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183-081
Ima~roject Well History File e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _] ~)'~-~_ - ~ 42~F _/ Well History File Identifier ' DIGITAL DATA OVERSIZED (Scannable) items: [] Diskettes, No. [] Maps: ~ Grayscale items: D Other. No/Type [] Other items scannable by large scanner [] Poor Quality Originals: -.- OVERSIZED (Non-Scannable) [] Other: : ~ NOTES: . ~vai'ious kinds BY; ~REN VINCENT SHERYL MARIA LOWELl. DATE: IS/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: /S/ BY: BEVERLY BRE~ SHERYL MARIA LOWELL + ---- TOTAL PAGES Production Scanning Stage 'i PAGE COUNT FROM SCA. NED FILE: 1 l C~ cou.T MATC.ES NUMBER,N SCA.N,NG PREPARAT,ON: YES ~lv / Stage 2 NO (SCANNING IS COMPLETE A'r THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN I~ID~VIOUAL PAGE BASIS DUE TO QUALR'Y, GRAYSCALE OR COLOR IMAGES) IF~, NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: __ YES NO Ill llllllllllll RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~SI General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd . . TO: Jim Regg P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 27,2006 FROM: Jeff Jones Petroleum Inspector SUBJECT: No-Flow Test Chevron / Dolly Varden PL T Well D-03RD2 PTD-1830810 Trading Bay Unit July 27, 2006: I traveled to Chevron's TBU Dolly Varden Platform in Cook Inlet to witness a No-Flow Test on oil producing well D- 03RD2. Chevron Operator Norm Fahnholz performed the test today in a safe and proficient manner. Prior to the test we inspected the well and verified to the extent possible an open flow path from the well bore and discussed the test procedure. Well D-03RD2 was lined up from the tree top swab valve through an Armor-Flow model # 3461-03TO flow meter (180 SCFH to 1800 SCFH span) and a 3/4" hose terminating in an open top container. Flow from the well was monitored for 3 hours with readings recorded every 30 minutes (see below). Unassisted gas flow from the well was below the measurable range of the flow meter and no liquid was produced during the test. Well D-03RD2 meets the AOGCC requirements for a No-Flow determination. Summary: I traveled to Chevron's TBU Dolly Varden Platform in Cook Inlet and witnessed a successful No-Flow test on oil producing well D-03RD2. Attachments: none ÇÇ¡ Chris Meyers, Norm Fahnholz (Chevron) Gos <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH Start Test End Test Produced to open top container through Annor-Flow meter model #3461-03TO calibrated: 3/21/06 Total liquid produced: None ~tJ SEP 0 8200B JBJ02 Page I of 1 NO-FLOW Dolly Varden PLT D-03RD2 7-27-06 JJ.xls ~- """,-,-""",,-, ,~ =-- ".~.. - '-=-~""'-' ---,,,-<"~/ =~ =o_~...=.;,~ ~ . FRANK H. MURKOWSKI, GOVERNOR A.fASfiA OIL AND GAS CONSERVATION COMMISSION August 3,2006 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Chris Myers Field Superintendent U nocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification Trading Bay Unit D-03RD2, PTD 183-081 .:.;;r' ;"^~...J~f¡ \:"".1/ 4';.i'r'~ 't ,~ ~ ~..- G Dear Mr. Myers: On July 27,2006 an AOGCC Petroleum Inspector witnessed a "no flow test" at Unocal's Dolly Varden platform, Trading Bay Unit Well D-03RD2. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. The well demonstrated no fluid flow while open to atmosphere, and a gas flow less than 180 standard cubic feet per hour. The subsurface safety valve may be removed from service in Well D-03RD2 based on this no-flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this welJ as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Dolly Varden platform. Sincerely, ~. ---,.---.., ://"1 ¡---...., K.,' /0 , .f /,1/1'; ,(,) f J /:;;/4,/' '-.--/t.. 'i~¡~J- . -----Zl~! James B. Regg ( ( Petroleum Inspection Supervisor cc: Bob Fleckenstein MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan seamoUnt, [~,~.,~- Commissioner ~///Z~¢z::~ Blair Wondzell, -~ P. I. Supervisor -~ ('~'I ab FROM: John Crisp,~'~' ~ ~. SUBJECT: Petroleum In~l~ector DATE' June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Yarden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due t© header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. 24 wells, ,57 components tested, 3 failures witnessedl 5,2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; :NON.CONFIDENTIAL SVS Dolly Pit. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: McArthur Ry. / Dolly Varde Separator psi: LPS 110 HPS 6/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE D-01 1670800 110 80 85 P 4 OIL D-02ARD 1750380 110 80 65 P 5 OIL ~ 1830810 110 801 80 P P OIL D-04RD 1820410 110 80 80 P P OIL D-05RD 1800650 110 80 100 P P 43 OIL D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P OIL D-II 1680730 110 80 80 P P P OIL D-12RD 1800820 110 80 75 P P 43 OIL D-17RD 1810230! 110 80 80 P P 43 OIL D-18 ' 1690040 800 700 700 P P P GAS D'20 1690950 110 80 90 P P OIL D-25RD 1780870 110 80 100 P P OIL D-26RD 1981290 110 80 75 P P OIL D-27 1750240 110 80 60 P P OIL ~-28 1760360 110 80 100 P P OIL D.30RD2 1880980 D-31RD 1760740 110 80 70 P P 43 OIL D-32 1700370 110 80 75 P P P OIL D-40RD 1820830 110 80 80 P P OIL D-42 1830530 110~ 80 70 P P OIL D-43RD 1853110 110 80 70 P P P OIL iD-46 1890610 110 80 60 P P P OIL D-47 1910110 110 80 70 P P 9 OIL D-48 1921540 110 80 80 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [-] 90 Day Remarks: 'Wells that have SSSVs Out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page 1 of 1 SVS Dolly Pit. 6-22-00jc 1 -' :,'-- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION L;OMMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 83-81 3. Address 8. APl Number P.O. BOX 196247 ANCHORAGE, AK 99519-6247 50' 73920090'03 i i ~ , , . . 4. Location of well at surface Leg A-2, Cond. 11, Dolly Varden Platform i ~ . 9. Unit or Lease Name "~ .... .~ ~ ,- ~.~ 757' FSL, 1,133' FWL, Sec. 6-8N-13W-SM .~ ~..,---~.-...--, TRADING BAY STATE At Top Producing Interval 9,800' MD !~~I 10. Well Number ;' '~ .... ~" ~",, 1,595' FNL, 1,166' FEL, Sec. 6-SN-13W-SM'i~ D-3RD2 At Total Depth 11. Field and Pool ,~ ¢ . 1,180' FNL, 728' FEL, Sec. 6-SN-13W-SM . McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Tyonek "G" Zone 106' KBI ADL 18729 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 11/19/1997 N/A 1/7/1998I 132' feet MSLJ 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) I 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11,055' MD / 9,947' TVD 9,970' MD / 9,872' TVDI Yes: No: X 291' feet MD N/A 22. Type Electric or Other Logs Run 0 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 61# J-55 45' 2506' 18-5/8" 0 9-5/8" 40# & 43.5~ N-80 45' 6570' 12-1/4" 0 7" 29# N-80 6188' 11055' 12-1/4" 1224 SX 0 24. Perforations open to Pro~tuction (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2' L-80 9644' 7952', 8460' & 9588' 3-1/2' L-80 9999'-10089' 9999' See Attached 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/AI Gas Uft Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 1/10/1998 24 TEST PERIOD => 256 42 50 I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE => 256 42 50 28. CORE DATA Brief description of litholegy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None 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. ; Tyonek "G" 9,755' 8,804' ,. · .-:- ',';.:~-, ;_,~.;i/j.,,,~/,,,...;:.h,,,.!~.t 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~&.~ ~'. ~[~J~,,.~ Title Date Dale A. Haines Drilling Manager March 2, 1998 Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 pedinent 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". TBU Well D-3RD2 Perforations EXISTING OPEN PERFORATIONS (Isolated W/7" CIBP): Bench Measured Depth True Vertical Depth HB- 1 10,278' - 10,310' 9,268' - 9,296' HB-2 10,328' - 10,352' 9,311' - 9,332' HB-3 10,440' - 10,450' 9,408' - 9,416' HB-4 10,520' - 10,630' 9,476'- 9,571' HB-5 10,650' - 10,668' 9,588' - 9,604' HB-5 10,720' - 10,740' 9,649' - 9,667' NEW OPEN PERFORATIONS: 1/6/98 Perforated "G" Zone W/2-1/2" Ultra Jet Guns, 6HPF, 60 Phase. Zone Interval MD Feet G-2 9,800' - 9,830' 30' Interval TVD 8,845'- 8,872' G-3 9,869' - 9,890' 21' 8,907'- 8,926' G-4 9,911' - 9,934' 23' 8,945'- 8,965' G-4 9,935'- 9,955' 20' 8,966' - 8,984' Workover Summary McArthur River Unit, Dolly Varden D-3rd 2 -11/28/97 -1/7/98 DAY 1 (11/19/97) PREP. RIG FOR COIL TUBING. DAY 2 (11/20/97) CONT. PREP. FOR COIL TUBING. RIG UP COIL TUBING UNIT ON D-3RD 2. STAB COIL IN INJECTOR HEAD. FILL COIL. DAY 3 (11/21/97) CONT. FILL COIL. PRESSURE TEST BOP'S. TEST GOOD. MAKE UP CLEAN OUT ASSEMBLY NO.1 3.796" BLADED MILL ON BAKER MACH 1 MOTOR. STAB BHA AND SHELL TEST. TEST GOOD. RIH WITH BHA NO. 1. CLEAN OUT 4-1/2" TUBING TO CROSSOVER AT 6,189'. POOH. MAKE UP CLEAN OUT BHA NO. 2, 2.80" MILL. STAB BHA AND SHELL TEST. TEST GOOD. RIH. CLEAN OUT 3-1/2" TUBING FROM 6,149' TO TUBING TAIL AT 10,069'. BACK REM TO 9,500'. REAM BACK TO 10,069'. POOH. RIG DOWN. DISPLACE COIL WITH NITROGEN. DAY 3 (11/21/97) CONT. RIG DOWN COIL AND PREP FOR BACKLOAD. DAY 4 (11/28/97) PUMP 563 BBLS. FILTERED INLET WATER DOWN ANNULUS TAKING RETURNS UP TUBING TO PRODUCTION. BULLHEAD 100 BBLS DOWN TUBING. DAY 5 (11/29/97) MOVE EQUIPMENT TO WEST SIDE OF PLATFORM. SET BPV, NIPPLE DOWN TREE. DAY 6 (11/30/97) NIPPLE UP BOPE, RIG UP HYDRAULIC WORKOVER UNIT (HWU)INSIDE OF WEST RIG. DAY 7 (12/1/97) CONT. RIG UP HWU. DAY 8 (12/2/97) SET TWO WAY CHECKS (-I-WC). TEST BOPE. TEST BLIND RAMS, TWC OR HANGER LEAKING. PULL TWC. ENGAGE HANGER WITH LANDING JOINT. TEST VBR'S, SLOW LEAK. TEST ALL OTHER BOPE. TEST GOOD. WORK TUBING LOOSE WITH 175K. LAY DOWN LANDING JOINT AND HANGER. DAY 9 (12/3/97) CONT. POOH WITH COMPLETION. HOLE OUT OF BALANCE. STAB FLOOR SAFETY VALVE. WELL STABLE. REVERSE 65 BBLS TO PRODUCTION. CONT. POOH WITH 4-1/2" COMPLETION. REPAIR HYDRAULIC LEAK ON JACK. DAY 10 (1 2/4/97) CONT. REPAIR JACK. COMPLETE POOH WITH COMPLETION, 100% RECOVERY. RIG UP SCHLUMBEREGER E-LINE UNIT. RIH WITH JUNK BASKET AND 5.87" GAGE RING TO 9,895' UNABLE TO GET DEEPER. POOH. PICK UP HALLIBURTON 7" EZSV. RIH. SET EZSV AT 9,980'. SETTING TOOL NOT RELEASED. SHEAR OFF AT WEAK POINT LEAVING RUNNING TOOL GR/CCL IN HOLE. POOH WITH E-LINE. TEST 7" CASING TO 1,500 PSI FOR 15 MIN. BLED OFF 550 PSI. NO COMUNICATION TO OTHER ANNULI. DAY 11 (12/5/97) RIG UP SLICK LINE. RIH AND RETRIEVE RUNNING TOOL, GR/CCL. FROM TOP OF EZSV. RIG UP SCHLUMBERGER E-LINE. RIH WITH 7" RTTS. SET AT 9,980'. POOH. TEST CASING TO 1,500PSI. BLED TO 750 PSI IN 15 MIN. RIG DOWN SCHLUMBERGER. MOVE DRILL PIPE TO PLATFORM. DAY 12 (12/6/97) PICK UP 7" BRIDGE PLUG RIH 3,502'. PICK UP 9-5/8" RTTS. CONT. RIH TO 6,297' SET 7" BP. PRESSURE TEST 7" CASING, LINER LAP AND 9-5/8" CASING TO SURFACE TO 1,500 PSI. BLED OFF TO 750 PSI.. DAY 13 (12/7/97) SET 9-5/8" RTTS AT 2,793'. PRESSURE TEST BETWEEN 7" BRIDGE PLUG AT 6,297' AND 9-5/8" RTTS AT 2,793'. TEST TO 1,500 PSI, BLED TO 750 PSI. PRESSURE UP ON ANNULUS TO TEST 9-5/8" FROM 2,793' TO SURFACE. TEST TO 1,500 PSI FOR 15 MIN. TEST GOOD. RELEASE 9-5/8" R-I-rS, RETRIVE BRIDGE PLUG. CONT. RIH TO LINER TOP. SET 9-5/8" RTTS AT 6,202'. TEST 9-5/8" FROM 6,202 TO SURFACE TO 1,500 PSI FOR 15 MIN. TEST GOOD. RELEASE RTTS. CIRC. SWEEP. POOH. DAY 14 (12/8/97) CONT. POOH TO 9-5/8" RTTS. PICK UP STORM VALVE ON 9-5/8" RTTS. RIH AND SET RTTS AT 305'. PREP TO PICK UP HWU WITH RIG FOR TUBING SPOOL SWAP OUT. LIFT HWU WITH RIG. REMOVE 'DCB' TUBING SPOOL. INSTALL NEW. TEST SAME. TEST GOOD. SET HWU DOWN AND FLANGE UP. SHELL TEST BOP'S. TEST GOOD. DAY 15 (12/9/97) PICK UP RETRIEVING TOOL AND RIH TO 305'. ENGAGE STORM VALVE AND RTTS. POOH. PICK UP LINER PBR POLISH MILL. RIH TO LINER TOP. POLISH TIE BACK SLEEVE FROM 6,268' - 6,274'. DAY 16 (12/10/97) CONT. POLISH PBR. CIRC. 30 BBL HIVIS SWEEP. POOH. WAIT FOR BOAT TO LOAD OUT WITH BAKER LINER TOP PACKER. DAY 17 (12/11/97) CONT. WAIT ON BOAT TO DELIVER EQUIP. PICK UP SEAL ASSEMBLY, 2 JTS. 7" CASING, 7" X 9-5/8" BAKER 'ZXP' LINER TOP PACKER. RIH AND STAB INTO PBR AT 6,268'. PRESSUR TEST DOWN DRILL PIPE TO 500PSI. NO TEST. PRESSURE TEST BACK SIDE TO 1,500 PSI. PRESSURE DUMPED AT 900 PSI. DAY 18 (12/12/97) UNSEAT SEAL ASSEMBLY. POOH. SEALS SCARRED AND TORN. CIRCULATING SUB DISC RUPTURED. MU 7" BRIDGE PLUG, 8 UTS. DRILL PIPE, 7,' RTTS. DAY 19 (12/13/97) RIH. SET 7'' RTTS AT 6,290'. TEST 7'' LINER DOWN DRILL PIPE. TEST TO 1,500 PSI. BLED TO 800 PSI IN 5 MIN. UNSEAT RTTS. RIH. SET RTTS AT 7,744' TEST 7'' DOWN DRILL PIPE. TEST TO 1,475 PSI. BLED TO 925 PSI IN 5 MIN. TEST BACK SIDE, 7" CASING, LINER LAP, 9-5/8" CASING TO SURFACE TO 1,750 PSI FOR 15 MIN. TEST GOOD. UNSEAT RTTS AND RIH TO 9,952'. SET R'i-rs AT 9,686'. TEST 7" DOWN DRILL PIPE TO 1,750 PSI FOR 15 MIN. GOOD TEST. ATTEMPT TO TEST BACK SIDE. TEST TO 1,750 PSI. BLED TO 1,300 PSI IN 5 MIN. POOH TO 9,487'. ATTEMPT TO SET RTTS AT 9,221'. PACKER SLIPPING DOWN HOLE. POOH AND SET R'I-rS AT 9,200'. TEST LINER FROM 9,200 DOWN, 1650 PSI. TEST GOOD. POOH TO 8,837'. SET RTTS AT 8,771'. TEST 7" DOWN DRILL PIPE. TEST TO 1,650 PSI FOR 10 MIN. TEST GOOD. POOH TO 8,562' SET RTTS AT 8,296'.TEST 7" DOWN DRILL PIPE TO 1,500 PSI. BLED TO 850 PSI IN 4 MIN. RIH TO 8,816' SET RTTS AT 8,546'. TEST DOWN DRILL PIPE TO 1,550 PSI. TEST GOOD. DAY 20 (12/14/97) PULL RTTS TO 8,423'. TEST 7" TO 1,475 PSI FOR 5 MIN. TEST GOOD. PULL RTTS TO 8,328'. TEST 7" TO 1,500 PSI. LEAK OFF TO 500 PSI IN 5 MIN. TEST ANNULUS TO 1,600 PSI. LEAK OFF TO 1,200 PSI IN 5 MIN. POOH WITH TEST STRING TO 1,783'. PICK UP 9-5/8" RTTS AND STORM VALVE. RIH AND SET RTTS AT 305'. TEST PACKER TO 500 PSI. AGAINST BLIND RAMS. GOOD TEST. RIG DOWN. SUSPEND OPERATIONS ON DOLLY VARDEN D-3RD 2 UNTIL SCHLUMBERGER ULTRA SONIC INSPECTION TOOL AND SCAB LINER EQUIPMENT IS AVAILABLE. DAY 21 (12/15/97) CONT. TO RIG DOWN. RELEASE HWU TO WELL D-5RD. DAY 22 (12/24/97) REMOVE TREE. RIG UP HWU ON WELL. DAY 23 (12/25/97) CONT. RIG UP. TEST ALL BOPE. TEST GOOD. RIH WITH RETRIEVING TOOL ENGAGE STORM VALVE AND R-IFS. POOH. RIG UP SCHLUMBERGER E-LINE. RUN JUNK BASKET, 5.75" GAGE RING. RIH TO 9,980'. POOH. PICK UP ULTRA SONIC INSPECTION TOOL (USIT). SURFACE GEAR COMPUTER PROCESSOR DOWN. ATTEMPT TO REPAIR. DAY 24 (12/26/97) CONT. ATTEMPT REPAIR SCHLUMBERGER SURFACE GEAR. MOBILIZE BACK UP FROM BEACH. INSTALL SAME ON ARRIVAL. RIH WITH USIT TOOL. LOG 7" CASING FROM 9,960' TO TOP OF LINER. FOUND BAD 7" CASING FROM 7,985' TO 8,420'. SEND LOG TO ANCHORAGE FOR EVALUATION. WAIT FOR ORDERS. MAKE UP 7" BWD PACKER AND RIH ON E-LINE. SET AT 9,588'. POOH RIG DOWN E-LINE. DAY 25 (12/27/97) MAKE UP LOWER SEAL ASSEMBLY. OVERTORQUE CONECTIONS ON STAB THROUGH TAILPIPE. SEND JEWELRY TO BEACH TO RE-THREAD. RECEIVE ITEMS BACK. MAKE UP TAILPIPE, SEAL ASSEMBLEY, LOWER GAS LIFT COMPLETION AND LOWER 7" SCAB LINER ASSEMBLY. DAY 26 (12/28/97) RUN LOWER COMLETION ON DRILL PIPE. SEALS ENTERED 7" BWD PACKER AT 9,588'. TEST SEALS. DROP BALL. SET LOWER SCAB LINER PACKER AT 8,461' WITH 2,500 PSI. PULL 20K OVER TO VERIFY SET. ROTATE OFF OF PACKER WITH 12 TURNS. PRESSURE UP AND SHEAR BALL. POOH. PREP FOR RUNNING 5". DAY 27 (12/29/97) PICK UP RATCH LATCH SEAL MANDREL, 5" SCAB LINER AND 7" AWR LINER TOP PACKER. RIH ON DRILL PIPE. SHUT DOWN TO REPAIR RADIATOR ON POWER PACK. CONT. RIH. STAB SEALS INTO LOWER SCAB LINER PACKER AT 8,461'. DROP BALL. SET UPPER SCAB LINER PACKER AT 7,952' WITH 2,300 PSI. DAY 28 (12/30/97) PRESSURE BLED TO 0. DECIDE TO SHEAR OFF PACKER. SETTING TOOL ALREADY SHEARED OFF. PRESSURE TEST CASING INTEGRITY TO 1,500 PSI FOR 15 MIN. TEST GOOD. PRESSURE UP AND SHEAR BALL. POOH. PICK UP SEAL ASSEMBLY, 3-1/2" FLUSH JOINT TUBING, XO, 3-1/2" BU'I-rRESS TUBING AND GAS LIFT COMPLETION. RIH. DAY 29 (12/31/97) CONTINUE RUNNING COMPLETION. SPACE POT COMPLETION AND STAB INTO PACKER AT 8,463' PRESSURE TLS TUBING TO 1,500 PSI FOR 15 MIN. GOOD TEST. DAY 30 (1/1/98) LAND COMPLETION. TEST TUBING TO 1,500 PSI FOR 10 MIN. GOOD TEST. SET BPV. RIG DOWN HWU. DAY 31 (1/2/98) CONT. RIG DOWN HWU. INSTALL TREE. TEST HANGER AND TREE TO 5,000 PSI. GOOD TEST. RELEASE HWU. DAY 32 (1/6/98) RIG UP ON WELL WITH SCHLUMBERGER E-LINE. RIH WITH GUN RUN NO. 1. PERFORATE FROM 9,955 - 9,964' WITH 2-1/2" ULTRA JET, 60 DEG 6 SPF. POOH. RIH WITH GUN RUN NO. 2. PERFORATE 9,935' - 9,955' POOH. DAY 33 (1/7/98) RIH WITH GUN NO. 3. PERFORATE 9,911' - 9,934'. POOH. RIH WITH GUN NO. 4. PRFORATE 9,869' - 9,890'. POOH. RIH WITH GUN NO. 5. PERFORATE 9,800'- 9,830'. POOH. RIG DOWN. RELEASE WELL TO PRODUCTION. UNOCAL ) Dolly Varden Well No. 3 rd 2 Actual Completion 1/2/98 RKB to A B C 10 11 12 14 15 16 17 H F~I Taggexl 10,4~2' w/ Z28" OR 7/23/96 = 41.5' SIZE WY CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 61 J-55 9-5/8" 40,43.5 N-80 BTC 7" 29 N-80 BTC Tubing 3-1/2" 9.2 L-80 BT & C SC 12.51 8.755 6.188 2.992 Surface Surface 6,267' 2,506' 6,570' 11,055' NO. Depth JEWELRY DETAIL ID OD Item 1 41.50 3.950 11.00 2 42.03 2.990 4.500 3 291' 2.813 4.330 4 2,433' 2.867 5.968 4,303' 2.867 5.968 5,541' 2.867 5.750 6,531' 2.867 5.750 6,990' 2.867 5.750 7,512' 2.867 5.750 7,907' 2.867 5.750 5 7,951' 2.867 5.75 6 2.992 3.50 7 8,482' 2.970 3.960 8 8,461' 4.00 5.875 9 8,465' 4.020 5.670 10 8,475' 4.00 5.020 11 8,490' 4.00 5.690 12 8,531' 2.867 5.750 9,024' 2.867 5.750 9,544' 2.867 5.750 13 9,588' 2.970 4.450 14 9,588' 4.00 5.875 15 9,592' 4.00 5.020 16 9,631' 2.813 3.970 17 9,644' 2.992 3.910 A 7,952' 4.00 5.875 B 4.402 5.00 C 8,460' 4.020 5.250 I 9,993' II 9,999' 4.00 5.85 CIW, 11" x 4", 5M, DCB Single Tubing Hanger Crossover, 4-1/2" Buttress x 3-1/2" Buttress HES, 'XXO' SSSV Landing Nipple McMurry Macco, 3-1/2" SMO-2 GLM. 1-1/2", RK McMurry Macco, 3-1/2" SMO-2 GLM, 1-1/2", RK McMurry Macco, 3-1/2" SMO-2 GLM, 1-1/2", RK McMurry Macco, 3-1/2" SMO-2 GLM, 1-1/2", RK McMurry Macco, 3-1/2" SMO-2 GLM, 1-1/2", RK McMurry Mace#, 3-1/2" SMO-2 GLM, 1-1/2", RI{ McMurry Mace#, 3-1/2" SMO-2 GLM, 1-1/2", RK Fluted No-Go Locator 3-1/2", 9.2#, L-80, ST-L Flush Joint Tubing Seal Assembly, 7.82' Long Ratch Latch Head HES, AWR Permanent Packer, 7", 29# Ported Nipple, 4 ea. 1" Holes 2 ea. Seal Bore Extensions (7.48' ea.) Tubing Adapter, 4-3/4" UN Box x 3-1/2" Buttress Pin McMurry Mace#, 3-1/2" SMO-2 GLM, 1-1/2", RK McMurry Mace#, 3-1/2" SMO-2 GLM, 1-1/2", RK McMurry Mace#, 3-1/2" SMO-2 GLM, 1-1/2", RK HFS, No-Go Seal Assembly, 10', Molded w/Tail Pipe (Stabbed Through Packer) HES, 7", 'WD' Permanent Packer HFS, Seal Bore Extension, (6.90' Long) HFS, 'X' Nipple Wire Line R-entry Guide SCAB LINER HES, AWR Permanent Packer, 7", 290 5", 15~, L-80, Buttress KC Scab Liner Ratch Latch Premium Seal Assy. 2' Long (Fingers Removed) SUSPENDED COMPLETION 7" CIBP Otis, 7", 'WI)' Permanent Packer 1/'//98 I G-2 I 1/7/98 G-3 1/7/98 G-4 1/6/98 G4 9,935' 9,955' Above Perforations Added after Workover B-1 10,278' 10,310' B-2 10,328' 10,352' B-3 10,440' 10,450' B-4 10,580' B-5 10,650' 10,668' 10,720' 10,740' PERFORATION HISTORY Interval Amt Accum, Top Btm spf 9,800' 9,830' 30' 6' 9,869' 9,890' 21' 6' 23' 6' 9,911' 9,934' 20' 6' 32' 24' 10' 60' 10,630' 50' 18' 20' Conunents 2-1/2" Ultra Jet, 60 deg. 2-1/2" Ultra Jet, 60 deg. 2-1/2" Ultra Jet, 60 deg. 2-1/2" Ultra Jet, 60 deg. solated Isolated Isolated Isolated solated solated solated PBTD = 9,993' TD = 11,055' MAX HOLE ANGLE = 32.5° @ 3,900' D-3rd2Actscab.doc DRAWN BY: tcb REVISED: 2/12/98 Unocal Corporation P,O. Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOf. Dale A, Haines Drilling Manager Monday, November 10, 1997 Mr. David Johnston Commissioner Alaska O&G Conservation Commission 300'1 Porcupine Drive Anchorage, AK 99501 - 1392 Dear Mr. Johnston, Enclosed is an application for Sundry Approval (Form 10-403) to suspend production from the Hemlock formation and to complete the G-zone in Dolly' Varden Platform Well No. 3® 2 The timing to begin the work is approximately November 25, I997. If you should have any questions regarding this request please contact Tim Brandenburg at 263-7657. Thank you for your attention to this matter. Sincerely, Dale Haines Ddlling Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. T;pe' o~'R'eque~ Abandon:' Suspend; X Operation shutdown';" Re.enter suspended well: .... Aller casing: Repair vCell; Plugging: -- Time extenslon~ S~mula~ . ~hange approv~ p~ogram; Pull't~ing: X VaCant: Pe~rate~X Other: ~. N~me of O~emtor " 5. Type of well; 6. 'DatUm elevation (DF or KB) "' UNOCAL Development; X 106' KB ~OVE MSL feet ~. Address ' ' ~plomt~: ~ 7. unit or Prope~y name Stmtigmphlc: PO BOX 190247 ANC, AK. 99519 So,ice; Trading B~ Unit 4. Lo'riCh of well at Su~ ~ A~, Cond. ~ 1, Dolly Varden Plaffo~ 8. W~Jl ~umber .... 757' FSL, 1,1~3' ~L, ~c, 6-SN-13W~M ~-~rd2 At top ¢ produc~e intewel 9. permit ~umber ....... 1,550'FNL, 905'FE~ S~. 6-SN-t3W~M 8341 ~,190' FNL, 771" FE~ eec. 6~N-13W~M S0-133-20090.~ Atto~l depB ~1. Pl~ld/poOl .... 1,~90' FNL, 740' FEb Sec. 6-8N-IZW4M McA~hur RlveEieid I Hemlock 12. Present~ell ~nd~l~n summaw ...... Te~l depB: m~sur~ 11,0SS' ~et Plugs (~asumd) None ~ue ve~l 9,947' ~et E~ve depth: ~e measured ve~l 19,970' 9,872' Casing Leng~ S~e Cemented Measured dep~ True ve~l depth S~u~ral Conductor Suda~ ~505' 13~8" 2,506' 2,334' Intermediate Pr~umion 6,570' Liner 4,788' 7" t~4 Sx 11,0~' 9,94?' Pe~m~n dep~; measured S~ A~ached true ve~l Tubing (sEe, grade, and measured dep~) 4-1/2" N~ ~ 6189', 3-1~" N~0 ~ 10,089' Packe~ and 8SSV (~e and measured dep~) ~ Packer ~ 9,999', & DC T~V ~ 289' - . 13. At~e~ ..... D~p~n summ~ of Pr~osal: X De~iled ~perarions program: X " BOP skeW:' X 14. EStimated date ~r ~mmen~g opemUen ' . 15. S~s of well c~assifi~ti~ as: ....... 11N5/1997 --.. , , 16. if p~posai Well v~bally approved: OI1: X Gas: Suspended; N¢~e ¢.~ppmver Date a~pmved Se~; 17. I hereby ~ ~at ~e ~re~oln~ ~ tree and ~rre~ to ~e best of ~y ~g[. ' .... FOR COMMISS'ION USE ONLY Plug inte~d~ BOP T~I M~ani~l Jn~~s( Subsequent ~ r~uired 10-~O_~ . _~oqe~~ ~ original Signed By David W. Johnston Ap,roved by order of ~e Commissioner Form 10-403 Rev 08/1.5/88 SUBI~IT IN TIq ~ATE ~ UNOCAL ) Dolly Varden Platform Well D-3 Hydraulic Workover Procedure Objective: It Is proposed to workover and recomplete well D-3rd2 as a G-Zone oil producer, The well is currently completed in the Hemlock formation. The workover will require removing scale from the tubulars via coil tubing, pulling of the tubing with the Hydraulic Workover Unit (HWO), suspend production from the Hemlock by setting a CIBP on E-Line, and complete the G-Zone with a 3-112" gas lift completion with the HWO unit. The G-Zone will be perforated through tubing in an under balance state. The worl(over will be complicated with NORM pipe. PREP Well for Workover: Scale Removal with Coil Tubing. , , . NOTE: . Mob 1-314' coil tubing and support equipment from the Beach platform to the Dolly Varden. Hold safety meeting with crews and discuss H2S Safety, Remove tree cap at flanged connection on 4" tree. Flange up adapter spools from 4" 5K to 4" 10 K (BX-155). Flange up BOPs and function test. Fill the mud pit under the West pipe rack with FIW and J313 friction reducer mixed at 5 gallons / 300 bbls. RU injector, BOP's, and lubricator. RU surface lines to pump down coil with returns lined out to production via flowline. Line up production to group separator. Pressure test all surface pressure lines to 4,500 psi. Fill coil with FIW mixed with J313 Friction Reducer.. Function and pressure test BOP's as per Unocal Alaska specs. Shear Rams have been tested and will not require a field shear. Measure up Slip Type Coil Connector, puli test to 25K. 'Blue Lock Tire' all connections, 2-7/8" Grapple type coil connector. · 2-7/8" Dual Check Valves 2-7/8" Hydraulic Disconnect · 2-7/8" Circulating sub · 2-7/8' PDM · 3.80" Button Mill NOTE: Fax in BHA sheet with all tool descriptions, lengths, O.D.s., and I.D.s with morning report. In Addition, FAX In complete circulating system with line pressure ratings 'including configuration of BOP's. . Stab injector, pressure test to 4500 psi. Ensure Non Produced Fluid Form has been sent to TBPF and returned approved. Open swab valve and increase gas lift to maximum rate (4-4.SMMCF). RIH to 50'. . Bring pump rate up to 2.4 bpm. RIH milling scale to 4-1/2" by 3-1/2" crossover at 6,189'. POOH. Cut off existing BHA. D 3fda,doc 11/7/97 UNOCAL ) Dolly Varden Platform Well D-3fa2 Hydraulic Workover Procedure 10. Measure up Slip Type Coil Connector; pull test to 25K. 'Blue Lock Tire' all connections. · 2-1/8" Grapple type coil connector. · 2-1/8" Dual Check Valves · 2-1/8" Hydraulic Disconnect · 2-1/8' Circulating sub · 2-1/8" PDM · 2.80" Button Mill Note: Note: Fax in BHA sheet with all tool des~;dptions, lengths, O.D.s., and I.D.s with morning report. 11. Stab injector, pressure test to 4500 psi. 12. Open swab valve and RIH to 6100'. 13. Bring pump rate up to 1.6 bpm. RIH milling scale to tubing tail at 10,069'. 14. Reduce pump rate to % bpm. RIH and tag fill / bottom. Do not attempt to drill out in casing. POOH. 15. SI lift gas and allow well to die. Bleed casing pressure back to production / flare. 16. RD Coil unit and re~ease from platform 17. RU APRS. MU ,5' of tubing punch guns. RIH and perforate the tubing at 9,980'. POOH. Verify all shots fired. RD APRS. 18. RU DS pump on tubing. Line out returns from casing annulus to productions WCT. Pressure test to 4,500 psi. Circulate down tubing taking returns from casing annulus valve. Pump a total of 2 well volumes to clear residual oil and gas. Displace the well to FIW mixed with 6% KCI. Hemlock SBHP = 4,000 psi. G Zone SBHP = 3,200 psi. MOB & RU HWO: Load out HWO equipment to platform. Lay out surface equipment per attached lay out plan. Note: Contact AOGCC 24 hours prior to testing BOPE (279-1433) 1. Hold safety meeting with crews and discuss presence of H2S and use of Fresh Air Breathing Systems. 2. RU and circulating system per attached layout_ Secure all lines with chains. Pressure test circulating system to choke to 5,000 psi. Pressure test down stream of choke to 2,500 psi. 3. Set 4-112" nominal Cameron Type "H" BPV in profile. 11/7/97 D 3fda.doc UNOCAL Dolly Varden Platform Well D=3rd 2 Hydraulic Workover Procedure Have Production check for H2S in the well head room.. Ensure that SCBA's are available for all hands working in the wellhead room. Verify that well is dead. If not circulate with kill weight fluid, Have Wellhead Service Rep. Verify that ali pressure has been bleed from all lines and voids associated with the tree, seal flange tubing hanger and tubing spool imediatley prior to removal. Nipple down tree and towlines. Blind flange flowlines per UNOCAL lock out tag procedure. Inspect hanger and verify lift thread type and condition. Verify that all ports in the hanger have.been plugged. NU BOP's. BOP's to be configured with variable rams to pull 4-1/2" x 3-1/2" singles per attached BOP Stack Layout, RU HWO unit and associated equipment. Ensure all safeguards are met for a safe operation with adequate fall protection and spill prevention. Check stack bolts once per tour and ensure bolts remain properly torqued, Workover: Accept Rig: 6. Hold Pre-well safety meeting. Brief crews on safety and environmental concerns, handling of NORM pipe, H2S Contingency and Slip hazards of slick decks. Accept HWO unit. 7. Pull BPV and set two-way check valve. 8. Pressure test BOP low / high to 250 psi/5000 psi, Pull two way check valve. Pull Completion: 9. Measure up 4-1/2" landing joint and engage hanger. Back out hanger hold down screws, PU hanger assembly and monitor well. 10. Pull seals from packer, monitor well. The pipe is expected to have BaSO4 scale. However the tubing will be checked for NORM with a LUDLUM Monitor, Norm pipe to be properly marl(ed and handled in accordance with UNOCAL's NORM pipe handling procedures. (Attached to end of procedure) 11. Set ClBP 12. 13. J4. POOH laying down 4-1/2" 12.6# & 3-1/2" 9.2#, buUress tubing string. and Run New Completion Packer on E-Line: RU E-Line unit. MU 7", 29#, CIPB, E-4 Setting tool, GR, & CCL. RIH and set CIBP at 9,993' DIL. POOH with Setting tool. Pressure test 9-5/8 X 7" and CIBP to 1,500 psi for 15 minutes. MU Halliburton's 7" x 4" WD permanent packer on Bakers Model 20 Setting tool. RIH and set packer at 9,600' DIL. POOH & RD E-Line unit. D 3fda.doc 11/7/97 UNOCAL Dolly Varden Platform Well D-3rd z Hydraulic Workover Procedure Run New Completion '~ 5. PU the completion as noted below. Pipe dope pin connections only using a paint brush with Lead Free Modified. . 3-t12" WLEG, 3-1/2' FL4S Box - ~12' Pup Joints 3-1/2", 9.2#, L-80, FL4S - 2.8'13" Otis X nipple, FL4S Box x Pin - 12' Pup Joint 3-'1/2", 9.2#, L-80, FL4S - Crossover from 3-1/2", NU 10 Round box to 3-1/2" FL4S Pin 10' Molded seal assembly with spacer rings No-Go seal shoulder 3-1/2", 9.2#, L-80 Buttress Completion with 1-1/2" GLV's per Gas lift design HES, (XXO' SCSSV profile nipple with SCSSV installed - 8 Joints 3-1/2", 9.2# L-80, Tubing, Buttress - Space Out Pups Joints 3-1/2", 9.2#, L-80 Buttress - Crossover Pup 4-1/2" Buttress Pin x 3-1/2" Buttress Pin - Cameron 11' DCB tubing hanger 161 17. 18. RIH with assembly torquing connections to make up marks on buttress connections. Rabbit all 3.112" tubing joints with a 2.875" rabbit. Control line to be banded 2 X's on pup joint on SCSSV and 1 per joint to surface. Maintain 5,000 psi on control line while RIH with SCSSV. Land seal assembly in packer. PU and space out for neutral stdng weight with seals fully engaged. Make up hanger assembly. Make 3 wraps around 3~1/2" tubing with control line prior to making up control line to the hanger Make up landing joint in top of hanger and tie in control line to the lop of the hanger. Pressure control line to 5,000 psi to open valve.. Stab into packer while circulating, note pressure increase. Land tubing hanger. Engage hold down screws. RD & Release HWO: 19. Set BPV's. RD HWO unit. ND BOP's. 20. IqU Tree, Puli BPV's and set 2 way checks. Pressure test tree to 5,000 psi. Pull 2-way checks. 21. Release HWO. 22. NU towlines, gas lift header lines and pressure test. RU two pin recorder. ?_3. Open towline to production and route well to test separator. Unload water in tubing and casing to production by slowly stacking gas to casing. Do not exceed 'I BPM to prevent flow cutting GLV'$. Unload 540 bbls fluid from tubing and casing with gas lift. 24. With well lifting off bottom orifice, SI tubing and stack 1 ,ODD psi on tubing. SI lift gas at header. D 3~'da.doc 11/7/97 Dolly Varden Platform Well D-3ra ~ t~l~iO~~l.~) Hydraulic Workover Procedure ~111111 ~-~--' - i I ~l. I~ 25. RU E-Line unit. Pressure test to 2500 psi. Establish Safeguards for handling perforating guns. MU 2-1/2" HC, 6-SPF, 60-Phase guns as noted below. RIH and perforate the following interval. Note initial pressure increase from perforating. SI well while RIH and POOH with perforating guns. G-4: NOTE INCREASE IN SITP. 9,935' - 9,955' 20'2-1/2', HC, 6 HPF, 60-PhaseWell 8hut In, G-4: 9,911' - 9,934' 24'2-1/2", HC, 6 HPF, 60-Phase Well Flowing G-3: 9,853'- 9,890' 37'2-1/2", HC, 6 HPF, 60-Phase Well Flowing G-2: 9,800' - 9,830' 30'2.-1/2", HC, 6 HPF, 60-Phase Well Flowing 26. RD E-line. Allow well to clean up in group separator for 24 hours obtaining WC's every 4 hours. D 3rda, do¢ 11/7/97 UNOCAL Dolly Varden Platform Well D-3 Hydraulic Workover Procedure 1997 NORM RIG & PIPE YARD SURVEY AND EXPOSURE MINIMIZATION PLAN The following procedures apply to workover operations that include the removal of production tubular equipment from wells that produce water along with oil or gas, RIG SITE: 1. During rig activation and prior to opening well, pipe rack, rig floor, mud circulating pits, shale shaker, and x-mas tree will be surveyed using a Gamma survey instrument, Survey is to be conducted under direction of Unocal IH person, by individuals having completed Unocal accredited survey training, using Unocal supplied or contracted equipment. A like survey will be conclucted prior to deactivation. Equipment registering NORM readings above 50 micro R/hr. will be cleaned prior to further use or demob. 2. Contract Toolpusher will conduct and document pre-job safety meeting with rig crews and effected support vendors prior to pulling production tubing. In addition to equipment safe operating procedures the following will be discussed. 2.1. Absolutely no open food or ddnk will be allowed on rig floor while tubing and ancillary equipment is being removed from the well. 2,2. Rig crews will wear hardhats, safety eyewear with side shields, slicker suits, work gloves, hearing protection and safety footwear while pulling completion equipment, 2.3. Hardhats, slicker suits and gloves will be removed and workers will thoroughly wash their face and hands prior to smoking or eating, 2.4. On Unocal platforms, footwear will be changed prior to entering crew quarters. 2.5. Clothing will be washed prior to reuse or removal from location. 2.6. Should pipe need to be hot tapped to remove trapped pressure, workers exposed to cuttings dust will wear at a minimum, half-face respirators with cartridges approved for radioncide Oust. Recovered tubulars and equipment will be laid out on pipe rack and receive a bulk "protectors on" ends survey with a Gamma type instrument (Gamma survey penetrates steel). Instrument standoff will not exceed 1/2" at a maximum survey speed of one foot per second. 3.1. Survey results will be noted on morning report. 3.2. Prior to transport, rig personnel will notify designated Unocal Environment representative of all well equipment that surveyed positive, noting weight, O.D., I.D., estimated scale thickness (absence of scale is possible indication of false positive) and total footage. 3.3, Recovered production equipment will not leave location prior to job specific written shipping instructions from the Environmental representative. 3.4. Equipment will be properly manifested and placarded. , PIPE INSECT[ON YARD: 1. Pipe yard has established 6-10 micro R/hr. as background. AI._.[I used tubulars entering yard are surveyed with Gamma instrument. The tubular ends are surveyed on the float with protectors on, in a designated staging area. 2. When survey rea~ds nothing over background, tubulars are handled as per Unocal 'job order'. 3. VVhen survey reads twice or more background, tubing is taken to designated area. 3.1. Each joint is rolled out for isolation and receives end survey with protectors on, then segregated: 3.1.1 .Less than twice background, 3.1.2.More than twice background. 3.1.3.Over 50 micro R/hr. 4. Tubing that comes in designated to junk automatically receives handling as per 3.1. 5. Tubing that comes in for inspection meeting requirements of #2 but fails Unocal "15% inspection", receives survey as per 3.1. lma~word60~busunit\97NORM-RIG&YARD.doc D 3fda.doc 11/7/97 UNOCALe RKB = 41.5' Dolly Varden Well No, 3 rd 2 Actual Completion 2/14/85 ill - -- --~lllllll ......................................................... CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM, 13-$/8" 61 3-55 9-5/8" 40,43.5 N-80 BTC 7" 29 N-80 BTC Tubtn~ 4-1/2" 12,6# N-BO ASL 3-1/2" 9,2 N-80 BT & C SC 12.51 Suxfac~ 2,506' 8.753 Surface 6,370' 6. i88 6,267' 11,055' 6,189' 6,189' 9,998' 1 41,50 2 ZOO 3 269' 3.813 ~ 2;~t15' 3.89 4,130' 3.89 5,569' 3.89 5 6,189' 6 6,?48' 2,813 7,769' 2.813 8,655' 2.813 9,247' 2.813 9:690' 7..813 9,905' 2,813 7 9,998' 3.06 8 9,999' 4,O0 9 t 0,008' a,20 10 10569' 2--94 JEWELRY DETAIL OD .... Item .... . _ crw', 11" x 4', SM, DL-'B Single Tubiug Hanger Ct~sowx. 4-1/2" Butt~s$ x 3-112" But. tr~$ (~is DCTRBV SSSV (3.813 I.D.) Cam:o, a-Il2' MMG GLM Camco. 4-1t2" MMG OLM Cara~o. 4- If2" MMG GLM Qro~$ov~r, d-It2" ASL Box z }-1/2" Buit~t Dim MctVlurray Hugh~$, $-1/2" TFD GLM Mc. lvlunay Hu/~h~l, 3-112" TPD GLM McMu~ray Hugh., 3-1/2' TPD GLM McMurray Hughas, 5-1t2" TPD GLM MzMtany [.lushea. lq/Z" TPD GLM MciVlutray ttu~h¢$. 3-1/2" TPD GLM 7.a0 4,75 Oti,, Nu-Oo $~al Az~n/oly, lO:,Mold~d w/T~il P/t~ 5.85 ~s, ~', '~' P~n~m ~ 5.72 ~l~ Wit Re~ ~ (~ ~m of Seal B~ E~ion) 3J8 M~e S~ IO,44~' ~/ ~,2;W' OR PERFORATION HISTORY ............. Date Zone Top_ .... Btm Ami ~ Co .mmenta , . B-I 10,27U 10,310' 32' Existing B-3:10.440: I 101450' B-4 10,580' : 10,630' I 50' gxlstln~g .. ............ ~-s lo,'~aa, ] lo34o' ! ~, ! Exi~ PBTD = 10,970' TD = 11,055' MAX HOLE ANGLE = 32.5° @ 3,900' P-3draw.dc~- DRAWN BY: tcb REVISED: 9130197 I UNOCAL ) RKB to = 41.$~ s~zE wr 13-3/8" 61 9.5t8" 40.43.5 7" 29 Tubing 3-1/2" 9.2 Dolly Varden Well No. 3 rd 2 Proposed Completion I Illl Ill I I I ___ CASING AND TUBING DETAIL GRADE CONN ID TOP 1-55 12.51 Surface N-80 BTC 8.755 Surface N-80 BTC 6.188 6~267' L-S0 BT&C$C 2.992 41.5' 2.506' 6,5'70' 11,055' 9,599' A 22~ GR. 7/23196 I>-3rclgproudtaw. doc NO. D~th ~n~ I 41J0 2 $.OO 3 250' 3.815 4 3.00 3.00 3.00 3.00 3.00 5 9~99' 3 6 9,60~' ,~OO 7 9,604: 4.OO 8 9,62a' 2.813 9 9,6:t6' 2.94 J~WFJ~Y DETAIL It~e~m __ crw, 1 !- x 4,,, SM, DEB $ingl, Tubing H~ ~v~, ~1/2" Bursa x ~- ~" Ba~ 7.~ ~i, DCTRBV SSSV O.813 I.D.) M~Ma~ 3-1/2" SM~2 GLM, 1-1~" McM~ Ma~, 3-1~" $M~2 G~I. 1-1~" M~ M~, 3-1&" 8M~2 GL.M, 1-1~" MrM~ M~, 3-1~" SM~2 O~, lq~" M~Ma~, ~-1~' $M~2 G~I. 1-I~" M~ M~, 3-1/2~ ~2 GLM, 14P2" M~ Ma~, ~-1~~ ~2 G~I, 1-1~" 4.75 HES, N~ $~ ~mbly, 10', Mo!~d w/'ral pi~ (S~ed 'f~ P~r) 5.20 H~, S~ ~ g~ioa, (8' Lou~ Hes, 'X' Ni~pl* 3.78 W~ Li~ R-,~ ~de A 9,993' .- 7" CIBP B 9,999' 4.00 5.85 Otis, 7". 'WI3' Pexmancat Packet PERFORATION HISTORY Alxum. [ 9.8~3' 9,890' 37' 6' 9,935' 9,955' 20' 6' ..... 10,a~a' 10,352' 24' - Sm~u~ PBTD = 9,993' TD = 11,0~;5~ MAX HOLE ANGLE = 32,~;° @ 3,900* DRAWN BY: tcb REVISED: 11t7/97 WELL D- 3RD2 HYDRAULIC WORKOVER PLATFORM DOLLY VARDEN 5" FILL DRILLING SPOOL 15 5/8" 5M x 13 5/8" 5M WITH 4 1/16" 5M OUTLETS ANNULAR PREVENTER HYORIL "OK" ~3 5/8" 5M DOUBLE GATE "NL" SHAFFER ~3 s/~" 5~ 2 7/8" X 5" VARIABLE RAMS IN TOP BLINDS IN BOll-OM ,/ RISER 15 5/8" 5M ADAPTER SPOOL 13 5/8" 5M x 11" 5M HrGH PREgSURE CIRCULATING PLATFORM DOLLY SYSTEM VARDEN 'E]~CHHYI) ~E I P~N~ UNE Z FILL []zt I~. FLOW LINE UNE FIANCE 2", 51~ 1502 UNION ~2", 5U HOSE " ,,/~so2 u.loH PRODUCTION ~', 51~ P,.ANOE 2', §l,i 1502 FOR HWC KELLY UFIE ,,,-- 2", 5M LOTORC FROt~ PUMP F-1 2" 1502 2", 5M STEEL TEE UNION PANEL UNE F-I' % 10 PRO~IIO~ ,<:: GENERAL CIRCULATING SYSTEM 'HYDRAULIC WORKOVERS PLATFORM DOLLY VARDEN HOSE: 4" HOSE FROM PLAITORM MTS FILL I~)SE ,,> 4" RETURN 2', 51~ KELLY HOSE 6' SUCTDN ,, 50 BBL. 1 TRIP T~I( --ioi'o oI . OP1 I'~IPLEX ~UO PUUP 4" RET'O RN (TO PLAT PITS) GRA~ITY 2 '. 5M 1502 TO PRODUCllON TO PRODUCTION OVERHEAD VIEW GAUGE VALVE AT 90 DEGREES FRO~I WELL 113' lO PITS SlOE VIE~ ] 3 ~/~6" SM FR0~4 PLATFORM WELL B1" CHOKE MANIFOLD DOLLY VARDEN TONY KNOWLE$, GOVERNOR ALAS OILAND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 CORRECTED WELL NO. December 20, 1995 .: Chuck Beaucannp, Field Superintendent Union Oil Company of California 260 Caviar Street Kenai, Alaska 99611 Re: No-Flow Verification FIRF Well TBU D-3RD2 (PTD 83-081) Dear PLr. Beauca/np: On December 6, 1995 our Inspector, Bobby Foster, witnessed a "no-flow" test on UNOCAL's McA_rthur River Field well TBU D-3RD2.. Gas lift to the wells had been shut-off and the well bled to atmosphere before the inspector arrived. He observed the well directed into a clean tank. No fluid flow was observed, there was gas flow that was too small to measure, "only bubbles in a bucket". He observed the well for 3 hours and saw no increase. The Inspector concluded that subject well is not capable of unassisted flow of hydrocarbons. McArthur River Field well TBU D-3RD2 (PTD 83-081) meets the criteria of a "no-flow" performance test and, as such, is considered incapable of flow to the surface. Under the authority of 20 AAC 25.265(A) a fail safe automatic SSSV is not required; however, the pilot and surface safety valve must be maintained in good condition and if, for any reason, the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be reinstalled and maintained in good working condition. Sincerely, Blair E. Wondze~-- ~ PI Supervisor ~-' CC: Bobby D. Foster Mark Atkins, UNOCAL bew\1995 \n~-mrf lw STATE OF ALASKA AL~K~ OIL AND GAS CONSERVATION COMMISSION REPORT OF'SUNDRY WELL OPERATiO I$ 1. Operations performed: Operation shutdown ~ Stimulate__ Plugging __ Perforate X Pull tubing __ Alter casing ~ Repair well w 2. Name of Operator UNOCAL (Marathon 3. Add[:)e?~). Box 190247 t 5. Type of Well: 0il Co- Sub 0perat r) Devel°pment X-~- Exploratory __ Stratigraphic ~ Anchorage, AK 99519] Service__ 4. Location of well at surfa[eBg A-2, Cond. #11, Dolly Varden Platform 757' FSL, 1,133' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,550' FNL, 905' FEL, Sec. 6-8N-13W-SM At ef[ective depth 1,190' FNL, 771' FEL, Sec. 6-8N-13W-SM AttQja,~,~j~ FNL, 740' FEL, Sec. 6-8N-13W-SM 12. Present well condition sUmmary Total depth: measured true vertical 11,055 ' feet Plugs (measured) 9,947' feet 13. 14. Other 6. Datum elevation (DF or KB) 106' KB AbQY~ MSL 7. Unitor Property name Tradin[l Bay Unit 8. Well number feet D-3Rrl? 9. Permit number/approval number 90-823 10. APl number 5o7-33_ 20090_0'~ 11. Field/Pool Hemlock None Effec!ive depth: measured 10,970 ' true vertical 9 o 872 ' Casing Length Structural Conductor Surface 2,505' Intermediate 6,570 ' Production Liner 4,788' Perforation depth: measured feet Junk (measured) feet Size Cemented true vertical 13-3/8" 9-5/8" 7" 1,224 sx See Attachment #1 None Measured depth 2,506' 6,570' 11,055' True vertical depth 2,234' 5,915' 9,947' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 ASL Tbg. ca Packers and S. SSV (tvpe and n)easured WD PEr w/7.5" SBE (4.00" ID)h)ca dep.t 6,189' 3 1/2" 9 2# , , · , 9,999' MD; Otis 4-1/2" Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N-80 Butt. Tbg. Ca 10,069' SSSV-DC Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl TRBV (3.813":~...~ , ,E6blV DEC 18 1990' Casing Pressure Tubing Pressure Prior to well operation 10/29/90 76 19 338 Subsequent to operation 11/7/90 203 13! 2389 15. Attachments #2 Copies of Logs and Surveys run m Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedForm 10-404 Re~d[''''~/15=/~- ~'~- ~;:~ '-.-.'--~v-,_ Title ~,~_~ .,~ ~'~'5,rlk,~ , 1000 120 1100 120 16. Status of well classification as: Oil ._.X Gas_ Suspended __ Service Date ~z- ~-7 -%o SUBMIT IN DUPLICATE Attachment #1 Well D-3RD2 Perforations Hemlock B-1 B-2 B-3 B-4 B-5 B-5 MD 10,278' - 10,310 10,328' - 10,352 10,440' - 10,450 10,520' - 10,630 10,650' - 10,668 10,720' - 10,740 TVD 9,225 - 9,252 9,268 - 9,289 9,366 - 9,375 9,434 - 9,527 9,547 - 9,561 9,607 - 9,625 NEF/em/57A/DVP Attachment #2 TBU Well D-3RD2 Daily Summary of Wel 10perati ons 10/30/90 E-line and PT lubricator to 2500 psi. RIH w/ 2-1/8" Enerjet gun~,4 SPF, ~§ phasing, offset 30 , correlate and reperforate HB-3, 10,440' - 450' DIL. Flow well for clean up. SI well and POOH. MU guns as before, RIH, correlate and reperforate HB-1, 10,278' - 10,310' DIL. Flow well for clean up. SI well and POOH. Place well on production. 11/4/90 RU wireline unit and PT lubricator to 2500 psi. Attempted to set K-Storm choke in "X" Profile 0 269'. Choke failed pressure test. Pulled choke out of hole. Secure well. Sent choke to beach to have dome pressure reset. 11/9/90 RU wireline unit and PT lubricator to 2500 psi. RIH w/ K-Storm choke and set in X-lock @ 269'. Conducted pressure tests. Choke failed due to choke closing at or above separator pressure. RIH and pull choke. RD and secure well. 11/25/90 RU wireline and PT lubricator to 2500 psi. RIH and set 4-1/2" Storm choke, dome pressure set at 42 psi. Test storm choke, closed at 82 psi. No buildup after valve closed - good test. RD and place well on production. docs\dvp\d3rd2, doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter Casing __ Repair well __ Change approved program __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Harathon 0il Co - Sub 0peratlr) Devel°Pment X-- Exploratory __ 3. Add~e?~. BOX 190247 Anchorage, AK 99519~ StratigraphiC__service__ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pulltubing ~ Variance__ Perforate X Other Platform 4. Location of well at surfa~eeg A-2, Cond. #11, Dolly Varden 757' FSL, 1,133' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,550' FNL, 905' FEL, Sec. 6-8N-13W-SM At effective depth 1,190' FNL, 771' FEL, Sec. 6-8N-13W-SM At to al ~ ~,i%P¢ FNL, 740' FEL, Sec. 6-8N-13W-SM 6. Datum elevation (DF or 106' KB Above HSL 7. Unit or Property name Trading Bay Unit 8. Well number D-3RD2 9. Permit number ~3-81 10. APl number 507-33-20090-03 11. Field/Pool Hemlock feet 12. Present well condition summary Total depth: mea§ured 11,055 ' feet true vertical 9,947 ' feet Effective depth: measured 10,970 ' feet true vertical 9,872 ' feet Plugs (measured) Junk (measured) None None Casing Length Size Structural Conductor Surface 2,505' 13-3/8" Intermediate 6,570' 9-5/8" Production Liner 4,788' 7" Perforation depth: measured true vertical Tubing.(size, grade, and measured depth) 4-1/2", 12.6#, N-80 ASL Tbg. ~ P~;)ke~t~(:¥dwS/~V" §~pe~cj~ r~/~.s~)r~J d~l~) C8 See 6,189', 9,999' Cemented 1,224 sx Attachment #1 3 1/2", 9.2#, MD; Otis 4-1/2" Measured depth True vertical depth 2,506' 2,234' 6,570' 5,915' NOV 1 ,: 'A~choraga N-80 Butt. Tbg. ~ 10,069' SSSV-DC TRBV (3.813" ID) @ 269'MD 13. Attachments 1, 2 & Description summary of proposal --X- 3 Detailed operations program __ BOP sketch 14. Estimated date for commencing operation October' 30, 1990 16. If proposal was verbally approved Russ Dou.qlas Name of approver 10/30/90 Date approved 15. Status of well classification as: Oil _,Y,.. Gas__ Suspended __ Service 17. I hereb.,.v_.g, ertify that the foregoing is true and correct to the best of my knowledge. Signed( ~~ ~, (~ ,-.,"-'~L Title ~'~. ~"~¢\ ~. ~ f,~ ' FOR COMMISSION USE ONLY Conditions ofk,alpprov'aff. Notify Commission so representative may witness Plu'"g integrity __ BOP Test __ Location clearance __ ~, , Mechanical Integrity Test __ Subsequent form required 10- ~ T- JApproval N:~¢., ~¢,~ ~Z.. ORIGINAL 91GNI~D B~ · 1.0NNIE C. SMITH Approved by order of the uommission Form 10-403 Rev 06115188 A~roved OoP~ ~eturme% Commissioner SUBMIT IN TRIPLICATE ~-5 .. 9 ,~5'Z' ,?_'ZS' 9,26B' 9,366' . 9,375' 9,~3&' o .9,561' 9 ,SM' .. §,625' 9,60'/' RECEIVED NOV 1 ~ 1990 1) 2) 3) Attachment #2 Well D-3RD2 PROCEDURE RU E-LINE UNIT. HOOK UP COMMUNICATION SYSTEM IN UNIT. PRESSURE TEST LUBRICATOR AND BOPE TO 2500 PSI. MAKE DUMMY,GUN RUN TO 10,750'. TAG FILL. POOH. RIH WITH 2-1/8" STRIP GUNS, 4SPF, O-PHASING, OFFSET 30-DEGREE AND PERFORATE THE FOLLOWING INTERVALS UNDERBALANCED (WELL FLOWING). OPEN CHOKE AND STABILIZE FLOW PRIOR TO PERFORATING. RUN BENCH INTERVAL DIL FOOTAGE i HB #3 10,440'-10,450' 10' 2 HB #1 10,278'-10,310' 32' 4) 5) 6) 7) 8) NOTE: RD E-LINE. FLOW WELL TO GROUP SEPARATOR AT A REDUCED RATE SLOWLY OPENING THE CHOKE COMPLETELY OVER ABOUT 4 TO 6 HOURS. FLOW WELL IN GROUP SEPARATOR FOR 12 TO 24 HOURS OBTAINING WC's EVERY FOUR HOURS. MONITOR SEPARATOR SCREEN FOR PERFORATING DEBRIS. PERFORM STEP RATE TEST WHILE OBTAINING FIRST 12-HOUR TEST. PLACE WELL IN 24-HOUR TEST AT OPTIMUM GAS LIFT RATE. TURN WELL OVER TO PRODUCTION. SI WELL. RU WIRELINE UNIT. PRESSURE TEST BOPE & LUB TO 2500 PSI. RIH WITH "K" STORM CHOKE DRESSED FOR 4-1/2" TBG. SET CHOKE & POOH. FLOW WELL TO SEP #1. DUMP D-3RD2 TO WELL CLEAN TANK & NOTE PRESSURE AT WHICH CHOKE CLOSES. CLOSING OF CHOKE TO BE SET 0 75 PSI. RD WIRELINE. RT WELL TO PRODUCTION. MAXIMUM ANTICIPATED SBHP IS 4100 PSI. \oe52\32.doc Attachment #3 DOLLY VARDEN F~ATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) LUBRICATOR -4'~.11~-i."6~.5000 psi CHISTMAS TREE POSITIVE CHOKE ---- 2' 5000 psi 2' 3000 psi 13 3/8' CASING STATE OF ALASKA -" AL/-,,.,<A OIL AND GAS CONSERVATION COMMIS,.,,ON' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate ~ Pull tubing __ Alter casing ~ Repair well __ Pull tubing ~ Other 2. NameofOperator UNOCAL (Marathon 3. Address P.O. Box 190247 4. Location ofwell atsurface Leg A-2, 757' FSL, 1,133' FWL, At top of productive interval 1,550' FNL, 905' FEL, Sec. At effective depth 1,190' FNL, 771' FEL, Sec. At total depth 1,159' FNL, 740' FEL, Sec. ! 5. Type of Well: Oil Co - Sub Operator) Devel.opm. ent--x J Exploratory __ / Stratigraphic __ Anchorage, AK 99~19 Service__ Cond. @fll, Dolly Varden Platform Sec. 6-8N-13W-SM 6-8N-13W-SM 6-8N-13W-SM 6-8N-13W-SM 6. Datum elevation (DF or KB) 106' KB Above MSL feet 7. Unit or Properly name Trading Bay Unit 8. Well number D-3RD2 9. Permit number/approval number 8-899 i0. APl number 50-- 733-20090-03 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,505 ' Intermediate 6,5 70 ' Production Liner 4,788 ' Perforation depth: measured true vertical 11,055' 9,947' 10,970' 9,872' Size feet feet feet feet Plugs (measured) Junk(measured) Cemented 13-3/8" 9-5/8" 7" 1,224 sx See Attachment #1 RECEIVED one JAH 25 t92q M &Gas Cons. C0mm ioa 2,506' 2,234' 6,570' 5,915' 11,055' 9,947' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 ASL Tbg. Packers and SSSV (type and measured depth) ~rD Pkr w/ 7.5' SBE (4.00" ID) @ 6,189' 3 1/2" 9 2# N-80 Butt Tbg @ 9,999' MD; Otis 4-1/2" SSSV-DC TRBV @ 10,069' (3.813" ID) @ 2fi 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11/26/88 245 81 1286 980 120 Subsequent to operation 12/30/88 15. Attachments( #2 Copies of Logs and Surveys run __ Daily Report of Well Operations ~ 282 92 1035 1010 140 16. status of well classification as: Oil x_._. Gas __ Suspended __ 17. I hereby certify that the f~regoi ng is true and correct to the best of my knowledge. Signed R.D. Roberts Title Environmental Engineer -- Form 10-404 Rev 06/15188 Service SUBMIT '1~ DUPLICATE Attachment #1 Well D-3RD2 Perforations Hemlock B-1 B-2 B-3 B-4 B-5 B-5 10,278' - 10,310' 10,328' - 10,352' 10,440' - 10,450' 10,520' - 10,630' 10,650' - 10,668' 10,720' - 10,740' TVD _ 9,225' - 9,252' 9,268' - 9,289' 9,366' - 9,375' 9,434' - 9,527' 9,547' - 9,561' 9,607' - 9,625' NEF/em/57A/DVP Attachment #2 TBU Well D-3RD2 Daily Summary of Well Operations 12/4/88 RU WL and PT to 2500 psig, OK. RIH w/ 2.70" gauge ring and tag fill at 10,796' WLM. POOH, RD WL. 12/6/88 RU E-line and PT to 2500 psig, OK. MU 2-1/8" Enerjet II perforating guns, 4 SPF, 0° phasing. RIH, correlate and flow well 1 hour to stabilize. Perforate Bench 2, 10,328' - 10,352' DIL. Flow well to clean up. POOH, RD and place well in test. em/57A/DVP STATE OF ALASKA AI~,..,<A OIL AND GAS CONSERVATION COMMIS,.,,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging Pull tubing __ Alter casing __ Repair well __ 2. NameofOperator UNOCAL (Marathon 3. Address P.O. Box 190247 4. Locationofwellatsudace Leg 757' FSL, 1,133' Attopofproductiveinterval 1,550' FNL,.;905' effectivedepth 1,190' FNL, 771' Attotaldepth 1,159' FNL, 740' Perforate _~x Pull tubing ~ Other __ ! 5. Type of Well: Oil Co - Sub Operator) Development_~ / Exploratory __ Anchorage, AE 99~19 StratigraphiCservice____ A-2, Cond. #11, Dolly Varden Platform FWL, Sec. 6-BN-13W-SM FEL, Sec. 6-8N-13W-SM FEL, Sec. 6-8N-13W-SM FEL, Sec. 6-8N-13W-SM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,505 ' Intermediate 6,570 ' Production Liner 4,788' Perforation depth: measured true vertical 11,055 ' feet Plugs (measured) 9,947 ' feet 6. Datum elevation (DF or KB) 106' KB Above MSL 7. Unit or Property name Tradin~ Bay Unit 8. Well number D-3RD2 9. Permit number/approval number 83-81/, 8'678 10. APl number 50-- 733-20090-03 11 Field/Pool 'Hemlock None 13. 10,970 ' feet Junk(measured) None 9,872 ' feet c~ ,~E i V E [~asured depth Size JAN 1 2' ]989 13-3/8" 2,506 ' 9- 5 / 8" AI~ Oil & Sa~ Co.~. I~~~ 6,57 O' '.~ Anchorage' 7" 1,224sx 11,055' 14. See Attachment #1 Tubing (size, grade, and measured dePth) P , 4-1/2". 12.6#, N-80 ASL Tbg. acKers anUSSSV (type an~l measured depth) T,'rr~ 'D .-. ,-,1. ,-, ..,. ~ OQQT .../'7 Sti m u I ~t'i'o n'~ ~6}'~nt '' ............ squeeze summary 6,189' 3 1/2" (4.00" Tn). Intervals treated (measured) Treatment description including volumes used and final pressure 9.2#, N-80 Butt. ~ TRRV 0 ?69' Represent~iveDailyAverageProductionorlnjectionData Oil-Bbl Gas-Mcf Water-Bbl CasingPressure 186 105 976 / 970~ 90 1351 Prior to well operation 9/22/88 Subsequent to operation 10/24/88 245 15. Attachments: #2 Copies of Logs and Surveys run __ Daily Report of Well Operations x 16. Status of well classification as: Oil x__ Gas_ Suspended_ feet 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~'=~ ~.~'~o~e~rts~~ Title Environmental Engineer Service True vertical depth 2,234' 5,915' 9,947' Tbg. @ 10,069' Tubing Pressure 140 120 Date 1/9/89 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Attachment #1 Well D-3RD2 Perforations Hemlock B-1 B-3 B-4 B-5 B-5 10,278' - 10,310' 10,440' - 10,450' 10,520' - 10,630' 10,650' - 10,668' 10,720' - 10,740' TVD 9,277' - 9,225' 9,366' - 9,375' 9,434' - 9,527' 9,547' - 9,561' 9,607' - 9,625' NEF/em/57A/DVP Attachment #2 TBU Well D-3RD2 Daily Summary of Well Operations 10/2/88 RU E-line & PT lubricator, OK. Made five perforating runs using 2-!/g" Enerjet II, A SPF~ 0° phasic, g, 13.5 gm charge perf g~n~. R!H and perforated Bet. ch ~ ic~ 770' - ]O 740' az~d 10,650' 10,668' DIL; Bench 4, 10,610' 10,630', 10,580' - 10,610', and 10,550' - 10,580' DIL. Flowed well for 10 min after each perforating run. Made two perforating runs using 2-1/8" Enerjet II, 4 SPF, 0° phasing, 13.5 gm charge perf guns. RIH and perforated Bench 4, 10,520 - 10,550' DIL; Bench 1, 10,280' - 10,310' DIL. Flowed well for I0 min after each run. SI & POOH. lO/4/88 Made one perforating run using 2-1/8" Enerjet II, 4 SPF, 0° phasing, 13.5 gm charge perf guns. RIH and perforated Bench 3, 10,440' - 10,450' DIL. Flow well for I0 min. POOH. ~]), flow well for cleanup and put well Jn test. em/57A/DVP STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISsiON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon Oil Co - Sub Opera~or) De~vel.opm. entM_ / ~-xp~ora[ory __ 3. Address | Stratigraphic_ P.O. Box 190247 Anchorage, AK 995119 Service 4. LocationofwellatsudaceLeg A-2, Cond. #11, Dolly Varden Platform 757' FSL, 1,133' FWL, Sec. 6-8N-13W-SM Operation shutdown ~ Re-enter suspended well __ Plugging m Time extension __ Stimulate __ Pull tubing ~ Variance __ Perforate ~ Other 6. Datum elevation (DF or KB) 106' KB 7. Unit or Property name Trading Bay Unit 8. Well number D-3RD2 feet Attopofproductiveinterval 1,550' FNL, 905' FEL, Sec. 6-8N-13W-SM Ateffectivedepth 1,190' FNL, 771' FEL, Sec. 6-8N-13W-SM ~totaldepth 1,159' FNL, 740' FEL, Sec. 6-8N-13W-SM 12. Present well condition summary Total depth: measured 11,055 ' feet true vertical 9,947 ' feet Effective depth: measured 10,970 ' feet true vertical 9,872 ' feet Plugs (measured) Junk (measured) 9. Permit number 83-81 10. APl number 50-- 733-20090-03 11. Field/Pool Hemlock None None Ff'FIVFh , ~,~,J~ .0il & Gas Cons· Casing Length Structural Conductor Surface 2,505 ' Intermediate 6,5 70 ' Production Liner 4,7 88 ' Perforation depth: measured Size Cemented Measured depth True vertical depth 13-3/8" 2,506' 2,234' 9-5/8" 6,570' 5,915' 7" 1,224 sx 11,055' 9,947' See Attachment #1 true vertical Tubing (size, grade, and measured depth) 4-1/2" 12 6# N-80 ASL Tbg @ 6,189' 3 1/2" 9 2# N-80 Butt· Tbg. @ 10,069' , · , · , ' · , Packers and SSSV (type and measured depth) ~ ~_r ¢ 9.999' w/7.5" SBE. ¢4.00" ID), DC TRBV @ 269' 13. Attachments 2 & 3 Description summary of proposal ~ Detailed operations program __ BOP sketch .,~ 14. Estimated date for commencing operation December 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas__ Suspended __ Service 17. I herebypOtify that the foregoing, is true and correct to the.,best of my knowledge. ~ ~o¥ D. :Rob~'bs } ' /"/FOR COMMISSION USE ONLY - Conditions of approval: Notify Core'mission so re, Fr/~ntative may witness Plug integrity __ ./ BOP Test ~ Location clearance / i ,,/, Mechanical IntegrityTest_ ' Subsequent form required 10-/'' :\pp~oved Copy ORIGINAL SIGNED BY Returned Approved by order of the ComrJrl{i)sl~loner' SMITH '/~;,~ - ~ ~:~ ~ Commissioner Date 1210]/RR JApprovalNo. ~_ ~~ Date /'~ -/' -~:F ¢ FOrm 10-403 Rev 06/15~88 SUBMIT IN TRIPLICATE Attachment Well D-3RD2 Perforations i0,278, - 10,310, i0,440, _ 10,450, 10,520, - I0,620, I0,650, _ i0,664, 10,720, - 10,740, TVD 9,277, _ 9,225, 9,366, _ 9,375, 9,434' _ 9,521, 9,547, _ 9,559, 9,607, _ 9,625, NEF/em/5 7A/DVp R CEIVED · -,<. "~,nuhorag. O >~ Attachment #2 Well D-3RD 2 Procedure 1. RU Electric line. PT to 2500 psi. 2. Perforate the following intervals underbalanced w/ 2-1/8" strip gun, 4 SPF, 0° phasing. Run Bench Interval DIL 1 B-2 3. RD E-Line. 10,328' - 10,352' Footage 24 Note: Maximum anticipated SBHP is 3450 psi. em/57A/DVP Attachment ~3 D~LLY VARDEN PLA'..:ORM Wireline Lubricator w/Associated BOPE - GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED ' BOP 5000 psi CHISTMAS TREE POSITIVE CHOKE ~ 2' 5000 psi _-- 2' 3000 psi 13 3/8' CASING 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 -- Alter casing '-'; T~me extension Change approved program Plugging '~. Stimulate .~ Pull tubing Amend order .r Perforate Xi Other 2 Name of Operator 5. Datum elevation(DF or KB) UNOCAL (Harathon O±l Company - Sub Operator) 106' KB feet 3 Address 6. UnitorPropertyname P.O. Box 190247 Anchorage, AK 99519 Trading Bay Unit 4. Locationofwellatsurfac~eg A-2, Cond. #11, Dolly Varden Platfo: 757' FSL, 1,133' FWL, Sec. 6-8N-13W-SM Attop of productive~nterval 1,550' FNL, 905' FEL, Sec. 6-8N-13W-SM Ateffective depth 1,190' FNL, 771' FEL, Sec. 6'8N-13W-SM Attotaldepth 1,159' FNL, 740' FEL, Sec. 6-8N-13W-SM ."m7. Well number D-3[~)2 8. Permit number 7-904 ,. ^,, 20090-03 i..~ 5- 50-- 10..P~elmlock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 2,505 ' Production 6,570' Liner 4,788' Perforation depth: measured true vertical 11,055 ' feet Plugs (measured) 9,947 ' feet None 10,970' feet Junk (measured) None 9,872 ' feet Size V E [ easured depth SEP - 6 1988 13-3/8" ~n 2, 5o6 , 9-5/8" Al~sk~ Oi~ & Gas Cons. C0mmis~i.[t 6,570' Anchorage 7" 1,224 sx 11,055' See Attachment #1 True Vertical depth 2,234' 5,915' 9,947' Tubing (size, grade and measured depth) 4-1/2", 12.6#, N-80 ASL Tbg. @ 6,189', 3 1/2", 9.2#, N-80 Butt. Tbg. @ 10,069' Packers and SSSV (type and measured depth) ~.~ Packer @ 9,999' w/7.5" SBE, (4.00" ID), DC TRBV @ 269' 12.Attachments 2 & 3 Description summary of proposal ~ Detailed operations program El BOP sketch 13. Estimated date for commencing operation September 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby Certify that the foregoing is true and correct to the best of my knowledge Si~~~ ~'~~~ Title EnvJ_ronmegl~al ,c~-- ' '/? "R°~ D. ~~ts ~~ ~~sion Use Only Conditions of approval Approved by Date Notify ~r-...:;;:c::~cc,r_'cpre~_e_ntati~ve may witness I Approval No. ~.' Plug integrity ~ BOP Test ~-Location clearanceJ ~Approved Copy Returned_ by order of LONNIE C. SMITH Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate/~f/ Attachment #1 Well D-3RD2 Perforations Hemlock B-1 B-3 B-4 B-5 B-5 10,278' - 10,310' 10,440' - 10,450' 10,520' - 10,620' 10,650' - 10,664' 10,720' - 10,740' TVD 9,277' - 9,225' 9,366' - 9,375' 9,434' - 9,521' 9,547' - 9,559' 9,607' - 9,625' NEF / em/57A/Sundr 3 Attachment #2 Well D-3RD2 Procedure 1. RU electric line. PT to 2500 psi. 2. Perforate the following intervals underbalanced w/ 2-1/8" strip gun, 4 SPF, 0° phasing: Run Bench Interval DIL Feet 1 Lower B-5 10,720' - 10,740' 20 2 Upper B-5 10,650' - 10,668' 18 3 B-4 10,610' - 10,630' 20 4 B-4 10,580' - 10,610' 30 5 B-4 10,550' - 10,580' 30 6 B-4 10,520' - 10,550' 30 7 B-1 10,280' - 10,310' 30 Test well for 12 hours after stabilized, then continue perforating if oil is below 500 BOPD. 8 B-3 10,440' - 10,450' 10' 3. RD electric line. Note: Maximum anticipated SBHP is 3500 psi. 57A/DVP Attachment #3 ~)LLY VARDEN PLA-FORM ! Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) ,, BRiCATOR 4 '~1/-,1,6~. 5000 psi CHISTMAS TREE POSITIVE CHOKE --- 2' 5000 psi 2' 3000 psi 13 3/8' CASING STATE OF ALASKA ALASK,-. ,.)IL AND GAS CONSERVATION COMM,_-,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) %INOCAL (Marathon 0il Company - Sub Operator) 106' KB Feet 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-2, Cond. #11, Dolly Varden Platf~ 757' FSL, 1,133' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,550' FNL, 905' FEL, Sec. 6-8N-13W-SM At effective depth 1,190' FNL, 771' FEL, Sec. 6-8N-13W-SM At total depth 1,159' FNL, 740' FEL, Sec. 6-8N-13W-SM 6. Unit or Property name Trading Bay Unit ,r~. Well number D-3RD2 8. Approval number 7-904 9. APl number 50-- 733-2009 O-geT'~ 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,055 ' feet Plugs (measured) 9,947 ' feet 10,970 ' feet Junk (measured) 9,8 7 2 ' feet Casing Length Size Structural Conductor Surface Intermediate 2,505 ' 13-3/8" Production 6,570 ~ 9-5/8" Liner 4,788' 7" Perforation depth: measured true vertical None None Cemented Measured depth True Vertical depth 2,506' 2,234' 6,570' 5,915' 1,224 sx 11,055' 9,947' See Attachment #1 Tubing (size, grade and. measured depth) 4-1/2", 12.6#, N-80 ASL Tbg. @ 6,189', 3 1/2", 9.2~, N-80 Butt. Tbg. @ 10,069' Packers and SSSV (type and measured depth) WD Packer @ 9 999' w/7.5" SBE, (4.00" ID), DC TRBV @ 269' ,, ~--,,-., 7' ~"; ':'2'.-~, 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to wel!_~'~peration 11/26/87 130 0 124 925 psi Subsequent to operation 12/14/87 429 335 832 1080 psi ~bing Pressure 140 psi 130 psi 14. Attachment~ #2 Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge I big~ Roy O. Roberts Form~:404 Rev. 12-1-85 Title Environmelltal ENgineer Date 1/18/88 Submit in Duplicate Attachment #1 Well D-3RD2 Perforations Hemlock B-1 B-3 B-4 B-5 B-5 10,278' - 10,310' 10,440' - 10,450' 10,520' - 10,620' 10,650' - 10,664' 10,720' - 10,740' TVD 9,277' - 9,225' 9,366' - 9,375' 9,434' - 9,521' 9,547' - 9,559' 9,607' - 9,625' NEF/em/57A/Sundr3 Attachment #2 TBU Well D-3RD2 Daily Summary of Well Operations 1211187 RU slickline, PT lubricator to 2500 psi, OK. RIH w/2.72" gauge ring and tag TD @ 10,805' WLM. POOH (no scale). RIH w/BHP inst and take FBHP survey @ 10,538' WLM. POOH, RD. 12/2/87 RU wireline and PT lubricator. Made three perforating runs using 2-5/8" hollow carrier guns, 4 SPF, 0° phasing. 1st run: perfed Bench 5 from 10,720' - 10,740' DIL; 2nd run: perfed Bench 5 from 10,650' - 10,668' DIL; 3rd run: perfed Bench 4 from 10,580' - 10,610' DIL. 12/3/87 Made four perforating runs using same guns as above. 1st run: perfed Bench 4 from 10,550' - 10,580' DIL; 2nd run: perfed Bench 4 from 10,520' - 10,550' DIL; 3rd run: perfed Bench 3 from 10,440' - 10,450' DIL; 4th run: perfed Bench 1 from 10,278' - 10,308' DIL. RD wireline, put well on test. NEF/em/57A/Sundr3 "-" STATE OF ALASKA .... · ALA,,KA OIL AND GAS CONSERVATION CO,...vlISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing L-J Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg A-2, Cond. ¢~11, Dolly Varden Platfc 757' FSL, 1,133' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,550' FNL, 905' FEL, Sec. 6-8N-13W-SM At effective depth 1,190' FNL, 771' FEL, Sec. 6-8N-13W-SM At total depth 1,159' FNL, 740' FEL, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106 ' KB 6. Unit or Property name Trading ~¢y Unit tm7. Well number D-3RD2 8. Permit number 83-81 9. APl number 50-- 733-20090-03 10. Pool Hemlock feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,055 ' feet Plugs (measured) 9,947 ' feet 10,970' feet Junk (measured) 9,872 ' feet Casing Length Size Structural Conductor Surface Intermediate 2,505 ' 13-3/8" Production 6,570 ' 9-5/8" Liner 4,788' Perforation depth: measured true vertical None None Cemented ,._. Measured depth · 6,570' 7" 1,224 sx 11,055' See Attachment #1 i £¢Eltf .E. 1 9]$8 ~laska Oil & Gas Cons, Co. Ancho_ /ra_re_ , ~, True Vert ica~b'~J'p,,, 2,234' 5,915' 9,947' Tubing (size, grade and measured depth) 4-1/2", 12.6#, N-80 ASL Tbg. @ 6,189', 3 1/2", 9.2~, N-80 Butt. Tbg. @ 10,069' Packers and SSSV (type and measured depth) 'WD Packer @ 9,999' w/7.5" SBE, (4.00" ID), DC TRBV @ 269' 12.Attachment~: ¢'/2 Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation November 1987 14. If proposal was verbally approved Name of approver Date approved 15.1 hereby certifyt~hat the for~in~ is !rue ~,,nd correct to the best of my knowledge Signed ~ Title Envif'onmenta] Special t;andace I~.'-Coc]<~ood b $ Commission Use Only Date 11/l 7/87 Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance I Approval No. Approved//_~O Copy/,~r,, / ~'/~ Returned ,.~..,o=~ ~ '~ 'byorderof Commissioner the commission Date 4 Form 10-403 Rev 12-1-85 Submit in triplicate Attachment #i Well D-3RD Perforations B-1 B-3 B-4 10,278, _ 10,310, 10,440, _ 10,450, i0,520' _ 10,620' 10,650' _ 10,664, TVD 9,277' _ 9,225' 9,366' _ 9,375' 9,434' - 9,521' 9,547' _ 9,559' NEF/em/5 7/Sundr3 RE:' IVE.D Alaska Oil ~,, ~ Cnn~. C~rnmission Attachment #2 Well D-3RD2 Procedure 1. RU Otis WL and PT to 2500 psi. 2. RIH with 2.72" GR and cut scale as necessary. 3. Tag bottom and POH. 4. Make up dual Amerada bombs. 5. RIH and stabilize well. 6. Measure flowing BHP at 10,538' (9,450' TVD). 7. POH and RD Otis. 8. RU E-line and PT to 2,500 psi. 9. Perforate underbalanced or flowing and test as indicated below with 2-1/8" or 2-5/8" through tubing guns. Gun size will be determined by the results of earlier gauge ring work. Run Interval Feet Zone ,, 10,720' - 10,740' 10,650' - 10,668' 10,580' - 10,610' 10,550' - 10,580' 10,520' - 10,550' 1 20 B5 2 18 B5 3 30 B4 4 30 B4 5 30 B4 Stabilize well and test for 12 hours, then continue perforating as below: 6 10,440' - 10,450' 10 B3 7 10,278' - 10,310' 32 BI 10. RD E-line. 11. RU Otis and PT lub. to 2,500 psi. 12. RIH with dual Amerada gauges and stabilize well. 13. Measure flowing BHP at 10,538' (9,450' TVD). Attachment #2 Well D-3RD2 Procedure Continued 14. POH RD Otis. Otis will read pressure charts then send data and chart to Rose Hamlin in Anchorage office. Data will also be sent to W. L. Browne in Nikiski. 15. Test well for at least 24 hours. NEF/em/57/Sundr3 STATE OF ALASKA -- ' ALAS.., OIL AND GAS CONSERVATION CON.' ~3SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~.' Stimulate ~ Plugging ~ Perforate ~ Pull tubing Alter Casing L~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) UNOCAL 106 ' KB Feet 3. Address 6. Unit or Property name P.O. Box 190247 Anchorage, AK 99519 Trading Bay Unit 7. Well number D-3RD2 , . #1 Dolly Varden 4. Location of well at surface Leg A-1 Cond 1, 757' FSL, 1,133' FWL, Sec. 6 - 8N - 13W - SM Platform At top of productive interval 1,550' FNL, 905' FEL, Sec. 6 - 8N - 13W- SM At effective depth 1,190' FNL, 771' FEL, Sec. 6- 8N- 13W- SM At total depth 1,159' FNL, 740' FEL, Sec. 6 - 8N - 13W- SM 8. Approval number 9. APl number 50-- 733-20090-02 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,055' feet 9,947 ' feet 10,970' feet 9: 872 feet Casing Length Size Structural Conductor Surface Intermediate 2,506 ' 13 3/8" Production 6,570' 9 5/8" Liner 4,788 ' 7" Perforation depth: measured See Attachment #1 true vertical Plugs (measured) Junk (measured) Cemented Measured depth 1,224 sx 2,506' 6,570' 11,055' True Vertical depth 2,345' 5,915' 9,947' Tubing(size, grade and measured depth) 4 1/2", N-80 @ '6,189' 3 1/2", N-80 @ 10,069' . Packers and SSSV(typeand measured depth) "WD" Packer @ 9,999' "DC" TRBV @ 269' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 134 192 135 900 156 110 302 940 Tubing Pressure 140 200 14. Attachments Attachment #2 E)ai~ty~ Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge~,.~r ~.~-~ Signed RoyD. Roberts Title Environmental Engineer Date 6/6/86 Form 10-404 Rev. 12-1-85 Submit in Duplicate Attachment #1 D-3RD2 Perforations Hemlock B-1 B-2 B-4 B-5 10,278' - 10,310' 10,440' - 10,450' 10,520' - 10,620' 10,650' - 10,664' 9,227' - 9,255' 9,366' - 9,375' 9,434' - 9,521' 9,547' - 9,559' WJL/em/094/LAV Attachment #2 IfELL D- 3RD 2 On April 20 and 21, 1986, the well was perforated with 2 1/2" guns, 4 SPF, 0° phasing under draw down, as follows: B-1 B-2 10,278' - 10,310' DIL 10,440' - 10,450' DIL WJL/em/093/LAV Unocal Oil & Gas Divisk Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District April 8, 1986 Mr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Hr. Chatterton: SUNDRY NOTICES AND REPORTS ON WELLS DOLLY VARDEN PLATFORM Attached for your approval are two (2) copies each of Form 10-403 for wells D-~RD2; D-SRD and D-43RD. Upon approval, please return one copy of each Notice to the undersigned. Very truly yours, Environmental Engineer cwl 00280 cc: Trading Bay Unit Participants RECEIVED APR 0 9 1986 Alaska 011 & Bas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Unocal* 83-81 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 50133-20090-02 4. Location of Well Surface: Leg A-2, 757' FSL, Cond. #11 Dolly Varden Platform 1133' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB Above MSL 6. Lease Designation and Serial No. ADL 18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-3RD2 11. Field and Pool McArthur River Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] Stim ulat ion Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). PERFORATE TBU WELL D-3RD2 It is Marathon's intention to perforate the well with 2 5/8" guns, 4 SPF, 0° phasing, under drawdown. 1. Rig up WL and lubricator, pressure test to 2500 psi. 2. RIH and perforate B-i; 10,278' - 10,310' DIL 3. Production test the well. 4. RIH and perforate B-3; 10,440' - 10,450' DIL. 5. Return the well to production. Perforating operations are expected to begin April 10, 1986. RECEIVED APR 0 9 1986 * Marathon Oil Company - Sub Operator 14. I hereb~y certify that the fo[egoing is true and correct to the best of my knowledge. Signed RO~"D o' ~' ~ Title Envi~l engineer The space below for Commission use 4/8/86 Date Conditions of Approval, if any: Approved by ;,; _ , .. :..',~' :. By Order of COMMISSIONER the Commission Date Form 10~03 R~,v 7-1-R~ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas -~.,ision: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union March 26, 1985 Mr. Chat Chatterton Alaska Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 SUNDRY NOTICE K-8RD & D-3RD #2 Dear Mr. Chatterton: Attached for your approval is a Sundry Notice of intention for K-8RD, Trading Bay Unit, and Subsequent for D-3RD #2, Trading Bay Unit. Please return the approved Sundry Notice to the undersigned. LOC/tj Attachments Very truly yours, Lawrenc 0~~. Cutting ENVIRONMENTAL SPECIALIST RECEIVED MAR 2 7 1985 AJaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA '~ ALASKA UIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Union Oil Company of California* 3. Address P.O. Box 6247 Anchorage, AK 99502 4. Location of Well Surface: Leg A-2, Cond. ~fl 1, Dolly Varden Platform 757' FSL, 1133' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 6. Lease Designation and Serial No. ADL-18729 7. Permit No. 83-81 8. APl Number 50- 733-20090-02 9. Unit or Lease Name Tpading Bay Un~ t 10. Well Number D-3RD2 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing ,~ Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). D-3RD2 WORKOVER · Workover operations began February 1, 1985, and were completed March 7, 1985. See the attached record of operations. RECEIVED MAR 2 7 1985 0i~ & Gas Cons. Commission .... Anchorage *Marathon OiI Company, Sub Operator 14. I hereby~ ~ ,r~nd correct to the best of mY knowledge. ~- (-~'7 Signed La, Pence O. Cut-t ing Title ENV I RONMENTAL SPEC I AL I ST The space below for Commission use Conditions of Approval, if any: p~e 03-26-85 By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate D-3RD2 WORKOVER ATTACHMENT OF PROCEDURES ! 1. RIH and perf'd tubing at 10,029. 2. Circulate well dead with 'workover fluid. 3. Set BPV. ND X-mas tree, NU and test BOPE. 4. POH & LD 4-1/3" X 3-1/2" tubing. 5. RIH and perf'd B-4; 10,580' - 10,620' 4 HPF 10,520' - 10,580' 2 HPF 6. RIH and set RBP at 10,642' and pkr at 10,447'. 7. Pump acid wash of 4000 gal. of 15% HC1 acid. 8. Pump frac treatment of 6300 lbs of 20-40 Carbo-Prop proppant in 240 bbls of SF-II frac gel. 9. Pull pkr. RIH, tag fill at 10,510' and wash sand to 10,630'. 10. RIH and reset pkr at 10,450'. Pump acid wash of 2000 gal. of 15% HC1 acid. 11. Pumped frac treatment of 24,500 lbs of 20-40 Carbo-Prop proppant, 6000 lbs of 100 mesh sand in 1000 bb!s of SF-II frac gel. 12. Pull pkr. RIH, taDo fill at 10,575', and wash sand to 10,642'. Pull RBP. 13. RIH with bit to 10,709' and circulate clean. PuI1 bit. 14. Set prod. pkr with wireline at ~10,Q00' DIL. RIH w/ short seal assy. and test pkr. POH and LD DP. 15. RIH w/ 4-1/2" x 3-1/2" tubing and sting into pkr. 16. Land tbg. hgr. and set BPV. ND BOPE, NU and test X-mas tree. Pull BP V. ~ 17. Return well to production. Production before workover: 261 BFPD, 55% WC, 117 BOPD, 143 BWPD. Production after workover: 789 BFPD, 28% WC, 568 BOPD, 221 BWPD. 18. RIH and reperforate Hemlock B-5 at 10,650' - 10,664i(~ V D Under drawdown at 4 HPF and 0° phasing. ~l E Production after B-5 reperforation: 739 BFPD, 29~ WC, 525 BOPD, 214 BWPD. Alaska Oil & Gas Corls. Commission Anchora~]e -~' FORUM 484 RE:V. 8-73 ,-DATE January 5, 1983 Marathon Oil Company HISTORY OF OIL OR GAS WELL WELL NO.._D3RD2 LEASE Trading Bay .Unit PARISH STATE Alaska MEASUREMENTS TAKEN FROM BLOCK SEC. 6 _ TWP. 8N 'ToP Of OIL STRING .ToP OF ROTARY TABLE ... GRD. OR MAT COUNTY Kenai Peninsula Borough 106 ' KB ELEV. ELEV. - ELEV. ELEV FIELD McArthur Rive R.i. 13W HISTORY PREPARED BY Lisa Y. Durham TITLE Secretary It 'is of the greatest importance to have a complete history of the well.. Use this form in reporting the history of all important operations ~at the well, together' with the' dates thereof, including size of hole,-size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE TBU Well D-3RD#2 (Marathon AFE #4878) 1983 09-28 09-29 09-30 10-0l 10-02 10-03 10-04 10-05 10-06 ll,iO0'TD ll,100'TD ll,100'TD ll,100'TD ll,100'TD ll,100'TD ll,100'TD ll,100'TD ll,100'TD Commenced operations on D-3RD#2 ~ 1130 hrs, 9-27-83. Skidded Rig #77 over D-3RD. Bullheaded 187 bbl FIW into tbg. Pumped 515 bbl FIW into csg/tbg annulus. RU WL. Press tstd lubricator to 2000 psi--OK. RIH w! perf gun on WL to shoot circ holes in tbg. Shot circ holes @ 10,060' tbg measurement. POH RD WL. Circ FIW to prod separator until well was dead. Installe~ BPV. ND X-mas tree. NU & tstd BOPE--OK. MU landing .jt in tbg hgr & PU tbg. Circ FIW to prod separator. POH LD 4-1/2" & 3~1/2" tbg. Torque converter went out on west crane. Wait on west crane repairs & mixed mud. Offload 4½" tbg across platform using east crane. PU RIH w/ 2-1/16" stinger. Following crane repair, PU RIH w/ 3½" & 5" DP. Tag fill @ 10,630' DPM--top of gravel pack assy @ 10,594' Prep to circ @ 0700 hrs. Circ hole @ 10,620' & mixed mud in pits. RU cmtrs. Mix- & spot 102 sx cmt to abandon Hemlock. Plug 10,620-070' (top of Hemlock Bench #1 perf @ 10,248'). Pulled 9 stds & rev circ. Displ FIW f/ hole w/ drlg mud. POH LD 3½" DP & 2-1/16" tbg stinger. RItt w/ 8½" bit & 9-5/8" csg scrpr to 8371' (TOL @ 8384'). Circ hole clean. POH. MU BP on DP setting tool & RIH. Set BP @ 8350'. POH to 6700'. Circ & cond mud to +150 sec/qt. Tstd csg to 1500 psi--OK. POH. MU section mill & RIH. Made initial cut in 9-5/8" csg @ 6570'. Milled 6570-76'. --. Milled 9-5/8" csg 6576-6600'. Circ BV. POH. MU section mill #2 & RIH. Milled 6600-08'. Milled 9-5/8" csg w/ section mill #2 6608-30'. Circ to clean hole. POH w/ section mill & LD same. PU 8½" bit & RIH. CO 9-5/8" csg stub 6636-737'. Cond mud for-kick off plug. POH. RIH w/ OEDP to 6726'. Circ BV. Spotted 140 sx C1G cmt 6726-6410'. CIP 1750 hrs, 10-05-83. POH to 6076'. Rev DP clean. LD 3 jts DP. Circ BV. POH. WOC. ~!aska ~11Mistory - Dolly Varden No. D-3RD#2 Page 2 10-07 6580'TD 10-08 6633'TD 10-09 6850'TD 10-I0 7037'TD 10-11 10-12 7320'TD 7775'TD 10-13 -8159 ' TD 10-14 8371'TD 10-15 8371'TD 10-16 8371'TD 10-17 8371'TD 10-18 9516'TD 10-19 9733'TD 10-20 9856 ' TD 10-21 10234'TD 10-22 10602'TD Tstd BOPE--OK. RIH w/ 8½" bit & tagged TOC @ 6488'. Drld hard cmt 6488-573'. C&C mud. POH. PU DD #1 & RIH to 6573'. RU RIH w/ steering tool. Oriented DD drld 6573-580'. Drld w/ DD #1 6580-633'. POH w/ steering tool 2 RD ~L. POM LD DD. MU & RIH w/ drlg assy. Ran leakoff test. 6633-732'. POM. w/ MWD. Reamed DD #1 run. Drld & surv RIH w/ DD #2. Drld 2 surv 6732-850' POH LD DD #2. MU BHA & RIH. Reamed 6732-850'. Drld & surv 6850-945'. Circ & dropped surv. POIt LD stabilizers. PU DD #3 & RIH. Oriented DD. Drld & surv 6945-7037'. Drld w/ DD #3 7037-43'. POH LD DD. MU BHA & RIH. Reamed 6945-7043'. Drld 7043-70'. Circ & surv. POH. MU locked BHA & RIH. Reamed 6950-7070'. Drld & surv 7070-320'. Drld 7320-339'. Circ & surv. POH. PU bit #6 2 RIH. Drld & surv 7339-587'. Short tripped to 9-5/8" csg shoe--no hole problems. Drld ~ surv 7587-775'. · POH. Chngd BHA & RIH w/ Bit #6. Drld 7775-976'. Circ & surv. Drld 7976-8159'. Circ & dropped a surv. POH to 9-5/8" shoe to retrieve surv. . . Retrieved surv. RIH. Drld 8159-252'. Circ & dropped surv. POH. Tstd BOPE--OK. Chngd BHA ~ RIH. Drld 8252-371'. Circ & surv. POH LD stabilizers. WO MWD equip. MU DD #4 & M~VD equip. Check M~¥D oper--OK. RIH to 8371'. MWD would not generate signal. POH. Chng out M~WD dquip. Check tools--OK. RIH. Difficulty orienting DD due to erratic signals, corrected problem. Orient DD for left hand turn & build. DD from 8371-410'. Cont drlg w/ DD #4 f/ 8410-444' (made total 73' w/ DD #4) POH LD DD & MWD tools. RIH w/ follow up assy. Reamed DD run 8371-444' & drld 8444-516'. Surv. POtt. Chng BHA. RIM ~ drld 8516-556'. Drld 8556~579'. Circ ~ surv. Drld 8679-925'. Circ & dropped surv. POH to 9-5/8" csg shoe. Retrieved surv. RIH to 8910' & washed to 8925' (15' of fill). Drld 8925-9112'. Circ &.droppe~ surv. POH to 9-5/8" shoe. Rec surv w/ sand line. RIH. Drld 9112-299'. Circ & dropped surv. POH to 9-5/8" shoe & rec surv. RIH. Drld 9299-516'. - Drlg suspended for prod shut down. Drlg opers suspended due to platform shutdown of 17 hrs. RIM f/ csg shoe. Wash 60' to btm for safety. Drld 9733-856'. Drld 9856-10,041'. Circ ~ dropped surv. shoe. Retrieved surv w/ sand line. RIH. 10,041-234'. POM to 9-5/8" Drld Drld 10,234-517'. Circ & surv. POH. Tstd BOP. Drld 10,517-602'. RIH. Well History - Dolly Varden No. D-3RD#2 Page 3 10-23 10950'TD 10-24 l1055'TD 10-25 l1055'TD 10-26 l1055'TD 10-27 l1055'TD 10-28 l1055'TD 10-29 l1055'TD 10-30 ll,055'TD 10-31 ll,055'TD 11-01 ll,055'TD 11-02 ll,055'TD Drld 10,602-763'. Circ & surv. POH. RIH & drld i0,763-950'. Drld 10,950-11,055'. Circ & dropped surv. POH to 9-5/8" shoe. Rec surv. RIH. Circ & cond hole for logs. POH. RU WL. RIH w/ DIL/Sonic/SP/GR--DIL failed. POH. RIH w/ DIL/SP/GR. Fin running.DIL/SP/Sonic--OK. Ran FDC/CNL/GR/Caliper. RD loggers. RIH to 11,055'--no fill. C&C hole. POH. RU & ran 118 jts of 7" lnr. MU lnr hgr @ 0700 hrs. Circ lnr vol. RIH w/ lnr on DP to 11,055'. Circ. Cmtd lnr w/ 1224 sx cmt. CIP @ 1830 hrs, 10-25-83. TOL @ 6267', shoe @ 11,055', & landing clr @ 10,975'. Set lnr hgr.. Rel tool & pulled 5 std. Circ. POH. WOC. RIH to 6100'--contaminated mud. Circ. Washed to'top of cmt @ 6157'. Drld firm cmt 6157' to TOL @ 6267'. Circ BU. POH. RU %~. Ran csg inspection log in 9-5/8" csg f/ TOL to surf. RD ~. MU DST equip to dry test lnr lap. RIH. Fin RIH w/ DST equip w/ 3000' water cushion in DP. Ran dry test on lnr lap. POH w/ DST equip--press charts confirmed that lnr lap tstd OK. PU 6" bit & 4-3/4" DCs & RIH to TOL @ 6267'. Tstd 9-5/8" csg to 1800 psi-- OK. Drld hard cmt f/ TOL to 6287', & cmt stringers to 6448'. RIH to 10,895'. Drld hard cmt to 10,970'. Circ. POH. RU WL. Ran CBL/GR/CCL--exceptionally good bond across Hemlock. Ran gyro surf-10,960'WLM. RIH w/ 6" bit & 7" csg scrpr to 10,970'DPM (PBTD). Press test to 1800 psi--OK. Rev mud out w/ FIW until clean. Mix & spot 50 bbl 3% KC1 across Hemlock. POH w/ bit & scrpr. RU WL' & ran 5.8" GR/JB to 10,970'. MU prod pkr w/ sealbore ext & millout ext. RIH & locate. Pkr got tight while locating--set @ 10,356'%~M in Bench #1. POt{ RD WL. MU pkr picker & RIH w/ DP. Burned over pkr @ 10,356'. POH w/ pkr--dragging. Lost drag @ 8750'. Fin POH--left pkr in hole. MU spear. RIH & engaged pkr @ 10,950'. POH LD spear, pkr mandrel, seal bore ext ~ mill out ext. RU WL. RIH to PBTD w/ 5.92" GR & JB--rec some pkr junk. Reran GR & JB to PBTD--no rec. MU pkr w! seal bore ext on WL. RIH & set pkr @ 10,030'DIL. RD WL. RIH w/ seal assy on DP. Stabbed into pkr & tstd pkr to 2500 psi--OK. POH LD DP. Chngd to 4½" pipe rams & RU to run tbg. Ran seal assr, 3½" tbg & 6 gas lift mandrels. Started running 4½" tbg & gas lift mandrels. Tagged pkr & tstd pkr to 2500 psi--OK. Spaced out & landed tbg. Pkr would not test. PU & circ. Pkr still would not test. RU WL. RIH w/ clr locator. CCL showed tbg mule shoe @ btm of pkr in bell guide. Seal assy was not in pkr. POH RD WL. POH w/ tbg. Inspected mule shoe, tbg clr & seal assy--all equip was smaller than pkr ID (4.0"). ~e'll History - Dolly Varden No. D-3RD#2 Page 4 11-03 ll,055'TD 11-04 ll,055'TD 11-05 ll,055'TD 11-06 ll,055'TD 11-07 11,055 ' TD 11-08 ll,055'TD 11-09 ll,055'TD 11-10 ll,055'TD 11-11 ll,055'TD 11-12 ll,055'TD 11-13 ll,055'TD Waited on WL tools. RIH w/ 3.75" OD gauge ring on CCL & thru pkr bore--OK. Chngd out mule shoe on tbg tail- pipe. RIH w! 3½" & 4½" prod tbg f/ derrick. Tstd to 4000 psi. Located seals in pkr & tstd to 2500 psi--OK. Spaced out & landed tbg. Tstd seals to 2500 psi--OK. Begin ND BOP. NU & tstd X-mas tree & prod lines. Unloaded 200 bbl FI~V w/ gas lift for approx 700 psi drawdown. RU ~VL & press tstd lubricator to 2500 psi--OK. RIH w/ perf gun #1. Perfd Hemlock Bench #4 10,550-580' DIL w/ 4 SPF. POH-- all shots fired OK. RIH w/ HP press gauge to 10,660' DIL (9600':TVD). Unloaded well thru test separaZor. At 0700 hrs, no fluid prod--blowing gas around. Bench #4 perfs 10,550-580' DIL contributing no liquid. SI well 2 POH w/ HP gauge. Load tbg to provide draw- down. RIH & perfd Hemlock Bench #4 10,520-550' DIL w/ 4 HPF. POH--all shots fired OK. Unload well to test. At 0700 hrs, Bench #4 tstg @ 960 BPD rate @ 30-40~% ~VC. Cont tstg Bench #4 @ 960 BFPD w/ water cut varying f/ 30-40~ ~o. SI well for press buildup. Prod tstd B-4 to verify water cut: 984 BFPD, 747 BOPD, 24Z water cut. SI well. RU WL. Perf Hemlock Bench #5 10,650-664' DIL--shot 8 HPF in two runs. Produced well totest separator.. Average prod rate during 10 hour test: 1442 BFPD, 1240 BOPD, 14% water cut. Released rig to D-20 workover @ 2400 hrs, 11-07-83. 24 hour prod test: 1343 BFPD, 1195 BOPD, 11~ water cut. 24-hour prod test:. 1041 BFPD, 969 BOPD, 7~ water cut. WOW for boat to bring WL tools. Rec tools @ 1500 hrs. RU. Test lub--2000 psi. Rate prior to SI well was 850 BFPD @ 7.2~ WC (789 BOPD). RIH w/ prod logging tools to 10,718' (9650' TVD). Returned well to prod, & stabilized. Tool string shorted out when attempted to'log. POH & chngd out BCM tool. RIH--tool shorted again. POH @ 0700 hrs. Worked on WL tools. RIH. Opened well to prod 2 stabil- ized. Ran prod logs across Bench #4 perfs (10,520-580' DIL) & Bench #5 perfs (10,650-664' DIL). Logs showed approx 52~ of prod out of Bench #5 perfs & 42~ out of upper 20' of Bench #4 perfs. POH w! logging tools. RIh & reperfd Bench #4 10,520-580' DIL w/ 4 HPF. POH RD ~. Prod well to cleanup & turned to test @ 0600 hrs. Prod Benches #4 & #5 to test following reperfg. Test @ 828 BFPD @ 4.4% WC (792 BOPD) & 217 GOR. FINAL REPORT. Union Oil and Gas D on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union November 3, 1984 Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Mr. Chatterton: Attached for your approval is a Sundry Notice to workover D-3RD2, McArthur River Field & Subsequent Report for D-14RD for your in¢ormation and file. Please return the approved Sundry Notice to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL TECHNICIAN LOC/tj Attachment RECEIVED C Alaska Oil & Gas Cons. commission Anchorage STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LID(~ OTHER [] 2. Name of Operator Union 0il Company of California* 3. Address P.0. Box 6247 Anchorage, AK 99502 4. Location of Well Surface' Leg A-2, Cond #11, Dolly Varden Platform 757' FSL, 1133' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL I 6 . Lease Designation and Serial No. ADL-18729 7. Permit No. 83-81 8. APl Number 50- 733-20090-07 9. Unit or Lease Name Trad~nn R~v Ilnif 10. Well Number D-3RD?_ 11. Field and Pool ~lcArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate (~ Abandon [] Stimulation Repair Well [~] Change Plans [] Repairs Made Pull Tubing [~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). WELL D-3RD2 WORKOVER Workover operations should begin in January, 1985, and be completed usinq the attached procedure. *Marathon Oil Company - Sub Operator' 14. I hereby certify that the foregoing is true and correct to the best of my knowledg~~.~ The space below for Commission use Title EnVironmental Technician RECEIVED L);? c 0.5' ]984 Alaska 0it & (;as Cons. C0mmJssJ0n Anchorage Date 12-04-84 Conditions of Approval, if any: Approved by ORtG!HAI. SIGNED BY ]lARRY W. KDGLEI Approved Ret~urnect By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,. D-3RD2 WORKOVER AFE #8218-5 RECOMMENDED PROCEDURE January 15, 1984 1. Skid Rig #77 over Well D-3RD2. 2. Perforate circ. holes w/ tubing perf. guns at 10,020' WLM. 3. Circ. well to prod. w/ FIW to clear oil out. Switch to workover fluid and circ. until dead. Keep back pressure on formation as low as possible. 4. Install BPV. ND tree and send in for R ~ M. NU and test BOPE. Remove BPV. POH and LD tbg. 5. PU 3-1/2" DP. RIH w/ pkr picker and mill over packer at 10,059'. POH w/ pkr. 6. RIH w/ bit and scraper to 10,700'. Circ. hole clean and POH. 7. Perf. Hemlock Bench 4 f/ 10,520' - 10,580' DIL using 4" casing guns at 4 HPF. 8. RIH w/ RBP and set at lO,610'. Set retr. packer at 10,480'. 9. Frac Bench 4 using 30,000# of proppant and cross-linked gel. Flush proppant to top perforation. 10. Clean out well and retrieve RBP. 11. Make GR/JB run on WL to 10,150'. RIH w/ WL-set prod. pkr. and set at lO,O00'. POH. 12. RIH w/ 4' seal assembl.y on DP and sting into packer. Test pkr. and casing to 1500 psi. POH and,LD DP. 13. RIH w/ 4-1/2" - 3-1/2" tbg. and completion equipment. a. Pkr. seal assembly w/ mule shoe and locator. b. 3-1/2" GLM's w/ l" GLV's. c. 4-1/2" GLM's w/ l-l/2" GLV's. d. 4-1/2" TRBV and control line. e. Tbg. hqr. 14. Land hgr. and install BPV. ND BOPE and NU tree. Hook up flowline and gas lift lines. Remove BPV. 15. Produce well until clean. TES: c as 09-17-84 16. Perf. Hemlock Bench 5 f/ 10,650' - 10,664' DIL under drawdown using 2.5" thru-tubing guns at 4 HPF. RECEIVED Alaska Oil & Gas Cons. commission Anchorage Union Oil and Gas Div~.ion' Western Region Union Oil Company o, ,.;alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union DOCUMENT TRANSMITTAL June 11, 1984 HAND DELIVERED TO: William Van Alen FROM: LOCATION: Anchorage LOCATION: ALASKA OIL & GAS CONSERVATION COMMISSION R. C. Warthen Alaska District Transmitting: One (1) directiOnal survey, listing and magnetic tape - Marathon's D-3 R~2 PL~EASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. .,rC D ,--v ,,~--- JUN '-"- DATED: Alaska 0il d, Gas Cons. Commission Anchorage Union Oil and Gas r-. ision: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl, n DOCUMENT TRANSMITTAL February 23, 1984 HAND DELIVERED TO: William Van Alan FROM: R.C. Warthen LOCATION: 3001 Porcupine Drive LOCATION: Alaska District Anchorage, Alaska 99504 ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting: Reference: Marathon - D-3 RD #2 One (1) directional surv. ey (tangential) One (1) magnetic tape ~' ~ ~ ~'~- ,~-" One (1) each sepia and blueline as follows: FDC CNL GR Raw 2" FDC CNL GR Raw 5" FDC CNL GR Porosity 2" FDC CNL GR POrosity 5" Dual Induction Gamma Ray 2" Dual Induction Gamma Ray 5" Borehole Compensated Sonic Gamma Ray 2" Borehole Compensated Sonic Gamma Ray 5" Gyro Continuous Tool PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT RECEIvEDTRANSMITTAL'By: THANK YOU. F E 2 .984 - '" DATED: AISsKa uii & G~s Cuns, Commissior~ Anchorage ALASKA OIL AND GAS CO#$££VATIOH CO~P~iSS/O~/ Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE.ALASKA 99501'-3192 TELEPHONE(907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed //_~_~z'--~._~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, C. V. Chattdrt~on Chairman FORM 484 REV. 8-75 "" -;'JiTE January 5, 1983 Marathon Oil Company HISTORY OF OIL OR GAS WELL BLOCK WELL No._D3RD2 LEASE Trading Bay Unit SEC. PARISH STATE Alaska COUNTy. Kenai Peninsula Borough FIELD McArthur River 106 ' KB ElEV. . TWP. MEASUREMENTS TAKEN FROM ~ToP OF OiL STRING __ ElEV .TOP OF ROTARY TABIE~ ElEV. ~ GRD. OR MAT, ElEV._ HISTORY PREPARED BY Lisa Y. Durham TITLE Secretary It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1983 09-28 09-29 09-30 10-01 10-02 10-03 10-04 10-05 10-06 ll,100'TD ll,100'TD ll,100'TD ll,100'TD ll,100'TD ll,100'TD ll,100'TD ll,100'TD ll,100'TD TBU Well D-3RD#2 (Marathon AFE #4878) Commenced operations on D-3RD#2 @ 1130 hrs, 9-27-83. Skidded Rig #77 over D-3RD. Bullheaded 187 bbl FIW into tbg. Pumped 515 bbl FIW into csg/tbg annulus. RU WL. Press tstd lubricator to 2000 psi--OK. RIH w/ perf gun on WL to shoot circ holes in tbg. Shot circ holes @ 10,060' tbg measurement. POH RD WL. Circ FIW to prod separator until well was dead. Installed BPV. ND X-mas tree. NU & tstd BOPE--OK. MU landing jt in tbg hgr & PU tbg. Circ FIW to prod separator. POH LD 4-1/2" & 3~1/2" tbg. , Torque converter went out on west crane. Wait on west crane repairs & mixed mud. Offload 4½" tbg across platform using east crane. PU RIH w/ 2-1/16" stinger. Following crane repair, PU RIH w! 3½" & 5" DP. Tag fill @ 10,630' DPM--top of gravel pack assy @ 10,594'. Prep to circ @ 0700 hrs. Circ hole @ 10,620' & mixed mud in pits. RU cmtrs. Mix & spot 102 sx cmt to abandon Hemlock. Plug 10,620-070' (top of Hemlock Bench #1 perf @ 10,248'). Pulled 9 stds & rev circ. Displ FIW f/ hole w/ drlg mud. POH LD 3½" DP & 2-1/16" tbg stinger. RIH w/ 8½" bit & 9-5/8" csg scrpr tO-837I' (TOL @ 8384').-Circ hole clean. POH. MU BP on DP setting tool & RIH. Set BP @ 8350'. POH to 6700.'. Circ & cond mud to +150 sec/qt. Tstd csg to 1500 psi--OK. POH. MU section mill & RIH. Made initial cut in 9-5/8" csg @ 6570'. Milled 6570-76'. Milled~9-5/8'' csg 6576-6600'. Circ BV. POH. MU section mill #2 & RIH. Milled 6600-08'. Milled 9-5/8" csg w/ section mill #2 6608-30'. Circ to clean hole. POH w/ section mill & LD same. PU 8½" bit & RIH. CO 9-5/8" csg stub 6636-737'. cond mud for kick off plug. POH. RIH w/ OEDP to 6726'. Circ BV. Spotted 140-~'x C1 G cmt 6726-6410'. CIP 1750 hrs, 10-05-83. POH to 6076'. Rev DP clean. LD 3 its DP. Circ BV. POH. WOC. Wei~l History - Dolly Varden No. D-3RD#2 .~Page 2 - 10-07 6580 ' TD 10-08 6633'TD 10-09 6850 ' TD 10-10 7037'TD 10-11 7320'TD 10-12 7775'TD 10-13 8159'TD 10-14 8371'TD 10-15 8371'TD 10-16 8371 'TD 10-17 8371'TD 10-18 9516'TD 10-19 9733'TD 10-20 9856'TD 10-21 10234'TD 10-22 10602 ' TD BOPE~OK T~d . RIH w/ 8½" bit & tagged TOC @ 6488'. ~Drld _~r~ cmt 6488-573'. C&C mud. POH. PU DD #1 & ~~o 6573'. RU RIH w! steering tool. Oriented DD & drld 6573-580'. Drld w/ DD #1 6580-633'. POH w/ steering tool & RD WL. POH LD DD. MU & RIH W/ drlg assy. Ran leakoff test. Reamed DD #1 run. Drld & surv 6633-732'. POH. RIH w/ DD #2. Drld & surv 6732-850' w/ MWD. POH LD DD #2. surv 6850-945'. PU DD #3 & RIH. MU BHA & RIH. Reamed 6732-850'. Drld & Circ & dropped surv. POH LD stabilizers. Oriented DD. Drld & surv 6945-7037'. Drld w! DD #3 7037-43'. POH LD DD. MU BHA & RIH. Reamed 6945-7043'. Drld 7043-70'. Circ & surv. POH. MU locked BHA & RIH. Reamed 6950-7070'. Drld & surv 7070-320'. Drld 7320-339'. Circ & surv. POH. PU bit #6 & RIH. Drld & surv 7339-587'. Short tripped to 9-5/8" csg shoe--no hole problems. Drld & surv 7587-775'. POH. Chngd BHA & RIH w! Bit #6. Drld 7775-976'. & surv. Drld 7976-8159'. Circ & dropped a surv. to 9-5/8" shoe to retrieve surv. Cir¢ POH Retrieved surv. RIH. Drld 8159-252'. Circ & dropped surv. POH. Tstd BOPE--OK. Chngd BHA & RIH. Drld 8252-371'. Circ & surv. POH LD stabilizers. WO MWD equip. MU DD #4 & MWD equip. Check MWD oper--OK. RIH to 8371'. MWD would not generate signal. POH. Chng out MWD dquip. Check tools--OK. RIH. Difficulty orienting DD due to erratic signals~ corrected problem. Orient DD for left hand turn & build. DD from 8371-410'. Cont drlg w/ DD #4 f! 8410-444' (made total 73' w/ DD #4). POH LD DD & MWD tools. RIH w/ follow up assy. Reamed DD run 8371-444' & drld 8444-516'. Surv. POH. Chng BHA. RIH & drld 8516-556'. Drld 8556-679'. Circ & surv. Drld 8679-925'. Circ & dropped surv. POH to 9-5/8" csg shoe. Retrieved surv. RIH to 8910' & washed to 8925' (15' of fill). Drld 8925-9112'. Circ & dropped surv. POH to 9-5/8" shoe. Rec surv w/ sand line. RIH. Drld 9112-299'. Circ & dropped surv. POH to 9-5/8" shoe & rec surv. RIH. Drld 9299-516'. Drlg suspended for prod shut down. Drlg opers suspended due to platform shutdown of 17 hrs. RIH f/ csg shoe. Wash 60' to btm for safety. Drld 9733-856'. Drld 9856-10~041'. Circ & dropped surv. POH to 9-5/8" shoe. Retrieved surv w! sand line. RIH. Drld 10~041-234'. Drld 10~234-517'. Circ & surv. POH. Tstd BOP. RIH. Drtd 10,517-602'. ~We:il History - Dolly Varden No. D-3RD#2 "Page 3 10-23 10950'TD 10-24 l1055'TD 10-25 l1055'TD 10-26 l1055'TD 10-27 l1055'TD 10-28 l1055'TD 10-29 l1055'TD 10-30 ll,055'TD 10-31 ll,055'TD 11-01 ll,055'TD 11-02 ll,055'TD Drld 10,602-763'. Circ & surv. POH. RIH & drld 10,763-950'. Drld 10,950-11,055'. Circ & dropped surv. POH to 9-5/8" shoe. Rec surv. RIH. Circ & cond hole for logs. POH. RU WL. RIH w/ DIL/Sonic/SP/GR--DIL failed. POH. RIH w/ DIL/SP/GR. Fin running DIL/SP/Sonic--OK. Ran FDC/CNL/GR/Caliper. RD loggers. RIH to 11,055'--no fill. C&C hole. POH. RU & ran 118 jts of 7" lnr. MU lnr hgr @ 0700 hrs. Circ lnr vol. RIH w/ lnr on DP to 11,055'. Circ. Cmtd lnr w/ 1224 sx cmt. CIP @ 1830 hrs, 10-25-83. TOL @ 6267', shoe @ 11,055', & landing clr @ 10,975'. Set lnr hgr. Rel tool & pulled 5 std. Circ. POH. WOC. RIH to 6100'--contaminated mud. Circ. Washed to top of cmt @ 6157'. Drld firm cmt 6157' to TOL @ 6267'. Circ BU. POH. RU WL. Ran csg inspection log in 9-5/8" csg f/ TOL to surf. RD WL. MU DST equip to dry test lnr lap. RIH. Fin RIH w/ DST equip w/ 3000' water cushion in DP. Ran dry test on lnr lap. POH w/ DST equip--press charts confirmed that lnr lap tstd OK. PU 6" bit & 4-3/4" DCs & RIH to TOL @ 6267'. Tstd 9-5/8" csg to 1800 psi-- OK. Drld hard cmt f/ TOL to 6287', & cmt stringers to 6448'. RIH to 10,895'. Drld hard cmt to 10,970'. Circ. POH. RU WL. Ran CBL/GR/CCL--exceptionally good bond across Hemlock. Ran gyro surf-10,960'~M. RIH w/ 6" bit & 7" csg scrpr to 10,970'DPM (PBTD). Press test to 1800 psi--OK. Rev mud out w! FIW until clean. Mix & spot 50 bbl 3~ KC1 across Hemlock. POH w/ bit & scrpr. RU WL & ran 5.8" GR/JB to 10,970'. MU prod pkr w! sealbore ext & millout ext. RIH & locate. Pkr got tight while locating--set @ 10,356'WLM in Bench #1. POH RD WL. MU pkr picker & RIH w/ DP. Burned over pkr @ 10,356'. POH w/ pkr--dragging. Lost drag @ 8750'. Fin POH--left pkr in hole. MU spear. RIH & engaged pkr @ 10,950'. POH LD spear, pkr mandrel, seal bore ext & mill out ext. R'U WL. RIH to PBTD w/ 5.92" GR & JB--rec some pkr junk. Reran GR & JB to PBTD--no rec. MU pkr w/ seal bore ext on ~%~. RIH & set pkr @ 10,030'DIL. RD WL. RIH w/ seal assy on DP. Stabbed into pkr & tstd pkr to 2500 psi--OK. POH LD DP. Chngd to 4½" pipe rams & RU to run tbg. Ran seal assy, 3½" tbg & 6 gas lift mandrels. Started running 4½" tbg & gas lift mandrels. Tagged pkr & tstd pkr to 2500 psi--OK. Spaced out landed tbg. Pkr would not test. PU & circ. Pkr still would not test. RU WL. RIH w/ clr locator. CCL showed tbg mule shoe @ btm of pkr in bell guide. Seal ass~was not in pkr. POH RD WL. POH w/ tbg .... We~l History - Dolly Vara~n No. D-3RD#2 ~P~ge 4 11-03 ll,055'TD 11-04 ll,055'TD 11-05 ll,055'TD 11-06 ll,055'TD 11-07 ll,055'TD 11-08 ll,055'TD 11-09 ll,055'TD 11-10 ll,055'TD 11-11 ll,055'TD 11-12 ll,055'TD 11-13 ll,055'TD Waited on WL tools. RIH w! 3.75" OD gauge ring on CCL & thru pkr bore--OK. Chngd oUt mule shoe on tbg tail- pipe. RIH w/ 3½" & 4½" prod tbg f/ derrick. Tstd to 4000 psi. Located seals in pkr & tstd to 2500 psi--OK. Spaced out & landed tbg. Tstd seals to 2500 psi--OK. Begin ND BOP. NU & tstd X-mas tree & prod lines. Unloaded 200 bbl FIW w/ gas lift for approx 700 psi drawdown. RU WL & press tstd lubricator to 2500 psi--OK. RIH w/ perf gun #1. Perfd Hemlock Bench #4 10,550-580' DIL w/ 4 SPF. POH-- all shots fired OK. RIH w/ Hp press gauge to 10,660' DIL (9600' TVD). Unloaded well thru test separator. At 0700 hfs, no fluid prod--blowing gas around. Bench #4 perfs 10,550-580' DIL contributing no liquid. SI well & POH w/ HP gauge. Load tbg to provide draw- down. RIH & perfd Hemlock Bench #4 10,520-550' DIL w/ 4 HPF. POH--all shots fired OK. Unload well to test. At 0700 hrs, Bench #4 tstg @ 960 BPD rate @ 30-40~ WC. Cont tstg Bench #4 @ 960 BFPD w/ water cut varying f/ 30-40~. SI well for press buildup. Prod tstd B-4 to verify water cut: 984 BFPD, 747 BOPD, 24~ water cut. SI well. RU WL. Perf Hemlock Bench #5 10,650-664' DIL--shot 8 HPF in two runs. Produced well totest separator. Average prod rate during 10 hour test: 1442 BFPD, 1240 BOPD, 14~ water cut. Released rig to D-20 workover @ 2400 hrs, 11-07-83. 24 hour prod test: 1343 BFPD, 1195 BOPD, 11~ water cut. 24-hour prod test: 1041 BFPD, 969 BOPD, 7% water cut. WOW for boat to bring WL tools. Rec tools @ 1500 hrs. RU. Test lub--2000 psi. Rate prior to SI well was 850 BFPD @ 7.2~ WC (789 BOPD). RIH w/ prod logging tools to 10,718' (9650' TVD). Returned well to prod, & stabilized. Tool string shorted out when attempted to log. POH & chngd out BCM tool. RIH--tool shorted again. POH @ 0700 hrs. Worked on WL tools. RIH. Opened well to prod & stabil- ized. Ran prod logs across Bench #4 perfs (10,520-580' DIL) & Bench #5 perfs (10,650-664' DIL). Logs showed approx 52% of prod out of Bench #5 perfs & 42% out of upper 20' of Bench #4 perfs. POH w/ logging tools. RIh & reperfd Bench #4 10,520-580' DIL w/ 4 HPF. POH RD ~. Prod well to cleanup & turned to test @ 0600 hrs. Prod Benches #4 & #5 to test following reperfg. Test @ 828 BFPD @ 4.4~ WC (792 BOPD) & 217 GOR. 'FINAL 'REPORT. · ' :,-.*-- STATE OF ALASKA .---,. ' ALASKA' LAND GAS CONSERVATION C( MISSION ~/~/' 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 Union Oil Company of California* 83-81 3' Ad~r(~SS BOX 6247, Anchorage, Alaska 99502 5o- 4. Location of well at surface Leg A-2, Cond #11, Dol]y Varden Platform 9. Unitor LeaseName 757' FSL, 1133' FWL, Sec. 6-SN-13W-SM Trading Bay Unit At Top Producing Interval 10. Well Number 1425' FNL, 1017, FEL, Sec. 6-8N-13W-SM D-3RD #2 At Total Depth 11. Field and Pool 1159' FNL, 740 FEL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106 KB Above MSL ADL-18729 HcArthur River Field 12. Da.re Sp_uddedl 0/3/53 13. Date T.D. Reachedl 0/24/83 14. I~a~t~ ~r~p~, Susp. or Aband. 115. Water Depth, if offshore901feet MSL I1~' N~' Of CpmpletiOnstOne) 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost l1055'MD 9947'TVD 10970'MD 9872'TVD YES[~ NoEl 291' feetMD --- 22. Type Electric or Other Logs Run DIL/Sonic/SP/GR, FDC/CNL/GR/Calip, CBL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 7" 29# N-80 6267 11055' 8 1/2" 1224 sks CI G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Bench 4 SIZE DEPTH SET (MD) PACKER SET (MD) Top -- Bottom 4 1/2" Surface X-over 6200' __ 10520'MD (9480' TVD) 10580'MD (9531' TVD) 3 1/2" 6200' 10059' Bench 5 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. Top ~: Bottom DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10650IMD (9591' TVD) 10664'MD (9603' TVD) 74' OPen 8 HFP 27. PRODUCTION TEST Date First Production . I Method of Operation (Flowing, gas lift, etc.) 11/5/83I Gas Lift DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAg-OIL RATIO 11/13/83 . 8 hrs. 'TEST PERIOD I~.. 264 57 12 ---I 217 Flow Tubing Casing Pressure CALCULATED OILoBBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 100 940 24-HOUR RATE ~ 792 172 36 35.0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. * Marathon 0il Company, Sub-operator !?ili!,;';~ ¥. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . . NAME Include interval tested, pressure data, all fluids recovered and gravity, M EAS. DEPTH TRUE VERT-. DEPTH GOR, and time of each phase. · . · . · _ · . ; . : -- . . . : . . . . 31. LiST OF ATTACHMENTS 32. I here~ilat the' foregoing is true and correct to the bes't o:f my knoWledge . S,~~] __~~'_~~ TitleDIST' DRLG SUPER. Date December 19, 1983 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 spaces 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), s° 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 cement- lng 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". GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR MARATHON OIL COMPANY D-3 REDRILb ~ TRADING BAY UNIT KENAI, AI, ASKA SURVEY DATE: 28-OCT-8] EN~INEER~ MC BRIDE ! MARATHON OI[{I COMPANY t),,,3': REDRIL[0 TRADING BaY UNIT KENA!, ALASKA MEASURED DEPTH 100,00 200.00 300.00 300 400 00 399 500~00 499 600,00 599 700,00 698 800.00 797 900 O0 895 lOOO:OO 993 1100 00 1200 00 1300 00 1400 00 1500 00 1600 O0 1561 1700 00 1651 1.800 00 1739 1900,00 1816 2000,00 1913 // ' TRUE / VERTICAL / VERTICAb,DEVI DEPTH LDEPTH/DEG/. 100 O0 ---,,16.,.7'O 0 200 00 0 00 99 99 6 54 80 77 i ~j~/.v COMPUTATION DATE{ 6-DEC-1983 PAGE /~ ' ". "' ENGINEER, ,C.:~:'BRXDE - ' ...... /I'NTERPObATED VAbUES FOR EVEN 100 FEET"'OF MEASURED DgPTHr/''' ~O~ 1091 10 1187 59 1.28] 08 1377 37 1470 25 69 49 75 42 83,~0. 183, 283.29 383,29 582, 680, 877,07 974 40 1070:89 1166.38 1260,67 1353i5~ 1444,9 1534.79 1622,59 1.700,05 1796,72 COURSE ATXON AZIMUTH MXN DEG MXN DOGLEG RECTANGULAR COORDINATES HORXZ DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST~..DISTANC~ AZIMUTH DEG/100 FEET FEET FEET DEG MIN 0 S 71 53 W 0 N 39 25 E 0 0 S 75 21 W 0 0 N 24 4 W 1 43 N 8 24 E 6 1 N 13 30 W 8 55 N 10 13 E 9 53 N 13 54 E 10 53 N 22 33 E 12 18 N 40 4 E 0,40 0,85 0,21 0,39 3,28 6,30 1.75 3,05 4,76 2,56 0038 0268 0125 0 0 7 09 N 21 09 N 36 23 N 53 97 N 68 86 N 0,19 W O. 0 20 S 79 42 W ~ 74 8 80 21 W 0 95 w .~ 11 07w '" . 2 25 W 7 1. 97 W 21 I 42 E 36 6 79 E 54 17 96 E 71 49 S 57 37 W 96 $ 85 58 W 46 N 4721 W 44 N t7 ]4 w 18 N 5 20 W 26 N 2 15 E 40 N 7 10 ' 16 N 14 31 ) 14 19 N 40 40 E 16 26 N 39 42 E 18 31 N 38 23 E 20 37 N 38 23 E 22. 44 N 37 48 E 24 51 N 37 14 E 27 32 N 36 40 E 29 13 N 36 40 E 29 47 N 36 40 E 29 13 N 37 14 E 1.84 1,96 2,05 2,48 ! 84 2~03 3,52 0,62 0 14 0:35 87 81N 107 85 N I 05 N 186 21N 218 28 N 253 46 ~ 291 90 N 327 09 N 370 90 N 49 68 66 E 89 26 E 112 08 E 136 73 E 163 9 E 191 ~6 E 217 65 E 250 31 E 93 80 N 20 35 E 118 86 N 24 51E 217 257 392 447 83 N 27 40 g 64 N 29 36 E~ 34 N 31 2 E 57 N 32 3 E 45 "32 46 E 20 N 33 17 E 88 N 33 38 E 46 N 34 0 E, 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 2900 00 3000 O0 3100,00 3200,00 3300 OO , 3400,00 3500,00 3600,00 3700,00 3800,00 3900 O0 4000:00 2000,51 2087,60 2174,80 2262.08 2349 46 2436i91 2524 31 2611 60 2698~69 2785,47 2871,95 2958,1.5 3044 21 3130 29 3216 26 3302 02 3387 42 3472 53 3557 44 3642 16 1.883,81 1970.90 2058,10 2145,38 2232,76 2320,21 24.07,6i 2494,90 2581,99 2668,77 29 13 N 37 14 E 29 13 N 37 48 E 29 13 N 37 48 E 29 13 N 37 48 E 29 13 N 37 48 E 28 58 N 37 48 E 29 13 N 37 14 E 29 13 N 37 16 E 29 41 N 37 48 E 29 47 N 37 48 E 2755.25 30 22 N 37 48 E 2841,45 30 22 N 37 51 E 2927,51 30 27 N 38 23 E 3013,59 30 44 N 38 57 E 3099,56 30 56 N 38 57 E 3185.32 31 7 N 38 57 E 3270,72 31 30 N 38 57 E 3355,83 31 30 N 38 57 E 3440,74 32 5 N 38 57 E 3525.46 32 5 N 38 57 E 0 19 0 22 0 22 0 33 0 30 0,29 0,21 0,20 0,21 0,52 0,56 0,57 0,26 0,20 0,35 0,71 0,81 0,30 0,86 1,17 410 O0 N 448 97 N 487 76 N 525 70 N 564 92 N 603 31 N 641 85 N 680 58 N 719 54 N 758 82 N 798 52 N 838 57 N 878 44 N 918 17 N 957 95 N 998 04 N 1038 65 N 1079,51N 120,54 N 161,95 N 280,09 E 310,02 E 3 70 E 399 36 E 429 O2 E 458 59 E 488,29 E 5i8,26 E 548,69 E 579 42 g 610 49 E 642 17 E 673 99 E 706 03 E 738 25 E 770,78 E 803,75 E 837,00 E 870,30 E 496 54 N 34 20 E 545 61 N 34 37 E 594 642 691 740 788 837 886 936 48 N 34 52 E 68 N 35 6 E 83 N 35 15 g 29 N 35 25 E 85 N 35 32 E 63 N 35 39 E 75 N 35 45" 4i N 35 52 ~ 986 59 N 35 57 E 1037 26 N 36 3 E 1088 1138 1190 1241 1293 1345 1398 1451 13 N 36 10 E 99 N 36 16 E 02 N 36 23 E 41 N 36 29 E 4t N 36 34 E 87 N 36 40 E 63 N 36 45 E 74 N 36 49 E MARATHON OIb COMPANY D-3 REDRIL6 TRADIIVG BAY [)NIT KENAI, AbASKA COMPUTATION DATEi 6-DEC-1983 PAGE 2 [')ATE 0F 8URVEYi 28-0CT-83 KELbY BUSHING .EbEVAT!ONI 116.70 FT ENGINEER: MC' BR!DE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURE0 VER?ICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MXN DEG MIN 4100.00 4200.00 4300 O0 4400~00 4500.00 4600.00 4700.00 4800.00 4900.00 5000.00 3726 3896 31 3981 4332 14 4420 56 4509,08 °53 421,5,44 4303.86 4392.38 32 39 N 38 57 E 32 5 N 39 32 E 31 3O N 40 6 E 31 29 N 40 6 E 28 6 N 46 47 E 28 4 N 51 28 E 28 38 N 51, 33 E 28 4 N 52 8 E 28 4 N 52 8 E 27 15 N 52 22 E 5i00.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700,00 5800.00 5900,00 6000.00 4598 O0 46 12 4866 90 4957 62 5049 O0 5140 5233 ~4 · 1 532~ 35 541 52 4481,30 4570.42 4659,89 4750.20 4840.92 4932 30 5024:24 5116.60 5209.65 5302.82 26 55 N 52 53 E 26 21 N 53 51 E 25 46 N 53 57 E 25 7 N 55 0 E 24 33 N 55 0 E 23 29 N 56 5 E 22 20 N 56 43 E 22 18 N 57 19 E 21 46 N 58 26 E 21 11 N 59 35 E 6100.00 6200.00 6300.00 6400°00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 5512 77 5606 08 5699 44 5792 98 5886 74 5980 42 6073 20 6165 29 6256 91 6347 75 5396.07 5489,3g 5582.74 5676.28 5770.04 5863 72 5956:50 6048.59 6140.21 6231.05 21 11 N 59 33 E 21 11 N 60 21 E 20 48 N 61 18 E 20 37 N 62 18 E 20 3 N 62 27 E 21 11 N 59 9 E 22 52 N 55 0 E 22 55 H 47 33 g 24 3 N 42 23 E 25 46 N 37 34 E 7100 O0 7200' .00 7300.00 7400.00 7500,00 7600.00 7700.00 7800.00 7900.00 8000.00 6437,55 6614,09 6701.66 6788.98 6875.83 6962.18 7048.07 7134,30 7221,69 6320.85 6409.53 6407,39 6584.96 6672.27 6759.13 6845.48 6931.37 70{7,60 7104,99 26 21 N 32 5 E 28 4 N 32 5 E 29 9 N 32 39 E 29 10 N 32 39 E 29 13 N 32 39 E 29 54 N 33 20 g 30 22 N 34 44 E 30 56 N 35 31 E 29 47 N 35 49 E 28 6 N 36 38 E DOGLEG RECTANGULAR COORDINATES HORIZ' DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DXSTANC~ AZIMUTH DEG/100 FEET FEET 0,67 0,98 0,21 1,38 5,53 0,94 0,40 1,41 0.37 1,26 0 85 1,38 2,36 1,39 1,72 0.81 0,87 2.37 0,36 0.58 0 78 0i43 0 65 0 56 0i19 ] O0 2.16 2,50 1.12 5.12 1.50 1.09 O.54 0,47 0.51 0,93 0.79 0.48 1.38 0.66 1203 69 N 1325 88 N 1362 91 ~ 1391 70 N 1422 78 N 1452 l! N 1480 81N 1509 40 ~ 1537 20 N 1564 18 N 1590 63 N 1615 57 N 1639 72 N 1662 67 N 1684 60 N 1705 55 N 1724 89 N 1743 62 N 1761 99 N 1779 86 N 1797 50 N 1814 42 N 1830 59 N 1847 07 N 1867 74 N 1891 88 N 1920 35 N 1951.64 N 1988 32 N 2027 34 N 2067 88 N 2108 59 N 2149 72 N 2191 33 N 2233 O5 N 2274 92 N 2316 07 N 2355,29 N 903 89 E 937 35 g 97 E 1038 05 E 1073 88 E 1111 23 E 1148 79 E 1185 65 E 1222 36 g 1258 72 E 1295:17 E 1331.15 E. 1366.10 E 1400 57 E 1434 O? E 1.466 70 E 1498 76 E 1529 92 ~ 1561 04 ~ 1592 12 1623 31 1654 52 1685 56 1716 36 1747 19 1778 22 1808t79 1836.94 1864.64 1888.92 E 1913.25 E 1938.89 E 1964.84 E 1991 00 E 2017 93 E 2046 25 E 2075 76 E 2105 25 Z 2133 95 E FEET DEG MIN I,~.~85 29 N 36 54 E 36 N 36 58 g 166 t713 1757 1805 1851 1896 1942 00 N 37 3 g 49 N 37 9 m 21 N 37 17 ~ 86 N 37 39 .. 31 N 37 59 E 58 N 38 20 E 99 N 38 41E 28 N 39 0 E 1986 79 N 39 18 E 2030 2156 2195 2233 227O 2305 2340 79 N 39 37 E 14 ~,39 55 E 72 N 40 13 E 45 N 40 30 E 68 N 40 46 E 63 N 41 2 E 51 N 41 18 E 62 N 41 34 E 31 N 41 50 E 2374 75 N 42 2408 2443 2476 2509 2542 2578 2617 2657 2699 6 E 95 r~ 42 21 g 04 N 42 37 E 54 N 42 53 F 37 N 43 9 { 51 N 4.3 24 c, 86 N 43 35 E 42 N 43 42E 47 N 43 43 E 22 N 43 41 g 2742 52 h 43 31 E 2787 59 N 43 20 g 2834 2882 2930 2978 3028 3079 3129 3178 68 N 43 9 E 14 N 42 58 £ 09 IV 42 48 E 92 N 42 38 E 81 N 42 30 E 61 N 42 22 E 90 N 42 i6 E 23 N 42 10 E ~ARA~HON OIb COMPANY D-3 REDEI[,6 TRADING BAY UNIT KENAI, ALASKA COMPUTATION DATE: 6-DEC-1983 PAGE 3 '~'. KEhLY BUSHING EbEVAT.~..I 116.70 F~{ ENGINEER~ MC.~BRIDE ,.' INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COt]ESE ~FASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG ~IN DEG MIN 8100 O0 8200 O0 8300 O0 8400 O0 8500 O0 8600 O0 8700 O0 8800 O0 8900 O0 9000 0o 7310 08 7399 68 7490 08 758O 89 7671, 76 7762 85 7853 67 7944 46 8035 22 8126 13 7193.38 7282.98 7373.38 7646.15 7736.97 7827.76 7918,52 8009.43 27 15 N 36 54 E 25 46 N 37 48 E 24 57 N 39 13 E 24 38 N 38 27 E 24 38 ~ 34 38 E 24 37 N 36 4 E 24 56 N 35 31E 24 38 N 37 13 E 24 38 N 38 38 E 24 38 N 40 41E 9100 O0 920O O0 9300 O0 9400 O0 9500 O0 9600 O0 9700 O0 9800 DO 8900 O0 lo000 O0 8217 09 8307 64 8398 04 8488 21 8578 02 8667 75 8757 37 88,47 30 8937 28 9026 48 8100.39 8190.94 8281.34 8371.51 8461.32 8551.05 8640.67 8730,60 8820 58 8909:78 10100 O0 1.0200 O0 10300 O0 10400 O0 10500 O0 10600 DO 10700 O0 1O8OO O0 10900 O0 10920,00 9115,04 9202,85 9290,16 9376,77 9462,54 9548 13 9634 58 9721 85 9809 86 9827 59 24 38 N 41 35 E 25 12 N 41 15 E 25 36 N 41 39 g 25 46 N 43 7 E 26 21 N 44 0 E 26 21 N 45 15 E 26 21 N 46 21E 25 46 ~ 46 42 E 26 21 N 46 24 E 27 20 ~ 45 50 E 8998.34 28 4 N 46 37 E 9086.15 29 13 N 48 7 E 9173.46 29 35 ~ 48 42 E 9260.07 30 31 N 47 57 E 9345.84 31 28 N 45 52 E 9431,43 30 37 N 45 50 E 9517.88 ' 29 47 N 45 50 E 9605,15 28 39 N 44 4'1 E 9693.16 27 30 N 44 58 E 9710.89 27 30 N 45 15 E DOGLEG RECTANGULAR COORDINATES HORXZ DEPARTURE ~ SEVERITY NORTH/SOUTH EAST/WEST DISTANC~ AZIMUTH " DEG/IO0 FEET FEET FEET DEG ~IN '?? 1.58 1 28 0:95 2,96 0,71 0,72 0,30 0,59 1,02 0,45 0,79 0,72 0,56 1,10 1,03 0 48 1:51 0,57 1,06 0,96 1,16 0,61 1,21 1,14 0,81 1,09 1,49 0,41 1,72 0,00 2388 32 N 2418 85 N 2461 50 N 3O N 2561 35 N 2595 34 N 9 N 2629 ~9 N 2662 2694 32 N ~725,56 2757.33 2789,36 ~821.39 2853,28 2884,60 2915,57 2945,46 2975,49 3006.79 3038 90 N 3071 36 N 3103 59 N 3136 76 N 3171 84 N 3207 84 N 3242 85 N 3277 12 N 3310 82 N 3333 09 N 21.58 52 E ' 32t9 21 N 42 2 7 E 32 2~ 6 33~I 44 N 42 2241 2266 2290 2314 2339 2365 2391 6 E 2 E 50 E 93 E 3353 45 E 3395 35 E 3436 78 E.' 3477 53 g 3519 3! E 94 E lN 41 59 E N 41 57 E 03 N 41 5? ]' ~I N 41 4~ N 41 43 E 38 N 41 39 E 3561 25 N 41 37 E 3602 88 N 41 35 E 2419 34 E 2447 47 E 2475 81E 2504 83 E 2535 Og E 2566 21 E 2598 01 E 2629 9O E 2661 54 g 2694 14 E 644 686 3816 386O 3992 4037 43 N 41 35 E 87 N 41 35 E 63 N 41 35 E 85 N 41 35 E 79 N 41 37 E 87 N 41 39 Z 5 N 41 42 E 9 N 41 45 E. 16 N 41 48 E 22 N 41 51E 88 E 2799 44 E 2836 81E 2874 41 E 2911 53 E 2947 60 E 2982 37 E 3015 82 E 3038 28 E 4083,55 N 41 54 E 4131,19 N 41 58 E 4179.61 N 42 3 E 4229 28 N 42 7 E 4280 51 N 42 11 % 4332 11 N 42 13 . 4382 29 N 42 16 E 4431 03 N 42 18 E 4478 47 N 42 19 E 4510 06 N 42 21 E MARATHOM 0IL COMPANY D-3 REDRI[,L TRADING BAY UNIT KFNAI, ALASKA COMPUTATION DATE: 6-DEC,.1983 PAGE 4 DATE ~F SURVEY! 28,.OCT-83 KELLY BUSHING EbEVATZONI 116,70 ENG~NE£RI ~C ,BRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT . , ! TRUE SUB SEA (..O JRSE MEASURED VERTICAL VERTICAL D..F, VI AT l ON AZIMUTH DEPTH DEPTH DEG [~ZN DEG 12 18 N 40 4 E 29 13 N 37 14 E 29 47 N 37 48 E 32 5 N 38 57 E 27 15 N 52 22 g 21 11 N 59 35 E 25 46 N 37 34 g 28 6 N 36 38 E 24 38 N 40 41 ~ 27 20 N 45 50 E 27 30 N 45 15 E DEPTH 1000,00 2000,00 3000,00 4000,00 5000,00 6000,00 7000,00 8000,00 9000,00 10000,00 10920,00 993 77 1913 42 2785 47 3642 16 4509 08 5419 52 6347 75 7~2~,69 8126,13 9026,48 DOGLEG RECTANGUt.,AR COORDINATES HORZZ, DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DISTANCE AZIMUTH DEG/IO0 FEET FEET FEET DEG 2,56 0.35 0,52 1,17 1,26 0,58 5,12 0,66 0,45 0,96 6~ 86N 370 90 N 758 82 N {161 95 N 1509 40 N 1743 62 N 1951 64 N 2355 29 N 2694 32 N 3006 79 N 17 96 E 250 3! E 548 870 1864 2133 2 2~91 94 71 16 N 447 46 N 34 0 E 69 E 936 41 N 35 52 E 30 E 145174 ~ 36 49 E 36 E 1942 28 O4 E 2340 35 N 41 5r 64 E 2699 22 95 E 3 178 ,23 N 42 10 94 E..' 3602,88 N 4{ 35 E 14 E 4037,22 N 41 51 g 0,00 3333,09 N 3038,28 E 4510,06 N 42 21E 9827,59 877 07 2668,77 3525 46 4392:3~ 5302,g2 6231.05 7104,99 ~009.43 8909.78 9710.89 MARATHON OIL COMPANY TEADING BAY UNIT KENAI, ALASKA COMPUTATION DATE= 6-DEC-1983 DATE OF SURVEYi 28-OCT-83 · KELLY BUSHING,ELEVATION,, 116,70 ENGZNEERI MC:.BEIDE INTERPOLATED VALUES FOE EV'EN 100 FEET. OF SUB-SEA DEPTH TRUE SUB-SEA COURSE ~ MEASURED VERTICAL VERTICAL DEVIATIOIV AZIMUTH DEPTH DEPTH DEPTH DEG ~IN DEC MIN 116 7O 21,6 41~ 70 51 70 6 70 816 70 91.6 70 1016 70 0,00 iO0,O0 200,00 300.00 400.00 500,00 600,00 700,00 800,00 900,00 1000.00 1100.00 1200 0 oo:§o 1400 O0 1500~00 1600.00 1700.00 1800,00 1900,00 2O0O,OO 2100.0o 2200,00 2300,00 2400,00 2500,00 2600,00 2700,00 2800,00 2900,00 3000,00 3100,00 3200,00 3300,00 3400,00 3500.00 3600,00 3700.00 3800,00 3900,00 0 0 S 57 36 W 0 0 IV 24 12 W 0 0 S 68 26 W 0 33 N 33 43 W 2 14 N 3 4,8 E 6 47 N 9 9 W 8 35 N 11 52 E 10 18 N 14 43 E lO 53 N 28 25 E 12 36 N 41 0 E 14 29 n 40 30 E 16 39 N 39 29 E 18 54 N 38 23 E 21 45 N 38 23 E 24 3 N 37 46 E 26 29 N 36 4O E 28 57 N 36 40 E 29 47 N 36 4O E 29 13 N 37 14 E 29 13 N 37 14 E 29 13 N 37 48 E 29 13 N 37 48 E 29 13 N 37 48 E 26 49 N 37 40 E 29 13 N 37 14 E 29 13 N 37 24 E 29 47 N 37 48 E 30 19 N 37 48 E 30 22 N 37 48 E 30 56 N 38 23 E 30 24 N 38 57 E 30 56 N 38 57 E 31 30 IV 38 57 E 31 30 N 38 57 E 32 5 N 38 57 E 32 5 IV 38 57 E 32 39 N 3~ 57 E 32 5 ~ 39 32 E 31 30 Iv 40 4 E 30 12 N 41 12 E 7O 316 70 416 71 516 72 617 05 718:16 819.46 921,30 t023,50 , 1126,44 1230,35 1335 50 14.42 14, 1550 59 1661 O0 1774 1 3 1899.97 2003.77 2118.61 2233 38 .2348~02 2462,52 2576.90 2691.28 2805.85 2920.7~ 3036.08 3151,89 .3268,02 3364.20 3500,51 3617,:16 3734,39 3851,99 3969.99 4088.26 4206.36 4323,98 44,'11 ,24 1116 70 12].6 770 1316 0 1.416 770 1516 0o 1616 7 1716 70 1.816 70 1916 70 2016 70 2116 70 2216 70 2316 70 2416 70 2516 70 2616 70 2716 70 281.6 ~0 2916 0 3016 70 3116,70 3216,70 3316,70 3416,70 3516,70 3616,70 3716 70 { 3816.70 391.6.70 4016.70 DOGLEG RECTANGULAR COORDINATES HORIZ DEPARTU{~E' SEVgRITY NORTH/SDUTH EAST/WEST DISTANC~ AZIMUTH DEC/lO0 FEET FEET FEET DEG MZN ' 0,46 o,61 0,40 0,40 3,51 6,32 t,76 2,26 5,43 2,25 2,21 2,30 ! 94 2~66 I 85 2 85 0 14 0 37 0 18 0,22 0,14 0,24 0,36 0,22 0 18 0i50 0 23 0 29 0,32 0068 0248 0158 0 O0 S 1 57 N 8 99 N 23 80 N 39 54 N 57 66 N 72 86 N 92.82 N 114.49 N 93 N 202 06 N 239 34 N 201 76 N 327 06 N 372 38 N 417 27 N 461,93 506,34 550,52 594.45 638 49 682:86 727.64 77].1! 819,28 865.71 0,25 0.42 ,00 ,59 ~.45 ,55 21,29 37 31 E 55 44 E E 98 124 34 E ! 52 61 E 184:1'/ E 217 63 E 25:1 44 E 285 66 E 319,99 E 354,20 E 388,25 E 422,20 E 456 02 E 490 03 E 524 51 E 559 75 E 595 49 E 631 98 E O, 26 S 75 40 W 0 0 83 S 79 27 W 0 99 S 89 5~-iV 1 86 N 32 4 9 35 N 16 b 23 84 N 3 29 W 39 60 N 3 18 E 58 29 N 8 25 g 75 .91 N 16 17 g 00 27 ~37 336 392 449 505 04 N 21 53 E 21 N 25 50 E 04 N ii 26 E 61 N 16 E 26 N 36 E 86 N 32 31 £ 61 i~{ 33 10 E 85 IV 33 38£ 32 N34 I g 68 N 34 23 E 561,93 N 34 42 E 617,93 N 34 58 E 673,65 N 35 11E 729,12 N 35 23 ~ 784,6! N 35 32 840.49 N 35 39 ~ B96.98 N 35 47 E 954.47 N 35 54 E 1012,~4 N 36 0 E ].071,84 N 36 7 E 0.47 0,34 0,61 0,32 0.19 0,55 0.17 0,86 0,30 5,44 911.09 N 958 15 N 1004 98 n 1052 70 N 1100 78 N 1149 58 N 1198 74 N 1247 54 N 1295,1B N 1342,13 N 668 95 g 706 19 E 743 81 E 782 07 E 821 03 E 860,34 E 899,94 E 939,48 E 979.05 E 1018,38 E 1130,94 N 36 15 E 1190,28 N 36 23 E 1250,30 N 36 30 E 1311,42 N 36 36 E 1373,24 N 36 43 E 1435,87 N 36 48 E 1498,96 N 36 53 E 1561,73 N 36 56 g 1623,59 N 37 5 E 1684,75 N 37 ll £ t MARATHON OIL COMPANY D'3 REDRILL TRADING BAY UNIT KENAI, AbASKR COMPUTATION DATE: 6=DEC-1983 PAGE 6 DATE OF SURVEY 2V8.,OCT,"83 KEbIJY BUSHING 4bE ATIONI 116,70 FT ENGINEER: MC BRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUIB.,SEA DEPTH TRUE SUB-SEA COURSE MEASURED VER?ICAL VERTICAb DEVIATION AZIMIITIt DEPTH DEPTH DEPTH DEG MIN DEG ~XN 4000 O0 28 4 N 50 27 E 4100~00 28 38 N 51 33 E 4200,00 28 6 N 52 8 E , oo.oo ,oo.oo 4800,00 25 0 N 55 0 E 4900,00 23 39 N 55 58 E 5000,00 51.00,00 5200,00 5300,00 5400,00 5500,00 5600 o0 5700:00 5800,00 5900,00 2 53 N 56 10 E 2 20 N 56 55 E 21 ]3 N 58 26 E 21 1i N 59 35 E 21 11 N 59 35 E 21 11 N 60 9 E 20 37 N 61 18 £ 20 37 N 62 8 E 20 3 N 62 27 E 2! 46 N 56 21E 6000'00 6100,00 6200,00 6300,00 6400,00 6500,00 6600,00 6700,01 6800,00 6900,00 22 55 N 52 24 E 23 29 N 44 9 E 25 21 N 39 58 £ 26 21 N 32 5 E 28 4 N 32 5 E 29 3 N 32 39 E 29 13 N 32 39 E 29 43 N 32 39 E 30 22 .N 34 16 E 30 56 N 35 25 E 7000,00 7100.00 7200.00 7300,00 7400.0O 7500.00 7600,00 7700,00 7800,00 7900,00 29 54 N 35 31 E 28 13 N 36 31E 27 6 N 37 3 E 25 26 N 37 48 E 24 38 N 39 48 E 24 38 N 35 30 E 24 3 N 35 31E 24 39 N 35 31 £ 24 38 N 36 36 E 24 38 N 38 14 E 4555,03 4668,65 4782.46 4895 63 5008 57 5121 02 5233 07 5344 47 5454 90 5564 76 89,63 5996.98 6104,21. 6211,37 6318.48 6425,32 6531.,92 6639,01 6747,24 6855,99 6980,06 7076.71 7189,11 7302.99 7417.20 7531.84 7647,27 7763,42 7879,71 7994,33 8107.45 8218,88 8329.34 8439.41 8549 40 8659' ,22 8769.46 8879,59 4116 70 4216 70 4316 70 441,6 70 4516 70 46 0 70 4816 70 4916 70 5016 70 5116 70 5216 70 5316 70 5416 70 5516 7O 5616 70 5716 70 5816 70 5916 70 6016 70 611.6 70 6216 70 631.6 70 6416 70 6516 70 6616 70 6716.70 6816,71 6916,70 7016,70 7116 70 7216:?0 7316 70 7416 70 7516 70 7616 70 7716 70 7816,70 7916,70 8016,70 DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DISTANCE AZIMUTH DEG/tO0 FEET FEET FEET DEG MIN .~!: 1 69 0i53 0 51 0,36 0 83 0 83 0 73 0 39 0 53 1 35 1379 14 N 1413 48 N 1447 02 N 1542 97 N 1572 94 N 160 86 N 162~ 79 N 1654 78 N 1057,43 E ' 1,737 87 N 37 28 E 1099.48 E 187~ 1142,23 E , 51 N 38 17 g I E 47 E I 38 E 1346 73 g 1385 08 E 1422 37 E 1895 1946 1996 2045 2092 2138 2182 74 N '37 52 g 01 N 38 40 '~ 10 N 39 1 ) 12 N 39 22 ~ 14 N 39 43 E 76 ~ 40 3E 08 N 40 22 g 07 N 40 40 E 2 48 1 22 0 68 0 58 0 77 0 37 0 26 0 28 0 75 2 30 1679 12 N 1701 82 N 1722 90 N 1743 07 N 1762 76 N 1781 88 N 1800 67 N 1818 55 N 1835 65 N 1854~72 N 1458 33 E 149~ 04 E 152 67 E 1560 10 E 1593 43 E 1626 85 E 1660,29 E 1693,39 E 1726,15 g 1759,30 E 2224 00 N 40 58 E 2263 93 N 41 15 E 23 2376 2412 2449 2484 2519 2556 98 N 41 32 E 27 N 41 49 E 20 N 42 6 E 90 N 42 57 E 76 N 43 14 E 39 N 43 29 E 4,06 3,70 3,62 0,84 1,3i 0,78 0 39 0,97 0,62 1878,59 N 1907 27 N 1940 48 N 1979 53 N 2023 04 N 2069 10 N 2115 63 N 2162 91 N 2211 O5 N 2259 59 N 1793 12 g 1824 75 E 1855 23 E 1883 41 E 1910 56 E 1939 66 E 1969 31 E 1999 44 E 2031 15 E 2064 85 E 2596 99 N 43 39 g 2639 2684 2732 2782 2836 2890 2945 002 060 59 N 43 44 E 65 N 43 42 E 36 N 43 34 ~ 61 N 43 21 10 N 43 34 N 42 56 E 49 N 42 45 E 38 N 42 34 E 94 N 42 25 E 1,76 0,95 1,58 1,41 0,75 3,92 1,39 1,04 1,50 0,80 2307 88 N 2353 12 N 2388 32 N 2430 56 N 2471 02 N 2503 55 N 2544,51N 2581,33 N 2619,00 N 2655,58 N 2099 33 E 2132 35 E 2158 52 E 2190 88 E 2223 36 E 2252,13 E 2278,20 E 2304,79 E 2331,85 E 2359,98 E 3119,86 N 42 17 E 3175,54 N 42 10 E 3219 21 N 42 6 E 3272 24 N 42 I g 3324 04 N 41 58 E 3367 47 N 41 58 E 3415 37 a 41 50 E 3460 54 h 41 45 E 70 N 41 37 E MARATHON OIL COMPANY. D-3 REDRILL TRADING BAY UNiT KENAI, ALASKA COHPUTATIO~ DATEI 6-DEC~1983 PAGE 7 DATE bF SURVEY! 28-0CT-83 KELLY BUSHINGEbEVATiONI 116.70 £NGINEERI MC BRIDE INTERPOLATED VALU£S FOR EVEN ].,00 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE' MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH LEG NIN LEG MIN 24 38 N 40 28 E 24 38 N 41 34 E 25 12 N 41 15 E 25 46 N 41 49 E 26 0 N 43 32 E 26 21, N 44 53 E 26 21 N 45 5O E 25 46 N 46 58 g 25 55 N 46 24 E 27 6 N 45 50 g 8989 65 9099i57 9210 02 9320,69 9431,66 9543,11 9654,60 9766,04 9877,07 9989,00 Rl16 70 8216 70 8316 70 8416 70 8516 70 70 861~ 7 871 0 881~ 70 891 70 9016 70 8000,00 8100,00 8200,00 8300,00 8400.00 8500,00 8600,00 8700,00 8800,00 8900,00 28 4 N 46 39 E 29 13 N 48 27 E 29 47 N 48 42 E 30 56 N 46 59 E 30 56 N 45 50 g 29 47 N 45 50 E 28 50 M 44 41E 27 30 N 45 15 g 27 30 N 45 15 E 10101,88 10215,84 10330,54 10446,43 10563,37 10679.39 10794.12 10907,73 10920,00 9116 70 9216 70 9316 70 9416 70 9516 70 9616 70 97 9827 59 9000.00 9100.00 9200,00 9300,00 9400,00 9500.00 9600 O0 9600:00 9710,89 DOGLEG RECTANGULAR COORDINATES HORIZ DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DISTANC~ AZIMUTH DEG/IO0 FEET FEET FEET DEG 0 84 0 78 0 84 0 5O 0 82 0,75 0,53 0,79 1,21 0,88 2691 08 N 2725 43 N 2760 55 N 2796 O1 N 2fl31 45 N 2866 89 N 290i 55 N 2935 37 N 2968 51 N 3003 29 N 2 2450 248 251~ 74 E 30 E 2548 44 E 2583 46 E 2619 17 E 2654.23 E 2690,51 E 3598 61 N 41 35 E 3644 3691 3738 3786 3835 3885 3934 3982 4032 21 N 41 35 E N 41 35 54 N 41 35 J 66 N 41 36 E 83 N 41 38 E O0 iV 41 40 E Ol N 41 44 E 09 N 41 48 E 20 N 41 51 E 1,16 0,80 0,97 1,10 1,08 0,94 0,80 0,00 0,00 3039 51 N 3076 48 N 311 5 N 315~ 5 78 N 3194 74 N 235 69 N 275 11 N 3314 39 N 3333 09 N 2728 36 E 2768 61E 281.0 79 E 2 04 E 2940 26 g 2980 37 E 30]9 40 g 3038 28 E 4084 43 N 41 54 E 4138 4194 4252 4313 4372 4428 4483 45i0 83 N 41 59 E 6t N 42 4 E 88 N 42 9 35 N 42 12 E 05 N 42 15 E 20 N 42 18 E 52 N 42 20E 06 N 42 21 E ~RRATHON OIL COMPANY D.] REDRILL TRAD/NG B~Y UNIT KENA~, ALASKA COMPUTATION DATEI 6-DEC-1983 INTERPOLATED VALUES FOR CNOSEN HORIZONS MARKER TOTAL DEPTH (DR/bt, ER) MEASURED DEPTH TVD BELOW KB FROM KB 10906,00 SUB-SEA 9695,47 DATE 0r SURVEY! 28-OCT-83 KELLY BUSHING EbEVATZONI ENGINEERI MC BRIDE SURFACE LOCATION AT ORIGINm'tl33 FNK 757 RECTANGULAR CO0~DINATE~ NORTH/SOUTH EAST/WEST 3312.79 N 30i, 7,79'E ,'MARATHON OIL COMPANY D-] RSDRILL TRADING BAY U~IIT KSNAI. AhASKA MARKER TOTAL PEPTH (D~I[,LE~) COMPUTATION DATEI 6-DEC-1983 ************ STRATIGRAPHIC MEASURED DEPTH BELOW KB 10906.00 PAGe, 9 DAT~ Or SURVEY! 28-0CT-83 KELLY BUSHINO,."ELEVATION{ ENGINEERI .NC~,':,BRXDE 116,70 FT TVD FRC]M KB SUB-SEA SURFACE LOCATION AT ORIGIN= 1133 FWK 75'/ FSD RF.,CTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 9815.17 9698,47 3312,7g N 3017,79 E SCHLUMBERGER MARATHON OIL COMPANY D-8 REOR~LL ~/~~ TRADINO BAY TrW PLOT FROM OCT OATA JOB REFERENCE 4000 9000 2000 1000 -I000 -~000 -gOO0 -4000 -4000 WEST REF 68711 SCALE = 1/1000 IN/FT -.P..HH+ .... H-.~--+-+-r-~-t..--.-k--?:' ..... ?"f"T"~ ..... ~"-t..'"T'-~ ..... ~?~'"T ....... 'r"?'"?'"?-'"T'-~"'T'"~-? ...... '.--?.'"~-~' .... .?'-':"'?."-.: ...... 't:'"?"'~-?. ..... -..-':'F'?'".t ....... 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Well History ~> '~ .~.'~ Yes _Sa~) les /~-~" '-' P i O ~.x' ,, ~u~ ~.~ .~/:) -PI .... · _ . Core Chips ... /,-? .4-.~_ ~--~' k _ Core ~sor~:on __ . . Inclination.___~,.., Survey /'~-~' "'---~ ' "" ,~t"/~ L/ Directional Survey · ' . Drill St~tn Test Reports prcddctiOn Test Reports _ .-w' ;c. ,-.T ..... -' ,..: C' ~ --. :L:. x:/. .... ~ ....... : '~ ................... " ' Digitized Data (.___::,:..>_..: ;': ,-]) :4. ?:. ':/' "~' /::{ ". ....... ~ ................ . _, ......... :~'~_ . :,%' STATE OF ALASKA ,._.~ ALASKA '-~_ AND GAS CONSERVATION C( MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERA'I'IONS 1. Drilling well Workover operation [] 2. Name of operator Union Oil Company of California * 3. Address Post Office Box 6247, Anchorage AK 4. Location of Well at surface 757'FSL, 1133'FWL Sec. 6-T8N-R13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 99502 6. Lez~s6~esi~.n~t_~o~_ ~)nd Serial. No. 7. Permit No. 83-81 8. APl Number 50- 733-20090-02 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-3RD#2 11. Field and Pool McArthur River Field For the Month of. November ,19 83 12. Depth at end of month, footage drilled, fishing jobs, dir~tional drilling problems, spud date, remarks Depth at EOM - ll,055'TD Footage drilled - 0' Released rig at 2400 hours, 11-07-83. 13. Casing or liner run and quantities of cement, results of pressure tests N/A 14. Coring resume and brief description N/A 15. Logs run and depth where run N/A DST data, perforating data, shows of H2S, miscellaneous data Perfd 10,550-580'DIL w/ 4 SPF. Perfd 10,520-550'DIL w/ 4 HPF. Perfd 10,650-664'DIL w/ 8 HPF in 2 runs. *Mara~f~on Oil Company Sub-OPerator 17.1 hereby~er~fythat the foregoing is true and correct to the best of my knowledge. SNIGN,F#I~_~ LE_DISTRICT DRLG SUPERINTEN.DATENOVEMBER 14, 1983 O E-~ep~rt on this form is required for each calendar month, regardless of the status of operations and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate -' STATE OF ALASKA ,..~ ~ ' ~ ALASKA i.~-'' AND GAS CONSERVATION CC' VIISSION 'MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. Name of operator Union Oil COmpany of California * 3. Address Post Office Box 6247, Anchorage AK 4. Location of Well atsurface 757'FSL, l133'FWL Sec. 6-T8N-R13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106 'KB above MSL 99502 6. Lease Designation and Serial No. ADL-18729 7. Permit No. 83-81 8. APl Number 50- 733-20090-02 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-3RD#2 11. Field and Pool McArthur River Field For the Month of October 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at EOM - ll,055'TD Total footage drilled - 4482' 13. Casing or liner run and quantities of cement, results of pressure tests Ran liner 6267-11,055' and cemented with 1224 hours, 10-25-83. Liner lap and casing pressure tests OK. sx cement. CIP @ 1830 4. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SP/Sonic 11,055' FDC/CNL/GR/Caliper 11,055' Casing Inspection Log 6267'-surface CBL/GR/CCL 11,055' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A *Marathon Oil Company Sub-Operator 17. I hereby/~fy that the foregoing is true and correct to the best of my knowledge. SIGNED -. ..... LE DISTRICT DRLG SUPERINTEN_TDATE NOVEMBER 14, 1983 NOTf~port on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil ~t&;;~el~Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate ~-.. STATE OF ALASKA .-.. ~ ALASKA LAND GAS CONSERVATION C(, ~MISSION ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well)~ Workover operation [] 2. Name of operator 7. Permit No. Union 0il Company of California* 83-81 3. Address Post Office Box 6247, Anchorage AK 99502 4. Location of Well at surface 757' FSL, 1133 ' FWL Sec, 6-T8N-R13W-SH 5. Elevation in feet (indicate KB, DF, etc.} 6. Lease Designation and Serial No. 106' KB above HSL ADL-18729 8. APl Number s0- 733-20090-02 9. Unit or Lease Name Tradinq Bay Unit 10. Well No. D-3RD2 11. Field and Pool McArthur River Field For the Month of. September ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations at 1130 hours, September 27, 1983, 13. Casing or liner run and quantities of cement, results of pressure tests N/A 14. Coring resume and brief description N/A 15. Logs run and depth where run N/A 6. DST data, perforating data, shows of H2S, miscellaneous data Perforated at 10,060' tubing measurement, *Mara~ Oil Company Sub-operator 17. I hereb/~ ce~ify that the foregoing is true and correct to the best of my knowledge. // ~/"~_ _ ' ~/'//~ ///2 /~ DISTRICT DRLG SUPT 10/14/83 SIGN · TLE__~ _____ DATE ~r each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate · ,~4_~ DRILLING ;,- ~ ..... ANO('~_LSERV~C~Na~.- ': BOP, ACCUMULATOR & cHOKE N~TEST REPORT m. B LOW OUT PREVENTER A~EMBLY PRESSURE TEST I UNIT APPLIED TIME HELD B II n<l ~iml B. KELLY COCK }uPPER ~-- ~i:~ ~'2 I ..~7..~, ',~./ 1 P R 5 SSU R E TE ST1LOm~-~ ~ ~ ~--.~ ,~ ~ .¢ OTHER ' t ' ' O 0 0 ~ ~'~ '~/ l PRE~URE ' I ii.l[e.~l...[,tI ~. · I TESTS ! , ' . '~' ' -I R~t~ Hc~. I ~-~ ~"-.~ ~ ' ' ' g. ~ST STRING 'J . . ~G ~- ' BL'E ED OFF -I Locking wh~-~ll InttIlled OY~'I ~NO CASING PRESSURE TEST Left In optn p.ositlonl' ~Ye$ ~ No TOP JOINT SIzI Weight OF P'ressufl On r..~slng/cz.~in~ annulus , -. By' - PSI Gy_ ,= Psi E. CHOKE MANIFOLD PRESSURE TE~T F! AC C U M U LATO R & BOP CONTROL MA.N I FO LD . · G. . . REMOTE STATI O N VALVE OPERATORS TESTED ACCUMULATOR TESTED J REMOTE CON. 5TA. TESTED I BOLTS ON .~,NiFOLO LAST l J~ IN "F" O YeS 0 No J O Y~ ~ NoJ TIGHTENED (DATE) ~ Yml ACCUMU~TOR VOLUt4E A TYPE J BOTTLE PRECHA~GE PR~SURE J REDUCING & REGU~T. VALVE HYDRAULIC PUM~ I FLUID OPERATING PRESSURE lAIR INLET PRESSURE OPERATING ~UIO J LOW PRESSURE NO. OF STATIONS NUMBER 5~ATIOH5 j ~WER SUPPLY J ~QCATION' I ~BEL~D CUR RE.TLY J BU~O RAM CONTROL ~Y~' 0 No ' p*l ~ Air g Llauid FLOOR ~ Y. ~ No n. AC( U,MU LATOR PE~ FORMANCE TELT l. EQUI?MENT CHEC~ Accumulator & Pumo Accgmc, lalc~ Only . __ Pf~-ASUt I I I~ e$$urII ' - Time ,I ~ m IJ J - , ~,.,.~ ~c~ l<~-~- ~o r~*C Clr~u!itln~ h~*d on ll~o¢ . _N~lo~lln~ mon~lor in~t~H~d & wotkln 'nsld. BO~ on ,l~r IY?I tFIll up Un' & KIll LIne ~:, .... ,.~,::,o,,-,::,,m:~o~,.,lVI ]~.~.,~,o. ..... Pump Only, ~ Pr{$$ufl wHERE LEAK OCCURRED I ' J HOW REPAIRED _ J. LEAKS ,/v'' '''~/t~/~-''- ' J I -" ~ ' ' ' ' ! . · BEPRESENT~VE~ AC CUr/UI~ATOR RECHARGE TI~aE · PIT DRILL Drilling T¢l;plnj [] Closing llr~e Iv~sl~,o May 24, 1983 Mr. Robert T. Anderson District Land ~nager Union Oil Company of California P O Box Anchorage, Alaska 99502 Re~ Trading Bay Unit D-3RDz ~nmon Oil Company of California Pe~it No. 83-81 . ~8~ R13W S~-~ Sur, ~c. 757'FSL, 1133'F~--~, Sec. 6, .... , , . . ~.~.L Sec. 6 Bt~noI~ Loc. 1029'~'NL- _. , 901'rr , , ~:, ~13U, '~--'. Dear ~-~. Anderson: Enclosed is the approved application for permit to drill the above referenced well. if coring is conducted, a one cubic inch ch~p from each foot of recovered core is required. Samples of well cuttings and a ~d log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log. infor~ation shall be subp~itted on all logs for copying except experimental logs, velocity surveys a~d dip~eter surveys. )~any rivers in A!a~ka and their drainage system, s have Been classified as important for' the spav~ing or migration of anadror~ou~ fish.· Operations in these areas are subject to AS !6.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior.to co~mencin$ operatiop~ you may be contacted by the Habitat Coordinator' Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promul~ated tbereum~)er (Title 18, Alaska Administrative Code, Chapter ~0) and by the ~e(~era! ~ater Pollution Control Act, as a~.ende~ Prior to com~encing operations you may be contacted by a representstive of' the Depart~en= of Envirom~enta! Conservatiom. To aid us in scheduling field work, please notify this of,=ice zA hours prior to c~menc~ng" ~ _ ? ~nstallation of the blowout Mr, Robert T. Anderson. Trading Bay Unit D-3RD2 -2- May 24, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment when the abandonment work commences and prior to milling the 9-5/8" as~n§ Where a dtverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may-witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness -present. Very truly yours, . / C. V. Chatterton Chairman of AlasP~ Oil and Gas Conservation Commission Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Union Oil and Ga~ '---'-~n: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager Hay 19, 1983 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska McArthur River Field Application to Drill and Complete Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to redrill, complete and produce Trading Bay Unit State D-3 Rd. #2 in the Hemlock Oil Pool pursuant to Rule 5, Conservation Order No. 80. This proposed completion at a crestal final withdrawal point will result in additional recovery of Hemlock Production. Your approval of this request will be appreciated. Very truly yours, sk cc: C. Case R. Warthen Alaska Oil & Gas Oo~-~s. Gom[nissior~ Anchorage Union Oil and Gas D' ';on' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl®n Robert T. Anderson District Land Manager Hay 17, 1983 Hr. Chat Chatterton Ak. Oil & Gas Conservation Committee 3001Rorcupine Drive Anchorage, Alaska 99504 WEST FORELAND AREA State of Alaska HcArthur River Field Trading Bay Unit, D-3 Rd. #2 8-86-71-5575-601351 Dear Hr. Chatterton: Enclosed for your approval are three (3) fully executed copies of the above captioned Rermit to Drill D-3 Rd. #2, Dolly Varden Rlatform. Also enclosed is our Check No. 19248 in the amount of $100.00 to cover the required filing fees. Upon approval of same, we would appreciate a copy so that we may complete our files. sk Enclosures Very truly yours, '~/ Kevin A. Tabler / Landman cc: O. R. Callender A. Lannin-O & G, Rasadena Alaska Oil & Gas Cons. Commission Anchorag~ STATE OF ALASKA ~. ALASKA ~.,L AND GAS CONSERVATION CC,,~MISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well .EXPLORATORY [] DEVELOPMENT OIL ['~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE I-~ MULTIPLE ZONE [] 2. Name of operator Union Oil Company of California (Marathon Oil Co. - Sub-operator) 3. Address P.O. Box 6247, AnchOrage, AK 99502 4. Locationofwellatsurface Leg A-2, cond #11, Dolly Varden Platform 757' FSL, 1133' FWL, Sec. 6-8N-13W-SM At top of proposed producing interval 3950' FSL, 3850' FWL, Sec. 6-8N-13W-SM At total depth 1029' FNL, 901' FEL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF etc.) 106' KB above MSL 6. Lease designation and serial no. ADL-18729 9. Unit or lease name Trading Bay Unit 10. Well number D-3RD2 11. Field and pool McArthur River Field 12. Bond information (see 20 AAC 25.025) Type Blanket Drilling Surety and/or number B-2-165-724-1 Amount $200,000.00 15, Distance to nearest drilling or completed we~ D-27 1000 feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 21 miles NW of Kenai miles 1300' FNL ADL 18729 feet 16. Proposed depth (MD & TV•) 17. Number of acres in lease 11,050' MD, 9,952' TV~eet 3085 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 6429fee~VI}MAXIMUM HOLE ANGLE 27 °I (see 20 AAC 25.035 (c) (2) 21 18. Approximate spud date July 1, 1983 2 8 / 3 psig@ 3500 psig@ 9952 Surface ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole ! Casing 8-1/2" 7" Weight 29# CASING AND LINER GradeN_80 Length '4300' SETTING DEPTH MD TOP TVD 6750' 16094' I I M D BOTTOM TV D 11050"I 9952' I QUANTITY OF CEMENT (include stage data) 1000 sx cl "G" 1 22. Describe proposed program: D-3RD2 Drilling Program 1) Abandon D-3RD as outlined on Sundry Notice to Abandon. 2) Mill a 60' section in the 9-5/8" csg. Set a cement plug across the section and kick off at approx. 7125' MD. 3) Drill 8-1/2" directional hole to 11,050' MD.* ' 4) Run open hole logs. 5) Run 7" liner and cmt. w/ approx. 1 000 sx. 6) Complete as a Hemlock producer. AlaskaOil& GasOons.~olnrnission !*The proposed well path does not come within 200' of any well except D-3R~,nch°rage 23. I hereby certify that the foregoing is true and co. rrect to the best of my knowledge S l G N~~//~~7 I TLE D is t r ic t Land Mgmt. The~P~ce below for Commission use [obe~t ~. ~de~so~ CONDITIONS OF APPROVAL Samples required J Mud log required DYES ~o j []YES mO I Permit number . I Appro~.~val date /~ Rev. 7-1-80 Directional Survey required f~FYES •NO DATE 5/17/83 APl number 50- '2'$ 3- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE May 24, 1983 by order of the Commission Submit in triplicate ALASKA OIL AND GAS .GONSEgVATION COMMISSION Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501 '-3'i 92 TEL EPHONE (907) 279.--1433 May 20, 1983 ADMINISTRATIVE APPROVAL NO. 80.46 Re: Application of Union Oil Company of California, operator of the Trading Bay Unit, to drill, complete and produce the Trading Bay Unit D-3RD2 well as part of the pressure main- tainence project approved by Conservation Order No. 80. . Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: The referenced application was received on May 19, 1983 and stated that the drilling, completion and production of the Trading Bay Unit D-3RD2 well will provide a crestal final with- drawal point in the Hemlock Pool. '~ The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion and production of the referenced well pursuant to Rule 5 of Conservation Order No. 80. Yours very truly, Harry W. Kugler, / Commis s ioner BY ORDER OF THE COMMISSION HWK:be 0 0 D. TD 12,600 VD 10,177 ,/ G-! ... 10,800 ?0 , VD 9734 vO 10.4 ~17 VO 9&45 0 0 ,1 D =26 ,D.-.3RD2 ADL 187: O ?~ I 1,600 TO IZ.4Z~ TD 10,660 D-2A 10,184. VD 9 D-4 D-25rd TO ,4 'ID I~',100 VO 10,014 ,,e\ 14 \,\ D-I s ~ARATHON OIL CC~PANY TRADING BAY UNIT McARTHUR RIV£R FIELD STAuCT~R[CC~lfC~ ~ TOP HEMLOCK BENCH I' MARATi'-Jq.N Oil COMPANY ~-'" DOLLY :RDEN PLATFORM . TBU D-3 RD 2. ' ' .:: ... ..... DIRECTIONAL PROGRAM ................... : ' ;'---:. ..... · . . . (: - :],850'- , , ~ TARGET - / ' ........ ' ~ ..... ~:~-~i' . _ .:/ ....... , .......... + ............. ..... PROPOSED * .SIOETRACK ' ' ~'~__~/ ' .,,,, .....~ : :: :.'---; ~'-:- ...... _.. :-~; .....2..- : . : ......... ,, ................ ......... : .......... ; .,~/": .' <---- EX,ST,.. ................. .......... i .... ~ .....~ .......................... i ....... : ........ I ...........,II' =====================, :::.:::::_::.:--:-.. :-::.: :::: :: ::::::.:::, :-=:-:: _:2-~ :_::: :_-'_:-::¥: !-L.--LT-Ie: :_--_ ;_----::-':: :.:::: ::_:~.L'_' 2~: :': .... F~--: - I ...... .... ; ............ ~ ...... "1' . --; ................ ~ .... -/' -i.--- .......... , ........ ~ ......... I~.1 ........ · : ,; ., ; ; ' ~ I'~1~ --- i ............... i-; ........ ; ..................... ~' ............... + ........... t- '-- ' ............... ~''' I ---i ............. '. / ........ -f ............ !--o ...... 1- .......... I ...... :-:: '-:-_-::::-:-::':-i: :': ', -:: :-:_T .-:_:_'-_.-_ :' .-::~- :': :' i-:: ~- : .-7:'~-: -- :':--::':: ~ -':-:-'.:- :'-: .... ~ ............... g .... k ...... : ............................................ ---, ............ ., ..... t' .....+ ..... ~ ......... ~---I -' ~ .... ? ........... ." .......t' .... -F---: ~ ................ ! .............................. _.. , .......... : ....... ~ ....-~-~.: .... ~ ............................ , ........... ---:::-':-::':-:-:-::: "|'_- .... :::--_-_'~_: :~ ..... :'_L_':."~ '.'._' .... L'-' ._*_.__2/..: .... "":::' ~-'= IT"-~''- :-::-::'' :-:!---'__-_:_:-:. :.::: ::.:.' ~ : .: : .... :':..:_:_;.:. :_"'"'----:-::.:L'---~-------::: ---? .......... t ............. I ........ · ....... .......... I ~ ................... - .. ~ ................... ?. ..... :': _ :.::: _ ............ ~ ............................... - i- ............ ........ ................ . ..................................... __. , .......................................... : ...... ......... ........... , ..................... · , I .... '~- ' ' -TVD :-6429 ....... .................. :1 ...... :-\ - - 0E~:~o ............... -.:: :::::-::~- :' : '-:::::::-) :-'i.: ! :i:'-" - ............ ~ ....... :i ..... !---.~_.~:--: .x:\ --AVERAGE ANGLE = ~6° 57 "'---'::. '::.'i- ' : --: .::i.i. iX::'~ !_!._;i!l:.}_!-i.~tl-i_!Z_!.::_::\\ .- .: ..... : :-:: ..... :.-.:.:::::.:':.:.'~ ...... -. :: :'":':::~ ::"':"-:':'~':: ....... :\\ ...... _ L_:' ''" ":" ~?-'-~-::" : : : ,,, :"': ~,,T,,5~-: '-:~-X~- .. ..:..:.:. :::.. ' :.:_:__::.:::: .... : > ,ooo- - \ \ ......... .. ' ' \ TARGET TMD: 10,270 ,~ ............ .'-': . .... : : -\ X . . _:Tvo= 9~5o ...... : ':' ':;::::... . . . ~_. ...... . 'X,X OEP =. 4195 ................... ~- ..... _.__ ~ .... I'- :____' .... :: ' - ........... ~ ~ '" TD .... TMD : 11,050' ~,~ ....... ' I I : ......... 3000 ...... _q000 ......... 5000 ..... · . . · . DEPARTURE ..... --; ; --' .... ' ":: "i .......... Oil & Gas (;or/u. C, ommtaslor, A~chorag~ i -- DOLLY VARDEN PLATFORM -- U l ~ 13 5,aoo -- Well Room Floor C.,ollar Surface C, onduc.±or .... ' ' 2 (P'P~~ms) 7 ~ 15~/~" D°ub~- Gate- ~IW ~ ~GIW Swing- Bolt Olamp - Diagram~- 1~/8"x 5,000~ fo 1 ! o i~ Riser ~ BOP 5f~ck For t0, ~o~ Drilling' From Uhdcr I~ 3/6'~ I I ~,¢r ~, F ~, ~.~ ! · . . 1£0 )o" VA ia"w .... · . . DVP Lease & Well No. , CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (3) Admin '-~' (4) Casg t-/z?J7/ ,~:7-/:/...%> (12 thru 20) (5) BOPE fxJ,'~ (21 thru 24) ' ?"~ ' (6) Add: 1. Is the permit fee attached .......................................... ® 3. 4. 5. 6. 7. 8. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. YES NO 25. Is well to be located in a defined pool ............................. Is well located proper distance from property line ................ Is well located proper distance from other wells Is sufficient undedicated acreage available in this pool ........... Is well to be deviated and is well bore plat included ............... Is operator the only affected party Can permit be approved before ten-day Wait .................... · ...... Does operator have a bond in force ..................................... Is a conservation order needed ... .................................. Is administrative approval needed . ....... onductor String provided ..'.. iiiiiiiii'iiiiiiiiiill Is c ......... . ~, ..... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate °r pr°ducti°n s}r~s !!' ~i... Will cement cover all known productive h'orizons ......... . . . . casing prote wa er zones ........... " ...... Will all casing give adequate safety in collapse, tension and iiii!21 ~,. . Is-this well to be kicked off from an existing wellbore ..... Is old wellbore abandonment procedure included ,on 10-403 ,...' Is adequate well bore separation proposed ..................... ..,.~.. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... ~/g~,/ Does BOPE have sufficient pressure rating - Test to.. ---.. Does the choke manifold comply w/AP1 RP-53.(Feb.78) ..... //:// Additional requirements ............................................. Additional Remarks: REMARKS o Z Geolog7: Engi~.e~r ing: csf X WVA ~ JKT~.~~HJH 7 JAL,( ~,,-,, MTi~-~ ~' ,, rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE · Well History File APPENDIX Information of detailed nature that is not particulady germane to the Well Permitting Process but is part of the history_ file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. UN'TT TYPE CATE SiZE CODE (~o0 00o o20 065 000 000 0o5 065 noO nO0 o!. 6 065 r)o0 0oo 004 065 OOn 000 002 065 0 {"~ n 0 00 0 0 6 0 6 5 000 00() 006 065 0 o 0 r> 0 0 (.) 04 06 5 6a I 68 1 68, .1. 6,8 I 68 :I 69 1. 6 ~ 1 68 ~ 68 .1 6~ I. 6 8 1 6 a I 6g '1 6 R !. 68 o 9 Q, 25 0 () '1; t.: D : -999~2500 i~lll~il ii;iii![q ~, O Fi P '!" SP SP N C.xl I., 9 E; P 1' S? N C N n E p T S P SP SP SP q ~] 'R A N(iNI, S D N C N L !084. t::~ (l. 16, 1267. 5R, ~ 21.. 1608. q. 1521, 7!. 44, 12. 259f~ ,, 4. F, ,,, 42. 37 '76 47 1.1., 28O8, 48. 12. 2716. 1.5, 21 02. 53. 27, 5 0. n () (! l) 0 0 (1 5625 .~ l. 25 04,69 3125 97 ?7 0000 3 7 .~ r'~ ]906 5525 044:9 0000 3125 3 '750 71,88 2559 00 00 3125 4.375 7R13 4 q 61 0000 [~437 1 .... 6,'2 2 ~:' 1 3 '750 (..) 3750 0000 n 93 a 7?27 00 00 96fl7 ~.~, 5 a 3 '~ 313 [')11 C ~ f) T C A {',, I f) T C ~ !., ! D T C A L I 1 [., r,,'t D T C ~ I.., I D T r':,. k/lq 0 CAI,I DT a. ~ '39 7 8. 6,539 i. 75,75aq a. 'J. ~ 1. 2 !.0.4531 5.4570 R3.062S 9.2500 7.7148 75,5625 0,046q 9.2969 !7.5625 69.4375 0,0200 9,()391 28,2d3t 9.6707 2~, R1.25 . 67,3 12.{; o, 1 14, 3 9.6 ~. 8 4 17,875:) 73'6875 0.0337 9.2813 38,3125 70, '7500 fl. F) b 4 9 q, 5.31 3 "2 O,. 5 7 81 76.4375 R !4 F)'.:-~ 'm'i R A T t t'., i) I r~ :'-ii Ii 4 R ~"~ (.~ NRAT GR ~ R A T T I.., D ¢:; R 1: t.., D (, R P i';IZ f"~ 13 T L 13 T ,.., D 2.3f)6fi .5" q ? _2 3 6,9023 49.5938 1,q883 5.6367 60.25O0 2.3398 2.2656 7.6953 68.6975 2,4727 2.2O90 ii. 1. 562 32.7188 2.45!2 1. ,6035 40,6250 48,7al. 3 2,5O39 1.4043 43. 7913 2. 527 3 1.. 5g,1, 1 20,1562 36,9.)62 2.4824. 1.6475 45, o 93 ~' 53,468~t 20 7813 4 4 * ,4 0 63 . [)EPT SP D E P T $? SP N C ~,~I_, DE:PT SP DE~T SP 8P SP O E P T S P -11 O.~Jr;(? u;'>l-.~I 't, ? "? a ? r; i~ -1. 1 [t. g .37 $ 41-'. }~ ]. ~ ,q 2 ,~- o r) 000 g C i'.! 1, 2,2 ('* 7 r:, C; 66, "25t~('~ .1.5.5762 2464.0()00 '-)3.53!3 !.. ~.. 5703 56,,.~63 PT 2o.2149 1732.o, 000 54,1 ~! 75 'q *. (.-, o q 3 ]' ,41,7500 DT 22.3 .t 4, 5 n R H ! 3~7. 0000 C~T.,I 4 5.40 6 3 16,(',0q4 74. 1250 22.94, C~ 2 .!, 365. O00(~ 5.q, 5625 ..1. cj. 23 4 ~, 'I b ~''~ r) 3. ,1. 25 fi D T 8,632~ 81.5625 0.0522 6.1.797 74.5625 0.0410 12.6250 12,015B '79.1.250 0.0063 9.3672 12.2969 67.1,875 0.1978 1,0.~125 23.1 :q75 79. 5000 0.2373 .!4.1797 7,3%ga 65..1875 0., 0 R 0 '.I 7 . ,,437 5 t0.4063 10.2o13 fi9.81.25 14.250() 76.9:375 IL, D I L P T .G P I L r';, N P g T 'lr f, D GR I .[, l .{ D 2. 4004 1.8135 R.SnO0 48,1250 2.4O43 6,5898 41,343~ 2,4668 2.459O 12.8984 65.8125 2.4063 2.3418 75,6250 2.5723 2,3047 1.9.8750 82.3125 2,64-g4 1.7383 29969 687 .2, .~ 01 44. 101. 500 2,5215 2,7227 9,34,38 65,0625 2.~1~9 2.634,~ 15,4922 91,6250 1¢t'~ ]I U Iii1 ,I:-] i[~ [:4 i I, V P 0 } (:, k 0.2. V E P !' F' T C. ,.~i 'r I P ~,: I. ] S .r T. f': G P A. C, E 6 13 ~ P T qCNI.. DEPT DE~T SP NCNI, D E: P 'r 87 SP SP SP NCNi D ~ P T NCNI, N C N O~PT SP ,D,. E P T SP -99 ~ %0 rio i',,pli T -6q,H!25 2025,000q FC~[, - 64.. ,5 o (') 0 fl R 2 '~ , 70 7 r) 1"> R tq 10,4.4. 0000 CALl .1 02.. 0(':00 I I 7. 5625 DT 11R. o000 C ~,f,'f 119.3125 J ,!1. 1. 6250 DT 27. 1973 DkHn t 04,5. OO0(~ CALl !00.8750 1357 9 . 35q'4 77.6~75 0.050t 6,6172 7q.1875 0. !. t)29 9.7965) 7 9. g 750 O. 1304 13. !.32f-; 0,()2~ fi 1.3.179'1 10.4844 1. 0625 0,1o35 0,8594 R4. f4B?5 0,1 '7 3 R ~i,?... ~ 2%0 9.2422 1.6.34:39 I06,~125 0.0566 9.7031 v5.3750 G R t.,. l! f.'- H NRAT I LP GR GR I L I') I 'f' D P ;4 O, P, GR R ..-~ r ~% '! h, D GR 2.5r;gH 2.591R 16,0625 90.3~25 2.5254 2,6397 6,8437 104.]1,,25 2.4453 3.t133 !0,2266 93,1250 2,5430 2'7969 22.921.9 42.4375 1,47~5 4.1211 86 5OO 2 ~ 4277 2,. 7O70 8 8672 68 1250 2 4473 2 3594 6566. 938 5~, 2,4023 2,2266 2('~, ~R1. 67 , rio 2.33og 2,9062, 9,0 () 00 08.0000 97(46 ] [.,,a a 750 D T n :i 49 DIP t-~ f": n 000 C,,~ I, I 2 5 o 0 45.6250 D ']" 1695. 0000 .C. ,~ 1,T 0. o659 ! 4. 4766 P . 75 C; ,} ~2.9375 0.0854. .], 1.8 .,~ 37 7.07 f41 ~6.8750 0, On9 '~1 9.0391 !5.I95,.% 75. 5625 -0. 0905 9.1,4, f4 3,2~32 g0,3125 0.099t ~3,4297 gn.3125 9.81~5 91.3'750 0.0166 9.195 { 42.6563 !, 39. 8750 -0 , 0 .t 27 ! a, .4063 79 , 1. 2, 59 1 r,,P P lr T., r',' ~i R A T I L l:;' !,.:~ ~ ~ T ? I, f) GR I GR 1' I..~,1'~ G R ~ H ii'! [3 G ~,~ [,'? t,{ o 'R :[. 1', I T,F~ 2,5 (', ~ ~ 2.7 g ,.t o E,32~1 g~,Sb25 2.39~a 2,7754 6.3555 50.9687 2,3516 2.~34~ 11,7656 t6.7188 2,44!.4 1,,6523 3,5E~98 [~0.8750 2,5000 3.4063 23.0625 50.9062 1,7~'71 4.5742 4 2,~535 2. 500 6.1406 46,1250 2,3125 5R 31.25 27'8125 , I, 333n 4,8477 I 3,2 i n 7 40,3439, I-'~ ;I I I I ill ii;-] ii! [;-] I N C ?,~ b SP N C N L DEPT 1) It? P T SP SP 13 ~ p T 8P 8P 8P N C ~* L SP ! . ? 'l '~ 5 rl 39 o g. 0000 F C ~'; b 2504.0r)00 CAt,.T 43,3125 q 249...2 I1' '~ 46,8750 DT 1.533.0000 CAt, I: 40.7500 4fl. ~. 562 DT ?, 6,7 n 9 (i [';, R H ~ 1214.0000 CALl 44. I g75 1. 01,06~5 13T 4~ 1934 DP~.~r'~ 420.0000 CAI I 92. 3125 I O2.1, 25 O D r 594,, 50 00 (', A L I 96. R 125 9.60!6 89,0000 o,0142 14.7031 R.5547 8~.5000 9.382g 7.5234 92.0000 0,0298 9.5781 9,5(>25 !,00.5625 '0,0161 16,781,'1 9B4 5625 94,. O. ~6F, 4. 9. 0703 7.69 5 ,.] 101.1.875 064 5 1:3.92.~,7 92.1250 O.O17l lO'95'31 ct · 1 7 q 7 95. 3750 o. () 51:3 8, . g22 4. [q203 97.25O0 RriOP !',j R ,~,T NRAT I i., [> N' R A T ]:: [., D 2,5352 1.6680 5.9492 62 · 9375 2 36ql 311211 7.7500 48.R125 2.3281 2,4570 7,093~ 39.9375 2,3770 2.1934 11,4766 70,5625 1.7900 4'2422 8,0625 43.9375 2,261.7 2.5664 8,7031 75,0000 2,0gq~ 4.0273 8,0547 88.3125 2,298~ 3.3965 9,4 'l b 6 5 o, 21 .~ 7 2,3652 ~.2227 1, o.7422 38.2813 ,'I i, I ii] ~l=-] il! [:-] i~ 26. 1230 t fl ~2. 000(.! 4 !.. % 0 c,, Il) -99q.25g(} lt.,tv -.qOq. PSO0 4q6.~OC~O CAf,I 32.1.562 1024 10,¢594 ~iR~T -999.25O0 -099.2500 -0.n~39 8.6~53 2.3096 2.6660 -99g,2500 -999.~50n 3.4~44 DATE ~.3/I, 2/ 2 0 }:;'. I (; I N : ~ F:~ I,, r,,~ ~ ~4' ~: :136928 ~,~,..~ i~11, i i i 1 ii:..] ii! [:..] dill
