMG' GLM at 3440.32' 4.) 4 1/2" Camco 'MMG' GLM at 4691.01' 5.) 4 1/2" Camco "MMG' GLMat 5571.26' 6.) 4 1/2" Camco "MMG' GLMat 6201.89' 7.) 4 1/2" Camco 'MMG' GLMat 6552.79' 8.) 4 1/2' Camco 'MMG' GLMat 6932.46' 9.) 4 1/2' Camco 'MMG' GLM at 73'11.00' 10.) 4 1/2' Camco 'MMG' GLM at 7660.69' 11.) 4 112' Camco 'MMG' GLM at 8040.47' 12.) 4 1/2' Camco 'MMG' GLM at 8391.11' 13.) 4 1/2' Camco 'MMG' GLMat 8770.27' 14.) 4 1/2' Camco 'MMG' GLMat 9120.25' 15.) 4 1/2' Camco 'MMG' GLMat 9470.22' 16.) 4 1/2' Camco 'MMG' GLM at 9759.24' 17.) 4 1/2' Camco 'MMG' GLM at 10,142.22' 18.) 4 1/2' Camco 'MMG' GLMat 10,307.02' 19.) 20.) 21.) 22.) 23.) 24.) 25.) 26.) 27.) 28.) 29.) 3O.) 31 .) 4 1/2' Otis "XO' Sleeve at 10,346.04' Baker Locator Sub at 10,379.32' Baker Model 'F-I' Packer with Baker Model Seal Assembly from 10,380.27' to 10,395.83' 4 1/2' Otis "X' Nipple at 10,426.76' Bottom of Mule Shoe at 10,459.87' Baker Model 'SAB' Hydraulic Packer at 10,864.35' Baker Millout Extension at 10,869.38' 6 5/8" x 4 1/2' Crossover at 10,874.73' 4 1/2' Otis 'XO' Sleeve at 10,968.39' Baker Locator Sub at 11,003.05' Baker Model 'F-I' Packer with Baker MOdel Seal Assembly from 11,004.00' to 11,013.00' 4 1/2' Otis"X" Nipple at 11,021.02' Cement Plug at 11,022' 32.) Baker Shear Out Sub at 11,032.59' PERFORATION RECORD DA TE INTERVAL CONDITION 24 5/10/75 10930'-10980° Closed Sleeve at 10968.39' 5/14/75 11042'-11080' Isolated by plug at 11,022' 5/18/75 10810'-10850' Hemlock Bench +4 Production 5/18/75 10755'-10800' Hemlock Bench +4 Production 5/18/75 10733'-10745° Hemlock Bench +4 Production 5/19/75 10660'-10690' Hemlock Bench +3 Production 5/20/75 10540'-10590' Hemlock Bench +2 Production 29 5/20/75 10605'-10635' Hemlock Bench +2 Production 2/24/80 10478'-10506' Hemlock Bench +1 Production WELL TE US G-21 I 0RIKOVER WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA :.,. --,**. ,F. :. ~s~ wellhead, it contains tour pairs of rams which are hydraulically-powered for opening and clo~ing, Thc preventers also contain a manual override to enable the rams to be operaled with loss of hydraulic power or to be locked closed. Thc four pairs fi'om thc bottom up are: l-inch OD tubing rams Io packoff around the tubing, l-inch OD tubing OTIS REELED TUBING UNIT BLOWOUT PREVENTER ASSEMBLY malfunction, i-inch OD tubing culler rnm~ to cut the tubing ~hile it is in the wellborc if necessa~', and a pair of blind rams to close when the tubing is out of lhe wellbore. This pre~enter a~sembly has a ~idc outlet or inlet to produce 0r pump through if n~c:ssary. ~, assembly is designed for H2S 5e~'ice and has a 5000 p~i working prea;ure rating. OTIS ENGINEERING CORPORATION [I[OWOUT PREVEI4TER ASSEUBLY -I: Training BLIND RAM I CI~TTER RA i · PI AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [-3 Alter casing Lq Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing FJ Amend order [_'] Perforate F-1 Other 2. Name of Operator 5. Datum elevation (DF or KB) UNOCAL Corporation 99' KB Above MSL feet 3. Address 6. Unit or Property name P. O. Box 190247, Anch., Ak. 99519 Attn' C. Lockwood Trading Bay Unit 4. Location of well at surface 1878' N, 1389' W f/SE Corner Section 29, R13W, S.M. At top of productive interval Top Hemlock: 1768' N, 3664' E f/SW Corner Section 28, At effective depth T9N, R13W, S.M. 1585' N, 3931' E f/SW Corner Section 28, T9N, R13W, S.M. At total depth 1223' N, 4423' E f/SW Corner Section 28, T9N, R13W, S.M. 7. Well number G-31L 8. Permit number 69-72 9. APl number 50-- 133-20194 10. Pool McArthur River Field/Hemlock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 368' Conductor 520 ' Surface 5222' Intermediate 11,667 ' Production Liner 1134' Perforation depth: measured 12,729 10,774 11,524 9,732 Size 26" 17-3/4" 13-3/8" 9-5/8" 1, feet Plugs (measured) feet feet Junk (measured) feet Alaska 0il & Gas Cons. Cemented Measured depthA~':"~'~nC':°r'T~rbe Verticaldepth Driven 368' 368' 790 s× 520' 520' 2500 s× 5222' 4602' 1600 sx 11,667' 9854' 300 sx 11,595'-12,729' 9792'-10774' true vertical Upper Most Perf: Lower Most Perf: Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 9263' ) 9556' ) ) ) ) ) SEE ATTACHED SCHEMATIC 12.Attachments Description summary of proposal Q~ Detailed operations program L~_ BOP sketch [] 13. Estimated date for commencing operation December 1, 1986 14. If proposal was verbally approved Name~ 15. I-'-~'~ereby c.c.c~tif~i/'tha/~e/for/egoin~,"/s ,r~correct ,o the best of my knowledge / /7F/ Signed ~ L~ Title Drilling Superintendent / ' / ~ -' Commission Use Only Co~tions of appr~al Notify commission so representative may witness ~ Approval / ~ Plug integrity ~ BOP Test ~ Location clearance~ ~:~ ,; Commissioner Approved by Date approved No. Date 11-10-86 by order of // "~ t~ the commission Date '~'/:'~ -' c~r,~ ~n.,~nq p,-,, ~9.~_R~ Submit in triplicate G-31L COILED TUBING CLEANOUT PROCEDURE 1. RU slickline and pull ball valve. 2, MU KCl-polymer workover fluid 3. RU skid pump unit to 1-1/4" coiled tubing unit. 4. Pressure test surface equipment to 3000 psi. Function test coiled tubing unit BOP system. 5. RIH with Otis Hydrablast tool on 1-1/4" coiled tubing to +--500' and break circulation with KCl-polymer fluid. 6. Continue down hole and clean out scale to tubing tail. (Reciprocate and check pick up weight on coiled tubing after every 20' drilled to insure no bridging. If returns are lost during operation turn on gas lift and reestablish circulation. Use nigrogen to provide additional lift if needed. ) 7. POH with coiled tubing and RD. Replace ball valve. 8. Return well to production and demob. 11-10-86 0173D G ZON HB-1 WELL T US G-31 CASING & ABANDONMENT DETAIL I.) Rotary Table Measurement at 0,00' II.) Cameron Split Dual Tubing Hanger at 38,60' III.) 17 3/4', 0.312° Spiral Weld Casing at 520' IV.) 13 3/8', 61+, J-55 Casing at 5222' V.) Howco 'EZSV' Retainer at 11,524' VI.) Top 7°, 29+, N-80 Liner at 11,595' VII.) 9 5/8', 43.5+ & 47+, N-80 & P-110 Casing at 11,667' VIII.) Bottom 7°, 29+, N-80 Liner at 12,729' TUBING DETAIL LONG STRING: 3 1/2"~ 9.2#, N-80 TUBING 1.) 2-17.) 18.) 19.) 2O.) 21.) 22.) 23.) 24.) Bottom of Mule Shoe at 10,933.50' ;HORT STRING: 3 1/2; 9.2#, N-80 TUBING A.) Otis Ball 'Valve at 299.57' B-H.) Camco Gas Lift Mandrels at: B) 1991.56° C) 3527,82' D) 5079.23' E) 6427 67' F) 7703.18' G) 8941.97' H) 10,059.54' I.) Otis 'XA' Sleeve at 10,290,05' J.) Baker Model 'A-5' Dual Packer from 10,323.90' to 10337.60' K.) Bottom of 'Q' Nipple at 10,349,15' PERFORATION RECORD DA TE INTERVAL CONDITION 9/18/69 10708'-10728' Open G Zone Production 5/04/74 10540'-10570' Reperf G Zone Production 5/04/74 10450'-10480' Reperf G Zone Production 5/04/74 10610'-10635' Reperf G Zone Production 5/13/74 '11255'-11315' HB-4 Production 5/15/74 11160'-11190' HB-3 Production 5/16/74 10966'-10986' HB-1 Production 11015'-11025' HB-2 Production 11042'-11057' HB-2 Production 11080'-11110' HB-2 Production Otis Ball Valve at 302.97' Camco Gas Lift Mandrels at: 2) 1901.62' 3) 3010.91' 4) 4031.06' 5) 4953.05' 6) 5582.82' 7) 6054;45' 8) 6494.80' 9) 6932.36' 10) 7362.30' 11) 7742.27' 12) 8143.55' 13) 8575.36' 14) 8971.56' 15) 9372.60' 16) 9780.26t 17) 10,162.45' Otis 'XA' Sleeve at 10,28'9.82' Baker Model 'A-5' Dual Packer from 10,323.90' to 10,337.6Q' Otis 'XA' Sleeve at 10,863.92' Buttress Locator Sub at 10,899.00' Baker Perm. Packer with Seal Assembly from 10,900.00' to 10,921.06'. Packer at tO,900' 'Q' Nipple at 10,931.22° HB'2 HB'3 HB-4 VII VIII NOTE: Bottom of Long String was shot off in Aug. 1980. WELL TBUS G-31 WELL SCHEMATIC UNION OIL COMPANYOF CALIFORNIA NOV 1 1986 Oil & Gas Cons. ~ .... ~,-,',ssion OTIS REELED TUBING UNIT BLOWOUT PREVENTER ASSEMBLY ..... :, m. ,, j~ wcllhcad. It contains four p~irs ~f ram~ which are hydraulically-powered for opening and clo~ing, The preventers also contain a manual override to enable the rams to be operated with loss of hydraulic power or to be locked dose~. The four pail's fi'om tl~c bottom up are: l-inch OD tubing rams to packoff around the tubing, l-inch OD tubing malfunction. I-inch OD tubing cuucr rams to cut the tubing ~hile it is in the wellbore if necessam and a pair of blind rams to close when the tubing is out of the wellbore. This pre~enter a~sembly has a side outlet or inlet to produce or pump xhrough if necessary. ~e assembly is designed for H2S Sen'ice and has a 5000 psi working pressure rating, OTIS ENGINEERING CORPORATION BLOWOUT PRE:VEHTER ASSE:MBLY' .[ Training BLIND RAM CUTTER SLIP I:AM l-INCH O.D. PIPE RAM /o0.' Union Oil and Ga.,-.~"vision: Western Region Union Oil Compa,,), ..,f California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 union October 22, 1975 99504 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska ...... lC.. ('. ~,:.~L1 I1 ~'~ I .. I ~-I:~"c~..l_ .... I"~ ~:,,ic; I I4 .. ..~ --I' '?'~?~°~''[ .... i-3 o~oL"I '] .... ~:,~v ]-' ---[---~;;:~.~--~ .... .... ] .... :~,~c -. ~--. . . ..- ............ Dear Mr. Marshall: Enclosed for your files are two (2) copies each of the Well Histories for the following wells: Trading Bay Unit State G-15 (WO) Trading Bay Unit State G-13 (WO) Trading Bay Unit State G-~2-----.(WO) Trading Bay Unit S~_~.-~-21 .~WO) Trading Bay Unit State-G'~-~'' (WO) Trading Bay Unit State G-23 Trading Bay Unit State G-22 Trading Bay Unit State K-21 Kenai Untit #21-6 (WO) Kenai Unit #33-30 (WO) Kenai Unit #43-7 (WO) Very truly yours, Jim R. Callender District Drlg. Supt. sk Encl. (22) · cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. - TBU only Skelly Oil Co. - TBU only Phillips Oil Co. - TBU only Standard Oil Co. USGS - Rodney Smith ~'orm D-IOOI-A UNION OIL CO. OF CALIFORNIA' SHEET A REPAIR RECORD PAGE 1'40. ..' ........ - ,' v T .... ' '": G:L2_!._WQONTt~/~CTOR Parkt:r Drilling Co~nz..a._nx . [,EASZ ! ~-?d)IU¢~_..h&:~__Uk:, [%._SI~.IE _:-WEI.,/', NO,.~ ........ - ....... - FIELD ..... ?LC:oztq3&E_!_~,B¢:~;)Z?'.3_cld_ ...................................... TYPE UN J" BEGAZ: ~.;'_//~]..L:L. 2 COMPLE I EI.' _.._p/__~.O]_{o ELEVATIONS: GROUND -'~,:,,~,~ NO ........... ~_ ....................... SERIAL NO. ADL-]8730 CASING HEAD' ,.;,~ ........ / ....... , ................. ,;:¢..~.1434 TUBINC; IIEAI) TUBING RECORD EEMAItKS Predyive~z to 356' Refer to original Well tHstory (1]_/20/74 for daily detail). Refer to original W.e]] History (1]./30/74 for dally detail). Refer to origJnal Weli History (].2/]_4/74 for da~ly detail). *P-110 & N-80. See attached tbg. detail. 4 !/2" t] 033ti ]2 .., , .ou , N-80 PERFORATING RECORD !Z'TE~\rAL . 2/30/74 2/31/74: }./1/75 ]/~/75 ~f~/75 1/2/75 5/t0/75 5/'14/75 5/14/75 5/lS/75 5/!s/75 5118/7.5 5/18/75 !i,053:-11,084 ~ , ,_,~.,. -I i, 063 10 o58'-1 0 OO ~ yU7 t0,,u~a"~'-10,930 11,042~-II,084 ii, 042'"'1]., 062~ 10,530]- !0.,850] t0,770'-I0,800J 10,755'-10,770] 10,733'-i0,745J. ti, 1].0' FC 11,110' 1t, !10' 11, 1t0' 11, It0' 11,110' t!, 091'Jun], 11,091' 11,091' 11,091' 11,091' tl,091' !1,091' ~$O N , Production Production Production Production Production Production Production Production Production Production Production Production Production Open Bench 4f6 Open Bench ~'~6 Open Bench #5 Open Bench #5 Open Bench #5 Open Bench #6 Open Bench #5 Open Bench #6 Open Bench #6 OPen Bench #4 Open Bench #4 Open Bench #4 Open Bench #4 PRESENT CONDITION Isolated by plug @ ]1,022'. Isolated by plug ~t 11,022'. Isolated by sleeve closed @ 10,968~ II II I! II Il Il II Il II II II Iso]ated by plug @ ]1,022' Closed sleeve @ 10,968' Plug @ 11,022'. Plug @ ].1,022'. 5/18/75 5/20/75, 5/22175 · ~24 hrs[, on O-2]. 2/27/ 10,733~ t~1145 i0,605~-10,85 5720 10, 54-0:-I1, 98 ' 5824 7_'-; & 4/1 /75 .6% .1% .1% ~Y 35.4 980 33.6 1080 32.9 1040 run Pro,.uction 140 175 180 Bench #4 test. 259 Benches #2, #3 & #4 Test. 258 Total well productio ~1 ~f 48 hrs,) ?rofile 1 (total WELl. HISTORY PRIOR TO REPAIR LAST COMPLETION NO. ''-7 '~'; (.,-;,;, , .iii [ j [ ;~; ~, ~X ....... ~.7. -.1 ] ! ,, ;-t 2[ ,: i~- t;t, '~.T':.k- ][ :~ L. ~_.} l~ [ . . ;; :] .... ..z~ ~R ~ J [9 J ,-2:- ;[~, ......: __..,]z[: ] ::7 ;~7;" -?~: zz.i 5 ' 7 ..................................................................................................................................................................... ................................................................ - . ........................................................................... . Form D-IOOI~B UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET B PAGE NO LEASE TRAt)ING BAY UNIT STATE COMPLETION DAli L: E,T.D. 5/20/' 75 WELL NoG-21-WO FIELD_McArthur River Field APPROVED DETAILS OF OPERATIONS, DESCRIPTIONS &' RESULTS PERFORATING RECORD (cont...) ['YPE: INTERVAL ETD REASON :~, 19/75 10,660~-]0 b90' 1].,091' Production ~/~0/'75 10, 540~-10, 590~ 11,091' Production 5/20/75 ;10,605"-10,635' 11,091' Production PRESENT CONDITION Open Bench ~3. :~2. Open Bench ~ Open Bench ~2. C ~ Nlo~ieon ]ASINGHEAD:_ WF 12" 3000*:,rWP X ,,]3 3/8" OD slip on weld btm. w/ two 2" 5000#WP flanged outlets. ]ASING t~GER: Slip & seal assy. CA 12" X 9 5/8" OD :AS!N'G SPOOL: :Ut3ING IIEAD: DC-B 117," 300(;~' W}:-' .,, :,[0" .~000~¢ WP w~ two 2" 5000~f WP STDD outlets ;Ut3!NG HANGER' DC.,-FBB 4 ............................... 'IJ't~ING HEAD TOP:. t0" 5000/~'- WP VALVES: -'/~' .,_) valve tv'pu F ~1 iL.L. PAGE UNIO['~ O.IL CCFPANY OF CALIFORHIA I,?ELL I<ECOI~D LEASE TRADING BAY UNIT STATE 1',ELL IlO, G- ~ ~. wo FIELD DATE 4? 2/27/'75 48 4/19/7S ETD II, ].60'TD 1]_, ll0tETD Float Collar 11,160lTD 11, I10'ETD Float Collar DETAILS OF OPEPJNTIONS, DESCRIPTIOI'IS 8 RESULTS (Footage 0') Commenced operations on TBUS 0-2] C} ]2:01 am, 2/27/75. RU WL unit. RIH w/ press, survey. Tagged ETD @ ll,107'WLM. Pooh. Left survey tool in hole. RU Schlumberger. Ran Production Profile from 11,088' to 10,434'. Survey indicated all production coming from Hemlock Bench #6. Diff. perf. J:-temlock Bench #5 from 10,987' to 10,958', 10,924'-10,904' & from 10,900'- 10,882' @4 hpf. RD Schlumberger & returned well to gas lift. Released rig from TBUS G-21 to TBUS 0-23 @ 12:00 Midnite, 2/27/75. (Footage 0') Commenced operations on TBUS G-2] @ ]2:01 am, 4/19/75. RU Schlumberger. Ran Production Profile w/ well stab. @2530 +BPD. Profile results: ].230 BOPD w/ 800 BWPD from ttemlock ~5 RD Bench#6 & 500 BOPD w/ no wtr. from Hemlock Bench ~ . Schlumberger. Released rig from TBUS G-2] to TBUS G-23 @ ]2'00 Midnite, 4/i. 9/75. UNION 0IL CCI'iP/g tY OF CALIFORNIA I, LL t,LC0t D LEASE TRADING BAY UNIT STATE I',ELL II0, G-z wo FIELD McARTIIUR RIVEP, FIEE]) BATE 5/8/75 5O 5/9/75 51 5/10/75 52 5/11/7.5 53 5/12/75 54 5/13/75 5/14/75 5/15/75 ETD ll,160;TD ].t, t]0~ETD Float Collar 1]., t60'TD 11, I!01ETD Float Collar 11,160'TD 11,09 t ?ETD Junk ll,160~TD Junk 11,160'TD 11,091 'ETD Junk ' 11,160'TD 11,091 'ETD Junk 11,160'TD 11,091 'ETD Junk 1t, 160'TD 11,091 'ETD Junk DETAILS OF OPERATIONS, DESCRIPTIOIIS g RESWLTS (Footage 0') Commenced operations on TBUS G-21 @ 1.2'01 am, 5/8/75. Skidded from TBUS G-23 to TBUS G-21. RU WL unit. Pulled ball valves & opened "XA" sleeve @ 10,367'. Displ. tbg. & annulus w/ 5% KCL-Dril-S W@ fluid. Installed BPV. Removed x-mas tree. Installed BOPE.. (Footage 0') Installed BOPE & tested to UOCO specs. PU on 4 1/2" tbg. & cleared bore of perm. pkr. @ 10,388'. Circ. well clean. Pooh w/ tbg. string. RIH w/ 8 1/2" X 6" BO mill &pkr. picker. Milled over perm. pkr. @ 10,388' & retrieved same. (Footage 0') Made bit & scraper trip to I[,091'DPM. Circ. xvell clean. Pooh. RU DA. RIH w/ 4" csg. guns & perf. Hemlock Bench #5 from 10,930'-10,980' @ 4 hpf. Ran WL guage ring & JB to 11,030'. Ran & set 9 5/8" X 6" Baker ModelF-1 pkr. 0 ]I,004'DIL. RD DA. Made up Baker 9 5/8" SAB Hyd. Ret. Prod. Pkr. w/ 4 1/2" tbg. tail & Baker seal assy. below. (Footage 0') RIH & stabbed into perm. pkr. @ 11,004' Tested perm. ,-,l-~ w 6'00 ?ct ~ ..... ~ ~ ........ ball & set ~-'-t~i on~ p~' 10 o~,, Tested pkr in tension w/ 75 0000 Released setting tool PoOh a laid dwn, 3 1/2" DP. AU DA, Ran a set 9 5/8" X 6" Bake~ ModelF-i Pkr, ~10,370'. RD DA, (Foota~e 0') RU & ran 4 1/2" prod. tbg. hydro-testing to 5000 psi. Stabbed into. Baker ModelF-1 Prod. Pkr. @ 10,370'DIL & tested ok. Installed BPV in tbg. hgr'. Removed BOPE. Installed x-mas tree & tested to 5000 psi. RU slickline unit & opened "XO" sleeve @ 10,346'. Displ. W@ fluid (5% KCL-Dril-S) w/ diesel. (Footage 0') Unloaded diesel xv/ gas lift. RU WL unit. Closed "XO" 'sleeve @ 10,346'. Gas lifted well for production test of Hemlock Bench ~6 perfs, from 11,042' to 11,084'. No entry from Hemlock Bench #6. Displ. tbg. w/ diesel. Press. tbg. to 1500 psi. Unable to pump into Bench #6 perfs. (Footage 0') RU DA. RIH w/ 3 1/8" carrier gun. Diff. reperf. Hemlock Bench #6 from 11,060'-11,080'. Put ~vell on gas lift for production test. Had limited entry. RIH w/ 3 1/8" carrier gun. Diff. reperf. Hemlock Bench #6 from 11, 042'-].1, 062*. Put well on gas lift for prod. test. No fluid entry. Displ. tbg. xv/ diesel. Pumped 25 bbls diesel into Bench #~ @ 0.5 bbls/min, w/ 1800 psi. Reltn'ned well to gas lift. No fluid entry. (Footage 0') RU slickline unit & pent_.d "XA" o , ~ sleeve 0 10,968' opposite Hemlock Bench #5 perfs. (10,882'-10,987'). Gas lifted well to prod. test Bench #5. Rate stabilized @ +],950 BPD w/ 60% cut (J2780 BOPD net). RU & displ, tbg. w/ diesel through "XA" sleeve @ 10,968'. Initial pump-in 50 psi. Final t)ump-in 900 psi. Total displ. 180 bbls. UNIOI'I OIL CQPANY OF CALIFORNIA I,&LL 16C0t® L~SE TRADINO BAY UNIT STA'£E I'ELL Il0, G-z wo. FIELD McARTIIUR RIVER FIELD BATE 57 5/16/75 58 5/1.?/75 59 5/18/75 6O 5/]_9/75 61 5/20/75 ETD ].1,160'TD 11,091'ETD Junk ll, 160'TD 11,091'ETD JUnk 11,160'TD 11,091'ETD 11,160'TD 11,091'ETD Junk 11,160'TD 11,091'ETD Junk DETAILS OF OPEI~'FiOh'S, DESCRIPTIOIIS & RESLILTS (Footage 0~) Displ. tbg. w/ diesel. Closed "XA" sleeve opposite Bench #5 peris. Gas lifted diesel out of tbg. RU Dowel] to to acidize Hemlock Bench #6 peris, from 1],042'-11,084'. Acidized B erich ~z- . . . -~,o w/ 1680 gal 15% }ICL Prod tested Bench #6 on gas lift, Initial 'rate of 1200 BPD w/ 50% cut. Decreased to 49 BPD w/ 45% cut. (Footage 0") RU Dowell & performed matrix acid job w/ 3 stages of 2 1/2% HCL & 12-6 HCL-HF & 2 1/2% HCL. Prod. tested Bench #6 peris, after matrix acid job @ ].152 BPD w/ 72% cut. Decreased to 576 w/ 51% cut. Set plug in tbg. tail @ 1],022' to isolate Bench #6 peris. Gas lifted tbg. dry & dry tester] Bench #5 & #6 for isolation-ok. (Footage 0') RU Dresser Atlas & perf. Hemlock Bench #4 from 10,830~-t0,850', 10,770'-10,800', 10,755'-10,770' & from 10,733'- 10,745'. Gas lifted well & production tested Bench #4. GROSS CUT NET GLR TBG/CSG. GRAVITY 1152 0.6% 1145 3451 140 980 35.4~ (Footage 0;) Continued testing Bench #4 per£s. RU North Star & raft Flowing Gradient Survey-gas lift system operating ok. RU DA & perf. Bench #3 from 10,660'-10,690' w/ 4 hpf. Maintained 500 BPD rate while perf. Bench #3. Production tested Benches #3 & #4 as follows: GROSS CUT NET GOR TBG. CSG. GRAVITY 4176 0.7% 4147 204 150-170 980 34.0~ RU DA to perf.. Bench #2 from 10,540'-10,590' & from 10,605'- 10,635'. '(FoOtage 0') Perf. Bench #2 from 10,540'-10,590' & from 10,605'- 10,635'. Maintained 500 BPD rate while perf. Bench #2. RD DA. Production teSted Benches #2, #3 & #4 as follows' GROSS CUT NET GOR TBG/CSG. GRAVITY 5726 0.1% 5720 259 175 1080 33.6.0 Released rig @ 12:00 Midnite, 5/20/75 for rig move from TBUS G-21 to [['BUS G-22. PAGE UNION OIL CCtiPNff OF CALIFO[a'IIA I',, LL I<ECORD LEASE TRADING BAY UNIT STATE 'ELL t!0, G-z wo FIELD McARTHUR RIVER FIEI, D bATE ETD JTS. 12 DETAILS OF OPEP&TIONS, DESCRIPTIOHS & RESULTS TUBING DETAIL TRADING BAY UNIT STATE G-21 4 1/2:' 12.60# N-80 Buttress Tbg. DESCRIPTION LENGTH BOTTOM ]Baker Shear Out Sub 4 1/2r~' t2.60# N--80 Buttress Tbg. Pup Jr. ©tis 4 1/2~': ~*Xt~' Nipple 3.812 ID 4 1/2''~ 12.60~ N-80 Buttress Tbg. Pup Jr. Baker Model 'G' Seal Assy. 6"OD X 4"~ID Baker Model F-1 9 5/8" X 6" Pkr. Set @ ]1,004' DIL meas. Baker Locator Sub 6 1/2"OD X 4"ID 4 1/2~ 12.60# N-80 Buttress Tbg. 4 1/2" Otis "XA' sleeve 3.812 lb 4 t/2""' 12.60# N-80 Buttress Tbg. Baker X-over 6 5/8H 8rd Box X 4 1/2~ Butt. ?in. Baker Mi!iout Extention 6 15/16"OD X 5 1/2".tD Baker 9 5/8" X 41/2" Model "$AB" Hyd. pkr. set @ 10,864.35', 1_.20 11,033.79 10.03 11,032.59 1.54 11,022.56 8.02 1],021.02 9.00 11,013.00 .95 11,004.00 30.].0 ]1,003.05 4.56 10,972.95 92.80 10,968.39 .86 10,875.59 5.35 10,874.73 5.03 10,859.38 4 1/2" Mule Shoe 4.920'1OD 4"ID 4 1/2" 12.60# N-80 Buttress Tbg. 4 1/2" Otis "X" Nipple 4.60"OD 3.812'1ID 4 1/2" 12.60# N-80 Buttress Tbg. Baker Model "G" Seal Assy. 6"OD X 4"ID Baker ~Model F-1 9 5/8" X 6"ID set @ 10,370'DIL meas. Baker Locator Sub 6 1/2"OD X 4"ID 4 1/2" 12.60# N-80 Buttress Tbg. 4 1/2" Otis "XO" sleeve 3.812ID 4 1/2" 12.60# N-80 Buttress Tbg. 4 1/2" Camco MMG GLV= ~17 4 1/2" 12.60# N-80 Buttress Tbg.- 4 1/2" Camco MMG GLV #16 4 1/2" 12.60# N-80 Buttress Tbg. 4 1/2" Camco h[h~G GLV #15 4 1/2" 12.60# N-80 Buttress Tbg. 4 1/2'' Camco MMG GLV #14 .75 10,459.87 30.94 10,459.12 1.46 10,428.18 30.89 10,426.72 15.56 10,395.83 95 10,380 27 28 90 10,379 32 4 38 10,350 42 30 49 10,346 04 8 53 10,3].5 55 156 27 ]0,307 02 8 53 10,150 75 374 45 10,]42 22 8 53 9,767 77 280 49 9,759 24 8 53 9,478 75 TOP ]1,032.59 11,022.56 11,021.02 11,013.00 11,0'04.00 11,003.05 10,972.95 10,968.39 10,875.59 10.874.73 10,869.38 10,864.35: 10,459.12 10,428.18 10,426.72 10,395.83 10,380.27 10,379.32 1.0,350 42 10,346 04 10,315 55 10,307 02 10,150 75 10,]42 22 9,767 77 9,759 24 9,478 75 9,470 22 UNION OIL CffiPAfff CE-CALIFO[ ,tIA I, LL tccOI-® L~SE TRADING !'~AY UNIT STATE IN~ELL [I0, G-2] WO__ FIELD ILL I U PAG[:-. [,lo, McART_I!UR RIV_ER I'~!Ei23_ *. DATE ETD JTS. 11 11 12 11 12 11 12 12 11 2O 28 4O 47 53 333 DETAILS OF OPEPT, TIOh'S, DESCRIPTIO!IS & RESUI_TS DESCRIPTION ThUS G-21 (WO)... TUBING DETAIL (cont .... ) LENGTH 1/2" 12 60~- , .~ N-80 Buttress Tbg 1/2~ Cam. co MMG GLV #13 1./.2~ 12.60# N-80 Buttress Tbg 1/2~ Camco MMG GLV #12 ]/2" 12.80# N-80 Buttress Tbg t/2~ Camco MMG GLV #11 1/2-" 12.60# N-80 Buttress Tbg 1/2" Camco MMG GLV #10 t/2" 12.60~ N-80 Buttress Tbg 1/2~ Camco MMG GLV #9 1/2~ 12.60# N-80 Buttress Tbg 1/2~ Camco MMG GLV #8 1/2" ].2.60# N-SO Buttress Tbg ]./2" Camco MMG GLV #7 1/Z" 12.60# N-SO Buttress Tbg t/2" Camco MMG GLV #6 1/2" 12.60# N-80 Buttress Tbg i/2:" ~amco ~w_~v~ta ta~v #5 1/2' 12.60# N-80 Buttress Tbg 1~2" Camco MMG GLV #4 1/2" 12.60# N-80 Buttress Tbg 1/2" .Camco MMG GLV #3 1/2" ~2.60# N-80 Buttress Tbg 1/2" Camco MMG GLV #2 1/2" 12.60# N-80 Buttress Tbg 1/2" Camco MMG GLV #1 1/2" 12 60# N-80 Buttress Tbg 1/2" Otis Ball Valve 4.850"OD X 3.812"ID 1/2" 12.60# N-80 Buttress Tbg. 1/2" 12.60# N-80 Buttress Pup Jr. 1/2" 12.60# N-80 Buttress Pup Jr. 1/2" 12.60# N-80 Buttress Pup Jt. 1/2" 12.60# N-80 Buttress Pup Jr. ]/2" 12.60# N-80 Buttress Pup Jt. 1/2" Cameron Tbg. Hgt. 4 1/2" Butt. btm.-4 1/2" EUE top. EleYation R. oatary Table to Tbg. Head TOTAL JTS, TBG, 329 Total jts. Upper String 4 Total jts. Lower Pkr. Assy. 333 I'CIAL J'.FS, TBG 341 44 8 53 34] 45 8 53 370 63 8 53 342 11 8 53 371 25 8 53 341 16 8 53 370 01 8 53 371 ].6 8 53 342 35 622 10 8 53 871 72 8 53 1242 16 8 53 1463 18 8 53 1648 92 3.10 253.52 5.10 4.97 4.10 8.14 1.30 1,00 38.46 BOTTOM 9,470 22 9,128 78 9,120 25 8,778 80 8,770 27 8,399 64 8,39]. 11 8,049 00 8,040 47 7,669 22 7,660 69 7,319 53 7,3].]. 00 6,940 99 6,932 46 6,561 30 6,552 77 6,201 89 5,579 79 5,571 26 4,699 54 4,691 01 3,448 85 3,440 32 1,977 14 1,968 61.' 319.69 316.59 63.07 57.97 53.00 48,90 40,76 39, 38.46 TOP 9,128 78 9,120 25 8,778 80 8,770 27 8,399 64 8,391 11 8,0:!9 O0 8,040 47 7,669 22 7,660 69 7,319 53 7,311 00 6,940 99 6,932 46 6,561 30 6,552 77 6,210 42 A ?(/1 ~Q 5,579 79 5,571 26 4,699 54 4,691 01 3,448 85 3,440 32 1,977 14 1,968 61 319 69 316.59 63.07 57.97 53.00 48.90 40.76 39.46 38,46 -0- 8. Tbg. Hgt. 38.46' 16.59' 1968 61' 3440 32' 4091 01 5571 26 6201 89 6552 79 6932 46 7311 00 76(>4 69 8040.47 8391.11 8770.27 9120.25 9470.22 9759.24 10,142.22 10,302.02' 3.8t2 ID OS X 4" ID Baker Locator Sub 10.370.32'. 6" mD ' .... ID ~aker · Seal Assy. w/'Baker 190.60 Model "F-l" pkr. 9 5/8" X 6 ID set 0 10,370~DiL meas. ~ 1/2" Otis "X" Nipple ~.60 OD X 3.812ID 10, 426 . 72' . 3. 4 1/2" Mule Shoe 4.93"OD X ~"' ID ' 10,~59.12~. ~. 4 1/2" 190.60 Baker Model "SAB" Hyd. 1. 4 1/2" Otis Ball Valve 3 2. 4 1/2" Camco MMG GLV 3. 4 1/2" Camco MMG GLV 4. 4 1/2" Camco MMG GLV 5. 4 1/2" Camco MMG GLV [-5. 1/2" Camco MMG GLV 4 ~. 4 1/2" Camco MMG GLV 8. 4 1/2" Camco MMG GLV 9. 4 1/2" Camco .MMG GLV 10. 4 1/2" Camco MMG GLV 11. 4 1/2" Camco MMG GLV 12. 4 1/2" Camco MMG GLV 13. 4 1/2" Camco MMG ©LV 14. 4 1/2" Camco MMG GLV 15. 4 1/2" Camco MMG GLV 16. 4 1/2" Camco MMG GLV :17. 4 1/2" Camco MMG GLV 18. 4 1/2" Camco MMG GLV ~9'. 4 1/2" Otis "KO" sleeve tO 10,346.04 ·6 1/2" pkr. 10,864.35'. .>5. 6 5/8" OD X 5.370 ID Baker Millout Extention. 10,867.38'. .~6. 6 5/8" Box X 4 1/2" Butt Pin ]3aker "X-Over" 10,874.73" . ]7. 4 1/2" Otis "XO" sleeve 3.812 ID ; 10,968.39'. 8. 6 1/2" OD X 4" ID Baker Locator Sub. 11,003.05'. '~--~' 7 8 9 ]_0 ]1 12 13 21 24 29. 6" OD X 4': ID Baker Model "G" Seal Assy. w/ 9 5/8" X 6" Baker Model ]90.60 FI pkr. set @ ll,004.00'DIL meas. 11,021.02' 30. 4 1/2" Otis "X" Nipple 3.812 ID 11,021.02' 31. Baker Shear Out Sub 11,032.59'· :" i WELL SCNEMATtC ' ,' TRADING :BAY UNIT sTATE WE!~L I O ~T~ ~ I UNION ~.1_ t.O,-d, A, IY OF 92 CONTROL LiNE NATIONAL BUTTRESS UNION OIL CO. OF CALIFORNIA ANCHORAGE, ALASKA P. O. BOX 1212- HOUSTON, TEXAS 77001 LINI01kl 01L COMPANY OF' CALIFORNIA ANCt'IORAGE ~ CAS lNG PROGRAM -~ 4-1/2"0D ~qTIONAL BUTTRESS W/1/8 "I~.! PT BILL Of' MAIERIAL, NUMBF_R 932698 QUOTE #9-4474 CONTROL LINE ON ORDERED UNIT PRICE 1q97.11 12.83 6.'23 1,74 4051, OC 4.29 248.56 PART NUMBER 20446 20 6590 58 6832 1 5926 29 38564 2 10 10 19937 3 6590 12 .. 17393 14 1 7 DESCRIPTION SINGLE STRING TREE AS FOLLOWS XMAS TREE ASSEHBLY 5000#WP SPOOL, TBG HD DC-B 12"3000,,r'~P X 10"5000~WP W/2~2"5000#WP STDD OUTL GASKET STEEL RING R 54 STUD 1'-'7/8" X 14-1/2" NUT 1-7/8" VALVE, "CROSSTYPE" CAMERON "F" GATE SINGLE STRING BLOCK LOG BTM FLGD 10" 5000,~'qqP W/7" OD SEAL SUB PREP AND 1/2" NPT OUTLET FOR 1/8" NPT CONTROL LINE, W/ONE 4-1/8"BORE MASTER AND ONE 4~1/8'' BORE S~/AB VALVES W/TWO 4" ~O00~qP STDD OIITI.q. TOP STDD b" 5000,(WP BO[)Y STYLE "FE~' INCL HANDWHEEL GASKET STEEL RING 6~3/8'' PD-R-39 CAP XMAS TREE FLGD 4"5000#WP THDD 4:1/2"EUE TOTAL XMAS TREE ASSEMBLY AMOUNT 1497.1 12.8. 74,7 41.7 4'051 , 0i 4.2.~ 248.5~' 5930.3~ P. O. BOX '1212- HOUSTON, TEXAS 77001 7-31 -69 BILL OF' MAIr_I{IAL NUM[]Et'.~ 932698 · UNION OIL COMPANY OF CALIFORNIA QUOTE .ANCHORAGE, ALASKA #9-4474 CAS lNG ORDERED PROGRAM - 4-1/2"0D NATIONAL BUTTRESS W/l/8" NPT COh'TROL LINE UNiT PRICE PART NUMBER DESCRIPTION A~OUNT ...... Z 6'29.64 8.48 28.69 ,O0 677162 1 7482,' 40 7484 40 18775 8721 1 LOOSE XI,¼S TREE MATERIAL HANGER, TBG ASSEMBLY "DC-FBB" W/7" OD EXT. SEAL NECK, 10" 5000,~WP X 4-1/2" OD NATIONAl. BUTTRESS BTH X 4-1/2" EUE TOP W/"H" BPV THD Ah'D 1/8" LP CONTROL LINE PREP VALVE,STRAIGHT'NEEDLE 1/2"NPT MXF GAUGE~ ASHCROFT PRSSR, 4-1/2"FACE 0-5000~ RANGE ST/STL CASE, #1020XT GUN PLASTIC PACKING, INCL. WRENCH TOTAL LOOSE X[~S TREE MATERIAL TOTAL LIST PRICES LESS CASH DISCOUNT 2 PER CENT 5TH AND 20TH PROX. TOTAL NET PRICE FOB HOUSTON~ PLANT TEXAS NOTE-PRICES SHOWN ON THIS QUOTATION VALID FOR 30 DAYS ONLY. 629.64 8.4~' 28.6.q ,OC 666.8t 6~7.iZ 131.9~ 6465.1 Union Oil and Gas D~sion: Western Region Union Oil Company ,.. California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 J.une 4, 1975 Mr. Tom Marshall Division of Oil & Gas State of' Alaska 3001 Porcupine Drive Anchorage, Alaska 99503 J 3FNG --F _.j CONFER: FILE: RE: TBUS G-23 (23-33) TBUS G-21 (21-33) rBOS 6-22 (12-32) TBUS D-24 (33-5) Dear Mr. Marshall: Listed below are the enclosed reports required for eaCh of the above captioned wells. TBUS G-23 (23-33) TBUS G-21 (21-33) Titus 6-22 (12-32) TBUS D'24A (33-5) Form P-4 Monthly Report Form 10-403 Sundry Notice Form P-4 Monthly Report Form 10-403 SUndry Notice 'Form P-4 Monthly Report Form P-7 Completion Report Well History Directional Survey sk Encl. cc: Marathon Atlantic Richfield Amoco Production Phillips Petroleum Skelly Oil Standard Oil Rodney Smith - USGS V ~ truly zygur s, David A. Johnson Drilling Engineer , Form 10-403 "'~ EV. 1-10-73 Submit "1 nte;,,~)ons" in Triplicate & ,,Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELLi ^ I WELL OTHER 2. NAMEOF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage; Ala~k~ 99501 4. LOCATION OF WELL At surface Conductor #2, Leg Rm. #3, 1802'N & 1415'W of SE corner. Section 29: T9N, R13W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RT 99' above MSL. 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20267 6. LEASE DESIGNATION AND SERIAL NO. ADL-18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. Sfa~P G-Z] (2l 10. FIELD AND POOL, OR WILDCAT McArthur River Field-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 2700'S, 2830'E of surf. loc. or 925'S, 2410'E of NW corner. Sec. 33: T9N, 12. PERMIT NO. R13W, S. M. 74-42 )ort, or Other Data FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING ~'~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) See below* (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. *The purpose of this wellwork was to determine the source of water production & isolate such zones for selective production. At such time the present productive zones became prohibitively wet, this installation would allow for thru tbg. perforating of additional zones & plugging off of wet zones. PLAN OF PROCEDURE: 1 2 3 4 5 6 7 8 9 10. Skidded rig over TBUS G-21. RU electric WL unit & ran Production Profile. Killed well w/ 5% KCL-Dril-S WO fluid. Installed BPV. Removed x-mas tree. Installed & tested BOPE. Pulled 4 1/2" tbg. & accessories. Milled over & retrieved permanent pkr. @ 10,403' tbg. meas. & 10,388'WLM. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. CC) 9 5/8" csg. to ll,I10'ETD. Perf. Hemlock Bench #5 from 10,930'-10,980' Recompleted well w/ 4 1/2" gas lift string & isolation pkrs. @ 11,004', 10,864' & 10,370' Installed BPV. Removed BOPE. Installed & tested x-mas tree. Prod. tested Hemlock Bench #5 & #6. Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate Worm 10-403 REV. 1-10-,73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--"' for such proposals.) 1. OIL ~ GAS WELLL-J WELL 2. NAME OF OPERATOR OTHER 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 3. ADDRESS OF OPERATOR 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL At su trace 13. ELEVATIONS (Show whether DF, RT, GR, etc.) CheCk Appropriate Box To Indicate Nature of Notice, Re 14. 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. )OFt, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. TBUS G-21 WO Continued.,. 11. Isolated Hemlock Bench #5 from wellbore by closing 'IXA" sleeve @ 10,968'. 12. Acidized Hemlock Bench #6 & prod. tested. 13. Isolated Hemlock Bench #6 by setting plug in tbg. tail @ 11,022'. 14. Thru tbg. diff. perf. Hemlock Benches #2 thru #4 as follows: BENCH INTERVAL #2 10,540'-10,590 #2 10,605'-10,635' #3 10,660'-10,690' #4 10,730'-10,745' #4 10,755'-10,800' #4 10,810'-10,850' 15. Returned well to production. 16. I hereby certify that the foregoing is true and correct FINAL REPORT. __ DATE. 6110/75 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE See Instructions On Reverse Side - ALAS ~To. P---~ STATE OF KA $-1-70 OIL AND GAS CONSERVATION COMMll-rEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5 APl NU~{ERiCAL CODE 50-133-20267 LE~SE DES]GNIAi~ION AND S]EI:~IAL NO ADL-18730 IF INDIA~. ALOTTEE O~ TRIBE NAME 1. OTIIER 8. L~.'IT F.kI'~1 OR LEASE NAM~ 2. N~E OF oPmroa UNION OIL COMPANY OF CALIFORNIA Trading Bay unit 9 WE~ NO State G-21 (21-33} 3. ADDress o~' opn~roa 909 West 9thAvenue, Anchorage, Alaska 99501 Conductor #2, Leg Rm. #3, 1802'N & 1415'W of SC', corner. Section 29' TgN, R13W, S. M. l0 FIELD A_'N'D PCK_3L. OR WILDCAT McArthur River Field-Hemlock ' 11 SEC . T.. R., M(BO'FTOM HOL,~ ommc-r.~vz> 2700'S, 2830'E of surf. loc. or 925'S, 2410'E of NW corner. .S~cticm 3~i_· TqN,_RI~W~ ,~: lX4 12. PEI~MIT NO 74-42 13. REPORT TOTAL DEiPTH AT E.ND OF MONTH, CHAZ'~GF.S IN HOLE SIZE, CASING AND CL-MF. NTING JOBS INCLUDING DEPTH SET AN'D VOLLrlVI'ES USED. PE.1R. FORATIONS, T'ESTS ANT) RESULTS FISHING JOl3~ JLrNK LN[ HoLE AND SIDE-T'RACKED HOLE A~NrD A_NY OTt-DER SIGNIFICAJN!T C'H.A3qGF.,S IN HOL,~ CON-DITIONS. Commenced operations on TBUS G-21 @ 12:01 am, 5/8/75. Skidded rig from TBUS G-23 to TBUS G-21. RU WL unit. Pulled ball valves & opened "XA" sleeve @ 10,367' Displ. tbg. & annulus w/ 5%KCL-Dril-S WO fluid. Installed BPV. Removed x-mas tree. Installed & tested BOPE to UOCO specs. PU on 4 1/2" tbg. & cleared bore of perm. pkr. @ 10,388'. Pooh w/ tbg. string. RIH w/ BO mill & pkr. picker. Milled over pkr. @ 10,388' & retrieved same. Made bit & scraper trip to 10,091'DPM. Pooh. RU DA. RIH w/ 4" csg. guns & perf. Hemlock Bench #5 frOm 10,930'-10,980' @ 4 hpf. Ran & set Baker ModelF-1 pkr. @ ll,004'DIL. RD DA. Made up Baker 9 5/8" SAB Hyd. ret. prod. pkr. w/ 4 1/2" tbg. tail & Baker seal assy. below. RIH & stabbed into perm. pkr. @ 11,004' Tested pkr. w/ 600 psi. Dropped shear out ball & set Baker SAB pkr. @ 10,864'. Tested pkr. & released setting tool. Pooh. RU DA. Ran & set Baker ModelF-1 pkr. @ 10,370'. RD DA. RU & ran 4 1/2" prod. tbg. Stabbed into Baker ModelF-1 prod. pkr @ 10,370'DIL & tested ok. Installed BPV in tbg. hgr. Removed BOPE. Installed x-mas tree & tested to 5000 psi. RU slickline unit & opened "XO" sleeve @ 10,346' Displ. WO fluid (5%KCL-Dril-S) w/ diesel. Unloaded diesel w/ gas lift. RU WL unit. Closed "XO" sleeve @ 10,346' Gas lifted well for production test of Hemlock Bench #6 from 11,042'- 11,084' No entry from Hemlock Bench #6. Displ. tbg. w/ diesel. Press. tbg. to 1500 psi. Unable to pump into Bench #6 perfs. RU DA & RIH w/ 3 1/8" carrier gun. Diff. reperf. Hemlock Bench #6 from 11,080'-11,060'. Put well on gas lift for production test. Had limited entry. RIH w/ 3 1/8" carrier gun. Diff. reperf. Hemlock Bench #6 from 11,062'-11,042' Put well on gas lift for production test. No fluid entry. Displ. tbg. w/ diesel. Pumped 25 bbls diesel into Bench #6. Returned well to gas lift. No fluid entry. RU slickline unit & opened "XA" sleeve @ 10,968' opposite Hemlock Bench #5 perfs, from 10,882'-10,987' Gas lifted well to production test Bench #5. Stab. well w/ excessive wtr. cut & low prod. rate. RU & displ, tbg. w/ diesel thru "XA" sleeve @ 10,968' Closed "XA" sleeve opposite Bench #5 perfs, for isolation. Gas lifted diesel out of tbg. RU Dowell to acidize Hemlock Bench #6 perfs, from 11,042'-11,084'. Acidized Bench #6 w/ 1680 gat. 15%HCL. Prod. tested Bench #6 on gas lift. Had limited entry. RU Dowell & performed matrix acid job w/ 3 stages of No. P---4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'I-I'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN Dt~LICAT~ ~-API NU~EPac~L ~ODE 8 LF~ASE DESIGIklAT~ON AND $E-~RIAL NO. 1. 7 IF INDI^~, AI-,OTTEE OR TRIBE NAME 2. N~E OF OP~TOR 8. L~IT F.~{ OR LEASE NAME 3. ADDRESS OF OPhiR 9 WELL NO 4. LOCA~ON OF W~ 10 FInD ~ND P~L. OR WILDCAT 11 SEC, T., R., 1~{. (BOTTOM HOLE OB.W_,c~rvE) 12. PgP,.MIT NO 13. REPORT TOTAL DKPTH AT END OF MON'rH, CHA~NGKS IN HOLE SIZE, CASING AND C~/iE, NTING JOBS INCLUDING DEPTH SET AND VOL~ USED, PERFORATIONS. TESTS A/ND IqESULTS FISHING JOB~ JLTNK L~T HOLE AND SIDE-TRACKED HOLE A2~D A3qY OTHER SIGNIFICANT CqlAJXTGF~S IN HOL~ CONT)ITIONS. TBUS G-21 WO Continued... 2 1/2%HCL & 12-6 HCL-HF & 2 1/2%HCL. Prod. tested Bench #6 perfs, after matrix acid. Had limited entry w/ 51%wtr. cut. Set plug in tbg. tail @ 11,022' to isolate Hemlock Bench #6 perfs. Gas lifted tbg. dry & dry tested Bench #5 & #6 for isolation - ok. RU DA & perf. Hemlock Bench #4 from 10,810'-10,850', 10,755'-10,800' & from 10,730'-10,745'. Gas lifted well & production tested Bench #4. RU North Star & ran Flowing Gradient Survey. RU DA & perf. Bench #3 from 10,660'-10,690' w/ 4hpf. Production tested Benches #3 & #4. RU DA &perf. Bench #2 from 10,540'-10,590' & from 10,605'-10,635'. RD DA. Production tested Bench #2, #3 & #4. 24 hr. production test - Hemlock Benches #2, #3 & #4. GROSS CUT NET GOR TBG/CSG. GRAVITY 5830 0.1% 5824 258 180 1040 32.9° Released rig @ 12: 00 Midnite, 5/20/75 for rig move from TBUS G-21 to TBUS G-22. FINAL REPORT 14. I hereby cer'j~y t~t th~p~ore~[ng is true an~ SmN~n /~//~/~/Z~ ~ ~~~ Dist. Drl~_. Sup:. oil a~d gas conlervation commlffee bythe 15~ of the $uoc~ding mon~. unle~ otherwise directed~ Form Ho. P--4 R~'V. 3- 1-70 STATE OF ALASKA SUBMIT IN DU!?LICA'I~: OIL AND GAS CONSERVATION CONW~R-[EE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS 2.NA/~[E OF OP~:~ATOR UNION Q~,COMPANY OF CAI,TF'C)RNTA s Abn~ss or oP~roa 909 West 9thAvenue, Anchorage, Alaska 99501 4 LOCATION (:}F WELL Conductor #2, Leg Rm. #3, 1802'N & 1415'W of the SE corner. Section 29!' T9N, R13W, S. M. AP1 NU~iERICAL CODE 50-133-20267 ~ LF~ASE DESiGA1A~'ION AND SE'HIAL NO, ADL-18730 ? IF INDIA~ ALOV'T-EE O1~ 'rI~IBE NAME 8 L,~IT FAPJv~ OR LEASE NAME Trading Bay Unit 9 WELL NO Stata G-2] (21-33) 10 FLELD £~_ND POO~L, OR WIILDCAT McArthur River-Hemlock n sec, T., a. M (acm-co HO~ °mm'r~2700'S, 3830'E of surf. loc. or 925'S, 2410'E of NW corner. ,qpcfion 33: TgN: R13W: S. Ur_ 1~ PElq]VIIT NO 74-42 13. REPORT TOTAL DEPTH AT END OF MONTH. CHANGF~ IN HOLE SIZE, CASING AND CKMF-.NTING JOBS INCLI;DING DEPTH SET A/gr~ VOLLrM'E~ USED. P~ORATIONS. 'In~STS A!N-D RESULTS FISHING JOB~ JL~'K IN HOLE AND SIDE-T~.ACKED HOLE AND A2%TY OTH3~R SIGNIFICAI~T CH_kN-GF, S IN HOL~ CONDITIONS Commenced operations onTBUS G-21 @ 12:01 am, 4/19/75. Skidded rig from TBUS G-22 @ 12:01 am, 4/19/75. Skidded rig from TBUS G-22 toTBUS G-21. RU Schlumberger. Ran Production Profile w/ well stab. @ 2530'+BPD. Profile results: 1230 BOPD w/ 800 BWPD from Hemlock Bench #6 & 500 BOPD w/ no wtr. from Hemlock Bench #5. RD Schlumberger. Released rig to TBUS G-23 @ 12:00 Midnite, 4/19/75. ~( · rrect 14. I hereby d~ert~fy that the ~o~go~.g ~?~rue and ~ , [.. ~ / - ~ ~ ,' , /~1m ~. (;a. ll~~ Dist. D_r_lj~. Sup. t_. n&~, 5/6/75 oil end gas conservotion committee by the I~th of the succe4ding month, u, lest~ otherwise d. ir~cted. Form 10-403 REV. 1-10-73 Submit "Intentions" In Triplicate & "Subsequent Reports" In Duplicate STATE Oi LASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use ,'APPLICATION FOR PERMIT---" for such proposals.) 1. OIL r~ GAS r-'] WELLl.~ WELL L-.-I OTHER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL Atsurface Conductor #2, Leg Rm. #3, 1802'N & 1415'W of the SE corner. Section 29: T9N, R13W, S. M. !3..-L~-C c,~-~lr..,_ ....,~I$' (Show whether DP, , RT, GR, etc.) RT 99' above MSL. z4. Check Appropriate Box To Indicate Nature of Notice, Re - , 5. 50-133-20267 ADL-18730 7. IF INDIAN, ALLOTTEE OR TRIB~-,.,¥.~ 8. UNIT,' FAR~ OR LEASE NAME Trading Bay Unit ~. W~LL ~o. State G-Z1 (21-33) z0. F,EL~ A~D ~OOL, O~ W,LDCA~ McArthur River Field-Hemlock 11. SEC., T., R., M., ([3OTTOM HOLE OBJECTIVE) Z?001S, 3830'E o£ surf. loc. or 925'S, 2410'E of the NW corner. 12. PERMIT NO.Sec. 33: T9N, RI3W, S.M. 74-42 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT~3FF FRACTURE TREAT SHOOT OR ACIDlZE REPAIR WELL (Other) See below PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) .... (NOTE: report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE ProPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of startin9 any proposed work. *The purpose of this well work is to determine the source of water production and isolate such zones for selective production. At such time the present productive zones become prohibitively wet, this installation will allow for thru tbg. perforating of additional zones & plugging off of wet zones. PLAN OF PROCEDURE: I Skid rig over TBUS G-21, RU electric WL unit & run Production 2 Kill we 11 w/5% KCL-" Dril-S" wor kover fluid. 3. Install BPV. Remove x-mas tree. Install & test BOPE. 4. Pull 4 1/2" tbg. & accessories. 5 Mill over & retrieve permanent pkr ~ l0 403' 6. ~Z~/ 8 1/2" b~t& 9 5/8" csg. sc~pe~, CO 9 5/8" csg, to 11,110'g%D ?, Aecomplete ~ell w/ & 1/2" 8as 1i~t st~i~g & iso1~tio~ p~s, As determined P~oducdo~ 2~o[~1e. 8, ~stA11 ~V. ~emove ~O~, ~stA11 & test ~-~s t~ee. 9, ~etu~ well to p~oduct~o~. %b~u tug. pe~o~Ate as determined f~om a~d ~oduct~o~ ~ofile. Estimated start date: 5/1/75 Estimated operating time: 16.I~~G N E DI hereby certifyy~_that the///~~,~i~/~ITLE f°~eg7 Is true and correct Dist, Drlg. Supt. 10 days. DATE ~ 4./17/75 APPROVED BY _ CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form No. P---4 STATE 0;'-' ALASKA OIL AND GAS CONSERVATION COMMII-[EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMI~ I~ DUPLICAT~ OIL [~ O~.S ~ 2. NAME (DF OP~TOR UNION OIL COMP/TNT OF CALIF ~ ~DDRZSS OF' OP~,ATOa 909 West 9th Avenue, Anchorage, Alaska 4, LOCATION OF WEL~ 99501 Conductor #2, Leg Rm. #3, 1802'N & 1415'W of the SE corner. Section 29: T9N, R13W, S. M. APl I'4UMERICAL CODE 50-133-20267 I.}L~$E DES:GIqA~'ION AND SEHtAL NO ADL-18730 7 IF IN@IAI0[ AL, O; I~.E OR TRIBE 8. L,~IT FAR. A! ()il LEA.C,E NAME ~ ~v ggL-.x53-~ - . State G-21 (21-33) 10 F£ELD ~_~:r) POOL. Oil Wii.DCA3' McArthur River Field - Hemlock s~c. ~.. a .~, modem ~o~ omm-rwm2700,S, 3830'E of surf. loc. or 925'S, 2410'E of NW corn- ~ ~mm~.~-o Section 33: TgN, R13W, 74-42 S.M. 13. REPORT TOTAL DEPi'I'H AT F-~X~D OF MONTH. CHA. NGLS IN HC)LE SIZE. CAKING AND CE~{F. NT!NG JOBS INCLUDING DEPTH SET A~,'D VOLLrM-ES USED PEi:I.FORATIONS. T'E.~T.K A_N"D RESULTS FISHING JOEh~ JL'~qK L'q HOLE AND .~IDE-.'i-RACKED HOLE A~ND ANY OTHER SIGNIFICANT CHANGF. S IN HOLIg CONDITIONS Recommenced operations on TBUS G-21 @ 12:01 am, 2/27/75. Skidded rig from TBUS G-23 to TBUS G-21. RU WL unit. RIH w/ press, gradient survey. Tagged ETD @ ll,107'WLM. Pooh. Left survey tool in hole. RU Schlumberger. Ran production profile from 11,088' to 10,434'. Survey indicated all production coming from Hemlock Bench #6. Diff. reperf. Hemlock Bench #5 from 10,987'-10,958', 10,924'- 10,904' and from 10,900'-10,882' w/ 2 7/8", 14 gram chg. hyperdome guns @ 4 hpf. RD Schlumberger & returned well-to gas lift. Released rig from TBUS G-21 to TBUS G-23 @ 12:00 Midnite, 2/27/75. FINAL REPORT hereby ~ J,b/at the fory~i~r is tru~and/,orr~'~t NOTE --Report on thie fora il required for each calendar ~nth~ regordlees of fh~ e'tatus of o~erations, and muff ~.flled in duplicate wit~ the oil and ga~ conservation comml~ee b~ the I~ of t~e euec~ding ~nth, ~le~ otherwise directed, ~' ~S W(?~Flistory. £obeaddeo ~ _ - G-21's UNIOI~ OIL CCI.~P~Y uF ~"~ ,.-.;:. ~,.,-.!tA I. LLL I~LCOt® TRADING BAY UNIT STATE 1'~_~_ ~10, G-21 bi ',l~L'.l JJ PAGE FIELD McARTHUR RIVER FIELD ]]ATE ETD 47 2/27/75 11,160'TD 11, I10'ETD DETAILS OF OPERATIONS, DESCRIPTIOIlS & RESLII_TS (Footage 0') Commenced operations onTBUS G-21 @ 12:01 am, 2/27/75. Skidded rig from TBUS G-23 to TBUS G-21. RU WL unit. RIH w/ press gradient survey. Tagged ETD @ ll,107'WLM. Pooh. Left survey tool in hole. RU Schlumberger. Ran production profile from 11,088' to 10,434'. Survey indicated all production coming from Hemlock Bench #~ Diff. reperf. Hemlock Bench #5 from 10,987'-10,958', 10,924'-10,904' & from 10;900'-10,882' w/ 2 7/8", 14 gram chg. hyperdome guns @ 4hpf. RD Schlumberger & returned well to gas lift. Released rig from TBUS G-21 to TBUS G-23 @ 12:00 Midnite, 2/27/75. DATE GROSS NET CUT FM.GAS GOR TBG/CSG. 2/28/75 5528 3317 40.0 514 162 160/1120 3/1/75 5433 3260 40.0 608 187 150/1040 3/2/75 5303 3765 29.0 639 170 150/1040 FINAL REPORT ,, I,,'IA,,,- 5 i975 ¢~¥b~,3t~ Or (d, AN!) ~).s Document Trans'";ttal Union Oil Company (. Jlifornia unlen DATE SUBMITTED ACCOUNTING MONTH 2//3/75 TO Mr. [t. %.;. Kugler ~ROM State Division of C, il .-q Ga.~ R. C. 'Warthen AT 3001 Porcupine Drive AT Anchorage, AK 99504 ~nchor age TELEPHONE NO. TRANSMITTING THE FOLLOWING: Union iradin9 Bay Unit State (3-21 (21 -33) Final Loqs; . 1 2" & 5" Sepia and 1-2" ~i,- [" BL o~ ~ach: , . ~.onic . 1 5" Sepia and 1 S" ~L of e~ch: . , F~C ("~ ,. , · . ; .. t'<~ ._-' , - . ,. _. .... , F'ORM 369 (REV 2/70) PRINTED IN U.S.A. SUBMIT IN DUi ~ ..'ATE* STATE OF ALASKA (Se,,, ~herin- st ructions on reverse side ,~ OIL AND GAS CONSERVATION COMMITTEE ii i WELl cOMPLETION OR RECOMPLETION REPORT. AND LOG* la. TYPE OF WELL; OIL ~ GAS [] [~ W ELL ',¥ ELL DR ¥ Other b. TYPI~. OF COMPLETION: W E L L OV rm £ x n.~cK nESV R. Other __ 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOC^TION OF WEIr, L (Report location clearly and in accordance with any State requirements)* Atsu~face Conductor #2, Leg #3, 1802'N & 1415'W of SE corner. Section 29: T9N, R13W, S. M. At top prod. interval reported below 5.API N~CAL CODE 50-133-20267 6.LF. ASE DESIGNATION AND SERIAL NO. ADL- 18730 7.1F INDIA. N, A.LLOTTEEOR TRIBE NAiV/~ 8, UNIT,FA/LM OR LF~kSE NAME Trading Bay Unit 9. WELL NO. Stat~ G-21 (21-33) I0. FIELD A~D POOL, OR WILDCAT McArthur River-Hemlock Top Hemlock 2386'S, 3504'E of surface location or 584'S At total depth & 1989'E of NW corner. Section 33: T9N, R13W, S. M. 12. P~Ra'VIIT ixrO. 2723'S & 3626'Eof surface location or 921'S, 2211'E of NW corner. Sec. 33' TgN, .. Section 33:. TgN, RI.~W, S. M~ 11/19/74 [ 12/23/74 [ 1/3/75 ~ 99' RT toMSL ~ 59' toMSL '~. TOTAL DEPTH, ~LD & TVD~lg. PLUG, BA~CK MD & TV~0, IF 1Vi'ULT1PLE COiVLPL., I gl. ';N'TERVALS Dh'[LLZD BY ! ! H~OW 1VI~/kNY* I ROTARY TOOLS 'l CABI,E TOOLS ll,160'MD (9712'TV~)) ii,I10'MD (9668'~VD) 22. PI%ODUCING IIx/T~,tRVAL(S), OF TI-IIS COMPLETIO~T--TOiP,' BOTTOM, iNTAME (MD AND T~rD)~ 123. ~VAS I~!RECTIONAL I S U[{rVEY MADE Hemlock Bench #5: 10,882'MD (9471'TVD) to 10,987'MD (9562'TVD) Hemlock Bench #6: ll~042'MD (9609'TVD) to ll,084'MD (9646'TVD) ~ Yes 24. TYPE ELECTRIC AND OTHEI% LOGS RUN DIL, BHC-Sonic-GR, FDC-CNL Density, CBL-GR Collar. ii i -- i 25. CASING RECORD (Report all strings set in well) ,., c~s~o s~zz "' 94# H'40 ' 20. i I 822 ! / _ 9s/a,,, 26. LINE~ ~mco~ TOP (A'ID) ["~O 'm m m[ " 28. PE~OR.AT[ONS OP~ TO P~OD~C ~ (~nLerval size and number) Bench gS: 10,958~- 19,987~ 10,904~ - 10,930~ 10,882~ - 10,900~ Bench g6: 11,042~ - 11,084~ 30, Pt~ODUCTIO~ DATE FIEST PfLODUCT[ON I 12/30/74 [ Flowing HOURS ?ESTEHD [CIiOI--SE SiZE IPEOD'N FOR [ ITEST PEI~OD ~ " lC LC~T~ OI~BBL. 040 ~*S (8ot'~, used lor fuel, vented, et~'.)' 11. SEC., T., R., M., (BOTTOM HOLE °m~'CnWE~ 2700 'S & 3830'E of surface loc. or 925'S 2410'E of NB/ corner. 23" !579 sx. G 8% eel w/200 s.x.lG w/3%CaCln · O ~ O r. 17 1/2" [1150 sx G 8~ gel & 1~ C,FR-~ & 400 sx O.. I w./ 1% CFR-2. . 1 27. TUBING ~ECO[~ ~ SCi-;E~ (~D) 8IZS DEPTII SET (MD, ~ PACIiE~ SET ()JD) 4 1/2" 10~434~ 10~40}~ ACID, SiiOT, FilAC5 URE, C~,IIXT SQUEEZE, ETC. ,D~W}~[ INT~V.~ (MD) [ AMOUNC AND I'21ND OF MAaE::aAL U~ .. 2595'___ _ 1550 sx G w/ 1% CFR-2 ~ 2% CaC12 25q5' 1600 sx.G w/ 2% CaC]2 I .... '*two stiles sql. thru DC ~ 2575'. , DATE OF TEST, 1/2/75 __ FLO;V, TqgTBING pmsss. 180 Sold 32.LIST OF ATTACHMENTS PI%ODUCT1OM MEI[{OD (Fiowii*g,. gaJ lifL pumping--size and type of pump~ [\5ELL STATUS (Producing or J Producing' OI~BBL. GA~CF. WATER--BBL. [ GAS-OIL ILkTIO I 4866 I 2572 GAS--~vICF. 529 WATETL~B BL. [ OIL GRAVITY-API (COldlY.) 30.0 JTEST WITNESSED BY 33. I hereby cer~fv-lhat the foregoing It.d attached information Is complete and correct as determi~l~ l[ro~[~al~va,rl.i~bl~ records *(See Instructions and Spaces [or Additional Data on Reverse SideJ .... : ' '" INSTRUCTIONS General: This form is designed for submitting a complete and correct wetl completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and ir) any ett~chments. Items :20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcducing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (parje) on this form, adequately identified, for each additional interval to be seperately prodUce, J, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ,, , 34. SUMMARY O~' FORMATION TF_.STS INCLUDIN(; INTERVAL TF, STED. PR]g~URIg DATA. A_N'D ~a.,1BCbVERIES OF OIL, GAS. 35. G 1DOI-,OG I C M AIR KI~t~ WATF__~ AND MUD __ AND D~'PgCTgl.) SIIOWS O~ OlM, .... . .... . . . ................ ,. ,,,~e,,~'! t,~,',})]N(., t:,AS, UNI:I olA,i,i/Ei,LNO. G-~] .[./--)CAT!(~iN Cc::;~.duclo~' II-2, Leg Itm, I~3. 74-42 SERI2M~ NO. ADL-]8730 "~..v.~. 97] ~' I~I~(.; I: bio ........... L · ......... . } lo SPUD DATE_ ] 1/19/74 COMP. I)A'I']'] ....... t_ ?. .<. _ - .-: "',, ........ i' ~';~' ..... "~"y U'~x>l:-~'-}~i~'l<~:v ltI(; i<(). -'"~ 7'YPZ UNIT ? ,lir,n~! 1';2(t ~'" .......... 5~__: ' -'- .... 2 . .. ~ - "': ': -' iL T. TO O" ..... " R.T. TO }, I LJ.~V ] ] 0.60 ' tl. T. TO D!'[[I,L I)I:X]K '~"'. CASING & TUBI:,G tlECO:D ":/:<-~:)"' .... ----l]./2" ?,/all Thicknes'~ 3fi6' ~_Predr5~:Iol 356~ .....'" :: "~3 '~~:l '~ 68-/,, uttress ,: - / I --:" :~ ::uttress ~-55 5201' / Refer to.. 11/30/74 _?_5~_147:_&!00 Bu. ttre~s 'bl~$-95 * 11,160' Rof~~/7.4.Fc,: dnjly dc:ta~. *P-i 10 e~9 ..... _. ].2.60 But, tress N-S0 1-0,434~_ ~ defai] , PERFOIIATING RECORD '31/7Z ,..]_~:..: 0~2-].1,063 _ 11., 110' .... Producti_on Op _n_e_~e~ch ~6 ./75 10,958-].0~987 11 .1'10_' ... P'rnduc+~nn Ope~_ Bench ~5 .......... f75 10,904-10~0 !l,]J0' __~roduction: _ O~ Bench ~ . ~:75 ]] 042-]1,D84 11 l'lO[ Prnd~f~nn ()aEon goneh i& ., ............. ........ . , '! 2/3 2/2: _17_1 IIFi'EF-,VAL Hemlock Hemlock Hemlock DATE 1/ ~/3/'75 il r'~,: Carneron~ INITIAL Pi ~,ODIICTIO~'i NET O~L! CUT ]' Oi~.,XV.I t040 _ ~:-!-~-~-! 30.0!11}070. ~337 ~ ..... ~ . 1050 180 200 ]90 __ ~li L_L_ H g A D_ &$ ~g 14 F_,I "WF" 12" 3000# WP X 13 3/8'"OD slip-on Weld btm. w/ two-2'' 5000# CASING HEAD: WP'flgd. outlets. CASING HANGER: Slip & seal assy. CA 12" X'9 5/8"OD. CASING SPOOL: 12" 3000#__ TUBING HEAD:__ TUBING !tANGER: 'FI1 r> T ~--:-~NG tIEA,~ TOP' DC-B 12" 3000# WP X 10"' 5000'# Wp wi two22'' 500~0__~5,,~2P_~[~~, ' DG-FBB 4 1/2'U)D top w/ "H" BPV. Thd. alloy_ stee! X 10" 5000# WP VALVES: 4 1/8" sxvab valve type F. TOP eX>N',.'I '., .DiSTi%IBUTO?. Ui',! !ON i Vi.c,C©%IT¥ t VIf, C©S;YY, i (P2~) ~ ~ ~ [ ~_ (lb/1O~t2) 0/!0 r'Z~' pH I APl I, F 1LT P~ 2,,T ~" (mil30 mir;) ¢. itt t7 ,, MUD t4 , , it. 1 i.;,? ~o oF · ,DISTRIBUTOR >A,~..-: ,'<. ~,~t'? I Y~ELO I GEL.~ (lb/IO~,t2)t 0110 671 /4, ~zz t~ .~c, .~--~,,. ~ t ,~.? 7t UNION OIL CO. OF CALIFORNIA ~ MUD RECORD t,?u'D TYPE FILTRATE {ml/3 0 rain) jilT-PiP OF PAGE NO._ VoL) M e',hy, j bbl I ~ I zo . - .1D!STRIBUTOZ UNION OIL CO. OF' CALIi--ORNIA MUD RECORD FAGE NO. ~>-- YIELD I GELI~ I 'i ' FILTRATE .._x. d 1 ;'/x; t.t,;t ,,/; (., 1 gl ZC --t- i t t t I VaL) C..-51 ) (5;::.) (: ::l bbI t ' --I I // tz ' j // // - ., ~":'1 ":: z.,-:lx,/,'/I,?:;,;J ----' t::_~?', t.,: t/?/'? ,~ ~. , -'-"' ', ' ': ...~ " ' ~ .'. I.~ :,.; ~ t '_: : :-.-; t/~ ~'~' ~,-,'-: l ,. ~- !/¢..~ !/:.. )4.',/ I .:,;¢ x .... ,. . . ,,,:,.x i//7 l:,d !.:-::-? t --,-"--'--' ~/-, .. , ,_ . .... .'~ u · '~, //.ct/t,, t 1:-:.'.~:~..:)'t -- · . 12.Tsz.-,..I .: 7 t /~' .d /~' ~ ', ".~ t - t '~-.,,x: l'" ' :' 7 2 ~1'- 't ":;J ri .,-,..,.,t uo ~ '-"~/~' //5t z2'4~ :,f ' -i ,"' "i "'"'t n:? !' " ._ t /I // , / cL J t/ // - !" i /, /1 ~ i // /, i ,,? // i I OIL CO1~4 PANY Tool PUSHE~ BIT RECORD DR DR COUNTY STATE FLD./TOWN · SEC/T'SHIP/ RANGE CODE OF giT CONDITION DEGREE OF TOOTH D!JLLNESS NEW Il 12 TS 14 TS T6 T7 TS HOV/ TO ;~EPORT BIT ~VEA~ i?~ EIGHTHS TOOTH DULLNESS (genera! ex~::-.inatlon) T! T2 T3 T4 T5 T6 TT., TS .. tooih height I/8 gone too:¼ height 1/4 gone too~.h height 3/8 gone :oath height 1/2 gone tooth heigh! 5/8 gone tooth he[ght 3/4 gone ~,oot!'. height 7/8 9one to,~fi-. !~eigh! alt gone NOTE: ~f any one ;c,.,,~ has a maiorlty of teeth bra~er., add the letters "BT" BEARING CC NDITION {ch~ck t!=c~ worst con~) B1 . . ,, bearl,-g life used: 1/8 B2 ... ~ecr]~g life u~ed: 1/4 ~3 ... beer~g life used: 3/8' B4 ... b~g~;=g llfe u:ed: 1/2 B5 . . . bea,:,~g life used: 5/8 B5 . . . baa:~ng llfe u~ed: ~/4 $7 . . . bear;nC J~fe used: 7/8 B3 . . . beo~:~g, llfe oil gone (iod-cJ or lost) ~}T GAGE ~... ~n gage 0 ... out of gage ~NOTE: ~ out of gc;;~, fallow the "O" whh Ike amount o.~ of gage in frae- ~xorn~e ~1 . ~ . T2-B4-1 (Teeth 1/4 gon~, ~eor;ng re,z-J;..-n, bb [n gage) Ex~m?e (2 . . . TLLT.B6-0 1/2 (Teeth 3/4 2c:-,:, broLen ! :.th, beefing !ease a MODEL No. ,ruMP MAKE ~ MODEL/ ~AKE ~ ~ODEL RUN SIZ~ ~AKE NO. /d.-/i oo' 'JETS.32ND BIT SER. NO. DEPTH OUT SHEET ~,~ RECORD NO. NO. SPUD D^Td/'t¢' ~','--SUR~.- ~ U~DER /Z--6'" 79 ,~:ER J"~ O / i FOOT. j HOURS AGE ///~ 0 //7 77?0 ..4'o JOINTS: MAKE DRILL COLLARS: NO. ¢ ..O.D. DRILL COLLARS: NO. O.D.-- NO. I ,V, UD DULL' COND. LENGTH REMARKS (FAILURE. ~:Jg. ETC.) ¢. BlT R~e, No. RECORD DR DR COUNTY FLD./TOWN · SEC./T'SHIP/ RANGE SHEET / RECORD NO., NO. - / UNDER ,NTER. ll f ~ 0 & MODEL 13~0. Moo MAKE & HODEL-$-~/ ' RUN SIZE MAKE 'JETS.32ND BIT DEPTH NO. SER, NO. OUT CODE OF giT"~,ONDitl g c'"'- R E ~- ,-, OF TOOin DULLNESS 4.~ .., ~ NEW T1 T2 T3 T4 T5 T6 T7 T~ HOV/ TO ~iT ~,/EAR i~"': EIGHTHS TOOTH DULLNESS T1 . . tcatk '-~eight 1/8 gone T2 . tooth height 1/4 gone T3 ~oot~ height 3/8 gone T4 toot';% ~e~g~ ]/2 gone '/5 ~ooth :":eight 5/8 gone T6 :oofi~ }~eight 3,"4 gone T7 tooth ','~e~g~t 7/8 gone T8 loath he;ght cji gone NOTE: If any one rc'~' has a majority of te~th broken, odd ~"te letters "BT" 5EARING CC ~:DtTION (ch,ak tFe worst cane) Bi . .. beg:;:~g tlfe used: 1/8 B2 . . . beari~g llfe used: 1/4 (t~gkt) B3 . . . bea:ng.llfe used: 3/8 bearing life used: 1/2 (met:urn) B5 . . . bearing llfe used: 5/8 B6 . . , bea~:'~g life used: 3/4 B7 . . . ~)earT:g llfe used: 7/8 B8... bear]rg life all gone ~acke~ or lost) ~,,nr~ GAGE J.., ~n gage 0 ... OUt of gage [NOTE: ',~ out ~ DaDo, Ia!low ~e "O" '~;th :he cmcun~ out ~ gage t~ons of cn ~xam~ ~1 ... T2-~4-1 (Teeth 1/4 9c .... bec r?ns medlar-,, blt ~n gage) ~<ern;:e '? . . . TfLT-B6-0 ~,'2 (Teeth 3/4 gcr,~, brc~e~ t:;:~'~, bear;r.g loose 31oA T. D,-- DRILL COLLARS: NO. O.D I.D..... LENGTH,,, WT. VERT. PUMP NO. ! NO. 2 MUD DULL coso. j RE 1ooo RPM DEV. PRESS. ~J { FAILL'R LB, SPM LIN SPM LIN. WT. i ~jIIs.I TIBJG . ~ * ~s~o 33' ' '7/, ~ 'l~ljo ~ ,:::~._,~__ ,>~i_t.2~:7~ ....... ~, ~ : : ......... MARKS · NUD. ETC.) o UNIO[I OIL CCt'iPANY OF CALIFORNIA l','L[i. I ' LCOI(IJ );ATE A 11/].2/74 B 11/13/74 C 11/14/74 -D 11/15/74 E 11/].6/74 F 11/].7/74 G 11/18/74 1 11/19/74 2 11/20/74 3 11/21/74 4 11/22/74 5 11/23/74 6 11/24/74 E '1 'D 840'TD 840'TD l128"TD 2005'TD 2397'TD 2699'TD DETAILS OF OPERATIONS, DESCRIPTIO[IS & RESUI_TS Plat.orm @ 12 01 am, Commenced Activating Rig #54, Grayling f · 11/12/74. Skidded Rig #54 from Leg Rm. #2 to I, eg Rm. #3 & rigged up over Conductor #2. Ran 17 1/2" bit to clean out 26" Drive Pipe. Drlg. cmt. from 337' to btm. of 26" Drive Pipe @ 356'. Ran 24" mill & stab.-unab]e to get below 182'. Laid dwn. stab. & turned dwn. mill to 23". Dressed & milled out Drive Pipe to btm. @ 356'. Built-up mill to 24". Milled out Drive Pipe to 356'. Pooh. Mill worn to 23 1/2". Ran 24" fixed blade hole opener-unab!c to get below 182' Pooh w/ 24" fixed blade hole opener. Laid dwn. 24" stab. & reran 24" hole opener. Unable to get below 182' Sent hole opener & stab. to machine shop to be turned dwn. to 23" OD. Ran 23" OD mill & stab. Dressed out 26" Drive Pipe to shoe @ 356'. Ran 23" OD fixed blade hole opener & 23" OD stab. to Drive Pipe shoe @ 356'-ok. Took survey @ shoe-356' 1/2° Pooh w/ 23" hole opener & 23" stab. (Footage 840') Ran 17 1/2" bit & spudded TBUS G-21 @ 3' 30 am, 11/19/74. Drlg. 17 1/2" hole to 840' Pooh. Ran 17 1/2" bit & 23" HO in tandem. Opened 17 1/2" hole to 23" to 730'. (Footage 0') Completed. opening 17 1/2" hole to 23" to TD @ 840'. Circ. out sand & cond. mud. Pooh & laid. dwn. BHA. RU & ran 20" 94# H-40 Butt. Csg. to 822'. Landed 20" csg. on CIW Flo-thru Hgt. Ran 5" DP & stab'bed into float collar @ 784'. Circ. hole clean. Mixed 579 sx. Class "©" cmt. w/ 8% gel pre]~yc]ratec] in mixing wtr. Slurry wt. 98Jt/cu. ft. Got cmt. returns to surface. Mixed 200 sx. Class "G" w/ 3% CaC12 in mixing H20. Slurry wt. llS#/cu, ft. Displ. DP & Pooh. CIP @ 7:00 pm. Released & laid dwn. 26" riser. . . (Footage 288') Installed 20" Hydril & 20" Riser System. Tested to 500 psi-ok. Ran 17 1/2" bit toFC @784' Tested 20" csg. to 500 psi-ok. Drlg. FC plus 15' of cmt. Retested 20" csg. to 500 psi-ok. Drlg. out cmt. & guide shoe @ 822'. Drlg. to 890'. Pooh. Picked up 17 1/2" stab. TIH w/ 17 1/2" ~it. Drlg. to ].128'. (Footage 877') Drlg. 17 1/2" hole 1128' to KOP @2001' Pooh. Ran 17 1/2" bit on DD #1. Oriented DD @2001' & drilled to 2005' (Footage 392') DD 17 1/2" hole 2005'-2397'. Hole angle & direction ok Pooh w/ DD #1. (Footage 302') Ran 17 1/2" angle building BHA #6.Dr]g. 2397' 2488'. Ran survey, (hole had turned 24° left). Pooh. Ran 17 1/2" bit on DD #2. Oriented DD @ 2488' & drilled to 2667'. Ran survey (hole direction & angle ok-18° left hand lead.). Pooh w/ DD. Ran ].7 1/2" angle building BHA #7. Drilled 17 1/2" tmle to 2699' UIilOl'l OIL Cffi[W IY OF CALIFOIINIA ) r · '] I,LLL f'AGU th, L¥~,TE Eli] DETAILS OF 0PEPATIONS, DESCRIP-FIOrlS & R'ESLII_TS 7 11/25/74 8 ].1/26/74 9 11/27/74 10 11/28/74 11 11/29/74 12 11/30/74 13 12/1/74 14 12/2/74 3324'TD 396!'TD 4645'TD 5170'TD 5205'TD 5205'TD 5205'TD 5205'TD (Footage 625') Drilled 17 1/2" hole 2699'-3102' Ran survey (hole angle not building as required). Pooh. Ran ]7 1/2" angle building BHA #8. Drilled 3102'-3324'. Ran survey (hole angle built 5 1/2° / 100'). pooh. Ran 17 1/2" locked BHA #9. (Footage 637') Ran 17 1/2" locked assy. & reamed out dogleg from 3102'-3324'. Drilled 17 1/2" hole w/ ]OM to break angle build- ing arc. Ran survey @ 3537' (34° S74E) hole angle & direction locked in ok. Drilled 17 1/2" hole to 3961' (Dropped angle slightly-3911' 32 3/4° S72E). (Footage 684') Directionally drilled 17 1/2" ho].e from 3961' to 4645' w/ packed hole assy. Hole angle & direction holding ok. (Footage 525') Directionally drilled 17 1/2" hole from 4645' to 5170' . (Footage 35') Directionally drilled 17 1/2" hole from 5170' to 5202' Hole angle & direction ok. Made cond. trip. Rigged up & ran 61# & 68# K-55 Buttress Csg. & landed on CIW flow thru csg. hgt. w/ csg. shoe @ 5201'. Circ. hole clean. (Footage 0') Cmt'd btm. stage w/ 1150 sx. Class "G" cm'[. w/ 8% pre-hydrated gel followed by 400 sx. Class "G-" Neat. Bumped plug on Baffle Plate @ 5071' w/ 2500 psi-ok. Float equip, failed to hold. Repressured 13 3/8" csg. to 2500 psi & held press, on cmt. for 8 hrs. Released press. Cmt. slayed in place ok. Opened DV tool ports @ 2595'-unable to circ. Pumped into formation w/ 750 psi-held 650 psi w/ pumps off. (Footage 0') 'Watched well for flow on annulus & 13 3/8" csg. No flow 6 hrs. Rernoved 20" hydril & 20" riser. Installed 12" 900 series BOPE& tested to UOCO specs. Rigged up Schlumberger & ran CBL-VDL. Had indication of good bonding to 1900' & partial bond to 1300'. Log indicated gas bubble migrating up ].3 3/8" csg. TIH w/ 12 1/4" bit. Gas bubble reached surface w/ bit @ 554'. SI well w/ 450 psi on csg. & DP. Have some gas migration on 13 3/8"-20" annulus. Stripped DP in hole to 2328'. Press. incr. slightly on csg. Circ. out gas cut mud & leveled,wt, off to 72# @ 2328' . (Footage 0') Circ. & cond. gas cut mud @ 2328'. SI well w/ 150 psi on DP & csg. Stripped DP in hole to 2554' (DV too] @ 2595') Circ. btm, s. up @ 2554'. SI @ 135 psi on DP & csg, Inc. mud wt. from 72#/cu. ft. ~o 81~/cu. ft. SI w/zero psi on DP & csg. Opened hydril & cond. mud. Pooh w/ 1.2 ]/4" bit. Ran 13 3/8" sqz. tool & set @ 2434:'. Tested 1.3 3/8" csg. Nv/ ]500 psi to surface, 15 mins.-ok. PI form. thru DV too] C~ 2595' w/ 15 cu., ft,/min. @ 400 psi. Mixed 550 s;x. Class "G" cmt. w/ 1% D-31 & 2% CaC]2 in mix_ins wtr. to l.]7#/cu, ft. slue'ry. Di,'~])]. 550 sx. thru DV to a final press, of 750 psi. C]P o~ block sqz. @ 10:30 pm. Press. bled to 450 psi in ]. ]./2 hrs. UNION OiL C(lqI ANY OF CALIFOIIIiIA BAY 1 DATE ETD DETAILS OF OPEF~TIONS, I)ESCRII)TIOI''~ ].5 12/.5/74 16 12/4/74 17 ]_2/5/74 12/6/74 19 12/7/74 20 12/8/74 21 12/9/74 .22 12/].0/74 23 12/11/7,1 5205'TD 5205'TD 5575'TD 6353'TD 6812'TD 7220'TD 7692'TD 8060'TD ,' 8535'TD (Footage 0') 6 hrs. WOC. 4:30 am. Sqz. press, had bled to 50 psi. Press. up on sqz. to 450 psi & PI. Press. bled to 50 psi. Rigged up for stage #2 sqz. #1 thru DV tool @ 2595'. PI 15 cfm @ 800 psi_. Mixed & pumped 600 sx. Class "G" cmt. w/ 2% CaC12 in mixing wtr. to 120#/cu. ft. slurry wt. Displ. 600 sx. cmt. thru DV tool ports to a final press, of 800 psi. CIP @ 9:35 am. 6 hrs. WOC. Sqz. press, bled to 200 'psi & held. Pooh w/ sqz. tool. Ran 12 1/4" bit. Tested sqz. w/ 1000 psi. Closed ports in DV tool. Tested DV tool & 13 3/8" csg. above tool to 2000 psi-ok. Dri].led out plug bomb in DV tool & retested 13 3/8" csg. below tool. Failed to test. TIH w/ 12 1/4" bit. Tagged top of cmt. @ 5020'. (51' above shut-off plug). Drilled out cmt. & float 'equip. to 5081' (Footage 0') Circ. & cond. cmt. contaminated mud @ 5081' Drlg. float collar @ 5114' & cmt. to 5178". Circ. & cond. mud. Tied in- to 13 3/8"-20" annulus. Unable to pump in w/ 800 psi. Held 800 psi 30 mins.-ok. Pooh w/ 12 1/4" bit. Ran 13 3/8" sqz. tool on 5" DP. Closed sleeve in DV tool @ 2595' Set sqz. tool below DV tool and tested 13 3/8" csg. above & below sqz. tool w/ 2000 psi- ok. Pooh. Rigged up Schlumberger & ran CBL-VD .log from 5152'-100'. Had good bonding to 1500', partial bonding from 1500'-800' and possible cmt. bond from 450'-250'. Rigged dwn. Schlumberger. (Footage 370') Completed i~stalling surface mud system, choke & kill lines. %['ested to UOCO specs. Picked up 112 ]_/4" bit & 12 1/4" square building assy. Drilled out 13 3/8" shoe @ 5201' & 10' of new hole. Tested 13 3/8" csg. seat & fro. equiv, to .650 psi/ft, gradient-ok. Drilled to 5420'. Washed out jet in b.it. Trip for bit change. Drilled from 5420'-5575' Hole a~gle & direction 'as desired. Pooh. Picked. up 12 1/4" square locked assy. (Footage 778') Drlg. tripped & surveyed 12 1/4" hole from 5575' to 6353' . (Footage 459') Drlg. tripped & surveyed 12 1/4" hole from 6353' to 6812'. (Footage 408') Drlg. tripped & surveyed 12 1/4" hole from 6812' to 7220'. (Footage 472') Drlg. tripped & surveyed 12 1/4" hole frorn 7220' to 7692'. (4 hrs." dwn.-repairs to drawworks). (Footage 368') Drilled, tripped & surveyed 7692'-8060'. cond. good. (Footage 475') Drill.ed, tripped & surveyed 8060-8535'. cond. good. -- - UNI0tl 0IL CG'qPAI,h' 0F UNL. II'-'0ItrlIA W1:![.L I',LC0i® .f;ASE 'FTR A i')I'Nd: ?~,A Y 1.. 'r'l',,] F-F ST'ATF; DATE 24 ]2/12/74 25 12/13/74 26 12/14/74 _27 12/15/74 28 12/16/74 29 !2/17/74 30 12/18/74 31 12/19/74 32 12/20/74 33 12/21/74 34 12/22/74 35 12/23/74 ETD 8787'TD 9036'TD 9352'TD ' 9535'TD 9793'TD 10,170'TD 10,370'TD 10,639'TD 10,856'TD 11,105 'TD 11,105'TD 11,160'TD DETAILS OF OPEICTIONS, DESCRIPTIOIIS g RESUI_TS ,, (Footage 252') Drilled, tripped & surveyed 8535'-8787'. H'ole cond. good. (Footage 249') Drilled, tripped & surveyed 8787'-9036' cond. good. Hole (Footage 316') Drilled, tripped & surveyed 9036'-9352' cond. good. Hole (Footage 183') Drilled, tripped & surveyed 9352'-9535'. Hole cond. good. (Footage 258') Completed TIH w/ bit #25 on BHA #]-9. Reamed 60' to btm. from 9475'-9535'. Drlg. 12 1/4" hole from 9535'-9740' Dropped survey. Pooh for bit #26on BttA #18. Reamed 60' to btm. from 9680'-9740'. Drlg. 12 1/4" hole from 9740'--9793'. (Footage 377') Drlg. tripped & surveyed 9793'-10,170'. (Footage 200') Drlg. 12 1/4" hole w/ bit #26 & BI-IA #18 £rom 10,170'-10,337'. Dropped survey. Pooh. Tight hole @ 10,090' & 9965'.. RIH w/ insert type (5-1-5) bit #27 on BttA #20. Reamed & washed 11.9' from '10,218'-10,337'. Drlg. 12 1/4" hole to 1_0,370'/ Est. 119' of fill on btm. after trip-could be hole out of guage. Bit out 1/8" guage. (determined to be out of guage hole rather than fill). (Footage 269') Drlg..12 1/4" hole w/ bit #27 on BHA ~20 from 10,370'-10,639'. · . (Footage 21~7') Drlg. 12 1/4" hole from 10,639'-10,805' Surveyed & Pooh for bit change (measured out of hole). RIH w/ insert type (5-1-5) bit #28. Washed 90' to bmr.. as a precautionary measure. Drlg. 12 1/4" hole from 10,805'-10,856' (Footage 249') Drlg. 12 1/4" hole from 10,856'-11,105'. Circ. hole Clean & survey. Pooh. (Footage 0') Completed Pooh. Rigged up Schlumberger & ran DIL Log. Stopped @ 10,260'. Pooh & ran Sonic w/ 18" hole finder. Stopped @ 10,260'. (DP rubber lost in hole-suspect formed bridging mechanism). Pooh. Rigged dwn. Schlumberger. Picked up 12 1/4" BHA & RIH to bridge @ 10,260'. Reamed bridge @ 10,260' & ].0,290' Washed & reamed to TD @ 11,105'. Circ. hole clean. Pooh to log. Rigged u.p Schlumberger. Ran DIL. Checked btm. @ ll,102'(WLM). Logged w~ ].)IL from 11,096'-5192'. R~an BHC-Sonic-CR Caliper l.,og from 1],096' to 7000' . (Footage 55') Ran BttC-Sonic--GR Log & FDC--CNL Density ]bog as required, l{igged dwn. Sct',.]umberger. ]:{i:t~ 12 ]/4" ~nill bit to TD 0 11,105'. Deepened hole to fi'nM ~]'D 0 trip-hole cond. good. Circ. & cc)nc], in,id ~o run 9 5/8" UNION OIL CC tPANY d: CALIf:OIINIA DATE 36 12/24/74 37 12/25/74 38 12/26/74 39 12/27/74 4© 12/28/74 41 12/29/74 42 12/30/74 ETD · 11,160'TD 11,160'TD 11,160'TD 11,160'TD 11, I10'ET] FC 11,160'TD 1], I10'ET] FO 11,160iTD 11, ll0'ET] FC 11,160'TD 11, ll0'ET[ FC DETAILS OF' OPERATIONS, DEoCkI, l tOIlo 8 t \L~,.~ _ I~lO (Footage 0') Circ. & C0nd. hole to run 9 5/8" 47# & 40# csg. Pooh. Rigged up to run 9 5/8" csg..Ran float shoe, 1 jr. 9 5/8" csg., float collar & 269 its. 9 5/8" 47# & 40# cs~. Circ. 2 1/2 hrs. Mixed'& pumped 200 cu. ft. caustic wtr. behind wiper plug. Mixed & pumped 100 cu. ft. BJ mud sweep. " Mixed & pumped 1000 sx. Class "G" neat cmt. w/ .75% .])-31, .5%D-19, 0.1%R-5 & 0.1%D-6 in mix wtr. Mixed & pumped 1000 sx. Class "G" cmt. w/ .75%D-31, .5%D' 19, .01%R-5 & .01%D-6 in cmt.- mix. Ail cmt. mixed w/ filtered Inlet wtr. Dropped plug ahead of cmt. in mixing tub & lines. Pumped plug dwn w/ rig pump (41]0 strokes). CIP @ 9:10 pm w/ csg. SI & hydril closed. Shut dwn..rig for x-mas. Completed shut dwn. operations @ 10:15 pm. (Bumped plug w/ 2500 psi). (Footage 0') Shut dwn. 24 hrs. for Christmas & engine overhaul. (Footage 0') Shut dwn. 24 hrs..for Christmas & engine overhaul. (Footage 0') Reactivated rig @ 12:01 am, 12/27/74. Removed BOPE. Hung off 9 5/8" csg. Installed 12" 3M X 10" 5M tbg. head & tested-ok. Installed 12" 3M BOPE & tested to UOCO specs. Ran 8 1/2" bit & 9 5/8" csg. scraper. CO to ETD @ ]1,]]0'. ~ Circ. & displ, drilling mud w/ Filtered Inlet wtr. (Footage 0') Pooh. RU WL unit & ran CBL-VDL-GR Log frora ETD to 8500'. Ran Sperry-Sun Gyro Survey on WL. Ra]~ guage ring & junk basket to 10,500' (Footage 0') Ran Baker Model F-1 WL prod. pkr. 9 5/8" X 6" bore & set @ 10,388'WLM. RD WL unit. RU & ran 4 1/2" 12.6# N-80 Buttress prod. tbg. Set in WL pkr. @ ].0,388'WLM (10,403'Tbg. Measurement) & tested pkr. w/ 2000 psi-ok. Spaced out & landed tbg. w/ tbg. tail @ 10,419'WLM (10,434'Tbg. Measure- ment) . (Footage 0') Displ. tbg. & annulus w/ diesel. Landed 4 1/2" tbg. string w/ locator sub 2' above top of WL prod. pkr. @ 10,388' Tested pkr.-ok. Removed BOPE & installed & tested x-mas tree. RU DA unit &perf. 21' of Hemlock Bench #6 from 1],063'-11,084' 'using 3 1/8" OD Jumbo Jetw/ 120° phasing - 3 hpf. Clean up well on 64/64" choke. Unloaded wtr. on gas lift. Shut dwn. gas lift. Stab. well on natural flow. Test Rate: '. B/D CUT FM. GAS GOR GLR TP CP 2640 0.8% 658 25]. 249 120 980 OiL CIY'd'W,IY OF CAI_IFOIlr,IIA IILL liCOtdJ ILl,RTE ETD DETAII_S OF 0PEI¥~TIONS, I)[iSCRIPTIO[IS 43 12/31/74 44 1/1/75 45 i/2/75 46 1/3/75 11,160'TD 11, ]10'ET] FC 11,160'TD 11, ll0'ETi FC 11,160'TD 11, i10'ET: FC 11,160'TD (Footage 0') Completed 'perf. Hemlock Bench #6 from 11,042'-1].,063' (Total interval 11,042'-11,084'). Production tested Bench #6 on natural flow. Average Test - 6 hrs. B/D CUT FM .GAS GOR GLR TP CP CHOKE 2952 1.3% 667 229 226 200 1000 64/64 (Footage 0') RU slicklinkunit & ran flowing press, gradient survey. Bottom hole flowing press=2960 psi. 12 hrs. SI BHP=3893 psi.. RD slickline unit. RU DA & perf. Hemlock Bench #5 using 3 1/8" OD Jumbo Jet w/ 120° phasing - 3 hpf as follows: 10,958'- 10,987' 10,904'- 10,930' 10,882'- 10,900' (29') (26') (18') TOTAL (73') Production tested Bench ~5 & #6 on natural flow: B/D CUT FM. GAS GOR GLR TP CP 3936 i8% 813 252 207 100 1000 CHOKE 209/64 Started gas lifting well @8:00 pm, 1/1/75. Production test: B/D CUT FM .GAS GOR GLR TP CP CHOKE 6240 16.7% 2219 450. 790 180 1040 209/64 (Footage 0') 24 hr. production testing of Hemlock Benches #5 & #6. Reperf. Hemlock Bench #6 from 11,042'-11,084' & prod. rate inc. -~600 B/D. Well not stabilized. Prod. rate now varying from 6400 B/D dwn. to 54'00 B/D & cut varying from 6 to. 24%. Average Test: B/D CUT FM . GAS GOR GLR TP CP CHOKE 6120 20.5% 2572 529 887 180 1040 209/64 (Footage 0') 24 hr. prod. testing well. Prep. to skid rig to Conductor #10 & RU to drill TBUS G-23. 24 hr. prod. test:, B/D CUT NET FM . GAS GOR GLR GRAV . TP 5497 20% 4398 2563 583 881 30.0 2000 CP CHOKE 1070 209/64 Completed operations (9 12:00 Midr~ite, ]/3/75. FINAI~ REI~OR'f UNION 0IL CCPANY 0F LI[:0I!IIIA I'LLI_ t,[L{. 14 ETD 3TS. 12 11 11 12 11 12 11. 12 12 11 2O 28 4O 47 54 328 Jts, DETAILS OF OPEPATIONS, DESCRIPTIO}IS I d2,9 UI_/O TUBING DETAIL DESCRIPTION LENGTH BOTTOM TOP Mule Shoe ID 4" OD 4.938" Otis "N" Nipple ID 3.725" OD 4.9" 4 1/2" 12.60# N-80 Buttress Pup Jr. Baker SealAssy. ID 4" OD 6" Baker Locator Sub ID 4" OD 6.5" 4 1/2" 12.60# N-80 Buttress Tbg. Otis "XA" Sleeve ID 3.812 4 1/2" 12 60#N-80 Buttress Tbg. Camco 4 1/2" Camco 4 1/2" Can2co 4 1/2" Camco 4 1/2" Camco 4 1/2" Camco 4 1/2" Camco 4 1/2" Camco 4 1/2" Camco 4 1/2" Camco 4 1/2" Camco 4 1/22' Camco 4 1/2" Camco 4 1/2" Camco 4 1/2" Camco 4 1/2" Camco 4 1/2" Camco 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2" 12 60# 4 1/2"' 12 6O# 4 1/2" 12 60# 4 1/2" MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG N-80 MMG Gas Lift Valve #17 Buttress Tbg. Gas Lift Valve #16 Buttress Tbg Gas Lift Valve #15 Buttress Tbg Gas Lift Valve #14 Buttress Tbg Gas Lift Valve #13 Buttress Tbg Gas Lift Valve #12 Buttress Tbg Gas Lift Valve #11 Buttress Tbg Gas Lift Valve #10 Buttress Tbg Gas Lift Valve #9 Buttress Tbg Gas Lift Valve #8 Buttress Tbg Gas Lift Valve #7 Buttress Tbg. Gas Lift Valve #6 Buttress Tbg Gas Lift Valve #5 Buttress Tbg Gas Lift Valve #4 Buttress Tbg Gas Lift Valve #3 Buttress Tbg Gas Lift Valve #2 Buttress Tbg Gas Lift Valve #1 4 1/2" 12 60#N-80 Buttress Tbg Otis 4 1/2" Ball Valve 4 ]./2" 12 60#N-80 Buttress Tbg 4 1/2" 12.60# N-80 4 1/2" 12.60#N-80 4 1/2" 12.60# N-80 Cameron Tbg. Hgr Buttress Pup Jr. Buttress Pup ,'ft. Buttress Pup Jr. · 4 1/2" Buttress btm. 4 1/2" EUE top Elevation Rotary Table to tbg. head 1.65 1.30 9.98 19.63 .91 28.56 5.43 30.49 8 53 156.27 8 53 374.45 8 53 28O .49 8 53 341.44 8 53 341 55 8 53 370 63 8 53 342 11 8 53 371 25 8 53 34] 16 8 53 370 01 8 53 371 ] 6 8 53 342 35 8 53 622 10 8 53 871 72 8 53 1,242.16 8 53 1,463.18 8 53 1,680.55 3 10 252.2]. 5]O 4.97 4.10 1,00 38,46 ]0,434 48 .10,432 83 10,431 53 10,421 55 ]0,401 92 10,401 01 10,372 45 10,367 02 10,336 53 10,328 00 10,17]_ 73 10,163 20 9,788 75 9,780 22 9,499 73 9,491 2O 9,149 76 9,141 23 8,799 69 8,791 15 8,420 52. 8,4.11 99 8,069 88 8,061 35 7,690 lO 7,681 57 7,340 41 7,331_ 88 6,961 87 6,953 34 6,582 ].8 6,573 65 6,231 30 6,222 77 5,600 67 5,5192 14 4,720 42 4,711 89 3,469 73 3,461. 20 1,998 O2 1,989 49 308 94 305 84 53.63 48.53 43.56 39.46 38.4.6 TOTAL JTS. 10,432 10,431 10,421 10,401 ]0,401 ,10,372 10,367 10,336 10,328 10,171 10,163 9,788 9,780 9,499 9,491 9,149 9,1_41 8,799 8,791 8,420 8,411 8,069 8,06.1 7,690 7,681 7,340 7,331 6,961 6,953 6,582 6,S73 6,231 6,222 5,6OO 5,592 4,720 4,711 o,469 3,461 1,998 1,989 308 305 53 48 43 56 39 46 38.4:6 83 53 55 92 0t 45 02 53 00 73 2O 75 22 73 20 76 23 69 1.5 52 99 88 35 ~0 57 4]_ 88 87 34 18 65 30 77 67 14 42 89 73 20 02 49 94 84 63 53 UfqlO[i OIL CO?IIW'IY LIf:O[I!,IIA ETD JTS. 1 1 18 19 Jts. JTS. 61 3 59 125 Jts. JTS. 11 42 182 31 1 1' 269 Jts. f DETAILS OF OPERATIONS, DESCRIPTIOliS & [~ESULTS 20" CASING DESCRIPTION 20" Float Shoe 20" 94# Buttress Csg. . 20" Float Collar 20" 94# Buttress Csg. Lan. ding Collar 20" X 24 3/4" BW Csg. Hgt. to RT Total 20" 94# Buttress Csg. 13 3/8" CASING DESCRIPTION 13 3/8 13 3/8 13 3/8 13 3/8 ]~3 3/8 13 13 "Howco Float Shoe "K-55 68# Buttress Csg. "Howco Float Collar "K-55 68# Buttress Csg. "Howco DV Tool 3/8" K-55 68# Buttress Csg. 3/8" K-55 61# Buttress Csg. 13 3/8" Cameron Flow-thru Csg. Hgt. Elevation Landed below RT Total ].3 3/8" K-55 Buttress Csg. 66 its. 68# 59 jts. 61# LENGTtt BOTTOM TOP 2.35 32.27 2.80 741.17 1.48 41.98 LENGTH 2.80 81.91 2.20 2515.94 3.10 120.62 2,431.40 1.05 42.60 822 05 819 70 787 43 784 63 43 46 41 98 BOTTOM 5201 62 5198 82 5116 91 5114 7]. 2598 77 2595 67 2475 05 43 65 42.60 DESCRIPTION 9 5/8" CASING 9 5/8" 47# 9 5/8" 47# 9 5/8" 40# 9 5/8" 47# 9 5/8" Howco Float Shoe 9 5/8" 47# S-95 Buttress Csg. 9 5/8" Howc0 Float Collar 9 5/8" 47# S-95 Buttress. Csg. P-il0 Buttress Csg. N-80 Buttress Csg. N-80 Buttress Csg. N-80 Buttress Csg. 9 5/8" 40# N-80'Buttress Csg. Landed 40.60 below RT on Cameron Slips. Total of 9 5/8" Buttress Csg. , ].2 its. 47-t~. S-95 42 jts. 47# P-110 1.83 jts. 47-ff N-.80 32 its. 40:t/ N--80 LENGTH 2.00 39.93 1.60 457.75 1,711.73 7,610.50 1,238.87 35.51 21.51 40.60 BOTTOM 1], ].60 O0 11,158 O0 1].,]18 07 ].1, ] 16 47 10,658 72 8,946 99 ]_,336.49 97.62 62.].1. 40.60 *Cut off. 819.70 787.43 784.63 43.46 41.98 --0-- TOP 5198.82 5116.9] 5114.71 2598.77 2595.67 2475.05 43.65 42.60 --0-- 'FOP ll, 158.00 11,118 07 11,1].6 47 10,658 72 8,946 99 1,336 49 97 62 62 11 40 60 '-0- · i 38.46 %'l')g. Nead · !0 'tUBING DATA. 4 1/2" 12.60# N-80 Buttress to mule shoe @ 10,434'. TUBING ACCESSORIES TOP ID 4 1/2" Otis Ball Valve 306 4 1/2" MMG GLV #1 1989 4 1/2" MMG GLV #2 3461 4 1/2" MMG GLV # 3 4712 4 1/2" MMG GLV #4 5592 4 1/2" MMG GLV #5 6223 4 1/2" MMG GLV #6 6574 4 1/2" MMG GLV #7 6953 4 1/2" MMG GLV #8 7332 4 1/2" MMG GLV #9 7682 4 1/2" MMG GLV ~10 8061 4 1/2" MMG GLV ~11 8412 4 1/2" MMG GLV ~12 8791 4 1/2" MMG GLV 813 9141 4 1/2" MMG GLV ~14 9491 4 1/2" MMG GLV ~15 9780 4, I/2" MMO GLV i~16 10,163 4 1/2" :' ~'"q~' , .~,'~.~-GLV ~17 -!0 328 Otis XA S!eeve 10,367 Baker Locator Sub 10,401 BaNer Seal Assy. 10,402 Otis "N" Nipple 10,432 Mule Shoe (Btm.) 10,434 3.812 3.812 4.000 4°000 3,725 4.000 13 3/8" Csg. @ 5201' 9 5/8" Ba]<er MDL F-1 Prod. Pkr. w/ 6" bore set @ 10,403' ETD 11,]_10' (FC) 9 5/8" Csg. © 1].,160~ ~i_~,,, ~~Original Completion ' - - Be,an 1]/]9/74 ~ ............ -- -t · -g . . · Completed 1/3/75 !-~fl--------'----~ COMPLETION SCHEMATIC JOB No ' A-II.15-?& ~ATV. Z-8-?~ REPORT and PLAN of SUB'SURFACE SURVEY T.B.U. State G-21 (21-33) O~-'~>'LET)::'~ REPORT DECE~4BER 30,1974 NION OIL OF CALIFORt'IIA G-21 TRADING BAY STATE (GRAYLING LEG 3 SLOT AGNETIC S/SHOT SURVEY BY ADDCO ELLY E~ING ELEVATION 101 FT, ANGE-NTI~L M[THOD OF CO~PUTATIONS BY F,M, LINDSEY AND ASSOC, , .................. RECORD OF SURVEY ALL` CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER ~-. ........................ TRUE _'_ ......... ~ .......... . ....... _ ........... ~: ....... _- ..... - .......... -___-nnn-LEG ~-~-~_.GRIFf_~VERTICAL SUB. DRIFT '- TOTAL COORDINATES C L 0 S U R E S SEVERITY SECTION EPTH Ah~GLE DEPTH SEA ._ _ DIREC DISTANCE DEG. 0 0 0 0,00 -101.00 $ 9 W .._ __850___0_ 0 .... 850.00 749.00 5 9 W 1098 0 30 1097,99 996,99 S 9 W _!~72_ 0 15 1471.98 1370,98 5 11E 1971 ! 30 1970.81 1869.81 N 89 E 2070 ._1 15 2069.79 '1968.79 N 46 W _2192 __1 15 2191,76 2090.76 N 80 E 2255 3 15 2254.66 2153.66 S 56 E -- . 2317 4 45 2316.44 2215.44 S 76 E 2348 5 a5 2347.29 2246.29 S 86 E 2426 8 30 2424,43 2323.43 N 72 E 2503 9 45 2500.32 2399.32 N 87 E 2565 10 45 2561,23 2460,23 S 78 E 2626 13 0 2620.67 2519.67 S 72 E 2728 15 45 2718,84 2617,84 S 77 E 2946 18 0 2926.17 2825.17 S 77 E 3052 19 0 30.26.39 2925.39 S 76 E 3273 31 0 3215.83 3114.83 S 74 E 3360 34 0 3287.95 3186.95 S 74 E 3412 34 0 3331,06 3230,06 S 74 E _3537 33 0 3435.90 353~,90 S 74 E .. _3755 33 0 361S.73 3517,73 S 73 E _391!_ 32 45__ 3749,93 3648.93 S 72 E 4,00 N 2,00 W 4,00 N 2,00 W _. le86 N 2,33 W 0.26 N 2.02 W 0.~8 N 11.03 E 1,98 N 9,47 E 2,45 N 12,10 E 0.45 N 15,06 E . - _ 0,78 S 20.04 E 1,00 S 23,14 E 2.55 N 34.10 E 3.24 N 47,12 E 0.83 N 58.44 E 3e40 S 71e49 E 9,63 5 98.46 E 24,78 S 164,10 E 33.13 S 197,59 E 64.50 S 307.00 E 77,91 S 353.77 E 85.93 S 381,72 E 104,69 S ~47,16 E 139,41 S 560,70 E 165,49 S 640,97 E ANGLE DEG/iOOFT DISTANC D 1'4 S 4.47 N 26 33 54 W 0,000 .......... '4,00 .... 4.47 N 26 33 54 W -0,000 ............ "4.00 2.98 -N 51'27-56-W .......... 0;202 .............. ;2';9-8 2,04 N 82 40 31 W 0,074 -1.77 11.04 N 87 27 52 E 0,296 8.52 9.68 N 78 9 5 E ..... 2~568 .............. 6;38 12,34 N 78 32 59 E 15,06 N 88 16 28 E 20,05 S 87 44 51 E 23,16 S 87 30 47 E 34,20 N 85 42 40 E 47.23 N 86 4 1 E 58,44 N 89 10 50 E 71.57 S 87 16 24 E 98e93 S 84 24 45 E 165.96 $ 81 24 39 E 200.35 S 80 28 48 E 313.71 S 78 8 O E 362.25 5 77 34 43 E 391,27 S 77 18 46 E 459,25 S 76 49 19 E 577,78 S 76 2 14 E 661.98 S'75 31 22 E 1.826 8.20 3,978 11.76 3,270 16.49 4,361 19,10 4.906 25.7 3,476 35e73 4,581 46,21 4.203 59,20 2,956 -84,50 1.032 146.08 0,990 177,87 5.443 -' 284,19 3e448 329.63 0,000 ..... 356.79 0,800 420.39 0.250 532.01 0.383 611.85 RECORD Of SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER .TRUE .:_E-A S ~, ...... DR~i'FT j'VERT ICAL sub DRIFT EPTH ANGLE DEPTH SEA DIREC D ,'q DEG. TOTAL COORDINATES ~123 34 15 3926,44 3825,44 S 71E ~314_.35_30 4081,93 3980,93 S 70 E ~595__35 15 4311,41 4210,41 S 69 E ~883 36 30 4542.92 4441.92 S 67 E 5150_32 15 4768,73 4667.73 S 64 E 5288.,33 15 _ 4884.14 4783.14 S 66 E 5442 34 45 5010.67 4909.67 S 64 E 5670.36 30 5193.95 5092.95 S 63 E 5981.,36. 0 5445.56 5344.56 S 63 E 6291 34_30 5701.03 5600.03 S 63 E 6666 34_45, 6009.15 5908.15 S 63 E 6988 36 BO 6267.99 6166.99 -$ 59 E 7140 35 45 6391.35 6290.35 S 62 E 7501 35 45 6684.33 6583.33 S 60 E 7720 34 0 6865.89 6764.89 S~57 E 8000 33 BO 7099.38 6998.38 S 54 E 8411 35 0 7436.05 7335.05 S 46 E 8605 35 45 7593.50 7492.50 S 42 E glO0 33 0 8008.64 7907.64 S 38 E 9303 32_ 0 8180,79 8079,79 S 36 E 9480 32 30 8330.07 8229,07 $ 33 E 9685 35 0 8~98,00 8397,00 $ 30 E 0277 38 0 8964,50 8863.50 S 25 E 074! 34 0 9352.49 9251,49 $ 21E 10~5 30. 0 9612,30 9511,30 $ 19 E ,1105 30 0 9664,26 9563,26 $ 19 E ,1160 30 0 9711.89 9610,89 S 19 E 180.99 S 685,98 E 203,71 S 751.96 E 241,64 S 856.19 E 299,76 S 1007.59 E 366.70 S 1165,29 E ~29,15 S 1293.34 E 459.93 S 1362,46 E 498,41 S 1441.36 E 559.98 S 1562.20 E 642.97 S 1725.07 E 722,68 $ 1881,52 E 819,72 $ 2071,97 E 918.37 S 2236.15 E 960,06 S 2314.56 E 1065,52 S 2497,22 E 1132e22 S 2599,92 E 1223,05 S 2724,95 E 1386,81S 289~,53 E 1471.05 S 2970.37 E 1683.49 S 3136.35 E 1770,52 S 3199.58 E 1850,28 S 3251.38 E 1952.11 S 3310,17 E 2282,43 S 3464.20 E 2526,75 S 3557,99 E 2668,58 S 3606.82 E 2696,94 S 3616.59 E 2722,95 S 3625,54 E ;OTTON HOLE CLOSURE 4534.21 FEET AT S 53 5 30 E DOG LEG C L 0 S U R E S SEVERITY SECTION DISTANCE ANGLE DEG/IOOFT DISTANC D M .S 709.45 S 75 13 11E 779.07 S 74 50 31E 889,64 S 74 14 20 E 1051.24 S 73 25 55 E 1221.62 S 72 31 54 E 1362,68 S 71 38 35 E 1~38.00 S 71 20 47 E 1525.10 S 70 55 29 E 1659,53 $ 70 16 ~5 E 1841.00 S 69 33 30 E 2015.5~ S 68 59 18 E 2228.23 S 68 2~ 53 E 2~17.39 $ 67 40 20 E 2505.78 S 67 28 17 E 2715.04 $ 66 53 34 E 2835.76 S 66 28 3 E 2986,84 S 65 49 39 E 3209,60 $ 64 24 0 E 3314,68 S 63 39 12 E 3559.61 S 61 46 28 E 3656.78 S 61 2 29 E 3740.99 S 60 21 24 E 3842.91 S 59 28 14 E 4148.52 S 56 37 14 E 4363,92 S 54 37 8 E 4486.70 S 53 30 12 E 4511,46 S 53 17 15 E 4534.21S 53 5 30 E 0.615 ..... 657.14 1.210 723.54 0.720 829.66 0,224 985,61 0.595 1151.89 1.713 1291.79 ._ 1.068 1365.54 ._ 1,215 1451.73 0.809 ' 1585,32 0.161 1765.39 . _ . 0,484 1938,35 0.067 2148.90 0.905 2339.41 1.264 '2427.14 · 0.324 2636e5' 1.119 2758.7- 0.621 2913,22 1.154 3147,16 1,254 3258.40 0.719 3518.71 0.723 3621,54 0e947 3710.86 1.465 3819.03 0,713 4140,60 0,991 4362,34 1.379 4486,58 0.000 4511.43 0.000 4534.21 DEPTH AND OTHEf-i DATA FOR EVERY EVEN 100 FEET OF ,SUB SEA DEPTH, TRUE HFASURED VERT I CAL SUB HD-,'TVD V£RT I CAL · DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL ................ ~ol .... 2ol · " 3Ol ~oi, 401 401. .... 501'I "~ 501, 601 601, '/01 ?01, 801 801. 901 901, 1001 1001, 1101 1101. 1201 1201, 1301 1301. ...... 1401 1401, . 1501 1501. 1601 1601, ........ 1101 1~01 · .... 1801 1801, ...... 1~01 " 1901 · ..... 2001 -~' 2001 · .... 2101 2101. 2201 2201. 2301 2301. 2~02 250~ 2501. .... 2606 2601, 2709 2701, 281~ 2801, 2920 2901, - ~025 3001, ..... ~1~9 ~101. ~256 ~201. ~376 ~01. ~615 3501, ~ 3601. .... 100, 200, 300, 400, 500, 600, ?00, 800, 900, 1000. 1100, 1200. 1300. 1400. 1500, 1600. 1700, 1800, 1900. 2000. 2100. 2200. 2300. 2400. 2500, 2600. 2700. 2800. 2g00, 3000. 3100. 3200. 3300. 3400. 3500, 0 0 0 0 0 0 . 0 '0 0 0 0 0 . 0 0 0 0 __ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O' 0 0 0 0 0 0 0 1 -1 __ 8 . ~5 ?5 20 114 20 133 19 4, 4, 4. 4. 4. 2, 1, 1. O. O, Oo O, O. COORDINATES O0 N 2,00 O0 N 2-00 00 N 2,00 O0 N. 2,00 O0 N 2.00 O0 N 2.00 O0 N 2.00 56 N 2,06 69 N 2,20 8q N 2.33 42 N 2.25 99 N' 2-16 56 N 2.08 27 N 1.26 31N 1,35 36 N 3,96 41 N 6.58 0.45 0.94 2.10 2,15 0.47 1,47 3,21 2,00 8,50 15,63 22.94 91,01 45,49 62.05 80.34 98.45 117.05 136,04 N 9.20 N 10.55 N 10.15 N 12.53 S 18,79 N 30.77 N 47.25 S 67,17 5 93,56 S 124.47 S 156.13 S 189,10 S : 240,68 S 298.43 S 362,22 S 425,37 S 487,59 S 549.69 W W W W W W W E E E E E £ E E E E E E E E E E MEAS[tRED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE MEAsuRED VERTICAL SUB MD-TVD ........... DE'P TH DEPTH SEA .DIFFERENCE ...... 38'53 3701. 3600. 152 . ........... 3972. 3801. 3700. 171 4092 __ _ 3901. 3800, 191 __. .......... 4215 4001. 3900. 214 ............ 433? _ 4101. 4000, 236 ............... 4_460 ........ 4201. 4100. _ 259 .............. 4582 4301. 4200. 281 ............. 4706 .... 4401. 4300, 305 4831 a501. 4400, 330 4952 4601. 4500. 351 507'0 4701. 4600, 369 5189 4801. 4700. 388 _ 5309 4901. 4500, 408 5430 5001 · 4900. 429 5554 5101. 5000. 453 5679 5201, 5100, 478 5802 5301 . 5200. 501 5926 _ 5401. 5300. 525 6048 5501 .' 54b0, 547 6170 5601., 5500, 569 6291 5701, 5600, 590 ........... 6~.13 5801. 5700. 612 6534 _ 5901. 5800, 633 ........ 6656 6001, 5900. 655 .... 6750 _ _ 6101, 6000, 679 ...... 6905 6201 · 6100, 704 7029 6301. 6200, 728 7152 6401. 6300. 751 · 7275 6501. 6400. 774 _ 7398 6601 · 6500. 797 7521 6701. 6600. 820 7642 68..01 · 6700. 841 7762 6901, 6800. 861 7~2 7001, 6900. 881 _ :' ~0~2 7101. 7000. 901 VERTICAL CORRECTION TOTAL COORDINATES S S S $ S S S $ S $ $ $ S S S S S S S S S S S S S S S S S S- S $ S S S 19 155.76 19 176,18 20 198.07 23 221,90 22 246,47 23 271,80 22 297.12 24 325,66 25 354,57 21 382,76 18 410,42 19 437.76 20 465,06 21 495,47 -. 24 528,75 25 562,30 23 595,29 24 628,27 _ 22 --660,27 22 691.47 21 722,67 ~2~2 754,17 21 785.66 22 817.15 24 854.73 25 892.84 24 929.52 23 963.53 23 999.53 23 1035.52 23 1071,64 21 1108,38 20 1145.87 20 1184,78 20. 1223,8~ 611,03 E 672.02 E 735.58 E 801,94 E 868.76 E 934,74 E 1000,72 E 1068.61 E 1136,73 E 1198,22 E 1254,95 E 1312,67 E 1372,97 E 1~35,33 E 1500,91 E 1566.76 E 1631,49 E 1696.23 E 1759.02 E 1820,26 E 1881,50 E 1943,31 E 2005.12 E 2066,93 E 2130.23 E 2193.65 E 2257,13 E 2320.57 E 2382.92 E 2445.26 E 2506.64 E 2563.21 E 2618,72 E 2672,27 E .. 2?25.?7 E DEPTH A"iD OTHER DATA FOR EVERY EVEN 100 FEET OF .SUB SEA DEPTH, ........ S£?T.H -. _ ........ =124 ........... 824,6 ' _ .......... 8368 ........ .... 86.14 __ ............. 873 3 ............. 8852 . 8972 ............... 9091 ...... 9209 ............ 9327 ......... 944 6 .... 9567 ....... g6~9 9816 9943 10070 10196 10321 1 0~42 10562 10683 10801 10916 11032 · _ .. _ _ TRUE VERTI(AL SUB MD-TVD DEPTH SEA DIFFERENCE 7201' 7100, 923 7301. 7200, 945 7401, 7300, 967 7501, 7400, 990 7601, 7500, 1013 7701. 7600, 1032 7801, 7700, 1051 7901. 7800, 1071 8001, 7900, 1090 8101, 8000, 1108 8201, 8100. 1126 8301, 8200, 1145 8401, 8300, 1166 8501, 8400, 1188 8601, 8500, 1215 8701, 8600. 1242 8801, 8700, 1269 8901. 8800, 1295 9001, 8900, 1320 9101. 9000. 1341 9201. 9100, 1361 9301, 9200, 1382 9401. 9300. 1400 9501, 9400, 1415 9601e 9500, 1431 VERTICAL ._.(ORREETION- 22 22 22 23 23 19 19 2O 19 -18 18 19 21 22 27 27 27 26 25 21 20 21 18 15 16 TOTAL COORDINATES . 1272,48 1321.12 S' 1369.76 S 1421,56 1474.88 S 1526,06 S 1577.23 S 1628,40 S 1679,58 $ 1730e18 S 1781.31 S 1834,74 $ 1893,29 'S 1954e23 S 2025,04 S 2095,85 S 2166,66 S 2237.46 S 2305.41 $ 2368,38 S 2431,35 S 2494,32 S 2553,23 S 2607,82 $ 2662e4! S 2776,13 E 2826,50 E 2876,87 E 2925,81 E 2973,37 E 3013,35 E 3053,33 E 3093.31 E 3133,30 E 3170,27 E 3206.59 E 3241,29 E 3276,21 E 3311,16 E 3344,18 E 3377,20 E 3410,21 E 3443,23 E 3473.02 E 3497,20 E 3521,37 E 3545,54 E 3567,10 E 3585,90 E 3604,70 E !;T-':SLATED VALUES FOR EVEN 1000 FEET OF HEASURED DEPTH. TRUE ~[ASURED VERTICAL SUB DEPTH DEPTH SEA 1000 2000 3000 4000 5000 6000 TO00 8000 9000 I0000 11000 _ . 2977. 2876, 3824. 3723. 46~1. 45~0, 5~61, 5560. 6277. 6176, '?099° 6998. 792~ 7823, 8746. 8645e 9573. 9472, TOTAL COORDINATES 2.70 N 2,20 W 0.92 N 10.57 E 29,03 S 181,16 E I81.17 S 686.51 E 394.07 S 1221,40 E 647.85 $ 173~.66 E 921,66 S 22~2.34 E 1223.05 S 2724.95 E 1640e57 S 3102,82 E 2127,87 $ 3392,13 E 26~7,31S 3599.50 E INTERPOLATED TRUE VERTICAL DEPTHS~ COORDINATES AND CLOSURES FOR GIVEN DEPTHS - TRUE .... MEASURED VERTICAL TOTAL COORDINATE5 C L 0 S U R E DEPTH DEPTH DISTANCE ANGLE D H $ COD~ NAME · -TOP E TOP F 'TOP G ZONE :-TOn G-! SD -TOP HEM, FORELAND 11096 -TO' 11160 '.'6847 6154,65 875,17 S 7908 7022,66 1193,21 $ 9467 8319,11 18~r4'42 S 9845 8624,08 10475 9128,65 9656,46 9711,89 SUB SEA 2164,26 E 2334,51 S 67 59 57 E 60.53,65 2683,87 E 3247,57 E 2041,38 S -3351.80 E 2385.80 S 3503.88 E 2692,69 $ 3615,12 E 2722.95 3625.54 2937.16 S 66 1 50 E 6921.56 3734,79' S 60 24 21E 8218.11 3924,52 S 58 39 24 E 8523,08 4239.01 S 55 4~ 56 E 9027.65 4507,74 S 53 19 11 E 9555.46 4534,21 53 5 30. 9610.89 I':%E.~.~OLATED TRUE VERTICAL DEPTHS, COORDINATES AND C.LOSURES FOR GIVEN DEPTHS_. TRUE 'i'CODE MEASURED VERTICAL TOTAL COORDINATES NA~E DEPTH DEPTH C L O S U R E DISTANCE ANGLE D M SUB SEA -': '[' "i ..... ' '' VERTICAL SECTION i ..... I .... ' ....... [ SCALE I =1000' .... UNION OIL OF CALIFORNIA 2000- ......... ' ..... [ ........................ ~ ........ G-21 TI~S(GRAYLING LEG .................................................... , ......... TANGENTIAL METH~ . .- { . . ,. . , . , ..... ~ . . ........ ~ ....... ~ -- - i ...... ..................... . ............................. - -~ i- .'-' ...... ........ ~ ....... ~ ......... ................ · - ~ ......... ~._ I [ _. - . ._' .......... ...... : ............. _ .. . ; I _ . i ....- ~ 68~ ': '' '"-' [ ' : ' t , - [ ~ 76~ . . ~ . I ~ .... . .................................. , - , ......... I ~ .... ~ 8800 .................................. : ~ ; ,._ ~ TVO = 9,712' ~ ~ TMD I1~ 160' HORIZONTAL, VIEW SCALE I"- 500' UNION OIL OF CALIFORNIA G-21 TBS (GRAYLING LEG :5 SLOT 2) TANGENTIAL MET/HOD TVD: 9,712" TMD :11,160' .. =OfqPl :'TION REPORT DECEHBER 30,,1974 ........................................................ ~. ......................... _)NION OIL OF CALIFORNIA G-21 TRADING BAY STATE _.(GRAYLING LEG ) SLOT 2) .......... ] ................................................. J ......................... ~AGNETIC S/SHOT SURVEY BY ADDCO <ELLY BUSHING ELEVATION 101 Fire .~. ..... ~ ........... = RECORD OF SURVEY ALL' CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER ................................... :: ........................... : ......... * ........ : ...................... ' " TRUE'' DOG LEG ~'~EA-S-~-DRIFT VERTICAL .... SUB DRIFT ....... TOTAL-COORDINATES ............ C L-O'S'-U-R-E' S .......... SEVERITY .... SECTION .. ~PTH ANGLE DEPTH SEA DIREC DISTANCE ANGLE DEG/iOOFT DISTANCE O M DEGe D ~ $ ........................................................... ....... 0 ....... 0 ....... 0 0.00 -101.00 $ 9.OOW 850--0-'0 850,00 749,00 Io9§-:-' ~!13o 1o~7.99_. 996,99 .. S ,9.oow-. 1-472 ~.:'.'15 1471,98 '1370~98 I971 I 30 1970.92 1869,92 N89,00E 2070 1 15 2069,89 1968,89 N46,00W 2192 1 15 2191,86 2090,86 N80,OOE -. 2255 3 15 2254,81 2153,81 $56,00E _ 2317 4 45 2316,65 2215,65 S76,00E 2348 5 45 2~47,52 2246,52 S86,00E 2426 8 30 242~-91 2323,91 N72,00E 2503 9 ~5 2500,94 2399,94 N87,00E 2565 10 ~5 2561,95 2~60,95 S78,00E _ 2626 13 0 2621.64 2520,64 S72,00E 2728 15-'~5 2720,.~ 2619.43 S77,00E 29~6 18 0 2929,03 2828.03 S77,00E 3052-19-'0 3029,56 2928,56 S76,00E 3273 3~i-' 0 3229,48-3128,~8 ST~,OOE 3360 34~"0 3~02,85 3201,85 3412 3~-"0 3345,96 324~,96 3537'-33'-0 3h50,19 3349.19 375~ 33'- 0 3633.02 3532,02 S73,00E 391[ 32~5 376~,0~ 3663,0~ $72,00E 3999 32 45 3838,05 3737,05 S71,00E 4123 3~ 15 39~1,~5 3840,45 S71.00E - . . ......... . ~.00 N 4.00 N 2 *93 N 3,91 S 2.185 0.12 $ 0.62 S 2.37 S 2,81 S 1,64 $ 0,57 N 0.29 S 3.53 $ 10,30 $ 24.53 S 4,47 N 26 3'3 54 W 4,47 N 26 33 54 W 2,00 2,00 W 2,16' 2_,.12L 3,32 E 5,14 S 40 19 2 E 4,00 E ........ 4,56 4,63 E 4.64 S 88 28 36 3,64 N 36 30 14.:W 0.2'02. 0..069--- 0,762 2,716 1.826 _ 7,02 S 8~ 53 49 E 6,540 .. _ 11.18 $ 77 44 24 E 3,989 0,000 ............. -3,97- 0,000 -3-97 -3', 47 -2,01--. ~,99: 3,82 6,02' i0.23 4,788 12.75 6,092 ....... 1°'77 _ . 3,879 2 13 4,998 37,50 6,99 E 10.93 E 13,72 E 23,27 E 35,24 E 46,21 E' 58,32 E-- 82,72 E 144,37 E 1~,01 S 78 23 55 E 23,32 $ 85 57 9 E' 35.24 N 89 4 10 E 46.21S 89 38 22 E 58,~3 S 86 31 44 E ~.411 ~9,20 83,35 S 82 54 2 E 3.064 72,90 146.44 S 80 21 17 E 1,032 - - i31.10 32,3B-S-" 177,08 E 180,01 S 79 38 6 E 56,51 $ 267,12'-E 273,04-S 78 3 14 E 69,39,..S. 312.05 E.. 31.9.68 S-77 27 42 E 77.41 S 340,00 E 96,43 S ~06.32 E 130.15 S 520.16 E 155,61 S 600,92 i 170,72 S- 646,07-~E 193.00 S 710,78 E .. 0.995 5,460 3.448 -'348.71S 77 10 23. E .... 0,000 417,61'S 76 38 57 E ..... 0.800 536.20 S 75 57 8 E 0.250 620.74 5 75 28 53 E 0.381 668,24 S 75 11 53 E 0,615 736,51 $ 74 48 30 E 1.210 162.14 249,11 293,00 320.31 385,09 496.94 577,18 622,56 687,97 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER'- TROE 'DOG LEG...? '~'~'~;'~'"bRIFT'-VERTICAE ........ SUB ...... DRIFT .............. ToTAL'-COORDINATE$ ............ C'"L'-O S UR'E S .......... SEVERITY ............. SECTION'- EPTH ANGLE DEPTH .... SEA- DIREC ................. DISTANCE ANGLE ....... DEG/LOOFT ...... DISTANCE D M DEG. D M 4595...35.15 4327.27 ~226.27 S69,00E ~883_36 30 .... 4560,63 4459,63 S6?,OOE 5150 32 15 4780,95 4679.95 S64,00E 5288 33 15 4897,01 4796.01 S66.00E 5442 34 45 5024.68 4923.68 S64,00E ._ 5670._.86 30__ 5210,00 5109,00 $63.00E 813,72 E 286,k2 S 966,09 E 349.64 S 1122,57 E 412.13 $ 1259,70 E 443,68 S 1327.35 E 480,07 S 1405,39 E 539.33 S 1524,24 E 845,45 S 74 15 8 E 0.724 1007,66 $ 73 29 9 E 0,223 1175.76 S 72 41 59 E 0,603 1325.40 S 71 53 0 E 1,690 1399,54 S 71 31 1 E 1,08~ 1485.13 S 71 8 24 E 1,232 1616.84 S 70 30 51 E ..... 949,30 1112,96 i26o,5a 13.33~83 1418.3~' 0.812 ...... 1549.26'" _. _ 5981 36~ 0.' 5460.80 5359.80- 563.00E 6291 34~30 5713.96 5612.96 S63,00E 704.04-S 1847.50 E- 6666 34 45 6022,54 5921,54 S63,00E 800,77 S 2037,35 E 6988 35 30~ 6284,27 6183.27 S59,00E 891.68 S 2201,36 E 7140 35 45 6407.04 6306.04 S62.00E 935,80 S 2279,34 E 7501 35 45 6700.02 6599,02 S60.OOE 1038,05 S 2463.80 E 7720 34 0 6879.68 6778.68 S57,00E 1103.47 S 2570,55 E 8000 33 30 7112.49 7011,~9 S54.00E 1191.57 S 2698.74 E 8~lZ 35 0 7452.21 7351.21 S46,00E 1340,13 S 2875.78 E 8605 35. 45 7610.39 7509.39 S42,00E 1420,90 S 2953.79 E ~100 33 0 8018.91 7917.91 S38.00E 1634.93 S 3133.38 E 9303 32_ 0 8190.11 8089.11 S36,00E 1722,03 S 3199.02 E 9480 32 30 8339,81 8238.81 S33.00E 1799.86 S 3252.51E q6~'5 35 0 8510.24 8409.2~ S30,OOE 1896,95 $ 3312.00 E 0277 38 0 8986.07 8885.07 525,00E 2209.17 S 3474.53 E _0745 34" 0 9364.61 9263.61 S2i.OOE 2462.28 $ 3581.97 E ~ . 11045 30~-' 0 9518,98 9517.98 S19,00E 2611,63 S 3636.33 E. 1105 30 0 9670.94 9569.94 S~9.00E 2640.00 S 3646.10 E 1160 30 0 9718,57 9617.57 S19,00E 2666,00 S 3655.05 E 622,82. S 1688,09 E.. 1799'32 S. 69 44 54. E_ I977,10' S 69- 8 21 E-' 2189.08 S 68 32 34 E 2375.09 S 67 56 56 E 2463,96 S 67 40 44 E 2673.55 S 6? 9 11 E 2797.39 S 66 46 2 E 2950.09 S 66 10 37 E 3172,71S 65 0 51E 3277,78 S 64 18 37 E 3534,2'7 S 62 26 43 E 3633,06 $ 61 ~2 22 E 3717.30 S 61 2 26 E 3816,78 S 60 11 52 E 4117,38 S 57 33 3 E 4346.65 S 55 29 41E 4477.00 S 54 18 50 E 4501.51S 54 5 35 E 4524.04 5. 53 53 34 E 0,16i: ...... 1730.84: 0,484. 1907-49; 0,067 2117,88~ 0.930 2303,95 1.245 2392-95 0,32/+ 2602-24- 1,095 2727,03 0,614 2882.5~ 1,195 3113.10 1.276 322 ,72 0 · 699 349-. 0.713 3599.31 0.959 3688,39 1.496 3793.67 0.739 4108,98 0.968 4344.94 1.370 4476.88 0.000 4501,49 0.000 4524.04 CLOSURE 4524.04 FEET AT S 53 53 34 E CASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH.~ TRUE ~ASURED VERTICAL SUB MD-TVD VERTICAL DEPTH. DEPTH SEA.: DIFFERENCe_ CORRECTIO~-;".~ TOTAL..,;.. CQQRD.INATES~:;; 201 ............. 201. 100 ................. :--~ ........0 ~,O0'N 301 30~. 200- 0 0 ~.00 N 2.00 40~ ......... ~01. 300 ' '0 ............. 0 ...................... ~.00 N 2.0'0 ........ 501 ........ 501~ ~00 0 ............. 0 ................. ~.00 N ..... 2,00 601 601, 500 0 .. 0 4,00 N 2,00 ?0~ - 701, 600 0 .......... 0 .............. ~.00 N 2.00 801 ......... 801. 700 -0 ............... 0 ............................ ~.00 N 2.00 901 ............ 901, 800 0 ............ 0 .......................... 3,95 N 2,00. 1001 .... 100i, 900 0 ............. 0 .............. : ..... 3,60 N .......... 2,06 1101 ............ 1101, 1000 O .......... 0 .................. 2,90 N 2,17 1201 ...... 1201, 1100 O ........ 0 ...................... 2,09 N 1301, 1200 0 -' - O ..................... I,~O N 2.26 1~01,.. 13OO - .0'. ':Q ....... O: ....................... O, 82:.....N 2,20':' W:- . . _ - .: . - =. - ...... ~ ........ ...... . 1501"~ I.~00?~ ' O ...... -" ' . Ok- '- _ ............0,35L ...... 1601, 1500 0 0 0.36 $ 1,79 1701, 1600 0 ' - 0 ........................ 1.3~ $ 1,09 1801, i700 0 ..... 0 .... 2.41 $ 0,10 1901, 1800 - - 0 ................. 0 ................... ~.39 $ 1.82 .__ 2001, 1900 0 ............. 0 ........... ~.16 2101. 2000 0 ' - 0 ....... 1,60 $ 3.67 ............ 2201, 2100 0 ....... 0 .... 0.09 $ ~.85 2301, 2200 0 0 1,98 $ 9,72 ....... ~401, 2~00 0 0 2,4~ $ 19.97 ........................ 2601. 2500 ' 3 I 2.20 $ 53.90 ...... .... 2701. 2600 6 ~ 9,03 S 77.%9 ......... 2801, 2700 10 .......... ~ ............... 15,56 $ 105.53 2901. 280'0." 15_ - 5 ............. 22.SQ.&-' 135,58 3001.. 2900:. 20 - - ~ 30', 05 ....... 3101. 3000 28 ...... 8 39,23' .................. .......... 3201. 3100 39 .............. 11 52.08 & 251,3~ 3301. 3200 56 17 69.05 3fl01. 3300 77 21 87.5~ $ 375.33 ..... ...... 3501. 3~00 96 19 105,51 5 ~37,71 3601. 3500 116 20 12~.10 $ 500.26 .... . _ 1301 ............ 140 ........ 150I _ 1601 1701 1801 .... 1901 2001 2101 2201 2301 2z~02 2503 2605 2708 2812 2917 3022- 3129 3240 3358 3/+78 . 3597 3717 !TASURED DEPTH AND OTHEP DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH', TRUE 'tJEASURED VERT !CAL ,SUB MD-TVD DEPTH ..... . .DEPTH · SEA DIFFERENCE-" VERTICAl. CORREC.TIOt%i- ' . TOTAL-.- 3955 4074 ............ 4195 4317 4440 468.5 ..................... 4809 ........ ..... ~93S 5055 5293. .................. 3783 ...... 5907 ................ 6030 6153 627~ ._ 6397 ..... 6518 ......... 66~0 .... 6762 - . 6885 7009 7132 . 725~ 7379 7502 7625 . 7746 798~ 3701, 3600 380I* 3700 3901, 3800 4001, 3900 4101, 4000 . 4201, 4100 4301, 4200 4401, 4300 4501, 4400 4601, 4500 4701. 4600 4801, 4700 4901 ·. 4800. 500:1, 490~'-- 5101, 5000 5201, 5100 5301, 5200 5401, 5300 5501, 5400 5601. 5500 5701, 5600 5801, 5700 5901, 5800 6001, 5900 6101, 6000 6201, 6100 6301, 6200 6401, 6300 6501, 6400 6601, 6500 6701, 6600 6RO1, 6?00 6901, 6800 7001, 6900 7101, 7000 135 154 19 163.05 173 19 184,09 194 21 206,40 216 239 262 284 307 332 354 372 39.1' .~-.- .. 412~- 434 457 482 506 529 574 595 617 638 660 683 708 731( 755- _. 778 801 824 845 865 885 22 230,05 23 .....~ .......... 254,71 23 279,78 22 305.40 23 332.70 25 361,27 22 389.76 18 417,66 19 . 444,75. 21' - ............... 472.,91 22 503.69' 23 536,31 25 569,79 24 603,04 23 635.85 23 668,35 22 699.92 21 731.23 22 762.52 _ _ _ 2! 793.99 22 826,29 _ .. 23 860,96 25 898,01 23 933,59 2~ 967,89 2~ 1002,77 _ 23 1038,34 23 1074,65 _ 21 1111,32 20 1148,74 20 11~7,03 623.49 E 684,90 E 749.28 815,36_E ................................ 882,28 E 948.74 E 1014,72 E ....... 1082,12 .......................... 1149,61 1212,86 .............................. la71,12 .......................... 1.3.29,7~ E~_ ..._... .... :-._. ...... · 1390'.:56' E;'::.: --.:_ . . . ......... 1453,38 E 1518,31 E .......................................... _ .... 1584,03 E ............................. 1649,29 E ................................................. 1713,68 E 1777,46 E ......................... 1839.42 E .............. 1900,87 E 1962,28 E .................................. 202~,04 E ............................... 2036,16 E 2148,~3 E .............................. 2211,97 E ..................................... 2275,21 E 2338,88 E: 2401,85 2464-3! E .... 2525°08 E _ 2582,58 ..... 2638,23 E 2692,48 E ASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, HEASURED DERTH 8108 822? ..... 8349 8671 8593 ~ . . 8838 8~59 ~079 9~98 9316 955.3 9796 9920 100~ 10169 1029~ 10~22 . 10668 10789 10907 1102~ 11I~0 TRUE VERTICAL :SUB _ MD-TVD VERTICAL_ DEPTH SEA:DIFFER'E~4¢E'V'_ CORRECTION-'.~ - TOTAL 7201. 7100 905 20 7301. 7200 926. 21 740! , 7300 9~7 2 7501. 7~00 969 22 7601. 7500 992 23 7701, 7600 1015 23 7801. 7700 1037 22 7901, 7800 i058 ' ' 21 8001, 7900 1078 8101, 8000 1097 8201, 8100 ~11~ i7 8301, 8200 1133 19 840.I.,.. 8300 ........ 1.15.g~-' 850I', 8400; 117~"-: .-~' 2:L--.:-" 8601. 8500 1195 23 8701, 8600 1219 26 8801, 8700 124~.._ ~901. 8800 1268/ .~ ~ 25 9001, 8900 1295 9101, 9000 1321': "'~ 26 9201. 9100 1345 9301, 9200 1367 22 9401, 9300 1388 21 9501, 9400 1406 18 9601, 9500 1423' 17 9701, 9600 1439 16 1227o12 $- 2745,8~'- E 1269,96 S 2798.29 1315,80 S 28~9,99 1364,22 $ 2900,21 1415,7i S 2949,08 1469,16 $ 2996-57 1521,92 $ 3041,80 1574,12 $ 3085,01 1625,75 5 3126,21 1676,83 $ 3165,55 1727,55 S 3203,01 1779,27 S 3238,93 1952,84 S 3343,65 2016.39 S 3378,20 2082.05 S 3412,38 2149,82 S 3446e15 2219,71 S 3479,63 2289.16 S ~510.80 2356.51 S 35:39.72 2~21.81 $ 3566,27 2~8~,96 S 3590.61 2545.01 S 3612,8~ 2601.76 S 3632,93 2656,40 ~ 3651 ~i'Ei~'i~Oii]~-_~ED._i_VA-L.uES._FO.R EVEN'-_IO00 ._FEET OF MEASURED DEPTH. ...................................................... TRUI ~.E ASUR.ED .........VER T I CAL ....... SUB DEPTH DEPTH SEA TOTAL COORDINATES ........ lO.O0 999, .... 898, .............. 3,60 N ....... 2,06 ............. 20.00 ................ 1999, 1898, ........... 4.15 S ~+,0l ........... 3000 ........ ~ ......2980, 2879, .................. 28.~1 S 160,84. E ............ 4000 '. ...........3838, 3737, 170,89 5 5000 4655, ~55~e ~76,95 S 118~,90~E 6000 .................... 5~76, ...... 5375e .............. 627,88 5 1698,03 .................... 7000 ............... 6293; ...... 6192' ................ 895.3~ S 2207.~8 SQ.00 ..... 7112, .......701_1~ ............. 1191,57 5 2698,7~ _.9000 ....................... 7935, ........ 783~, ........... 1591,90 S 3099,34 1.0.O00 ...................... 8765,_ 866.4, ............. 2058,60 S 3400,39 ........... 1.100~_~_ ............... 9580, ......... 9~9.~ .................. 2590,18 5 _3628,90 · INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS CODE NAH F. TRUE MEASURED VERTICAL TOTAL COORDINATES C L O-$ U R E 'SUB DEPTH DEPTH DISTANCE ANGLE SEA DM --TOP E ' 68~7 TOP F 7908 .TOP G ZONE g~67 -,TOP G-1 SD 98~5 TOP HE~. 10475 -W FORELAND 11096 -TD 11160 6170.36 850.00 $ 2129,46 ?035.85 1162,01S 2657.92 8328.84 1794,02 S 3248,69 86~0,65 1977,77 S 3357,~0 91~3.88 2318.27 S 3523.~6 9718,57 2666,00 $ ~655,05 2292.8~ $ 68 1~ 23 E 6069.36 '2900,28 $ 66 22 51 E 693~,85 ~711.13 S 61 5 28 E 8227.8~ 3896.63 S 59 29 5~ E 8539.55 ~217,72 $ 56 39 2~ E 90~2.88 ~97,83 S 5~ 7 3~ E 9562.1~ ~52~.0~ $ 5~ 53 3~. E 9617.57 /. IN'FERPOLATED TRUE VERTICAL DEPTHS~ COORDINATES AND CLOSURES FOR GIVEN DEPTHS _._ TRUE .CODE HEASURED VERTICAL. .NAH.E DEPTH DEPTH TOTAL COORDINATES CLOSURE DISTANCE ANGLE D M S SUB SEA 800- 1600- 200O 2400- VERTICAL SECTION SCALE !"= I000' UNION OIL OF CALIFORNIA G- 21 TBS (GRAYLING LEG 3 SLOT2) RADIUS OF CURVATURE METHOD 2800 44~ 76~ 9600 TVD= 9,719' TMD = 'I1', 160' HORIZONTAL VIEW SCALE 1"=500' UNION OIL OF CALIFORNIA G-21 TBS (GRAYLING LEG :~ SLOT2) RADIUS OF CURVATURE METHOD 9200 9600 TVD: 9,719' TMD = I I,..~ 160' · ,, DIRECTIONAL SURVEY REPORT FOR ri rttlf[ .... Union O~l Of Ca]~fm'mia . T~P~ oF SURVEY:, Surwell G~pic Multishot SURVEY i~PTH: FROM Surface FT. TO 110OO _Fr. LE~', Trading B~,,,y Unit --WELL NO. Grayling G-21 FIELD:. L McArthur River COUNTY~PAI~I~ DATE OF ~JRVEY OFFICE: _ Kenai Peninsula _ STATF Alaska 12-28-74 ._ JOe NO._ SU-3-169~7 Anchorage SPERRY-SUN WELL SURVEYING COMPANY PAGE I JNION Oil. OF ;RAYLING G-21 CALIFORNIA ANC'HORAGE t ALASKA COMPUTATION DATE .. DATE OF SURVEY DECEMBER 28, 1974 --SURWEL GYROSCOPIC MULTISHOT SURVEY 4CARTHUR RI.VER J, LASKA JANUARY 13, 1975 JOB NUMBER Sbr3-16947 KELLY BUSHING ELEV. = gO. O0 FT. TRUE' qEASURED VERTICAL DEPTH DEPTH 0 0.00 100 99.99 200 i99o99 300 299.98 SUB':SEA COURSE COURSE VERTICAL INCLINATION DIRECTION DEPTH DEG MIN DEGREES DO'G-LEG SEVERITY DEG/IO0 TOTAL REC'TANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERTICAL SECTION ... -99.00 0 0 S O. 0 W 0.00 0.00 0.00 0.99 0 30 S I7.58 W 0.50 0.4I S 0.I3 W I00.99 0 4I S I7.I6 W 0. I8 1.40 S 0.43 W 200.98 0 42 S 20.76 W 0.06 2.54 S 0.83 W 0.00 0. I5 O. 52 0.93 400 399.97 300.97 500 499.97 400.97 600 599.96 500.96 '?00 699.95 600.95 800 799.94 700.94 900 899.93 800.93 1000 999.92 900.92 1100 1099.92 1000.92 1200 IIgg.9I IIO0.9I 1300 "1'29~.90 1200.90 140'0 139'9.90 1300.90 0 41 S 24.49 W 0.06 3.65 S 1.29 W 0 42 S 6.24 W 0.22 4.80 S 1.60 W O' 45 S 8.80 E 0,20 6,06 S 1,57 W 0 44 S 10.49 E 0.05 ?.33 S 1.35 W 0 44' S 18.14 E 0.10 8.57 S 1.04 W 0 46 S 1.23 E 0.22 9.85 S 0.82 W 0 40 S 3.25 W 0.12 11.10 S 0.84 W 0 40 S 1,73 W 0.04 12.26 S 0,89 W 0 ' 40 S 4.72 W 0.05 13.42 S 0.96 W 0 41 S 1.69 W 0.05 14.59 S 1.02 W 0 40 S 3.84 E 0.07 15.77 S 1.00 W S 0.I3 W 0.06 I6.95 S 0.97 W 1'5oo 1499'89 1600 1 599.88 1700 1699.87 1800 1799.86 lgO0 1899.85 2000 1999.84 '1400'89 0 41" --1500~-88 0 45 1600.87 0 50. 1700.86 0 55 1800.85 0 0 1900.84 1 15 S 35.76 E 0,44 18.08 S 0,58 W S 38.53 E 0.10 19.18 S 0.24 E S 41.95 E 0. I0 20.34 S 1.23 E S 50.81 E' 0.91 20.93 S 1.76 E N' 54.14 W 1.25 20.30 S 0.88 E 2100 2099.82 2200 2199.79 2300 2299.56 '2400 2398.35 2500 2497.59 2600 2595.63 2700 2692.49 2000.82 1 16 N 45.30 2100.79 2 30 S 66.I0 2200.56 5 14 S 81.27 2299.85 8 20 N 86.14 2398.59 9 50 S 80.65 2496.63 12" 51 S 72.46 2593.49 15 53 S 74. W 0.19 18.88 S 0.78 W E 3'71 18.99 S 0-42 E E 2.89 20.56 S 6.92 E E 3.~2 ................ 20.77._,S 18.66 E.. E 2.55 21.67 S 34.32 E E 3.41 26.41 S 53.35 E 7 E 3.05 33.51 S 77.12 E S 73.92 E 1.28 41.36 S 104.46 E S 73.43 E 0.68 49.81 S 133.32 E S 72.P5 E 9.75 58.87 S 163.20 E 17 !0 17 50 18 3~ 1.26 1.73 2.54 3.50 4.52 5.49 6.25 6.93 7.61 8.29 9.04 9.80 10.80 12.14 13.64 14.43" 13.34 11.15 12.16 18.23 27.54 40.34 58.18 81.29 107.47 135.31 164.33 JNION Oil OF CALIFORNIA ;RAYLING G-21 ~CARTHUR RIVER I~LASKA _. SPERRY-SUN_WEL~.L SURVEYING COMPANY ANCHORAGE, ALASKA COMPUTATION DATE JANUARY 13, 197.5 P A_G_F~ -DATE OF SURVEY DECEMBER 28, 1974 'SURWEL GYROSCOPIC MULTISHOT SURVEY JOB NUMBER SU3-16947 KELLY BUSHING ELEV. = 99.00 FT. TRUE 4EASURED VERTICAL )EPTH DEPTH SUB-SEA COURSE COURSE VERTICAL INCLINATION DIRECTION DEPTH DEG MI N DEGREES DOG-L SEVERI DEG/1 EG TOTAL TY RECTANGULAR COORDINATES O0 NORTH/SOUTH EAST/WEST VERTICAL SECTION 3100 ....... 30~2,._91 ............. 2973.91 3200 3t64.30 3065.30 3300 3250.79 3151.79 3400 3334.31 3235.31 3500 3417.74 3318.74 3600 3501.43 3402.43 3700 3585.30 3486.30 3800 3669.44 3570.4% 3900 3753.71 3654.71 4000 3837.65 3'738.65 4100 3920.57 3821.57 4200 4002.29 3903.29 4300 4083.48 3984.48 4400 4164.69 /*065.69 4500 4246.04 4147.04 4600 4327.57 4228.57 4700 4409.27 4~'.27 · 4800 4490.54 4391.54 4900 4571.94 4472.94 EGGO 4654.38 4555.38 5100 4737.85 4638.85 5200 4822.00 4723.00 5300 4905.69 4806.69 5400 4988.41 4889.%1 5500 5070.40 4971.%0 5600 5151.47 5052.47 5700 5232.45 5133.a5 5800 5313.54 5214.54 59C0 5394.41 529~.4! 6000 5475.61 5370.oI ........... 2 0 .... 3 7 ...... S_._7 2 27 10 S 70.52 E 33 0 S 70. 8 E 33 43 S 69.90 E 2.05 68.91 S 195.19 5 195. .... 6.59 81.88 S 233.53 E 233- 5.83 98.79 S 280.70 E 281- 0.72 117.60 S 332.36 E 333. 60 67 09 22 33 12 S 69.78 E 33 10 S 69.58 E 32 50 S 69. 9 E 32 35- S 68.12 E 32 34 S 67.49 E 33 16 S 66.89 E 0.52 13.6.61 S 384.12 E 0.13 155.61 S 435.44 E 0...% 43__ 17.~.,8 3__.S_ .......... ~86._40_ E 0.58 194.54 S 536.71 E 0'.34 214.88 S 586.56 E 0.77 235.95 S- 636.65 E 385.54 437.52 489.36 540.99 592.65 644.95 34 41 S 66.30 E 1.45 35 43 S 65.70 E 1.09 35 43 S 65.58 E 0.09 35 40 S 65. 3 E O. 35 27 S 64.53 E O. 35 19 S 64. 3 E O. 258.15 S 687.93 E 698.89 281.60 S 740.59 E 754.68 305.68 S' 793.77 E 811.28 330.05 S 846.77 E 867.92 354.83 S 899.38 E 924.51 379.96 S 951.55 E 980.96 33 36 32 35 7 S 63.84 E 36 9 S 63.69 E 34 52 S 62.69 E 34 5 S 62.11 E 32 44 S 61.55 E 32 40 S 6i. 2 E 33 41 S 60.81 3/, 42 S 60.68 35 g S 60.50 36._ 30 S 59.97 35 20 S 59.87 36 1@ S 59.39 35 45 S 59.B'~, 35 36 S 5~.27 0.23 405.29 S 1003.35 E 1037.27 1.03 431.05 S 1055.61 5 1094.18 1.40 457.29_~ ~107~44.._.E 11~.9~_ 0.85 483.46 S 1157.61 E 1206.6i' 1.38 509.44 S 1206.1.4 E 1260.77 o.~9 535.~o s 1253.52 E 1314. oo 1.02 562.00 S 1.02 589.46 S 0.46 617.57 S 1.38 646.63 S 1'16 676.03 S 1.O0 705.62 S 0.53 735.61 S C.14 765.42 S 1301.34 E 1367.97 1350.37 E 1423.43 1400.24 E 1479.95 1451.04 E 1537.79 1501.80 E 1595.81 1552.28 E 1653.73 1602.~9 E 1712.~0 i~55.S~ 5 1769. SI SPERRY-SUN WELL sURVEYING COMPANY PAGE 3 UNION OIL OF CALIFORNIA GRAYLING G-2I MCARTHUR RIVER ALASKA ANCHORAGE, ALASKA COMPUTATION DATE JANUARY 13, 1975 'DATE OF SURVEY DECEMBER 28, 1974 SURWEL GYROSCOPIC MULTISHOT SURVEY JOB NUMBER SU3-16947 KELLY BUSHING ELEV. = 99.00 FT. TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG MIN COURSE DOG-LEG TOTAL DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEGREES OEG/IO0 NORTH/SOUTH EAST/WEST SECTION 6200 5639.50 -5540.50 34 23 S 60.49 E 6300 5722.26 5623.26 33 54 S 60.32 E 6400 5805.14 5706.14 34 9 S 60.98 E 6500 5887.72 5788.72 34 30 S 60.72 E 6600 5970.13 5871.13 34 30 S 60. 8 E 6700 6052.36 5953.36 34 53 S 59.81 E 6800 6134.29 60.35.29 35 5 S 59.25 E 6900 6215.87 6116.87 35 35 S 58.84 E 7000 6297.07 6195.07 35 50 S 59.38 E 7100 6378.27 6-279.27 35 35 S 59.47 E 0.55 0.49 0.44 0.38 O. 36 0.41 0.38 0.55 O. 40 0.26 822.36 S 1752.54 E 1883.09 850.07 S 1801.34 E 1938.53 877.50 S 1850.11 E 1993.76 904.97 S 1899.36 E 2049.39 932.94 S 1948.61 E 2105.34 961.45 S 1997.87 E 2161.64 990.52 S 2047.28 E 2218.40 1020.27 S 2096.88 E 2275.72 1050.23 S 214-6.96 E 2333.57 1079.92 S' 2197.21 E 2391.37 ?200 6459.73 7300 6541.18 7400 6622.15 7500 6702~86 7600 6783.88 7700 6865.83 7 8 o o -- 6'9-4-§;'44 7900 7032.24 8000 7115.18 6360.73 35 19 S 59.54 E 6442.18 35 36 S 59.18 E 6523.15 36 16 S 58.78 E 6603.86 36 6 S 58.41 E 6684.88 35 40 S 57.82 E 6766.83 34 15 5 56.20 E 6849.94 33 20 S 53.77 E 6933.24 33 50' S 52.58 E 7016.18 34 6 S 51.81 E 0.27 0.35 0.70 0.28 0.55 1.69 1109.35 S 2247.19 E 2448.80 1138.92 S. 2297.10 E 2506.25 1169.16 S 2347.39 E 2564.43 !199.92 S 2397'78 E 2623.01 I230.88 S 2447.55 E 2681.23 1262.06 S 2495.61 E 2738.24 8100 7198.09 7099.09 33 53 S 50.66 E 82C0 7281.08 7182.08 33 56 S 50. 5 E 8300 7363.89 7264.89 34 15 S 45.98 E 1.63 0.82 O. 50 0.68 0.34 2.30 1293.96 S 2541.15 E 2793.74 1327.11 S 2585.43 E 2849.02 1361.36 S 2629.57 E 2904.89-.. 1396.36 S 2673.16 E 2960.79 1431.95 S 2716.11 E 3016.57 1469.43 S 2757.75 E 3072.48 8400 7446.01 8500 7527.19 8600 7608.37 8700 7690.03 88OO 7771.S0 8900 7854.23 90C0 7937.65 91~0 ~02'~. 9C 7347.01 35 7428.19 36 7509.37 35 7591.03 35 7672.80 35 7755.23 33 7833.65 33 20 S 44.94 E 1.23 1509.45 S 2798.41 E 3129.22 7 S 44.86 E 0.78 1550.81 S 2839.62 E 3187.23 20 S 42.74 E 1.46 1592.94 S 2880.03 E 3245.09 11 S 41.52 E 0.72 1635.75 S 2918.76 E 3302.05 6 S 39. 3 E 1.43 1679.65 S 2955.96 E 3352.51 51 S 37.70 E 1.46 t724.02 S 299!.'~o E 34!3.64 5 S ..... ~,:~P ;~ C,cC 1767,~aI~ ~., 302~-.-~''=' =: ~4~ ~, 6 S 35,1:S .2 i, IS I~II,2'{ ,3 365o,.~i ~ 351:9,i3 UNION OIL OF CALIFORNIA GRAYLING G-21 S PE RRY-S U ~_WE LL_S _U.R_VE Y I N G COMPANY ANCHORAGE, ALASKA COMPUTAT!ON DATE PAGE 4 DATE OF SURVEY DECEMBER 28, 1974 SURWEL GYROSCOPIC MULTISHOT SURVEY HCARTHUR RIVER ALASKA JANUARY 13, 1975 JOB NUMBER SU3-16947 KELLY BUSHING ELEV. : 99.00 FT. MEASURED DEPTH TRUE VERTICAL SUB-SEA COURSE COURSE DOG-LEG TOTAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES DEPTH DEPTH ,_ 9300 8192.05 8093.04 DEG MIN DEGREES VERTICAL OEG/IO0 NORTH/SOUTH EAST/WEST SECTION . ....... ~1 ..... 4~ ......... $__3~,36 E 0.25 1697.5.6__s 32 15 S 32.94 E 0.91- 1941.66 S 33 6 S 31.27 E 1.24 198?.39 S 34 17 S 28.36 E 2.00 2035.51 S 9600 8276.86 8177.~6 9500 8361.03 8262.03 9600 8444.23 8345.23 9700 8525.73 8426.73 36 30 S 26.92 E 2.36 2086.82 S 3228;88 E 9800 8605.8% 8506.84 37 2 S 25.39 E 1.06 2140.54 S 3255.25 E 9900 8685.36 8586.36 37 37 S 24.42 E 0.83 2195.53 S 3280.78 E lO000 8764.44 8665.44 37 5:1 S 23.54 E 0.59 2251.45 S 3305.65 E 10100 8843.15 8744.15 38 19 S 23.46 E 0.47 2308.01 S 3330.25 E 10200 8921.69 '8822.69 38 lO S 22.41 E 0.66 2365.02 S 3354.37 E 10300 9000.56 8901.56 37 42 S 21.80 E 0.60 2421.97 S 3377.50 E 10400 9080.28 8981.28 36 34 S 20. 4 E 1.55 2478.34 .S 3399.06 E __10500 9161.21 ........... 9062. ~_1 .......... 35 .....22 ........... S__l 9_._97 E 1._20- 2 533..53. ~..S _. 10600 9243.09 914a.09 34 42 S 19.18 E 0.80 2587.61 S 10700 9325.70 9226.70 33 53 S 18.82 E 0.84 2640.88 S 10800 9409.22 9310.22 32 51 S 18. 2 E 1.12 .2693.06 S 10900 9493.83 9394.33 --31 33 S 17. 7 E 1.39 2743.86 S 11000 9579.69 9483.69 30 7 S 16.36 E 1.47 2792.94 S 3116.45'E 3619.82 3145.80 E 3670.26 3174.48 E 3721.19 3202.03 E 3772.73 3825.69 3879.80 3934.0A- 3988.33 4042.82 4097.20 4150.79 4202.79 3419.16 E 4252.8~' 3438.39 E 4301.6'~ 3456.73 E 4349- 18 3474.12 E 4395.29 3490.19 E 4439.52 3504.93 E 4481.64 HORIZONTAL DISPLACENE~:T = 4481.64 FEET AT SOUTH, 51 EEG. 27 MIN. EAST AT ND = 11000 THE C_AL_CU_LATI ON _pROC_EDU~ :2 S ARE BASED .ON _SHE_ _U!E__O~__T.d~_E.E___D!MEBS__I_C.NAL_R~DI US__.CF .... CURyATURE__MEI'_HOD.__ JNZON OIL OF CALIFORNIA ~,RAYLING G-2! ~-c~ ~T R u P,-- R iV E R It, LASKA SPERRY-SUN WELL SURVEYING COMPANY PAGE 5 ANCHORAGEt ALASKA COMPUTATION DATE JANUARY 13t 1975 DATE OF 'SURVEY DECEMBER 28t 1974 SURWEL GYROSCOPIC MULTISHOT SURVEY JOB NUMB ER SU3-16947 KELLY BUSHING ELEV. = 99.00 FT. ttLASKA KELLY BUSHING ELEV. = 99.00 FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF TRUE SUB-SEA TOTAL MEASURED VERrICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MEASURED DEPTH MD-TVD DIFFERENCE VERTICAL CORRECT ION 0 lO00 2000 30-00 0.00 -9~.00 0.00 0.00 0.00 999.92 900.g2 11.10 s 0.84 w 0.07 1999.84- 1900.84- 20.30 S 0.8.8 E 0.15 ~ 9 7 8.7 2 ....... -2'~ 7 ~ ,7 2 ...................... %. 8 7 s "'~ ....... ~.'~-'~'~'6,~--~- ' -~T~ ~-- 4000 3837.65 3738.65 235.95 S '~ 636.65 E ~ 162.34 5000 4654.38 4555.38 483.46 S~/ i 1157.61 E ~.l~ 345.62 6000 5475.61 5376.61 ~g-5'-~-2'-~ 'i~5~;06 E~ 524.38 7000 6297.07 6198.07 1050.23 S '~ 2146.96 E~, 702.92 ~o0o ..... ~15~__~.8_ .....~o.~a. ~8 ............. !~6~.36. S .~ ......2629~5~E ~/ 884.8 1 9000 7937.65 7838.65 1767.91 S~ 3024.48 E~ 1062.34 10000- 8764.44 8665.44 2251.45 S ~ 3305.65 E~° 1235.55 ILO00 9579.69 9480.69 2792.94 S~' 3504.93 E ~/ 1420.30 0.07 0.08 21.12 141.06 "183.27 178.76 178.54 181.88 177.52 173.21 184.75 THE CALCULATION PROCEDURES ARE BASED ON' THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. SPERRY-SUN WELL SURVEYING COMPANY PAGE 6 UNION OIL OF CALIFORNIA GRAYLING G-21 HCARTHUR RIVER ALASKA ANCHORAGE~ ALASKA COMP'UTATION DATE JANUARY 13, 1975 -DATE OF SURVEY DECEMBER 28, 197~, - SURWEL GYROSCOPIC MULTISHOT SURVEY JOB NUMBER SU3-16947 KELLY BUSHING ELEV. = 99.00 FT' INTERPOLATED VALUES FOR EVEN 100 FEET OF .SUB-SEA DEPTH MEASURED DEPTH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES DEPTH NORTH/SOUTH EAST/WEST 0 0.00 -99.00 0.00 0.00 99 99.00 0.00 0.40 S 0..12 W M.D-TVD DIFFERENCE VERTICAL CORRECT ION 0.00 0o00 0.00 199 199.00 100.00 1.39 S 0.43 299 299.00 200.00 2.53 S 0.82 399 399'00 300.00 3.64 S 1.29 499 499.00 400.00 4.79 S 1.60 599 599.00 500.00 6.04 S 1.57 699 699.00 600.00 7.32 S 1.36 ]99 799.00 700.00 8.56 S 1.04 899 899.00 800.00 9.83 S 0.82 0.00 0.00 0.01 0o00 0.02 0.00 0.02 0.00 0.03 0.00 0.04 - 0.00 0.05 0-00 0.06 0.00 999 999.00 900.00 11.08 S 0.84 W 1099 1099.00 IO00.O0 12.25 S 0.89 W 1199 1199.00 I100.00 13-41 S 0.96 W 1299 1299.00 1200.00 14.58 S '1.02 W 1399 139~)-~-b 0 1300-:bO i5:76 S 1.00 W 1499 1499.00 1400.00 16'94 S 0.97 W 1599 1599.00 1500.00 18.07 S 0.59 W 1699 1699.00 1600.00 19.17 S 0.23 E 1799 1799.00 1700.00 20.~3 S 1.22 E 0.07 0.00 0.07 0.00 0.08 0.00 0.09 0.00 O.Og 0.00 O.lO 0-00 0.11 0.00 0.12 0.00 0.13 0.01 SPERRY-SUN WELL SURVEYING COMPANY PAGE 7 ~NION OIL OF CALIFORNIA 3RAYLING G-21 ANCHORAGE, ALASKA COMPUTATION DATE :_DATE O'F SURVEY DECEMBER 28, SURWEL GYROSCOPIC MULTISHOT 1974 SURVE'~ MCARTHUR RIVER ~LASKA JANUARY 13, 1975 JOB NUMBER SU3-16947 KELLY.BUSHING ELEV. = 99.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 20.93 S 1.76 E 0.14 0.00 20.31 S 0.89 E 0.15 0.01 1899 1899.00 1800.00 1999 1999.00 1900.00 2099 2099.00 2000.00 18.89 S 0.77 W 0.17 0.02 2199 2199.00 2100.00 18.97 S 0.39 E 0.20 . 0.02 2299 2299.'00 2200.00 20.5'5 S 6.87 E 0.43 0.23 2400 2399.00 2300.00 20.76 S 18.68 E 1.14 0.71 250I 2499.00 2400.00 21.71 S 34.57 E 2.43 1.28 2603 2599.00 2500.00 26.64 S 54.10 E 4.45 2.02 2706 2699.00 2600.00 34.02 S 78.90 E 7.76 3.30 2811 2799.00 2700.00 42.27 S 107.62 E 12.13 4.37 2916 2899.00 2800.00 51.21S 138.02 E '17.04 4.90 '--~'02! ..... 2g~g. O0 '--290'0'00 .............. ~0i88-"S ........ i6~"7i--E 22.39 5.34 3128,~ 3099.00 3000.00 72.11 S 205.04 E 29.06 6.67 . 3239 3199.00 3100.00 88.15 S 251.15 E 40.42 11.35 3357-- 32-9-g.-6'o 32001-00 109.51 S 310.25 E 58.55 --18.1"3 3477 3399.00 3300.00 132.37 S 372.61 E 78.60 20.04 3597 3499.00 3400.00 155.06 S 433.95 E 98.09 19.49 3716 3599.00 3500.00 177.99 S 494.66 E 117.30 19.21 3835 3699.00 3600.00 201.58 S 554.2/+ E 136.07 18.77 NION OIL OF RAYLING (;-21 CALIFORNIA SPERRY-SUN._~.E.LL SURVEYING COMPANY ANCHGRAGE, ALASKA COMPUTATION DATE DATE OF SURVEY DECEMBER - PAGE 8 28, 1974 SURWEL GYROSCOPIC MULTISHOT SURVEY CARTHUR RIVER JANUARY I3, 1975 LASKA - JOB NUMBEJ~ SU3-16947 KELLY BUSHING ELEVo = 99o00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL EASURED VERTICAL -VERTICAL RECTANGULAR COORDINATES MD-TVD EPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE 3953 3799.00 3700.00 226.03 S 613.36 E 154.79 4073 3899.00 3800.00 252.15 S 674.26 E 174.75 VERTICAL CORRECTION 18.71 19.96 4195 3999.00 3900.00 280.62 S 738.43 E 196.94 4319 4099.00 4000.00 310.29 S 803.93 E 220.11 - 4142 4199.00 4100.00 340.45 S 869.08 E 243.22 4564 4299.00 4200.00 371.-09 S 933.35 E 265.97 4687 4399.00 4300.00 402.1'1 S 996.87 E 288.43 4810 4499.00 4400.00 433.78 S 1061.14 E 311.46 4932 4599°00 4500.00 465.88 S 1124.19 E 333.97 5053 4699.00 4600.00 497.52 S 1184.10 E 354.76 5172 4799.00 4700.00 528.25 S 1240.62 E 373.67 5291 4899.00 4800.00 559.82 S 1297.44 E 392.95 22.18 23.16 23.10 22.75 22.46 23.02 22.50 20.79 18.91 1.9.27 5412 4999.00 4900.00 593.05 S 1356.76 E 413.88 5534 5099.00 5000.00 627.49 S 1417.77 E 435.98 565~ 5199.00 5100.00 66,.12 s 1481.27 E 459.9~ 5781 5z9~.oo 52oo.oo 7oo.18 s ~3.o~ ~ ~2.~ 5905 5399.00 5300.00 737.30 S 1605..73 E 506.65 6028 --5499.00 5400.00 .............. 773-'98-S ....... '1'66~"~"46 E ~529.7'7 6~5o 5599. oo 55o,~.oo ~os.s8 s ~s.37 ~ . 20.92- 22.09 24.00 22.97 23770.. 23.11 22.12 S. PERRY-SUN WELL SURVEYING COMPANY PAGE 9 UNION OIL OF CALIFORNIA GRAYLING G-21 MCARTHUR RIVER ANCHORAGE, ALASKA COMPUTATION DATE ~DATE OF SURVEY DECEMBER 28, 1974 --SURWEL GYROSCOPIC MULTISHOT SURVEY JANUARY 13, 1975 JOB NUMBER SU3-16947 ALASKA KELLY BUSHING ELEV. = 99.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATE.S DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6271 5699,00 5600.00 842.33 S 1787.76 E 6392 5799.00 5700.00 875.48 S 1846.47 E 6513 5899.00 5800.00 908.75 S 1906.I2 E 6635 5gg9. CO 5900.00 942.84 S 1965.80 E 6756 6099.00 6000.00 977.86 S 2025.98 E 6879 6Igg. o0 6100.00 I014o02 S 2086.55 E 7002 6299.00 6200.00 1050.94 S 2148.16 E 7125 6399.00 6300.00 1087.46 5 2209.99 E 7248 6499.00 6400.00 1123.48 S 2271.18 E 7371 6599.00 6500.00 1160.36 S 2332.86 E 7495 6699.00 6600.00 1198.45 S 2395.38 E 7618' 6799.00 6700.00 1236.66 S 2456.73 E 7740 6899.00 6800.00 1274.62 S 2514.37 E 7859 6999.00 6900.00 1313.57 S 2567.73 E 7980 709~.~0 7000.0'0 ...... i3~4~58 S 262~6 E 8101 7199.00 7100.00 1396.75 S 2673.63 E 8221 7299.00 720{).00 1439.69 S 2725.35 E 8342 7399.00 7300.00 1486.07 S 2774.94 E 8465 7499.00 7400.00 1536.23 S 2825.11 E 572.97 21.07 593.57 20.60 614.67 21.10 636.02 21.34 657.87 21.85 .. 680.25 22.37 703.38 23.12 726.49 - 23.11 749.14 22.64 772.28 23.14 796.21 23.93 819.60 23.38 841.12 21.51 860.97 I9.85 881.45 20.48 902.09 20.63 922.59 20.49 943.4E 20.88 966.09 22.61 SPERRY-SUN WELL SURVEYING COMPANY PAGE 10 JNION OIL OF CALIFORNIA ;RAYLING G-21 ~CARTHUR RIVER ANCHOR.AGEt ALASKA COMPUTATION DATE JANUARY 13, 1975 DATE OF SURVEY DECEMBER 28, 1974 SURWEL GYROSCOPIC MULTISHOT SURVEY _ JOB NUMBER SU3-16947 ~LASKA KELLY BUSHING ELEV. : 99.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASURED VER'TICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH NORTH/SOUTH_ ....... EAST/WEST DIFFERENCE 8588 7599.00 7500.00 8710 7699.00 7600.00 8833 7799.00 7700.00 8953 7899.00 7800.00 9072 7999.00 7900°00 9190 8099.00 8000.00 9308 8199.00 8100.00 9426 8299.00 8200.00 9545 8399.00 8300.00 9666 8499.00 8400.00 9791 ' 8599.00 8500.00 1588.06 S 2875.52 E 989.50 23.41 1640.,48 S 2922.95 E 1011.96 22.46 1694-.-5'0 S 2967.99 E 1034.23 22.26 1747.72 S 3009.34 E 1054.83 20.59 1799.64 S 3047.99 E 1073.96 19.I2 -i8'~0'-* 3 5-S' ......... '3-0 $'4-~' 0 5 E 1091.74 17.78 1901. lt S 3118.88 E 1109.17 17.43 9917 8699.00 8600.00 10o43 8799.00 8700.00 10171 889-9.00 8800.00 1 ~)-2"~8 - 899'9. O0 8 ~-O-c~-0--0 10423 9099.00 9000.00 10546 9199.00 9100.00 10667 9299.00 9200.00 10787 9399.00 9300.00 1953.39 S 3153.40 E 1127.18 ' 18.00 2008.64--S 3187.30 E 1146.36 19.18 2069.18 S 3219.92 E 1167.74 21.38 2135.88 S 3253.04 E 1192_.~3 __24.68 ......... 2205'10 S 3285.13 E 1218.22 25.78 2276.08 S 3316.38 E 1244.77 26.55 2348.52 S 3347.57 E 1272.13 27.36 2420.85 S 3377.05 E 1299.02 26.88 2491.39 S 3403.82 E 1324.30 25.28 2558.70 S 3428.28 E 13477..3i 23.00 ........ 2623.90 S 3450.95 E 1368.83 21.51 2686.78 S 3472.08 E 1388.83 20.00 ,. ',, ,SPERRY-SUN WELL SURVEYING COMPANY' PAGE 11 UNION OIl OF CALIFORNIA GRAYLING G-2I ANCHORAGE,. ALASKA COMPUTATION DATE DATE OF 'SURVEY DECEMBER 28~ 1974 SURWEL GYROSCOPIC MULTISHOT SURVEY MCARTHUR RIVER ~.LASKA JANUARY 13, 1975 JOB NUMBER SU3-16947 KELLY BUSHING ELEV. = 99.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COOROINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORR:ECT ION 10906 9499.00 9400.00 2746.89 S 3491.12 E 1407.06 ilO00 9579.69 9480.69 2792.94 S 3504°93 E 1420.30 18.22 13.24 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS ~ ~. ~ ~ . ~ , -- ~ t ~ , ' ~ ~ ~--~-':-----'-~- -, '~-------~ .................. r-'-r-4~ ~ '-----~ --.--'-'----r'-, · - - ," ' , j '. ,, . .'-t--i--'FT.,,t t'fi--~- .-' , , i . ','--T-,. . - .. r-l, . :--7-t , . =-FT-i'?-; , ...... V'7't; , .... -.ir'-_ ~- ~-, ~t--t . : - ~"~-"fi-'" ~ - ' ' "- i --h,-t'-- - j j'----]-- -'"q- ..... ,-h- - _ ' I J J J I il Il J Jl .j J J t i J J J j ' I l i !-- il ! ! J J J J t Il L_I .LL--L LI_J LLI ,,. J LLL_! .LIli i i I t _-J_ i l! i._J-.LIMj__.L,,L~_~:~LJ,_L_~ LI ~iit l! l! _i l Ii I_L_! ! .l J~ '. ~ ' . ....... t J , , J t . !, ~~ ~ i ' I ' , ~ , ~ j , ~ , ' ~ ~ , [ T-F-F- ! J I I i t i ]~.~ I J%"'"'~L_ , I t f J I . J J 'J-j [~L-J J il I J J ILI J j , ! I J j j ~ ! !_ilL I i i i ~ ~ : i ~.-', I ! .L-J t.._j-~,-~ ,~ I--; i i ' '- ~ ' - / j I - - ' i I ' i -- i I--~ ~ ~ i---' I t -i t t i . t I ~ J i "~'~,~i "'~j ~ i i ~"~ i ~ ~ -I i_ i -f -F'i- ; F'-F,,'T- i _~__- .-T-Fi- 1111 i-~-ii*l I I! Ittti ~I ~_~_.,~i._j ,,"!%i I ~ i I i _;,_LL_L_._Lj'i_.~L !_L_LJ__ ~-t ~ ~ ii i-F! i j N i ! ii!! .I i.-F,,-]~_j i -T- I I i i i i i I t i , :___j! I ] i-'~ ! I -' , ½ L,,, .,"FL.,,,,,, i i- _f-]--~t i : t ' It i% itlt I t, ~ l i iN , , , t l ,'~.~._]%1' I ' _ ~. j . ~' , ' ' ~ ! ' ', , ' ' ,~ ', ~ I I ! i i I i I I ! i i I I I tl i. I I i i i I -~! i , , .I ~' I Z_ 4~.i_r i j i ,,I~(_,' _T-i ..... ! I · I ' ' , ,' ! I ' ' ' , ' ' ' ' , ~.. _1 ' j , i , ~ 'JN,,~ ii'N!7'1 ! f , i i il ti !1 , %!i ' _ I',' ~- ! I ! ! i"~-.__ ~!. ~__i~._=~...L ,,: ;t ~ i . , ~ :.'_;_.'_: ~ !ii! ilili ii i I t ~ il t!~l ~i;j i !lt!~ I i 'N" ~F~;Ii!~"~'~-:~..'':iI I ...... , I , ' ' ~ .1 ', ' t ' '. : ' ,' : ~' t I : ' ' ' , , , . ,. . j . , : . , , , -~-- ' ' i .... ,-h'- ' ' - ' : ' ~-'~:- .... -~-- ~+--:- . , , , , , , L ........... T-- .... I ~ ~ ' ' ' : ' i ' --~--' ,--F- '-'?-,-- ....... ? - --- ' ' , -'--, -- J , ~ , ' : ; i ~ i : t , . j , ' , . , . t . , : : · , ; ' . . : , . , ~ I .... , , ,' f , ' '.-I-L- . ' -~------,-~,'---- '''-. '.~.--.--- ~--;--~, - - ~ .... L__~ i . , ~ -~---. -' ' - .... :-- ~ ' -- ~w ' : ..... [--' .............. ' ' ......... .......... _,__..: .... __, , .... ,..::t . : L ' ' ' : ' J ' 'i I ! !" ' i ; ' 4 : . ~ · ' ' I .~' ~ : : I .--' . _L_L I ...... i .-- ..... 7--- · . , ': J i ....... .--~ --- ! ~-~'-~-'~ ............... -:-7-.' F:----:--t~-, . , J ...... ~: '. : i, :, . . -~:' b=-J-:__ :J '~ .... ~--_~:.__'._ j_--'..; .__i : L'_L___ [~_::_' i=' '=---~---L: .......... :---:-.~'J--~- DIRECTIONAL SURVEY REPORT TANGENTIAL CALCULATIONS FOR UNION OIL COMPANY OF CALIFORNIA ...... i I ii i ii i i i ii i rV~ OF SURVEY' Gyroscopic Directional Multishot Surface SURVEY DEPTH: FROM,, , Grayling, TBU State McArthur River FIELD:, ....... ~_~. rt. TO 11~000 , WELL NO. O-21 COUNTY/PARISH,Kenai Peninsula Borough Alaska STATF I:~TE OF $URVEY~ December 8,, ,1974 JOB NO, SU-3-16~47 _ . _ O~FICi: ...... Anchorage, Alaska UNION OIL COMPANY OF CALIFORNIA GRAYLING WELL NO, G-21 MC~RTHUR RIVER DECEr-'tBER 2B,'.197~+ VERTICAL SECTIOt, j cOMPUTED -PAGE ! ;SURVEY .DATE' ALONG CLOSORE KENAI PENNiSULA BOROUGH, ALASKA SP£RRY-SU~.~ NELL SURVEYING COMPANY RECORD OF SUEVEY TRUE INCLINATION OIRECTiO~; DOG-LEG ~EARURED VERTICAL SUB-SEA SEVERITY VERTICAL OEPTH DEPTH DEPTH DEG ~.~iN OEG ~IN DEG/IO0 SECTION .RECTAN6ULAR COORDINATES O, -9~, 100. O, 0,00 0,00 O0 ORIGIN AT THE SURFACE 99.~3 99 0 30 S 17,58 W 0.31 ' · ": "0.00 N " 0,83 S 0,00 W 0,26 W 200, I9'9.98 100,98 0 ~1 S i7,16 ~ 0.!8 0,75. 300. 299,98 200,98 0 ~2 S 20.7~ ~ O,Og 1.13 0,61 W ~,0~ ~'~ ~00, 599,97 500,97 0 41 500, 499,96 q00,96 0 ~2 S 6,2~ ~! 0,21 2,08 600, 599,95 500,95 0 ~5 $ 8,80 E 0,19- 5,0~ 700, 699,95 600,95 0 ~ S 10,~9 E 0.02 ~,01 800, 799.9~ 700,9~ 0 qq S 18,1~ E 0,09 5.08 5,~1 S -1,5~ W I',67 W 6,70 7,96 S 9,18 1,24 W 900, 899,93 800,93 0 ~6 S 1,23 E 0,22 5.9~ 10,51 S _. 1000, 999,92 900,92 0 ~0 S 3.25 ~ 0.11 6,62 11,68 S 1180, 1699,91 1000,91 _. 0 ~O S 1,73 N 0,01 7,3~ ,- 12,8~ S 0.81 W 0,88 W Oegl ' 1200. 1199.91 1100.91 0 40 S ~.72 W 0.03 7.97 1~.00 S 1,01 W I~00, 1299,90 1200,90 0 ~1 S 1.69 ;~ 0.03 6,69 lqO0, 1399',89 1300,89 0 ~0 S. 5,8~ E 0,06 9,~7 15.19 S 16,~5 S 1,0~ 1500, 1600. 1700. --'~'g99',g'~ 1~00,89 0 gl S 0,1~3 W 0,0~ 10,22 17,5~ 15~9.88 lSO0,~B 0 ~5 S 35.76 E 0,~ 11.~8 169= 87 1600.~7 0 =0 S 58.5~ E 0.05 12.90 19.7~ S . 0,97 0.20 0,69 · - - =~ E 0.09 lq,a8 20,93 1800, 1799,85 1700,85 0 ~5 S *~,-.- . 20,76 S' .. 1.76 E 3.12 E. 1,35 E t ~5.~0 .-: ~.19 11.~% 19,20 S c .ti7 Z ~ ~ ........ ' ~7 S ' .:S ~=.?S 23, c :-,Sv : : '~: 2~.== 22,5~ S 0 ', 21 12.YE £ UNION (]IL CO~"PANY,', Of CALIFORNIA ,. DECE'~BER '28, VERTICAL SECTION COMDUTEO PAGE 2 SURVEY 'CATE ALO~JG CLOSURE' KENAI Pc~-~&ISULA BOROUGH, ALASKA SPERRY-SUi~ WELL SURVEYING COMPANY SU-3-1G9~? RECORD OF SURVEY TRUE INC~ N~I 0~.~ OiRECTION DOG-LE: AE~TANGUL~R MEARURED VERTICAL SUB-SEA SEV£E~TY VERTICAL COORDINATES CEPT~ DEPTH OEPTH OEG ihlN BEG M!N BEG/lO0 SECTION 2~+00. 2398.22 2299,22 8 20 N 86,1~ E 3,~2 3ur,_~3 21,38 S 2500, 2~6,75 2397,75 9 50 S 80,65 E 8.55 ~9.51 2~,15 S 2600, 259~'5 2~95.25 l~'i S 72.~g E ~,~i ~0~ ~O,6g S - 2700. 2690.~ 2591.~ 15 5~ S 7~. 7 E 5.05 95.~7 ~6.37 S ._ ~ GO 2785~,98 2686 96 17 10 S 75,92 E 1.2.3 122.71 46,5q S 2900, 2~.~I:.17 2782,17 17 50 S 73,%3 E 0.6~3 15i.07 55.28 S 27,2~ ~.09 65.30 1i9.96 E 1~9.33 E 3000, 2975.~'~" 2876.97 18 ~ S 72.85 E 0,75 180.6~' 6~,67 3100, 306~'.56 2970,56 20 37 S 72,33 E 2,05 213.5~ 75,35 3200. 3158.53 3059,53 27 I0 $ 70.52 E 6.59 25G,&5 90.5~ !7~,75 213.30 256,35 3300, 32~+2,~+0 31~3.Q0 33 0 S 70. S E 5.63 308.20 109.1~ S ~.~O0, 3325,58 522~,58 33 ~3 S 69,90 E 0,72 :SGO.&O 128,21 S S500, 3~-09'2S 0,"52 ~i2,72 i~7,i~ S 3600, 3~92,96 0.11 ~6%.6& !66,23 S 3510,25 ~3 12 S 69,76 E 3393.96 33 10 S 67.58 E 307.55 359,G8 ~!1.06 ~62.33 3700, 3576,99 3~77,99 32 50 $ 69, 9 E O.ff2 516,27 185,58 S 3800, 3661,25 3562,25 32 35 $ 6~.12 E 0,55 567.61 205,65 S 512,95 562,96 3900. 37a5,53 36~6,55 32 3~ · , aOOc, 3829.1~ 3730.1~ 33 16 _ ' ~7 3812 =7 3~ ~1 ~lOO. 3911, ... . 55 ~5 3~ ~0 67.~9 E 0.3'3 G19.~O 22&.25 S 66.89 E 0.77 672.33 2~7.7~ S &g.3~ f -. 1.q5 727,2~ 270.66 S .. 6~.70 E 1.'Ga 78~.~2 29~.6S S 65. 5 E n 32 -=7.j! 3~~ %5 S 6'i2,6s 665,1~ 715.2q 768.~q 82!,&0 ? 7 o. 79 - . E UNION OiL CO~.iPANY GRAYLiN$ WELL MC_ARTHUR RIVER OF CALIFORNIA ,. OECEF!BER 28, VERTICAL SECTION-COHPUTEO P~GE 3 SURV.EY OATE ALONG CLOSURE' KEFiAI PENNISULA BOROUGH, ALASKA SPERRY SU:~ WELL SURVEYING COHPA~'~Y SU-3-189~7 RECORD OF SURVEY TRUE ZFCCLINATIO{~ MEARURED VERTICAL SUB-SEA ~EPTH BERTH DEPTH OEG PiIN OIRECTION BOG-LEG SEVERITY VERTICAL DEG MiN OEG/IO0 SECTIOr\; RECTANGULAR COORDINATES 5100, ~72~,59 ~830,59 32 ~ S 63.69 E 1.05 1123,60 S 62.69 E I.~0 1179.63 S J2,11 E 0,8~ 123'.&7 ~5.19 S 1083,30 E ~71.~2 S 113~.10 E ~7.63 S 1185.65 E S .~5 E 1.5*o 1287.88 523,33 S 1231.17 E 5200, '815.77 ~71~,77 ~2 ~O 5500, ~896,98 ~797,98 ~5 ~1 S 61. 2 E 0,2~ 1541.07 S ~0.81 E 1.02 !~95.77 5~,5~ S 1278,~9 E 576,59 S 1326.80 E 5~Q,P. ~979,20 ~880,20 5~ ~2 60.68 E 1,01 1~51.95 60~.~7 S 137G.a~ E 5500, 5.0,6.0..,.96 ~961.96 35 9 5600. 5i.~;-i. ~5 50~2. ~5 S& ~o S 60.50 E 0.~6 1508.75 =8 1567.5~' S 59,97 E 1,~ 652,82 S 1426.55 E 6S~ 59 S ~78,05 E 570 O, 5222;95 512:5,93 55 20 5800, 530:3,52 520q',52 56 18 5~00. 558;'~-~g~52e 5 . 66 KS--ge 6000. 5~&5.9~ 5~66.9(+ 35 ;58 6100, 5~.~+-7 . 92 5q.q-8,92 3~-6 6200. 5630,~5 5531,~5 3~ 25 ~5 '56ia.a5 ~3 5q &3CO, 5713, , . 6frO0. 5796,21 5697,21 5~ 9 6500. 5878,62 5779,&2 3q 50 .., $ 59,87 E 1,16 162~.73 S 59,39 E 1.OO S 59,30 E 0,5'5 17'~-1',2i 69i.62 S 1528.0~ E 721.7& S 1579.02 E 7'51,60 $ 162-9.'-~7 Z S 59,27 E 0.13 1798,91 A-~ 02 1855,%2 S 60.-~ E 1, S 60.~9 E 0.55 19!1,1~ S 60,32 E--O.~9 S 60,95 E 0.~% 2021,57 S &0.72 E 0,37 2077,~ 781.37 S 809,52 S 1679.35 E ~29.22 E 1776.37 E as~.95 s 1;52 .~2 852.18 s la75.si 919.89 s 1925.52 6600. 5961.03 5862.q3 5~ 50 Gn~3 06 59~ ~6 3~ 55 67U0. ......... <._: , ........ ~q 602c, S 59,~1 E 0.~I 21:0...-'. s~ = ~;'2'5 :'6 ..... ~.57'-- 2z~:. ,~ =--'-'~ 9~8,1~ S 197%,%1 E 976.90 S 2025,3~ E lOGS.=,-' ~ .-='~--', - ~900, 7100 , .. ~-' S 5~ ~% ~ 32q6.22 61~7,~ ,:-. ~u.~Je ~ ~.-- ~ - , 2123.~ ~ 2a:3.55 :'l UNION OIL COMPANY OF CALIFORNI.~ GRAYLING WELL NO, G-21 ~MCARTHUR RIYER PF_NNISULA BOROUGH, ALASKA SPERRY-SdN ~4ELL PAGE .... OECEF::BER 28, 197.~d SURVEY OATE VERTICAL S.ECTI ,'..~ COMPUTED "CL ALu':~ OSUR'E , , . SURVETIN6 CONPAMY TRUE ARURED VE,RTICAL SUB-SEA OEPTH DEPTH OEPTH RECORD OF SURVEY I N C L-I-N A--A-TI 0 N0TR-E~:~ 0 N O-~B~- E! e SEVERITY DEG MIN DEG MI?,I OEG/IO0 VERTICAL SECTIOhl R-E'C-~A i'~t G U L A R COORDINATES 7200. 7300. 6~50.22 6351,22 6531.53 6~32.55 --6512,16~ 6~13,16 7~00o ~5 19 S 59.5~ E 0,,26 35 ~6 s 5~.18 z '~o'.35 5~ 16 $ 58,?~ E 0,70 2~77.33 1125,08 $ 253%.99 1154~.90 S 2273.36 E 2323,3G E. 2 ~ 7"ST~'E .... 7500. 6692,95 ~593.95 36 8 S 58.~1 E 0,27 2652,0~ 12!~,~ S 2~2~,13 E 7600, 677~,20 6675.20 7700, 6856.86 6757,86 7800. '6'9q7'0. ~ 0 68~.!.~0 7900, 7023.q-7 692~.q7 8000. 710~.28 70o7.28 35 ~.0 S 57,82 E 3~ 15 S ¢,- 20 E 3;5 50 S 5~.58 = 3~ 6 S 51.81 E 0,55 2TiO,C2 12~7,~3 S 1,&9 2716,09 1276,7~ S - 1.65-- '2820.~9 i311,27 S 0,82 2576,65 1~5.10 S 0.50 29~2.71 1379,T6 S 2~73.~8 E 2520,25 E 2608,80 E 2652,86 E ' 8100, 7189,29 7090,29 8200, 7272,26 7173,26 8500, 735~,92 7255.92 6~ 53 $ 50,66 E 33 56 S 50. 5 E 3~ 15 $ 45,98 E 0.67 2~88,~6 1~15.1~ S 2695,98 E 0,34 30~.27 1~50.95 S 2738,77 E 2.50 3100.31 1~50,0~ S 2¢7~.2~ E 8~00. 7~56.50 753T.50 8500. 7517,2B 7~18.28 8600, 7558,86 7~$9.85 ~700. 8800. 76S0,60 75~1,60 7762,~1 7665,%1 78~5,~6 7746,~6 .. . ~5 20 $ ~.gq E $6 7 S ~,86 E ~5 20 S ~2.7~ E _ ~5 11 S ~1,5~ E 35 6 S 39, 3 E $3 51 S 37.70 E 1,23 3157.79 1530,99 S 2820,09 E 0,78 3216,37 1572,7d S 2861,&7 E 1,~6 3273,5& 1615,25 S 2900,92 E 0"~-72 3330,~5 1655,59 S 2959,12 E 1,~3 3586,5x 1703,06 S 2975,33 E 1.~5 3~0.69 17~7.i~ S 3009,35 E 9000,. ~160. 7929.25 7830.25 8013.96 791~.9& 8099,22 8000,22 5400. 8o&£.A5 ci':c ~= 33 5 S 36,82 32 6 S 35.88 E 0.90 3993,5~ 1790,85 S 30~2,10 E 1,1;3 3.~q~. 79 !8~.5,8C S 3073,25 E 3,92 35'9:+,~5.~ f~77&,92 S 3102,.57 52 "5 S ~2.9~ UNION OI~ COMPANY OF CALIFORNIA PAGE 5 GRAYLING WELL NO, G-21 MCCRTHUR RIVER OECENBER ~8, 1974 SURVEY DATE VERTICAL SECTION COMPUTED ALONG CLOSURE KENAI PENNISULA BOROUGH, ALASKA SPERRY-$U~,~} HELL SURVEYING CO~iPANY SU-3-15947 TRUE MEARURED VERTICAL SUB-SEA DEPTH OEPTH DEPTH RECORD OF SURVEY Ih;CLINATIo;,! DEG 2iRECTIO~; DOG-LEG SEVERITY VERTICAL DEG NIN BEG/lO0 SECTIOiki RECTANGULAR COORDINATES ~600. 8~5.25 8~36,25 3~ 17 S 26,36 E 2.00 3799.01 2061,37 S 3216.68 E ~700, 8515.63 841~.63 ~6 50 S 26,92 E 2.36 ~855.20 2114.~1 S ~243.6.1 E 9800. 8595.~6 8~6,46 ~7 2 S 25,~9 E --1.05 ~9~'?.37 2168.82 S ~26~,45 E 9900. 867q.67 8575,6? ~7 ~7 S 24.~2 E 0,82 , ~961.85 222~.40 S ~29~.67 E 10000, 875~.65 8654.6~ ~7 ~1 S 2~.5~ E 0.58 ~016.17 2280,65 S 5319,17 E IOzIO0. ,, 8.B52.09 87~,09 ~8 i9 S 2~.q6 E 0,46 4071,01 2537,52 S ~q~,85 E 10200, 8910.71 8811,71 ~8 lO S 22,41 'E 0,66--4125o1~ ~$94.~-5 S ~5---~7,41 E 10~00, 8~89,8~ 8890,84 ~7 q2 $ 21.80 ~ 0,59 ~178,~7 2~51,~3 S ~390.12 E ~0400, ~070.15 8971,15 ~6 34 S 20, ~ E . 1..55 4229,~2 2507,~0 S 3410,54 E 10'500, 9151.70 9052.70 ~5 22 S 19,9T E 1.20 4278.78 25gl.80 S ~50.~1 E 10600. 92.~3.91 91~4.91 ~ ~2 S 19.18 E 0.$0 4527.01 2~15.57 S ~4~9.01 E 10800. 9400,94 9~01,9% ~2 5t S 18, 2 E 1,12 10900, 9486~-16 9~7,i6 51 5~ S 17. 7 E 1.]? 110.00. 9572.66 9~75.G6 50 7 S i6,56 E 1,47 ~19.42 2719.92 S 3453.77 E 4505.55 28'18.09 S 551~.27 E **~, THE CALCUL&TiOH PROCEDURES A~RE 8~S=00i~ THE USE 3F'T!~ TA,,;G£r,]TIAL SR CHORD }iETHO~. HORIZO:,iTAL SISPi_ACE:¢- :T : ~E53,"5 ¢SET ~T ~O,JTH ~l dEG. 15 :'-'I?". EAST(TRUe) · No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS NAME OF OPERATOR UNION OIL COMPANY OF CALIF. 3. ADbRESS 909 West 9th Avenue, Anchorase 4. LOCATION OF W,~, , Alaska 99501 Conductor #2, Leg #3, 1802'N & 1415'W of the SE corner. Section 29: T9N, R13W, S. M. SUBMFr ]3N' DU?LICATE APl NUA{ERICA3L CODE 50-133-20267 LEASE DESiGIh~AT'IoN AND SEIqIAL NO, ADL- 18730 IF INDIAk~. ALOT'T'£E OR TRIBE NAME 8. L~IT FAJ~{ OR LEASE NAME Trading Bay Unit WEL~. NO Stal~e G-21 (21,33) l0 FLF, JhD A31D P~L. OR WILDCAT McArthur River Field - Hemlock 11 S~C. T.. R.. M. (~)~OM HO~ °~~2700'S, 3830'E of surface location or 925'S, 2410'E of NW corner, Sec. 33" TgN. R13W~SM 1~ P~IT NO 74-42 13. REPORT TOTAL DEPTH AT F2'~D OF MON~-t_, CHA~NGES IN HOLE SIZE, CASING AND C~VlF~TING JOBS INCLUDING DEPTH SET A/~q~ VOLLqVlF~ USED, PERFORATIONS, TESTS ANT) i:~ESULTS FISHING JOt~ JloLiX/K IN HOLE AND SIDE-TRACKED HOLE AND A3~Y OTH~,R SIGNIFICANT ~GF~S IN HOLI~ CONDITIONS RU Schlumberger. RanCBL-VDL Log. Had bond to 1900' & partial bond to 1300'. Installed 12" 3M BOPE & tested to UOCO specs. Circ. out gas bubble in 13 3/8" csg. Squeezed DV tool ports @ 2595' w/ 1150 sx. Class "G" cmt. in two stages. Closed ports inDV tool & tested csg. w/ 2000 psi. Held-ok. Press. tested 13 3/8" X 20" csg. annulus w/ 800 psi. Held-ok. Reran CBL & had indication of cmt. to surface in 13 3/8" X 20" annulus. Drilled out 13 3/8" csg. shoe & tested formation & csg. seat equivalent to .650 psi/ft, gradient. Directionally drilled 12 1/4" hole to 11,105'. RU Schlumberger & ran DIL, BHC-Sonic & FDC-CNL-Density logs. Made cond. trip & deepened well to 11,160' Set 9 5/8" csg. as per design @ 11,160' & cementedw/2000 sx. Class "G" w/ .75% D-31, .5%D-19, .1%R-5 & .1%D-6 additives. RanCBL-GR-VDL Log. Bond in Hemlock ok..Set Baker ModelF-1 prod. pkr. @ 10,388'WLM & ran 4 1/2" 9.2#N-80 Buttress prod. tbg. Displ. wellw/ diesel. Perf. Hemlock Bench #6 from 11,042'- 11,084' & tested well @ 2952 B/D rate on natural flow. Perf. Hemlock Bench #5 from 10,958'-10,987', 10,904'-10,930' &from 10,882'-10,900'. Tested @ 3936 B/D natural flow. Production tested well on gas lift: B/D CUT NET FM. GAS GOR GLR GRAV. TP 5497 20% 4398 2563 583 881 30.0 2000 Completed operations on TBUS G-~/ @ 12:00 Midnite, 1/3/75. CP ~ CHOKE I~/0 E--Report on this form is required for each calendar ~ntht regardless of lhe status of o~erations, and must ~ flied In duplicate with the oil and gas conservation commiffee by the 15~ of the suec~ding month, u~le~ otherwise directed. Union Oil and Gas L" .... ~ion' Western Region Union Oil Company of California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 unl ,n December 13, 1974 99504 Mr. Tom Marshall Division of Oil Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska RE: TBUS G-21 TBUS D-14 TBUS K-10 KU #14-6 RD. Dear Mr. Marshall: Enclosed for your files are two (2) copies each of the P-4 Form, Monthly Report of Drilling & Workover Operations, for TBUS G-21 (Grayling Platform), TBUS D-14 (Dolly Varden Platform) and TBUS K-10 (King Salmon Platform). Also enclosed, per conversation 12/11/74, is the P-7 Form, Well Completion or Recompletion Report and Log, for the original KU #14-6 drilled in 1959 and for the Redrill of KU #14-6 drilled in 1974. Logs run in the new portion of the hole & DST's #1-#3 are also enclosed. Very truly yours, · Callender District Drlg. Supt. sk Encl. l~rm N'o, P--4 le~, 3-1-70 STATE OF ALASKA SUBMIT IN DUPLICATII OIL AND GAS CONSERVATION COMMI'I-I'EE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS NA.ME OF OPERATOR UNION OIL COMPANY OF CALIF. ADDRESS 909 West 9th Avenue, Anchorage, Alaska 99501 4 LocATioN OF Conductor #2, Leg #3, 1802'N & 1415'W of the SE corner. Section 29: T9N, R13W, S. M. ApI NU,-~iERICAL CODE 50-133-20267 ~ LF~.$E DE$iGAIATION AND SERIAL NO ADL-18730 ;= 7 IF IA1DIA~r AL~D'Fi~.E O1~ TRIBE NAl~[E 8. L~NIT FAI'i{vl OR LEASE NAME Trading Bay %Init g %VEIl. NO State G-21 (21-33) 10 FIF. IL,D AND PCW~I,. OR '~VH,F)CA.T McArthur River F~ld-Hemlock =ii s~C T~. R. M (BOSOM nO~ o~~ 2700'S, 3830'E of surface location or 925'S, 2410'E of NW corner,. Sec. 33: T9N.,R13W, SM: 11 P~IT HO 74-42 Commenced activating Rig #54, Grayling Platform @ 12:01 am, 11/12/74. Skidded Rig #54 from Leg Rm. #2 to Leg. Rm. #3 & rigged up over Conductor #2. Ran 17 1/2" bit to CO 20" Drive Pipe to btm. @ 356'. Ran 23" fixed blade hole opener to btm. of 20" Drive Pipe. Surveyed & Pooh. Spudded TBUS G-21 @ 3:30 am, 11/29/74. Drlg. 17 1/2" hole to 840'. Opened 17 1/2" hole to 23" to 840'. Circ. & cond. mud. Pooh. RU & ran 20" 94# H-40 Butt. Cig. to 822'. Landed 20" cig. on flow-thru hgT. Ran 5" DP & stabbed into float collar @ 784'. Circ. hole clean. Mixed 579 sx. Class "G" cmt. w/ 8% gel prehydrated in mixing wtr. Got good cmt. returns to surface. Mixed 200 Ix. Class "G" w/ 3% CdC12 in mixing H20. Displ. DP to 20" FC & Pooh. CIP @ 7:00 pm. Removed 26" riser system. Installed 20" hydril & 20" riser assy. & tested-ok. Drlg. out cmt. to 822'. Tested 20" cig. to 500 psi-ok. Drlg. to 890' & Pooh. RIH. Drlg. tripped & surveyed 17 1/2" hole to 5205'. Circ. & cond. hole. Pooh. Rigged up & ran 13 3/8" 61# & 68# K-55 Buttress cig. to 5201'. Landed 13 3/8" cig. on flow-thru hgT. Circ. hole clean. Cmt'd btm. stage w/ 1150 ix. Class "G' cmt. w/ 8% prehydrated gel followed by 400 ix. Class "G" Neat. Bumped plug on baffle plate @ 5071' w/ 2500 psi. Float equipment failed to hold. Repressured 13 3/8" cig. to 2500 psi & held press, on cmt. 8 hrs. Released press. Cmt. stayed in place ok. Opened DV tool ports @ 2595'-unable to circ. PI formation w/ 750 psi . Removed 20" hydril & 20" riser assy. Installed 12" 900 series BOPE & tested to UOCO specs. DIVI~N O.F OIL A~ (}A~ ANCHORAO! 14. I hereb~ c~rti~that t~e, forje~tnji,~j~ trpe and correct sm~ ~~~= Dist. Drl~. Suet. .&~ 12/6/74 .... ~im H,. I.;~,,~der NOTE --Report on this form is required for each calendar ~,t~ regardless of t'~'fa*us of o,,roti~ns, and must ~ filed in duplicate wit~ th, oil and gas conlervation commi~ee by the 15~ of the succ~ding mon~. uqle~ ofherwi~a ~irectad. Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE WELL L._J OTHER SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 909 West 9th Avenue~ Anchorage, Alaska 99501 4;, LOCATION OF WELL At surface Conductor ~2, Leg #3, 1802'N & 1415'W of SE corner Section 29: T9N, R13W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RT 99' above MSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 1 3 ;'h;,~ I 4 ~t','~' 50-133-20267 6. LEASE DESIGNATION ANDSER AL Nd! ;, .... ADL-18730 '" .C."~L 7. IF INDIAN, ALLOTTEE OR TRI.B -- N~I~EG~OL UN,T, FARM OR LEASE NAME .... f- Trading Bay Unit I SEC 9. WELL NO. - State a-gl (21-$3) -('}~:- ....... 10. FIELD AND POOL, OR WILDCAT McArth~]r River Field-Hemlock L 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 2700'S & 3830'E of surface loc. or 925'S & 2410'E of NW corner. Sec. 33: T9N, 12. PERMIT NO. 74-42 R13W, S. M. )ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Corrected Location SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING ORACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. TBUS G-21 (21-33), GRAYLING PLATFORM, COOK INLET, ALASKA Corrected Location: Conductor #2, Leg #3, 1802'N & 1415'W of the SE corner Section 29: T9N, R13W, S. M. BHL 2700'S, 3830'E of surface location or 925'S, 2410'E of the NW corner Section 33: T9N, R13W, S. M. NOV § t974 DIVtSI~.I-, ~F OIL AND 16. I hereby~,~r~tify that the foregoing is true and correct SIGNEF~' / TITLE C,~Jim R. Callellder Dist. Drlg. Supt. DATE.ii/22/74 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side September 23, 1974 Re: Trading {~y Unit (21-33) #G-21 Union Oil Co. of California, ~)perator Permit No. 74-42 Mr. R. T. Anderson Union Oil Co. of Calif. P. O. Box 6247 Anchorage, Alaska 99502 Dear Sir: Enclos~ is the approved application for permit to drill the above referenced well at a location from t~ Grayling Platform. ~!l ~mptes, core chips and a m~ log are not required. A directional survey is required. Pollution of any waters of the State is prollt bt ted by AS 46, Chapter 03, Article 7 and the regulations promulgated thereuhde) (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Bollu&i4)u Control Act, as amended. Prior to cmncir, g operations you may be contacted by a representative of the Department of Enviro~ntal Conservation. Pursuant to AS ~.40, Local Hire Under State Leases, the Alaska Department of Labor is ~ing notified of the issuance of this permit to drill. Ve~ ~'~,Jly youth, s- Chairman Alaska Oil and Gas Conservation Con~ittee ~tLB:pj Enclosure cc: Department of Fish and Game, Habitat Section w/o encl. Depar~nt of Envirom~ntal Conservation w/o encl. Deparbment of Labor, Supervisor, Labor Law Compliance Division w/o encl. Porto I0-- 401 REV, I-I--71 STATE OF ALASKA SU]~MIT IN TRIr (Other mstructtor. reverse side ) OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN lB.. TYPm OF WOI~K DRILL [] b. TYP~ OF W~LL OIL ~-~ OASD W~LL W~-LL DEEPEN [] AP! #50-133-21 ADL-18730 ~. IF INDIAN, 8. UNIT FARM OR LEASE 2. NAME OF OPEIR~kTOR Union 0il ~.any of California 3. ADDRESS O~ OPE1V~ATOR P.O. Box 6247, Anchorage, Alaska 99502 ~' LOCATIONOF WELLconductorAtsurf.ce 91, 1798'N & 1413'W of the SE corner, Sec. 29, TgN, R13W, SM ^, p,.o~se~ pro~. ~.one 2425 ' S & 3450'E of surface location or 675 'S & 2025'E of the NW corner, Sec. 33, T9N, R13W, SM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 23 air miles NW of Kenai~ Alaska 14. BOND INFORA~ATION: Tradinq ,Bay Ur. Lt! ~;~/,~7~'i .... State G-21 (21.-3)'-~-~:_ ......... lO. hELD AND POOL, OR ~L~i~.t~_~ .... River.JI~aCAT _ ,. SEC. T.. R.. ~.. (~o~o.~ 2700'S & 'E of s~face l~ation; or 925'S & 2410'E of ~ ~ ~corner Sec. 33, T9N,R13W, SM TYPE Statewide surety ~.d/or No. United Pacific Insurance Co. B-55372 DISTANCE FROM PROPOSED* . . __ , . ~15. NO. OF ACRES IN LEASE. 15. LOCATION TO NEAREST 1--1/2 ral±es J PROPERTY OR LEASE LIN~-. ~Al~o to ,e.rest dr,~. ~. i~ ~ e~5 of U~t ~ 3,840 18. DISTANCE FROM PROPOSED LOCA~ON' ~ 1~. PRO~S~ D~ ' TO NEAREST WELL DRH~- ~O~LET~ o~ ~PP~D ~o~. ~. Hemlock Completion ,.,,o..-, $!00,000 :.. ~o. AcREs ASS,~.~E. TO THiS WELL 80 ROTARY OR CABLE TOOLS 21. ELEVATIONS (Show whether DF, RT, CR, etc,) 22. APPROX, DATE WORK WILL STAR'[" t~ 99' above MSL Nov~i)er 1~ 1974 23, PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRAI:~E Slx'rING D~PTH quantity of cement 26" 20" 94~ H-40 800 'MD See_Attached 17-1/2" 13-3/8" 616 - 686 K-55 5,00.0' " " 12-1/4" 9-5/8" 47~ N-8C &U~S~95 lltl00MD "' " ,,. , , , See attached plan of procedure. AND GAS ANCHORAG~ IN ABOV~ SPAC'~ D~SCRIBE I~ROPOS~'D PI~X~RAM: If p~posal ts to deepen give ddl~a on present productive zon~ and proposed new productive zone. _lf_~o__ro_p~_s~.l is to (lrill or cl~pen (Iurecttonally, give Pertinent. data' on stibsur~ace l~itiorts and measured and true Vertical depths. Give blowout Pi'ev-e.nter- Prog~-am. ' 24. I hereb~at the Foregoing is True an~J Correc~ . (This space for State office use) CONDITIONS OF APPI~)VA.1L,, IF AN'Y: SAMPLES AND CORE CHIPS i~.F~itlJII~ J M,UD LO'C ~ ~U~: S Y~ '~NO J $ Y~ ~' NO SEE TRANSHITTAL LETTER DI~ION~ SURVEY Rm~ A.P.I. ~C~ COD~ September 23, 1974 September_ 23, 1974 PI2LN OF PROCE. DURE 1. Drill a 17-1/2" hole to 800' and open hole to 26". 2e Set 20'~ csg. at 800' and cmt. to surface. Install and test 20" armular BOP. 3.~ Drill 17-1/2" hole to a KOP of 2,000'. Directionally drill 17-1/2" hole to 5,000' MD, 4~640' TVD. e Se e · 9~ RLm rec~ired logs at 5,000 ' MD. Run 13-3/8" csg. and cmt. to surface in two stages. Install 13-5/8" BOPE and test to UCCO specifications. Directionally drill 12-1/4" hole to approximately 150' below t~he base of Hemlock i1,100' TMD, 9750' TVD. Run required logs. Comple~on will be dependent upon results of logging at TD. PROPOSED RASING AND CF24~Tl~G PROGR~4 Hole Casing Quantity Cement 26" 20" 1,400 cu. ft. Class "G" cmt. w/8% gel followed by '230 cu. ft. Class "~" 17-1/2" 13-3/8" · DV _~bol at 2,600', First Stage - 1920 cu. ft. Class "G" cmt. w/8% gel,'l% CFR2 followed by 480 cu. ft. Class "G" Neat ?~,~ ~ ~.~,~ w/l% Second Stage - 2800 cu. ft. Class "G" cmt. w/8% gel ~nd 1% CFR2 followed by 230 cu. ?~,~ ~?~.~ ft. Class "G" Neat w/l% OFR2. 920 cu. ft Class "~" · ~.~ Neat cmt. w/l% CFR2, t~heoretical fill of 2200'. ~, ,' . ;. ./ i/ > ..; P~' ~'e NOT UP TO DATE. 13 24" 2B" O.D. CASIN 20'--~34~¢ H-40 1,9.95G" DRIFT 12 s/~ I D _ r, . 7 ! 2. 18 s4~' OD 24" I[) -. '-. -- '---- 17 s,§" I.D · . . 9 ,8, iTEM~ 1 IT E-'. M ~'2 61~BUTTR.ESS 15 4 UNION OIL CO ALASKA OF CALIFORNIA DISTRICT DoubZz {4Y --/'>/','s :.:.S F. m bi ¥ /0" S'OoO ps;.,, ~ L,P V~Z~8 T9N-RI4W TSN-R 14W ,'~ MARATHON 2-28- 83 ADL-59586 MARATHON 2-26-95 ADL-59386 MAP SOURCE Division of Lands Protracti(>n ,%heel' Grid No' S-13-5, S-13-12 State ()il & Gas Leases ADL- LEGEND T. El.U, BOUNDARY $ HEMLOCK POOL G POOL WESTFORLAND POOL IA~ H AOC Z1068 I $0C &t 17579 18750 17594 18758 17602 18772 18716 18777 18729 21068 W. Fu, 4 2-28- AMOCO PHILLIPS ARCO $OCAL -23 · K-I 3 6'45 G -15 · K-II ~RA¥, ,,J pjiG-19 HU ADL- 59389 I IIlIIlI ADt T ION-R 13 W ~8 ~A~ UN ON ':~¥ARA ADL 87 3~ &~A~'* 'r HO~/K-6 MC ~rt"~U~I ST .~ K-I~ARCO K-7 ~DL 8.77 -~'· G--I :'°'. 1-7 0-6 G.2I · .~,,,'l ~00-~0~.~ .8 ~ I i ! I - F . AMOCO ~ILLI~ ARCO )-IO SOCAL 6 D'~$ ARCO T9N-RI3W TBN-RI3W unlen TRADING BAY UNIT WELL LOCATION STATE G-21 (21-35) SEPT, 10, 1974 qC:..\l_E: 1" 200o ~i6 ~ o / /~ 0 O0 CHECK LIST FOR NEW WELL PERMITS Company .~,( Lease & Well . . Yes No Remarks t. Is wel 1 to be 1 ocated i n a defi ned .pool ................. A~ ~-, Do statewide rules apply ........................ x/~___/~t~.K /J~J~ Is a registered survey plat attached .................. /~ Is well located proper distance from property line ............ well located proper distance from other wells ............ ~K<)/c 6. Is sufficient undedicated acreage available in this pool ........ 7,- Is well to be deviated ......................... B. Is operator the only affected party ................... ZF~(_ Can permit be approved before ten-day wait ............... ~ ..... lO. Does operator have a bond in force ................... 1.1. Is conductor string provided ...................... ~=~'"'~:~'12. Is enough cemen ~'''~~ used~":~'~ ~'~'~"~'~'~"~"~to circulate~'~=~:~'" ~ ''~'~''' on' .... conductor and sUrfaCe l.4. '~l cement cover all possible prOdUctive horizons .......... 1.5; Will surface casing cover all fresh water zones ............ 16. Will surface csg. internal burst equal .5 psi/ft to next string 17. Will all casing give adequate safety in collapse and tension ...... 18. Does BOPE have sufficient pressure rating ............... :Additional Requirements' _