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Home My WebLink About187-0611. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,510 feet See schematic feet true vertical 6,486 feet See schematic feet Effective Depth measured 2,880 feet See schematic feet true vertical 2,521 feet See schematic feet Perforation depth Measured depth 2,655 - 2,861 feet True Vertical depth 2,356 - 2,507 feet Tubing (size, grade, measured and true vertical depth) See schematic Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Middle Kenai Gas 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 4,020psi 3,810psi 3,090psi 6,450psi 6,330psi 1,907 1,796 Burst Collapse 1,540psi Production Liner 508 7,002 Casing Structural 508 6,485 508 7,510 755 1,907 755Conductor Surface Intermediate 34X28" 20" 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 187-061 50-733-20389-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018730 McArthur River / Middle Kenai Gas Trading Bay Unit M-02 Plugs Junk measured Length measured TVD true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD ~488 N/A 216 Size ~488 755 1 120185 0 90 13-3/8" 10-3/4" Other: CTCO, N2 13 324-289 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 136 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Casey Morse Casey.Morse@hilcorp.com 907 777-8322Operations Manager N/A ~488 measured Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Gavin Gluyas at 11:24 am, Feb 27, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.02.27 10:29:32 - 09'00' Dan Marlowe (1267) RBDMS JSB 030325 BJM 4/28/25 DSR-2/28/25 Updated by: JLL 01/23/25 SCHEMATIC Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) 34"x28"Conductor -Driven ~26.5"Surface ~488' 20”91#Structural Surface 755’ 13-3/8”61 K-55 BTC 12.515”Surface 1907’ 10 3/4”55.5 N-80 BTC 9.760”Surface 508’ 9-5/8”43.5 N-80 BTC 8.755”508 5668’ 9 5/8”47 N-80 BTC 8.681”5668’7510’ Tubing 3-1/2”9.2 L-80 Hydril 563 2.992 Surface 3,508’ 5-1/2”15.5 J-55 Csg Butt 4.96 3,511’ 3,538’ 3-1/2" (SS)9.2 L-80 2.992 4,550'5,979' 3-1/2" (LS)9.3 N-80 Hydril 2.992 4,516'7,034' JEWELRY DETAIL NO. Depth (MD) Depth (TVD) ID OD Item 1 470'470'2.813 5.37 Baker TE-5 SCSSV, Tubing Ret. W/ Profile 2 1,654' 1,523’2.867 5.313 GLM 1 -Orifice (08/05/24) 3 2,880'2,521'CIBP (9/16/24) 4 3,250'2,786'--Cement Retainer (08/03/24) 5 3,403’2,898’2.867 5.313 GLM 2 –Open Pocket (7/19/24) 6 3,440'2,923'--CIBP (7/20/24) 7 3,461’2,940'4.750 8.36 S-3 BOT 5" Packer TC II box x pin P BTD = 4,900’ TD = 7,510’ M AX HOLE ANGLE = 44q RKB to TBG Head = 68.5’ Tree connection: 4-1/16” 5,000# B C D-16 D-7 D D-17 II 1 2 1 0 11 12 C-3 D-2 D-4 IV I V V I VIII 1 3 14 1 5 16 4 III A-6 B-1 B-3 B-5 8 8a /8b 9 7 13-3/8 at 1,90 A-5 A-5 A-5 ECP @ 1750 MD A E VII TOC 4,740' CBL 10/07/00 D-1 Low Tbg P unch 7/25/96 6 5 S Z 3 S Z XN X X X X Cement Details 20” Tagged ToC at 104’, then topped off ToC at surface 13-3/8" 17-1/2” Hole:Pumped 780sxs of 15.8ppg lead cement followed by 473sxs of 15.8ppg tail cement. ToC assumed at surface 9-5/8" 12-1/4” hole:Pumped 1900sxs lightweight lead cement followed by 1900 sxs Class G tail cement. Inflated ECP at 1750’ MD with cement. Circ’d 930sxs to surface. ToC at ~1900’’ MD from 10/12/00 CBL. 3-1/2” x 9-5/8” IA Pumped 99 bbls 15.3 ppg cement through retainer at 3250’ MD and around GLM #2 at 3403’ MD. CBL showed ToC at 1,888' MD (8/7/24) Fish 2,664'28.5' Spiral strip gun w/ ~30' cable LIH (TOF 2,664') (9/29/24) 3,525-4,380 CT Fish stuck in hole (btm of fish @ 4,380)- Tbg Punch @ 4,354 / Jet Cut @ 4,348 (June 2024) PERFORATION DATA ZONE TOP (MD) BTM (MD) TOP (TVD) BTM (TVD) AMT Condition Date SZ-19 2,581’ 2,601’ 2,302’ 2,316’ 20’ Open 01/23/25 SZ-20 2,655’ 2,665’ 2,356’ 2,364' 10’ Open 01/22/25 SZ -21 2,768' 2,778' 2,439' 2,447' 10' Open 09/24/24 SZ-22 2,821' 2,841' 2,478' 2,493' 20' Open 09/23-24/24 (Re-perf) SZ-22 2,821' 2,861' 2,478' 2,507' 40' Open 08/13/24 SZ-23 2,888' 2,898' 2,527' 2,534' 10' Isolated 09/16/24 Updated by: JLL 01/23/25 SCHEMATIC Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 Isolated PERFORATION DATA (DIL) ZONE TOP (MD) BTM (MD) TOP (TVD) BTM (TVD) AMT Condition Date A-5 3,465' 3,475' 2,941' 2,948' 10’ Isolated (7/20/24) 07/29/20 A-5 3,497' 3,505' 2,965' 2,971' 8' Isolated (7/20/24) 07/29/20 A-5 3,518' 3,598' 2,979' 3,036' 80’ Isolated (7/20/24) 07/28/20 – 07/29/20 A-6 3,660’ 3,692’ 3,082' 3,105' 32’ Isolated (7/20/24) B-1 3,885’ 3,924’ 3,246' 3,274' 39’ Isolated (7/20/24) B-3 4,020’ 4,095’ 3,345' 3,401' 75’ Isolated (7/20/24) B-5 4,336’ 4,415’ 3,582' 3,641' 79’ Isolated (7/20/24) Short String C-3 5,000’ 5,060’ 4,108' 4,161' 60’ Isolated (10/08/00) 8/10/96 D-7 6,060’ 6,112’ 5,084' 5,133' 52’ Isolated (10/08/00) 1987 Long String D-2 5,558’ 5,598’ 4,614' 4,651' 40’ 08/04/96 D-4 5,754’ 5,794’ 4,796' 4,833' 40’ 08/04/96 D-15_Lower 7,082' 7,090' 6,065' 6,073' 8' Isolated (10/08/00) 09/08/95 D-16 7,136’ 7,172’ 6,121' 6,156' 36’ Isolated (10/08/00) 1987 D-17 7,227’ 7,293’ 6,210' 6,274' 66’ Abandoned w/ cement retainer 1987 Isolated JEWELRY DETAIL NO. Depth (MD) Depth (TVD) ID OD Item 8a 3,487' 2,958' 2.813 X nipple profile 8b 3,508' 2,973' 5.664 8.220 7" csg BTC Overshot 9 3,528' 2,988' 2.813 5-1/2" Perma Packer w/ X-Nipple (10/12/08) 10 3,538’ 2,995' 4.000 7.000 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) A-6 Gravel Pack 11 3,543’ GR 2,998' 2.813 5.37 Packer, SC-1R, Inclusive Gravel Pack Assembly B-2 and B-3 Gravel Pack 12 3,704’ GR 3,114' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly B-5 Gravel Pack 13 4,106’ GR 3,409' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 14 4,424’ GR 3,648' 6.000 8.210 Sump Packer, FB-1 15 4,465’ GR 3,679' 2.813 4.500 Nipple, ‘X’ 2.813” I.D. 16 4,509’ GR 3,712' 3.500 8.380 Overshot, 5-3/4” w/ Over Size Guide Lower Existing Completion (LS) 4,900’ 4,022’ Bridge Plug w/20’ cement (10/08/00) Milled 10' Cement 5/30/24 I 5,954’ 4,983' Packer, Dual, Baker A-5 II 5,999’ 5,026' 2.813 Nipple, “X” III 6,060’ 5,084' Carbide Blast Joints IV 6,957’ 5,947' Snap Latch, S-22 V 6,958’ 5,948' Packer, 9-5/8” x 3-1/2”, Baker, “SC-1” (6’ Seal Bore ext) VI 6,969’ 5,958' Crossover, 6-5/8” x 3-1/2” VII 7,003’ 5,991' 2.813 Nipple, “X” VIII 7,034’ 6,022' Wireline Entry Guide A (SS) 4,980' 4,088' EZ Drill Plug w/ 20' cement (10/08/00) B 5,954’ 4,983' Packer, Dual, Baker A-5 C 5,970’ 4,998' Nipple, “XN” D 5,979’ 5,007' Wireline Entry Guide E 7,198' Cement Retainer Page 1/2 Well Name: MRF M-02 Report Printed: 2/14/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:5/21/2024 End Date:12/31/2024 Report Number 2 Report Start Date 5/27/2024 Report End Date 5/28/2024 Last 24hr Summary Arranged deck, Offload Fox CTU #9 and equipment. Spot in and R/d, M/u 4-1/16" riser and BOP's, function test stack. Report Number 3 Report Start Date 5/28/2024 Report End Date 5/29/2024 Last 24hr Summary IFO, M/u Injector and riser, stab on well. Tested BOP's 250-2500psi. PASS. Witness waived by AOGCC. Performed Drawdown test, good test. L/d injector and riser. N/d Riser and BOP's. Closed SSSV bled tbg install TWC, changed out master valve on tree. PT tree to 5000psi good test. SDFN Report Number 4 Report Start Date 5/29/2024 Report End Date 5/30/2024 Last 24hr Summary Held PJSM, N/u Riser and BOP's, P/u injector head and Lub, M/u Milling BHA, Stab on and shell test breaks to 250-2500psi, RIH no returns, begin motor work multiple stalls and pipe differentially stuck w/no jar action. Shut down pump wait 30mins pipe free. POOH park 3400'. Loaded tbg with 150bbls of FIW and 28bbl hi- vis sweep. RIH still no returns, hard milling f/4380 t/4382'. Washed through fill at 4768', tag 4855' hard milling t/4857'. POOH secured well SDFN. Report Number 5 Report Start Date 5/30/2024 Report End Date 5/31/2024 Last 24hr Summary PJSM, Inspect BHA, Changed out bit 2.75" OD, RIH no retruns. Tag and drilled cement plug from 4857' t/4867'. Observed 900psi drop in circulation pressure while on CIBP. Pipe stuck then free, Made short trip, overpull at 4380' pipe stuck no jar action. Filled back side caught pressure after 40bbls away. Cycled pipe every 15mins no movement or jars, motor is in a stall, tried filling backside again well now on vac. Cycle pipe every 15mins no movement or jar action. Pumped 20bbl lube pill down the backside. Waited 1 hr still no pipe movement or jar action. Tried pumping down coil, motor still in a stall. Closed in pipe rams and slips. Notified production that coil will be left in hole overnight Report Number 6 Report Start Date 5/31/2024 Report End Date 6/1/2024 Last 24hr Summary PJSM, Came online with pumping down backside (3-1/2"xCT) after 40bbls away catch pressure. Worked rate up to 4bpm/850psi. Pumped 500bbls and SD. Pumped and spotted 12bbls of diesel down backside. Worked pipe no movement. Discuss plan with town, launched 9/16" ball to open circ sub with 2gals of gel working rate. Pumping ball until reaching max pressure, then bleeding back pressure slowly with needle valve. Every cycle taking 1.5hrs. Pumped away 1.5bbls and motor completely locked up not taking fluid. Pressured up to 8500psi and left pressure on coil overnight. SDFN Report Number 7 Report Start Date 6/1/2024 Report End Date 6/2/2024 Last 24hr Summary PJSM, check coil pressure 8500psi, no pressure drop overnight, Bleed off, worked pipe no movement or jar action, check ball launch on reel with magnet and confirmed ball was in reel. Pumped 350bbls of FIW down 3-1/2"xCT at 4bpm/850psi. pressure dropped to 750 after 300bbls away. Tried moving coil no luck, pressure up on coil to 8600psi, monitored pressure holding steady. Build and pump 33bbls saturated salt pill down backside (3-1/2"xCT). Let soak overnight. Secure well and SDFN. Report Number 8 Report Start Date 6/2/2024 Report End Date 6/3/2024 Last 24hr Summary PJSM coil pressure 8600psi, no pressure lost overnight. Work pipe no movement, Check 3-1/2 x CT annulus on vac. Pumped 150bbls of FIW down backside and never caught pressure. Stacked 15k down on coil, Mix and pumped 22bbls LCM pill, followed FIW, after 59bbls pumped started seeing differential pressure, worked rate up to 3.5bpm/1000psi. Changed pump rates and surging trying to free coil. Report Number 9 Report Start Date 6/3/2024 Report End Date 6/4/2024 Last 24hr Summary PJSM. Attempt pumping down CT string. Held 3500 psi no bleed down in 2 hours. Diagnose injector head hydraulic issues. Swap hydraulic motor lines. Pull 58K on CT. Still stuck at 4380'. Attempt max pump rate down CT X tubing IA at 3.25 bbls/min while snubbing -15K and pulling 58K. After tubing volume of 23 bbls pumped we caught fluid level. WHP increased to 600 psi. Continue with snubbing and pulling. Attempt to hold in both directions to wait for jar licks. No luck with jars. SDFN. Plan to cut coil and drop disco ball in AM. Call AOGCC and give update. Send update email. Report Number 10 Report Start Date 6/4/2024 Report End Date 6/5/2024 Last 24hr Summary PJSM. Attempt to pick up on coil string 58K no movement. CT string still stuck at 4380'. Fill back side with 60 bbls of FIW. Perform stripping procedure to expose CT. Make surface cut. Install ext slip coil connector and TIW. Drop 5/8" ball down CT stuck in well. Let it move for 4 hrs. Line up to pump and shear disconnect. Pressured up to 8500 psi multiple times did not gain circulation nor see pins shear. Call out AK E-line. Waiting on Fed ex for cutter parts. Report Number 11 Report Start Date 6/5/2024 Report End Date 6/6/2024 Last 24hr Summary PJSM, Pumped 50 bbls down IA to pull well on vac. Wireline arrive on location. Move equipment around deck to spot N2 for boat. Rig Up AK Eline and 1" tools string. RIH with punch. Dry tag down CT string at 4362'. Punch stuck CT String at 4356' perform tubing punch. Good indication punch fired. Check CT string for vac. Good vac. POOH rig back AK E-line. Send update to state Rep Jim Regg. Field: McArthur River Field Sundry #: 324-289 State: ALASKA Rig/Service: Coil #9Permit to Drill (PTD) #:187061Permit to Drill (PTD) #:187061 Wellbore API/UWI:50733203890000 Page 2/2 Well Name: MRF M-02 Report Printed: 2/14/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Report Number 12 Report Start Date 6/6/2024 Report End Date 6/7/2024 Last 24hr Summary PJSM, RU E line for run 2 of jet cutter. RIH through stuck 1.75" CT and tag as expected at 4350' . Punch at 4354'. Shoot cutter at 4348'. Cut looked good on E line unit. Had to work tools up thorugh cut coil. At surface with E-line. Cutter looked uniform. Rig down AK E-line. Pick injector head and dress both sides of CT with double roll on coil connector. Roll on coil and scope down with injector head. Pump 60 bbls down CT reel and stuck coil string. Reel Volume 30 bbls. No increase in pressure. Looks like Jet cutter made communication. Pump 27 bbls down CT annulus x 3.5" tubing. Pull coil and push down try to work free. Max pull 48K, push -5K. Coil still stuck. Close in pipe/slip rams with 48K up. Well secure. Wait for Jet cutter to arrive from AK E-line. SDFN. Report Number 13 Report Start Date 6/7/2024 Report End Date 6/8/2024 Last 24hr Summary PTW/PJSM. Coil pressure (CP) 0 psi. Backside (coil x tbg) 0 psi. Pumped 26 bbl FIW down coil, pressure built to 4000 psi. SD, pressure didn't bleed off. Pumped 35 bbl FIW down backside at 200 psi while working coil. SD, backside on vacuum. Pull 37K on coil. Pumped 300 bbl FIW down backside at 2 bpm and 500 psi. No change in CP (still 4000 psi) and no change in coil weight. SD, backside on vacuum. Bled CP to 2000 psi. Pumped 250 bbl FIW down backside at 2 bpm and 600psi. No change in CP (still 2000 psi) and no change in coil weight. SD, backside on vacuum. Bled CP to 0 psi. Pumped 100 bbl FIW down backside at 2 bpm and 600 psi. No change in CP (still 0 psi) and no change in coil weight. SD, backside on vacuum. SDFN. Sent status update to Jim Regg w/ AOGCC. Report Number 14 Report Start Date 6/8/2024 Report End Date 6/9/2024 Last 24hr Summary PTW/PJSM. Coil pressure 0 psi. Backside (coil x tbg) on vacuum. Pumped 30 bbl FIW down backside. Cut coil at surface to RU AK E-line. GIH with jet cutter and cut coil at 3,525' MD. PU on coil with crane; pipe is free. Pick up injector and MU new coil connector between reel and pipe in hole. POH with coil. SI well. SDFN. Report Number 15 Report Start Date 6/9/2024 Report End Date 6/10/2024 Last 24hr Summary PTW/PJSM. RD Fox CTU. Field: McArthur River Field Sundry #: 324-289 State: ALASKA Rig/Service: Coil #9 Page 1/3 Well Name: MRF M-02 Report Printed: 2/19/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:6/28/2024 End Date: Report Number 1 Report Start Date 7/19/2024 Report End Date 7/20/2024 Last 24hr Summary RU slickline. PT to 250/2500 PASS. Tag at 3,526' with 2.5" LIB. Pull 2 gas lift valves, set dummy in top station 1,654' KB. 3 1/2 AD-2 Stop slip breaks off in hole. Retrieve broken slip. NOTE: STA #2 at 3403' MD has an open pocket Report Number 2 Report Start Date 7/20/2024 Report End Date 7/21/2024 Last 24hr Summary PT to 250/2500. PASS. Drift to fish at 3525', Set CIBP plug at 3440' MD above packer at 3461' MD, but below GLM #2 at 3403' MD Report Number 3 Report Start Date 7/21/2024 Report End Date 7/22/2024 Last 24hr Summary Loaded well with fresh water, bled off gas cap several times. CMIT-TxIA against CIBP PASSED to 1640psi 0mins: 1640/1650/7 (T/IA/OA) 15mins: 1640/1650/7 30mins: 1640/1650/7 Report Number 4 Report Start Date 8/2/2024 Report End Date 8/3/2024 Last 24hr Summary Coil crew arrive on Steelhead. Orientation, PTW, and PJSM w/ production. Arrange and set coil equipment in position on deck. Nipple up riser and BOP on M-02. Install hydraulic lines and circulating lines. function test equipment. Install coil into injector. Cement crew arrives, go through orientation. Look through cement equipment. Go over coil and cement procedures. Report Number 5 Report Start Date 8/3/2024 Report End Date 8/4/2024 Last 24hr Summary R/u coil equip. Fluid pack and test BOPE 250/2500psi, 5minutes each, all tests passed, Jim Regg from AOGCC waived witness. M/u retainer BHA, test breaks to 2500psi, test good. RIH to 3250'. Drop 1/2" ball to set retainer, pump 2 coil volumes of FIW w/ no set. Drop second ball w/ same results. POOH , found balls on top flapper of dual flapper check valve sub. Run retainer in hole w/o DFCV to 3250', drop ball, pump 2 coil volumes, retainer not setting. P/U 500' and run in to 3250', turn on pump, pressured up immediatly to 1800psi, stage pressure up to 4000psi, retainer not shearing to release pressure. Stack 5k down attempt same. P/u 3k over, stage up, pressure broke over at 3500psi. Stack 8k down on retainer, confirm set by pressuring up on tubing to 2500psi, holding 10 minutes, good test. PT CT x Tubing annulus for 10 minutes to ensure retainer is set. Good test. Establish circulation rates/pressures. SD for night Report Number 6 Report Start Date 8/4/2024 Report End Date 8/5/2024 Last 24hr Summary R/u Drill water to cement pump. Circulate down coil, up IA at 1.5bpm, 1850psi, confirm no communication with tubing annulus and pressures are stable. Pump 99bbls 15.3ppg cement, displacing coil volume w/ 23bbls drill water, initial pressure 1800psi at 1.25bpm, max pressure 2400psi at 0.9bpm, final pressure pumping cement 2050psi at 0.9bpm, displacement pressure 1800psi at 1.2bpm (CIP 16:13, calculated cement top in IA @1850'). Shut in IA, unsting from retainer, p/u from 3250' to 3235', circulate surface to surface (45bbls) at 1.8bpm, 2600psi. POOH, close in swab on tree. Standback CT. Report Number 7 Report Start Date 8/5/2024 Report End Date 8/6/2024 Last 24hr Summary RU slickline. PT PCE to 250low / 2500psi high. PASS. Tag at 3,270' with 2.80" gauge ring. Pull dummy valve at 1,654' KB, set 1/4" orifice valve. Report Number 8 Report Start Date 8/6/2024 Report End Date 8/6/2024 Last 24hr Summary RIG UP ELINE. PT LUBE TO 250 / 2500 PSI. PERFORM CBL IN 3.5" TBG. TAG 3282'. PERFORM REPEAT PASS OVER INTERVAL 3272' - 2796'. PERFORM MAIN PASS FROM 3276' TO SURF. RIG DOWN ELINE. Report Number 9 Report Start Date 8/7/2024 Report End Date 8/7/2024 Last 24hr Summary - Report Number 10 Report Start Date 8/8/2024 Report End Date 8/9/2024 Last 24hr Summary Field: McArthur River Field Sundry #: 324-289 State: ALASKA Rig/Service:Permit to Drill (PTD) #:187061Permit to Drill (PTD) #:187061 Wellbore API/UWI:50733203890000 PERFORM CBL IN 3.5" TBG. TAG 3282'. Set CIBP plug at 3440' MD above packer at 3461' MD, but below GLM #2 at 3403' MD Pump 99bbls 15.3ppg cement, NOTE: STA #2 at 3403' MD has an open pocket Page 2/3 Well Name: MRF M-02 Report Printed: 2/19/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Report Number 11 Report Start Date 8/8/2024 Report End Date 8/8/2024 Last 24hr Summary - Report Number 12 Report Start Date 8/10/2024 Report End Date 8/10/2024 Last 24hr Summary MIT-T to 1600psi PASS Initial: 1651psi 15-mins: 1649psi 30-min: 1648psi CMIT-TxIA to 1600psi through live OGLV- PASS 0min – 1650psi 15min – 1631psi 30min – 1614psi Report Number 13 Report Start Date 8/11/2024 Report End Date 8/12/2024 Last 24hr Summary Fox Energy hands arrived on platform. PTW/PJSM. Spot and RU equip as needed. CTU BOPE test 250/2500 psi - good. SDFN. AOGCC witness waived by Jim Regg. Report Number 14 Report Start Date 8/12/2024 Report End Date 8/13/2024 Last 24hr Summary PTW/PJSM. GIH w/ coil, tag at 3,254' CTM. Displace well over to nitrogen and POH, while bleeding well pressure to zero. RD coil equip. RU e-line equip and p-test 250/2,500 psi - good. SDFN. Report Number 15 Report Start Date 8/13/2024 Report End Date 8/14/2024 Last 24hr Summary PTW/PJSM. Perforate SZ-23 from 2,888’ – 2,898’ (Init SITP: 46 psi,15 min SITP: 49 psi). Perforate SZ-22 from 2,821’ – 2,861’ in two runs (Init SITP: 55 psi, final SITP: 136 psi). RD e-line and turn well over to Production. Report Number 16 Report Start Date 8/21/2024 Report End Date 8/22/2024 Last 24hr Summary Rig up slickline. PT PCE 1500 PSI- pass. Rih w/ 2.5" X 5' DD Bailer to 3182' kb. w/t pooh. RIH w/ tandem Tri-gauges, see stop sheet. OOH w/ tools, download data -GOOD. Report Number 17 Report Start Date 8/22/2024 Report End Date 8/23/2024 Last 24hr Summary Standby Charge Report Number 18 Report Start Date 9/11/2024 Report End Date 9/12/2024 Last 24hr Summary Move 404 equipment to make access to M-02 and room to rig up E-line. Work boat; offload iso, load 3-1/2" PH-6 workstring. Report Number 19 Report Start Date 9/12/2024 Report End Date 9/13/2024 Last 24hr Summary Pull wire line bridge from NW leg, place on deck and assist welder on modifying access hatch. Report Number 20 Report Start Date 9/16/2024 Report End Date 9/17/2024 Last 24hr Summary MU TOOL STRING AND PERFORMED OPS CHECK. (PASSED). PICKED UP AND STABBED ONTO WELLHEAD. PRESSURE TEST PCE 250LP - 3000HP. (PASSED). RIH w/ 2.75" CIBP to 2,880' MD ABOVE SZ-23 PERFS. PRESSURED UP VIA GAS LIFT TO PUSH AWAY FLUID AND SET CIBP AFTER PRESSURE WAS STABLE. Report Number 21 Report Start Date 9/23/2024 Report End Date 9/24/2024 Last 24hr Summary Eline arrive on location from OSK. PJSM and sign onto JSA. Remove hatch cover and install bridge. Prepare and install PCE to SV. MU tool string and 10' strip gun. Pressure test PCE 250/1500 psi. Reperforate SZ-22 interval from 2831-2841'. POH to surface, close SV, LD Lub. Turn well over to production for test and evaluation. Field: McArthur River Field Sundry #: 324-289 State: ALASKA Rig/Service: ET CIBP AFTER PRESSURE WAS STABLE Page 3/3 Well Name: MRF M-02 Report Printed: 2/19/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Report Number 22 Report Start Date 9/24/2024 Report End Date 9/25/2024 Last 24hr Summary PJSM and sign onto PTW. RIH w/ 10' strip gun. Tag at 2830'. Reperforate SZ-22 interval from 2821-2831'. Flow test to production. Shut in well and monitor 15min pressure build ups. RIH w/GPT logging tools. Log down pass at 100 ft/min to 2600' and from 2600'-2830' at 30ft/min. 15min station stop at 2830', send log to town. Flow to production. RIH w/ 10' strip gun. Tag at 2834'. Perforate SZ-21 at 2768-2778'. POH 70', tools stuck at approx. 2700'. Worked wireline multiple times. Manipulated pressures while trying to work tool string free- no success. Decision made to cut wire. Wait on wireline cutters. Secure well and monitor. Production flowing tbg to production header- no GL. Report Number 23 Report Start Date 9/25/2024 Report End Date 9/26/2024 Last 24hr Summary E-Line cutter arrived on location. Held PJSM and sign onto PTW. T/IA 8/40 psi. Install kinley cutter and secure to wire. Drop cutter, PU on wireline, no tool string weight. POH. Recover approximately 2670' of wireline. Approximately 30' remaining with tool string. Secure well and RD Eline equipment. Remove wireline bridge and install hatch cover. Report Number 24 Report Start Date 9/28/2024 Report End Date 9/29/2024 Last 24hr Summary Rig up on well. PT 1500 PSI- pass. Attempt to fish Kinley cutter. Report Number 25 Report Start Date 9/29/2024 Report End Date 9/30/2024 Last 24hr Summary Fish E-line Report Number 26 Report Start Date 10/4/2024 Report End Date 10/4/2024 Last 24hr Summary Sale of kinley cutter Report Number 27 Report Start Date 1/22/2025 Report End Date 1/23/2025 Last 24hr Summary M-02 Flowing on Arrival. MIRU AK Eline. PT PCE 250psi/1500psi. RIH w/ 2.73" LIB Drift BHA. Tag TD/Fish at 2665.7'. Log 80 fpm up past GLM#1. Correlate to previous CIBP setting log. Send drift correlation pass to RE/GO and pass confirmed on depth. Pooh. No impression on LIB. Shut in well and stack out Tbg with gaslift to 200psi. RIH w/ 2.5" x 10' Perf Gun #1. Perforate SZ-20 sands from 2655' - 2665'. Tbg pressure climbed from 200psi to ~ 440psi. Pooh. Verify all shots fired. Decision made to test well overnight. Report Number 28 Report Start Date 1/23/2025 Report End Date 1/24/2025 Last 24hr Summary Decision made to shoot next perf interval. Make up & RIH w/ 2.50" x 20' Perf Gun #2. Shut in well and pressure up Tbg to ~ 300psi. Correlate and perforate SZ-19 Sands from 2581' - 2601'. Good indication of firing and pressure response. Pooh. At surface Tbg pressure increased from 309psi to 350psi. Verify all shots fired. Rig down Eline. Turn over to Ops to POP. Job Complete Report Number 29 Report Start Date 2/14/2025 Report End Date 2/15/2025 Last 24hr Summary Mobe S/L crews, R/U P/T 250/1500,good, RIH set AD-2 stop@1977', Pull live valve @1658', RIH install Dummy valve @ 1658', RIH pull AD-2 stop @ 1977', secure well, Rig down. Report Number 30 Report Start Date 2/17/2025 Report End Date 2/18/2025 Last 24hr Summary Tie into IA and fill with Inhibited FIW. Report Number 31 Report Start Date 2/18/2025 Report End Date 2/19/2025 Last 24hr Summary MITIA to 1500 psi as per Sundry. initial pressure 1730, 15 min 1704, 30 min 1685, Good test. Rig down & secure same. Field: McArthur River Field Sundry #: 324-289 State: ALASKA Rig/Service: Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/04/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241004 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 214-13 50283201870000 222117 9/26/2024 AK E-LINE Perf END 2-72 50029237810000 224016 8/26/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON RBT MPI 2-16 50029218850000 188134 9/9/2024 AK E-LINE Perf MPI 2-16 50029218850000 188134 9/20/2024 AK E-LINE Perf MPU B-16 50029213840000 185149 9/28/2024 READ CaliperSurvey MPU B-24 50029226420000 196009 8/20/2024 HALLIBURTON PERF MPU B-28 50029235660000 216027 9/28/2024 HALLIBURTON TUBINGCUT MPU I-01 50029220650000 190090 8/17/2024 HALLIBURTON PERF MPU R-103 50029237990000 224114 9/20/2024 AK E-LINE Hoist MRU M-02 50733203890000 187061 9/23/2024 AK E-LINE Perf PBU 02-21B 50029207810200 211033 9/30/2024 HALLIBURTON RBT PBU L2-10 50029217460000 187085 8/23/2024 HALLIBURTON RBT PBU L-212 50029232520000 205030 9/24/2024 HALLIBURTON IPROF PBU L-254 50029237520000 223030 9/20/2024 HALLIBURTON IPROF PBU P1-17 50029223580000 193051 9/7/2024 HALLIBURTON RBT PBU S-09A 50029207710100 214097 8/21/2024 HALLIBURTON RBT PBU Z-235 50029237600000 223055 9/19/2024 HALLIBURTON IPROF Please include current contact information if different from above. T39619 T39620 T39620 T39620 T39621 T39621 T39622 T39623 T39624 T39625 T39626 T39627 T39628 T39629 T39630 T39631 T39632 T39633 T39634 MRU M-02 50733203890000 187061 9/23/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.04 15:10:24 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 9/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240927 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 8/14/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 8/18/2024 YELLOWJACKET PERF BRU 214-13 50283201870000 222117 9/13/2024 AK E-LINE Perf BRU 221-26 50283202010000 224098 9/9/2024 AK E-LINE CBL BRU 222-26 50283201950000 224035 8/20/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 9/14/2024 AK E-LINE CBL END 1-61 50029225200000 194142 9/11/2024 READ CaliperSurvey KBU 32-06 50133206580000 216137 8/6/2024 YELLOWJACKET PERF MPU B-24 50029226420000 196009 9/9/2024 READ CaliperSurvey MPU L-03 50029219990000 190007 9/18/2024 READ CaliperSurvey MPU R-103 50029237990000 224114 9/16/2024 AK E-LINE TubingCut MPU R-103 50029237990000 224114 9/19/2024 AK E-LINE TubingCut MRU M-02 50733203890000 187061 9/17/2024 AK E-LINE Plug NCIU A-19 50883201940000 224026 9/20/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/13/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/15/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 8/18/2024 AK E-LINE CBL NCIU A-20 50883201960000 224065 9/11/2024 AK E-LINE PPROF NCIU A-20 50883201960000 224065 8/26/2024 READ MemoryRadialCementBondLog PBU 09-27A 50029212910100 215206 9/13/2024 AK E-LINE CBL/TubingPunch PBU 09-34A 50029213290100 193201 12/31/2023 YELLOWJACKET PL PBU 13-24B 50029207390200 224087 8/21/2024 YELLOWJACKET CBL-PERF PBU 13-24B 50029207390200 224087 8/23/2024 YELLOWJACKET CBL PBU 13-26 50029207460000 182074 8/13/2024 YELLOWJACKET CCL PBU NK-26A 50029224400100 218009 7/20/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T39593 T39594 T39595 T39596 T39597 T39598 T39599 T39600 T39601 T39602 T39603 T39603 T39604 T39605 T39605 T39605 T39605 T39606 T39606 T39607 T39608 T39609 T39609 T39610 T39611 MRU M-02 50733203890000 187061 9/17/2024 AK E-LINE Plug Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.27 14:47:28 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240827 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 23 50133206350000 214093 7/18/2024 AK E-LINE PPROF BRU 222-24 50283201800000 220043 8/8/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 8/6/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 7/16/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 8/12/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 8/2/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 7/28/2024 HALLIBURTON CAST-CBL IRU 44-36 50283200890000 193022 8/10/2024 AK E-LINE PlugPerf PBU 18-13D 50029217560400 224039 8/2/2024 HALLIBURTON RBT PBU 18-33A 50029225980100 204070 8/13/2024 HALLIBURTON RBT PBU Z-228 50029237180000 222055 7/28/2024 HALLIBURTON PPROF PBU Z-234 50029237620000 223065 7/29/2024 HALLIBURTON IPROF PCU 2 50283200229000 179009 7/9/2024 AK E-LINE TubingCut TBU M-02 50733203890000 187061 8/6/2024 AK E-LINE CBL TBU M-02 50733203890000 187061 8/12/2024 AK E-LINE Perf Please include current contact information if different from above. T39491 T39492 T39493 T39493 T39494 T39495 T39495 T39496 T39497 T39498 T39499 T39500 T39501 T39502 T39502 TBU M-02 50733203890000 187061 8/6/2024 AK E-LINE CBL TBU M-02 50733203890000 187061 8/12/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.27 11:27:22 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/13/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240813 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 222-24 50283201800000 22Ϭ043 8/1/2024 AK E-LINE CIBP BRU 222-26 50283201950000 224035 7/21/2024 AK E-LINE Plug BRU 232-04 50283100230000 162037 7/25/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 7/24/2024 AK E-LINE CBL BRU 241-26 50283201970000 224068 7/31/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/10/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/18/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/23/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/28/2024 AK E-LINE Hoist IRU 44-36 50283200890000 193022 8/3/2024 AK E-LINE CBL IRU 44-36 50283200890000 193022 7/31/2024 AK E-LINE CIBP IRU 44-36 50283200890000 193022 7/29/2024 AK E-LINE RCT MPU I-01 50029220650000 190090 7/20/2024 AK E-LINE CBL MRU M-02 50733203890000 187061 7/20/2024 AK E-LINE Plug PBU PTM P1-08A 50029223840100 202199 7/23/2024 AK E-LINE CBL PBU V-220 50029233830000 208020 6/28/2024 READ InjectionProfileAnalysis PTU DW-01 50089200320000 214206 7/16/2024 READ CaliperSurvey PTU DW-0ϭ 50089200320000 214206 7/17/2024 READ TemperatureSurvey Please include current contact information if different from above. T39418 T39419 T39420 T39421 T39421 T39422 T39422 T39422 T39422 T39423 T39423 T39423 T39424 T39425 T39426 T39427 T39428 T39428 MRU M-02 50733203890000 187061 7/20/2024 AK E-LINE Plug Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.13 13:58:22 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Juanita Lovett; Dan Marlowe; Rixse, Melvin G (OGC) Subject:RE: M-02 CBL (PTD#187-061) Date:Monday, August 12, 2024 11:30:00 AM Hilcorp has approval to proceed with the perforations per the sundry 324-289. Top of cement at +/-1880’ MD. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Friday, August 9, 2024 3:21 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: M-02 CBL (PTD#187-061) Checking in here. We intent to get on this well with CT on Sunday 8/11 Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: Ryan Rupert Sent: Wednesday, August 7, 2024 9:46 AM To: 'bryan.mclellan@alaska.gov' <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: M-02 CBL (PTD#187-061) Bryan- Please see attached for the CBL log from M-02. Also attached are the daily summaries, and an as-is schematic for ‘phase II’ up until this point. Given the cement quality, Hilcorp requests permission to proceed with perforating as sundried. Please advise. Thanks, Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Dan Marlowe; Juanita Lovett; Davies, Stephen F (OGC) Subject:RE: [EXTERNAL] RE: M-02 Path Forward (PTD#187-061) Date:Tuesday, July 2, 2024 12:33:00 PM Ryan, Hilcorp has approval to proceed with this plan, in accordance with Sundry 324-289 with the change to plug type and depth described below. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Tuesday, July 2, 2024 10:42 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: RE: [EXTERNAL] RE: M-02 Path Forward (PTD#187-061) Answers below in red Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, July 1, 2024 6:51 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: [EXTERNAL] RE: M-02 Path Forward (PTD#187-061) Ryan, I think it should be fine, but want to confirm a few things first: Do you think you milled through the bridge plug at 4900’ MD before getting stuck? Any sign of communication with perfs below that? Possibly. On 5/30/24 we made 10’ of progress from 4857 -4867’ CTMD on what felt like cement, then lost 900psi in circulation pressure suddenly. I assume this was communication through the partially milled plug. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. The only change from the original sundried procedure that I see is that you left coil in the hole and the bridge plug will be set slightly shallower at 3463’ instead of the sundried 3487’. Is there anything else that’s changing? I don’t see any changes requiring sundry modification. I’ll probably set a cast iron on EL instead of a SL TTP now, but that would be the only tweak. Please confirm depth of the top of each pool in this well. Only Pool present in M-02 is the Middle Kenai Gas Pool with bottom below TD, and top at 1496’ MD. Per sundry, isolating all perfs below 3463’ MD will be required to keep lower open potentially higher pressure sands isolated from to be perf’d sands from 2200 – 3375’ MD. No change in this plan. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Monday, July 1, 2024 4:25 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: M-02 Path Forward (PTD#187-061) Bryan- Attached is our current schematic and work completed to date on M-02 under sundry #324-289. After technical review, Hilcorp has elected not to attempt and recover the cut coil. We now intend to move onto Phase II per our approved sundry, leaving the CT where it’s at, and setting a plug around ~3463’ MD. Correct me if I’m wrong, but I don’t think any approval is necessary to move on and leave CT in the hole, since we’re still all within the same pool, and covered by the original sundry. Just a heads up. Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you arenot an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. Ifyou have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanentlydelete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use ofthis message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry outsuch virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you arenot an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. Ifyou have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanentlydelete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use ofthis message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry outsuch virus and other checks as it considers appropriate. Updated by: JLL 06/13/24 SCHEMATIC (As-Is) 2024-06-13 Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) 34"x28" Conductor - Driven ~26.5" Surface ~488' 20” 91# Structural Surface 755’ 13-3/8” 61 K-55 BTC 12.515” Surface 1907’ 10 3/4” 55.5 N-80 BTC 9.760” Surface 508’ 9-5/8” 43.5 N-80 BTC 8.755” 508 5668’ 9 5/8” 47 N-80 BTC 8.681” 5668’ 7510’ Tubing 3-1/2” 9.2 L-80 Hydril 563 2.992 Surface 3,508’ 5-1/2” 15.5 J-55 Csg Butt 4.96 3,511’ 3,538’ 3-1/2" (SS) 9.2 L-80 2.992 4,550' 5,979' 3-1/2" (LS) 9.3 N-80 Hydril 2.992 4,516' 7,034' JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 1 470' 470' 2.813 5.37 Baker TE-5 SCSSV, Tubing Ret. W/ Profile 2 1,654' 1,523’ 2.867 5.313 GLM 1 3,403’ 2,898’ 2.867 5.313 GLM 2 3 3,461’ 2,940' 4.750 8.36 S-3 BOT 5" Packer TC II box x pin 4 3,487' 2,958' 2.813 X nipple profile 5 3,508' 2,973' 5.664 8.220 7" csg BTC Overshot 6 3,528' 2,988'2.813 5-1/2" Perma Packer w/ X-Nipple (10/12/08) 7 3,538’ 2,995' 4.000 7.000 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) A-6 Gravel Pack 8 3,543’ GR 2,998'2.813 5.37 Packer, SC-1R, Inclusive Gravel Pack Assembly 3,643’ GR 3,070'2.867 5.313 Screen, 5-1/2” with 20/40 gravel pack sand down to 3,707’ 3,710’ GR 3,118' 2.867 5.313 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-2 and B-3 Gravel Pack 9 3,704’ GR 3,114'6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 3,881’ GR 3,243'4.892 5.970 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,103’ 4,105’ GR 3,408' 4.000 5.600 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-5 Gravel Pack 10 4,106’ GR 3,409'6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 4,309’ GR 3,561'4.892 5.500 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,420’ 4,422’ GR 3,646' 4.000 7.000 Snap Latch, Seal Assy. W/ 80-40 Seal Ext (4.000” I.D.) 11 4,424’ GR 3,648' 6.000 8.210 Sump Packer, FB-1 12 4,465’ GR 3,679' 2.813 4.500 Nipple, ‘X’ 2.813” I.D. 13 4,509’ GR 3,712' 3.500 8.380 Overshot, 5-3/4” w/ Over Size Guide Lower Existing Completion (LS) 4,900’ 4,022’ Bridge Plug w/20’ cement (10/08/00)Milled 10' Cement 5/30/24 I 5,954’ 4,983' Packer, Dual, Baker A-5 II 5,999’ 5,026' 2.813 Nipple, “X” III 6,060’ 5,084' Carbide Blast Joints IV 6,957’ 5,947' Snap Latch, S-22 V 6,958’ 5,948' Packer, 9-5/8” x 3-1/2”, Baker, “SC-1” (6’ Seal Bore ext) VI 6,969’ 5,958' Crossover, 6-5/8” x 3-1/2” VII 7,003’ 5,991' 2.813 Nipple, “X” VIII 7,034’ 6,022' Wireline Entry Guide A (SS) 4,980' 4,088' EZ Drill Plug w/ 20' cement (10/08/00) B 5,954’ 4,983' Packer, Dual, Baker A-5 C 5,970’ 4,998' Nipple, “XN” D 5,979’ 5,007' Wireline Entry Guide E 7,198' Cement Retainer PBTD = 4,900’ TD = 7,510’ MAX HOLE ANGLE = 44q RKB to TBG Head = 68.5’ Tree connection: 4-1/16” 5,000# B C D-16 D-7 D D-17 II 1 2 7 8 9 C-3 D-2 D-4 IV I V VI VIII 10 11 12 13 III A-6 B-1 B-3 B-5 4 5 6 3 13-3/8” at 1,907 A-5 A-5 A-5 ECP @ 1750 MD A E VII TOC 4,740' CBL 10/07/00 D-1 Low Tbg Punch 7/25/96 XNX X X X Cement Details 20”Tagged ToC at 104’, then topped off ToC at surface 13-3/8"17-1/2” Hole: Pumped 780sxs of 15.8ppg lead cement followed by 473sxs of 15.8ppg tail cement. ToC assumed at surface 9-5/8" 12-1/4” hole: Pumped 1900sxs lightweight lead cement followed by 1900 sxs Class G tail cement. Inflated ECP at 1750’ MD with cement. Circ’d 930sxs to surface. ToC at ~1900’’ MD from 10/12/00 CBL. Fish 3,525-4,380 CT Fish stuck in hole (btm of fish @ 4,380)- Tbg Punch @ 4,354 / Jet Cut @ 4,348 (June 2024) Updated by: JLL 05/09/24 SCHEMATIC (As-Is) 2024-06-13 Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 PERFORATION DATA (DIL) ZONE TOP (MD) BTM (MD) TOP (TVD) BTM (TVD)AMT Condition Date A-5 3,465' 3,475' 2,941' 2,948' 10’ Open 07/29/20 A-5 3,497' 3,505' 2,965' 2,971' 8' Open 07/29/20 A-5 3,518' 3,598' 2,979' 3,036' 80’ Open 07/28/20 – 07/29/20 A-6 3,660’ 3,692’ 3,082' 3,105' 32’ 7”, 18 spf B-1 3,885’ 3,924’ 3,246' 3,274' 39’ 7” 18 spf B-3 4,020’ 4,095’ 3,345' 3,401' 75’ 7” 18 spf B-5 4,336’ 4,415’ 3,582' 3,641' 79’ 7” 18 spf Short String C-3 5,000’ 5,060’ 4,108' 4,161' 60’ Isolated (10/08/00) 8/10/96 D-7 6,060’ 6,112’ 5,084' 5,133' 52’ Isolated (10/08/00) 1987 Long String D-2 5,558’ 5,598’ 4,614' 4,651' 40’ 08/04/96 D-4 5,754’ 5,794’ 4,796' 4,833' 40’ 08/04/96 D-15_Lower 7,082' 7,090' 6,065' 6,073' 8' Isolated (10/08/00) 09/08/95 D-16 7,136’ 7,172’ 6,121' 6,156' 36’ Isolated (10/08/00) 1987 D-17 7,227’ 7,293’ 6,210' 6,274' 66’ Abandoned w/ cement retainer 1987 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,510 N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate 4,020psi Production 3,810psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng McArthur River Middle Kenai Gas Same 6,486 4,900 4,022 2,163psi 4,900 (LS) 4,980 (SS) Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 187-061 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20389-00-00 Hilcorp Alaska, LLC Trading Bay Unit M-02 Length Size Proposed Pools: !488 ~488 See schematic TVD Burst See schematic 6,330psi MD 6,450psi 3,090psi 755' 1,796' 508' 755' 1,907' 6,485'9-5/8" ~488 34x28 20" 13-3/8" 755' 10-3/4"508' 1,907' Perforation Depth MD (ft): 508' 3,465 - 4,415 7,002' 2,941 - 3,641 Other: CTCO, N2 CO 228A 5/27/2024 See schematic See schematic See schematic 7,510' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:47 am, May 14, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.05.13 06:37:06 - 08'00' Dan Marlowe (1267) 324-289 10-404 SFD 5/14/2024 Perforate MITIA to 1500 psi within 30 days after final perforation. Submit CBL to AOGCC and obtain approval before Phase II perforations. BJM 5/24/24 DSR-5/14/24 If Phase II is completed, ensure wellbore diagram in 10-404 reflects the correction made to the attached proposed diagram. *&:JLC 5/24/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.05.24 12:03:22 -08'00'05/24/24 RBDMS JSB 071024 CT Uphole Recomplete Well: Steelhead M-02 Well Name:M-02 API Number:50-733-20389-00-00 Current Status:Online Gas Producer Leg:Leg B2 (NE corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:187-061 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:2,781 psi @ 6,178’ TVD 0.45psi/ft to deepest sundry perf TVD Max. Potential Surface Pressure: 2163 psi Using 0.1 psi/ft Brief Well Summary Gas producer M-02 has good recomplete opportunities and is currently producing <150mcfd. The historic perforations below 4900’ MD were shutoff in 2000 in favor of uphole sands. The lower intervals were cutting water, and sanding issues started to become problematic at surface. The well was still producing >4000mcfd at 600psi from the lower sands at the time of shut off. This project aims to re-access the deep production, and also infill perf some deeper opportunity sands. If unsuccessful in establishing production from the deep sands, all existing perfs will be isolated, and the well recompleted to shallower sands (still within the Middle Kenai Gas Pool). These sands above the current highest packer will require an IA cement job for recompletion. The goals of this project are to re-access the lower perfs, and perf/test additional deeper sands. If unsuccessful, an uphole recomplete above the existing top packer is the next step. Top of the Middle Kenai Gas Pool in M-02 is approximately 1,496' MD, per M. Petrowsky email dated 5/14/2024. SFD CT Uphole Recomplete Well: Steelhead M-02 Pertinent wellbore information: - TRSSSV: Baker TE-5 installed in 2009. Currently operational - Live GLV’s currently installed - Max Inclination: 44 degree sail angle from 1900 – 4500’ MD. - Pertinent events o 1987: D&C as a dual string producer from D-16 (long string) and D-6 (short string) o 1996: Annulus cement inside 9-5/8” Cement placed from 4740 – 5884’ MD by pumping down the short string LS still had communication with D-16 LS string punched at 6004’ to allow D-6 production up the LS D and C sand perfs added through the cement o 2000: RWO recomplete Well was still making 4.0MM+ at 600psi FTP But base water rate of ~5bwpd increased to 15-20 bwpd, and solids production started All existing perfs were abandoned, and the well recompleted uphole in the A and B sands via gravelpacks LS was isolated with a bridge plug and 20’ cement at 4900’ Below this plug should still communicate to all perfs except the C-4 LS tag right before RWO found fill at 7204’ MD (below all perfs) o 10/12/08: HAL WS permanent packer set inside 5-1/2” at 3528’ MD (2.813” X nipple in tail pipe). 20’ assembly o 9/23/09: Swapped existing 5-1/2” tubing for 3-1/2” tubing due to TRSSSV issues (well had been operating with a K-valve for a while at this point) o 11/30/15: SL found a tight spot at 3528' MD, but made it to 4366' MD with a 1.75" bailer Pressures: x Phase 1: Re-access existing lower perfs o 11/23/96: Short string PBU with downhole pressure gauge shows reservoir P = 989psi (C-4 only) o 9/1/99: Long string SITP built up to 780psi. Chevron converted to depth and reported Long string Reservoir P = 850psi This pressure includes all open sands below 4900’ MD (excluding C-4) o Honoring 13.7ppg LOT from 13-3/8” casing shoe, the max pressure that the shallowest open sand (A-5 at 2941’ TVD)could tolerate = 2095psi o Given this, reopening existing perfs below 4900’ MD does not pose a fracture risk to existing shallow perfs x Phase 1: add new deeper perfs o Frac pressure at shallowest open perf = 2095psi per above at 2941’ TVD o Deepest planned perfs at 5100’ TVD. o Worst case normally pressured = 5100ft * 0.45psi/ft = 2295psi o Gas gradient of 0.1psi/ft up to shallowest perfs = 2079psi (under frac gradient) x Phase II: Shallow recomplete o All lower perfs will be isolated before any shallow intervals opened o AOGCC can confirm this at CBL review step All lower perfs will be isolated before any shallow intervals opened reopening existing perfs below 4900’ MD does not pose a fracture risk to existing shallow perfs All existing perfs were abandoned, and the well recompleted uphole in the A and B sands via gravelpacks CT Uphole Recomplete Well: Steelhead M-02 Phase I: Re-access deep perfs and test additional Sands Coiled Tubing Plug Mill Out Procedure 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. MU Millout BHA a. Working fluid will be water (8.33ppg or greater) b. Take returns to surface up the CT x tubing annulus c. If necessary, add foam and nitrogen to carry solids to surface d. Taking returns to formation is also permissable e. Can use GL to assist with hole cleaning 4. RIH and cleanout / mill to plug in Historic 3-1/2” long string at 4880’ MD 5. Mill through 20’ cement and 3-1/2” Fasdrill plug set at 4900’ MD 6. Continue cleanout / mill to 9-5/8” cement retainer at 7198’ MD 7. Once hole is clean, lift well to production with nitrogen 8. POOH and RD CT 9. Flow test well E-Line Perf / Test 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. RIH and perf / reperf Middle Kenai Gas Pool sands from ±3,465’ – ±6077’ MD (±2,941’ - ±5,100) 4. Stand back EL and flow test 5. RDMO EL CONTINGENCY: (if any zone makes unwanted solids or water) 1. RU Gas Lift or nitrogen to tubing and PT nitrogen lines to 2500psi 2. Pressure up on tubing and displace water back into formation 3. MIRU E-line and pressure control equipment 4. PT lubricator to 250psi low / 2500psi high 5. Set 3-1/2” CIBP or patch per OE 6. RDMO Nitrogen and EL ±3,465’ – ±6077’ MD (±2,941’ - ±5,100) CT Uphole Recomplete Well: Steelhead M-02 Phase II: Recomplete above packer SL Prep for IA cement 1. MIRU SL and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. Pull GLV from STA #2 at 3403’ MD (leave pocket open) 4. Pull live GLV from STA #1 at 1654’ MD and replace with Dummy GLV 5. RIH and set 3-1/2” TTP at 3487’ MD 6. Perform CMIT-TxIA to 1500psi (charted) to confirm TTP and 9-5/8” casing integrity CT Cement IA Procedure 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. Fluid pack Tubing + IA with water (WBV = 252bbls) 4.RIH with 3-1/2” cement retainer and set at ±3,375’ MD 5. Establish circulation down CT taking returns up IA 6. RU cementers and PT to 2500psi 6. Pump IA cement job down CT a. Target ToC in IA at 1,850’ MD b. Aiming for ToC above 13-3/8” surface casing shoe c. But below GLM at 1654’ MD. d. Required volume ~86bbls 7. Obtain CBL (may be executed on EL. TBD) Submit CBL to AOOGCC 8. WoC 9. MIT-IA to 1500psi (charted) 10. RIH and blow well dry with nitrogen a. Reverse circulate water out of wellbore (no perforations, passing MIT’s) b. Tubing volume to recover = 29 bbls 11. RDMO CT CT Uphole Recomplete Well: Steelhead M-02 E-Line Perf Procedure 1. Review CBL results with AOGCC before perforations are shot 2. MIRU E-line and pressure control equipment 3. PT lubricator to 250psi low / 1500psi high 4. RIH and perforate Middle Kenai Gas Pool sands from ±2,200’ – ±3,375’ MD (±2,016’ – ±2,876’ TVD) 5. RDMO EL CONTINGENCY: (if any zone makes unwanted solids or water) 1. RU Gas Lift or nitrogen to tubing and PT nitrogen lines to 2500psi 2. Pressure up on tubing and displace water back into formation 3. MIRU E-line and pressure control equipment 4. PT lubricator to 250psi low / 2500psi high 5. Set 3-1/2” CIBP or patch per OE 6. RDMO Nitrogen and EL If the well is successfully returned to fulltime production,perform a final MIT-IA to 1500psi (charted) within 30 days. Perform MIT-IA after all perforating is complete. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic (Phase I) 3. Proposed Wellbore Schematic (Phase II) 4. CT BOP Drawing 5. Nitrogen procedure perforate Middle Kenai Gas Pool sands from ±2,200’ – ±3,375’ MD (±2,016’ – ±2,876’ TVD) Updated by: JLL 05/09/24 SCHEMATIC Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) 34"x28" Conductor - Driven ~26.5" Surface ~488' 20” 91# Structural Surface 755’ 13-3/8” 61 K-55 BTC 12.515” Surface 1907’ 10 3/4” 55.5 N-80 BTC 9.760” Surface 508’ 9-5/8” 43.5 N-80 BTC 8.755” 508 5668’ 9 5/8” 47 N-80 BTC 8.681” 5668’ 7510’ Tubing 3-1/2” 9.2 L-80 Hydril 563 2.992 Surface 3,508’ 5-1/2” 15.5 J-55 Csg Butt 4.96 3,511’ 3,538’ 3-1/2" (SS) 9.2 L-80 2.992 4,550' 5,979' 3-1/2" (LS) 9.3 N-80 Hydril 2.992 4,516' 7,034' JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 1 470' 470' 2.813 5.37 Baker TE-5 SCSSV, Tubing Ret. W/ Profile 2 1,654' 1,523’ 2.867 5.313 GLM 1 3,403’ 2,898’ 2.867 5.313 GLM 2 3 3,461’ 2,940' 4.750 8.36 S-3 BOT 5" Packer TC II box x pin 4 3,487' 2,958' 2.813 X nipple profile 5 3,508' 2,973' 5.664 8.220 7" csg BTC Overshot 6 3,528' 2,988'2.813 5-1/2" Perma Packer w/ X-Nipple (10/12/08) 7 3,538’ 2,995' 4.000 7.000 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) A-6 Gravel Pack 8 3,543’ GR 2,998' 2.813 5.37 Packer, SC-1R, Inclusive Gravel Pack Assembly 3,643’ GR 3,070' 2.867 5.313 Screen, 5-1/2” with 20/40 gravel pack sand down to 3,707’ 3,710’ GR 3,118' 2.867 5.313 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-2 and B-3 Gravel Pack 9 3,704’ GR 3,114' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 3,881’ GR 3,243' 4.892 5.970 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,103’ 4,105’ GR 3,408' 4.000 5.600 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-5 Gravel Pack 10 4,106’ GR 3,409' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 4,309’ GR 3,561' 4.892 5.500 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,420’ 4,422’ GR 3,646' 4.000 7.000 Snap Latch, Seal Assy. W/ 80-40 Seal Ext (4.000” I.D.) 11 4,424’ GR 3,648' 6.000 8.210 Sump Packer, FB-1 12 4,465’ GR 3,679' 2.813 4.500 Nipple, ‘X’ 2.813” I.D. 13 4,509’ GR 3,712' 3.500 8.380 Overshot, 5-3/4” w/ Over Size Guide Lower Existing Completion I (LS) 4,900’ 4,022’ Bridge Plug w/20’ cement (10/08/00) II 5,954’ 4,983' Packer, Dual, Baker A-5 III 5,999’ 5,026' 2.813 Nipple, “X” IV 6,060’ 5,084' Carbide Blast Joints V 6,957’ 5,947' Snap Latch, S-22 VI 6,958’ 5,948' Packer, 9-5/8” x 3-1/2”, Baker, “SC-1” (6’ Seal Bore ext) VII 6,969’ 5,958' Crossover, 6-5/8” x 3-1/2” VIII 7,003’ 5,991' 2.813 Nipple, “X” IX 7,034’ 6,022' Wireline Entry Guide A (SS) 4,980' 4,088' EZ Drill Plug w/ 20' cement (10/08/00) B 5,954’ 4,983' Packer, Dual, Baker A-5 C 5,970’ 4,998' Nipple, “XN” D 5,979’ 5,007' Wireline Entry Guide E 7,198' Cement Retainer PBTD = 4,900’ TD = 7,510’ MAX HOLE ANGLE = 44q RKB to TBG Head = 68.5’ Tree connection: 4-1/16” 5,000# B C D-16 D-7 D D-17 III 1 2 7 8 9 C-3 D-2 D-4 V II VI VII IX 10 11 12 13 IV A-6 B-1 B-3 B-5 4 5 6 3 13-3/8” at 1,907 I A-5 A -5 A -5 ECP @ 1750 MD Tbg Punch 7/25/96 A E VIII TOC 4,740' CBL 10/07/00 D-15 Low XN X X X X Cement Details 20”Tagged ToC at 104’, then topped off ToC at surface 13-3/8"17-1/2” Hole: Pumped 780sxs of 15.8ppg lead cement followed by 473sxs of 15.8ppg tail cement. ToC assumed at surface 9-5/8" 12-1/4” hole: Pumped 1900sxs lightweight lead cement followed by 1900 sxs Class G tail cement. Inflated ECP at 1750’ MD with cement. Circ’d 930sxs to surface. ToC at ~1900’’ MD from 10/12/00 CBL. Updated by: JLL 05/09/24 SCHEMATIC Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 PERFORATION DATA (DIL) ZONE TOP (MD) BTM (MD)TOP (TVD)BTM (TVD)AMT Condition Date A-5 3,465' 3,475' 2,941' 2,948' 10’ Open 07/29/20 A-5 3,497' 3,505' 2,965' 2,971' 8' Open 07/29/20 A-5 3,518' 3,598' 2,979' 3,036' 80’ Open 07/28/20 – 07/29/20 A-6 3,660’ 3,692’ 3,082' 3,105' 32’ 7”, 18 spf B-1 3,885’ 3,924’ 3,246' 3,274' 39’ 7” 18 spf B-3 4,020’ 4,095’ 3,345' 3,401' 75’ 7” 18 spf B-5 4,336’ 4,415’ 3,582' 3,641' 79’ 7” 18 spf Short String C-3 5,000’ 5,060’ 4,108' 4,161' 60’ Isolated (10/08/00) 8/10/96 D-7 6,060’ 6,112’ 5,084' 5,133' 52’ Isolated (10/08/00) 1987 Long String D-2 5,558’ 5,598’ 4,614' 4,651' 40’ Isolated (10/08/00) 08/04/96 D-4 5,754’ 5,794’ 4,796' 4,833' 40’ Isolated (10/08/00) 08/04/96 D-15_Lower 7,082' 7,090' 6,065' 6,073' 8' Isolated (10/08/00) 09/08/95 D-16 7,136’ 7,172’ 6,121' 6,156' 36’ Isolated (10/08/00) 1987 D-17 7,227’ 7,293’ 6,210' 6,274' 66’ Abandoned w/ cement retainer 1987 Updated by: JLL 05/09/24 PROPOSED PHASE I Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) 34"x28" Conductor - Driven ~26.5" Surface ~488' 20” 91# Structural Surface 755’ 13-3/8” 61 K-55 BTC 12.515” Surface 1907’ 10 3/4” 55.5 N-80 BTC 9.760” Surface 508’ 9-5/8” 43.5 N-80 BTC 8.755” 508 5668’ 9 5/8” 47 N-80 BTC 8.681” 5668’ 7510’ Tubing 3-1/2” 9.2 L-80 Hydril 563 2.992 Surface 3,508’ 5-1/2” 15.5 J-55 Csg Butt 4.96 3,511’ 3,538’ 3-1/2" (SS) 9.2 L-80 2.992 4,550' 5,979' 3-1/2" (LS) 9.3 N-80 Hydril 2.992 4,516' 7,034' JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 1 470' 470' 2.813 5.37 Baker TE-5 SCSSV, Tubing Ret. W/ Profile 2 1,654' 1,523’ 2.867 5.313 GLM 1 3,403’ 2,898’ 2.867 5.313 GLM 2 3 3,461’ 2,940' 4.750 8.36 S-3 BOT 5" Packer TC II box x pin 4 3,487' 2,958' 2.813 X nipple profile 5 3,508' 2,973' 5.664 8.220 7" csg BTC Overshot 6 3,528' 2,988'2.813 5-1/2" Perma Packer w/ X-Nipple (10/12/08) 7 3,538’ 2,995' 4.000 7.000 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) A-6 Gravel Pack 8 3,543’ GR 2,998' 2.813 5.37 Packer, SC-1R, Inclusive Gravel Pack Assembly 3,643’ GR 3,070' 2.867 5.313 Screen, 5-1/2” with 20/40 gravel pack sand down to 3,707’ 3,710’ GR 3,118' 2.867 5.313 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-2 and B-3 Gravel Pack 9 3,704’ GR 3,114' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 3,881’ GR 3,243' 4.892 5.970 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,103’ 4,105’ GR 3,408' 4.000 5.600 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-5 Gravel Pack 10 4,106’ GR 3,409' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 4,309’ GR 3,561' 4.892 5.500 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,420’ 4,422’ GR 3,646' 4.000 7.000 Snap Latch, Seal Assy. W/ 80-40 Seal Ext (4.000” I.D.) 11 4,424’ GR 3,648' 6.000 8.210 Sump Packer, FB-1 12 4,465’ GR 3,679' 2.813 4.500 Nipple, ‘X’ 2.813” I.D. 13 4,509’ GR 3,712' 3.500 8.380 Overshot, 5-3/4” w/ Over Size Guide Lower Existing Completion I 5,954’ 4,983' Packer, Dual, Baker A-5 II 5,999’ 5,026' 2.813 Nipple, “X” III 6,060’ 5,084' Carbide Blast Joints IV 6,957’ 5,947' Snap Latch, S-22 V 6,958’ 5,948' Packer, 9-5/8” x 3-1/2”, Baker, “SC-1” (6’ Seal Bore ext) VI 6,969’ 5,958' Crossover, 6-5/8” x 3-1/2” VII 7,003’ 5,991' 2.813 Nipple, “X” VIII 7,034’ 6,022' Wireline Entry Guide A (SS) 4,980' 4,088' EZ Drill Plug w/ 20' cement (10/08/00) B 5,954’ 4,983' Packer, Dual, Baker A-5 C 5,970’ 4,998' Nipple, “XN” D 5,979’ 5,007' Wireline Entry Guide E 7,198' Cement Retainer PBTD = 4,900’ TD = 7,510’ MAX HOLE ANGLE = 44q RKB to TBG Head = 68.5’ Tree connection: 4-1/16” 5,000# B C D-16 D-7 D D-17 II 1 2 7 8 9 C-3 D-2 D-4 IV I V VI VIII 10 11 12 13 III A-6 B-1 B-3 B-5 4 5 6 3 13-3/8” at 1,907 A-5 A -5 A -5 ECP @ 1750 MD A E VII TOC 4,740' CBL 10/07/00 D-1 Low Tbg Punch 7/25/96 XN X X X X Cement Details 20”Tagged ToC at 104’, then topped off ToC at surface 13-3/8"17-1/2” Hole: Pumped 780sxs of 15.8ppg lead cement followed by 473sxs of 15.8ppg tail cement. ToC assumed at surface 9-5/8" 12-1/4” hole: Pumped 1900sxs lightweight lead cement followed by 1900 sxs Class G tail cement. Inflated ECP at 1750’ MD with cement. Circ’d 930sxs to surface. ToC at ~1900’’ MD from 10/12/00 CBL. Updated by: JLL 05/09/24 PROPOSED PHASE 1 Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 PERFORATION DATA (DIL) ZONE TOP (MD) BTM (MD) TOP (TVD) BTM (TVD)AMT Condition Date Middle Kenai Gas ±3,465' ±6,077' ±2,941' ±5,100' Perf/Reperforate A-5 3,465' 3,475' 2,941' 2,948' 10’ Open 07/29/20 A-5 3,497' 3,505' 2,965' 2,971' 8' Open 07/29/20 A-5 3,518' 3,598' 2,979' 3,036' 80’ Open 07/28/20 – 07/29/20 A-6 3,660’ 3,692’ 3,082' 3,105' 32’ 7”, 18 spf B-1 3,885’ 3,924’ 3,246' 3,274' 39’ 7” 18 spf B-3 4,020’ 4,095’ 3,345' 3,401' 75’ 7” 18 spf B-5 4,336’ 4,415’ 3,582' 3,641' 79’ 7” 18 spf Short String C-3 5,000’ 5,060’ 4,108' 4,161' 60’ Isolated (10/08/00) 8/10/96 D-7 6,060’ 6,112’ 5,084' 5,133' 52’ Isolated (10/08/00) 1987 Long String D-2 5,558’ 5,598’ 4,614' 4,651' 40’ 08/04/96 D-4 5,754’ 5,794’ 4,796' 4,833' 40’ 08/04/96 D-15_Lower 7,082' 7,090' 6,065' 6,073' 8' Isolated (10/08/00) 09/08/95 D-16 7,136’ 7,172’ 6,121' 6,156' 36’ Isolated (10/08/00) 1987 D-17 7,227’ 7,293’ 6,210' 6,274' 66’ Abandoned w/ cement retainer 1987 Updated by: JLL 05/09/24 PROPOSED PHASE II Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) 34"x28" Conductor - Driven ~26.5" Surface ~488' 20” 91# Structural Surface 755’ 13-3/8” 61 K-55 BTC 12.515” Surface 1907’ 10 3/4” 55.5 N-80 BTC 9.760” Surface 508’ 9-5/8” 43.5 N-80 BTC 8.755” 508 5668’ 9 5/8” 47 N-80 BTC 8.681” 5668’ 7510’ Tubing 3-1/2” 9.2 L-80 Hydril 563 2.992 Surface 3,508’ 5-1/2” 15.5 J-55 Csg Butt 4.96 3,511’ 3,538’ 3-1/2" (SS) 9.2 L-80 2.992 4,550' 5,979' 3-1/2" (LS) 9.3 N-80 Hydril 2.992 4,516' 7,034' JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 1 470' 470' 2.813 5.37 Baker TE-5 SCSSV, Tubing Ret. W/ Profile 2 1,654' 1,523’ 2.867 5.313 GLM 1 (Dummy) 3 ±3,375' ±2,876' - - Cement Retainer 4 3,403’ 2,898’ 2.867 5.313 GLM 2 (Open Pocket) 5 3,461’ 2,940' 4.750 8.36 S-3 BOT 5" Packer TC II box x pin 6 3,487' 2,958' 2.813 X nipple profile (Set Plug) 7 3,508' 2,973' 5.664 8.220 7" csg BTC Overshot 8 3,528' 2,988'2.813 5-1/2" Perma Packer w/ X-Nipple (10/12/08) 9 3,538’ 2,995' 4.000 7.000 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) A-6 Gravel Pack 10 3,543’ GR 2,998' 2.813 5.37 Packer, SC-1R, Inclusive Gravel Pack Assembly 3,643’ GR 3,070' 2.867 5.313 Screen, 5-1/2” with 20/40 gravel pack sand down to 3,707’ 3,710’ GR 3,118' 2.867 5.313 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-2 and B-3 Gravel Pack 11 3,704’ GR 3,114' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 3,881’ GR 3,243' 4.892 5.970 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,103’ 4,105’ GR 3,408' 4.000 5.600 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-5 Gravel Pack 12 4,106’ GR 3,409' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 4,309’ GR 3,561' 4.892 5.500 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,420’ 4,422’ GR 3,646' 4.000 7.000 Snap Latch, Seal Assy. W/ 80-40 Seal Ext (4.000” I.D.) 13 4,424’ GR 3,648' 6.000 8.210 Sump Packer, FB-1 14 4,465’ GR 3,679' 2.813 4.500 Nipple, ‘X’ 2.813” I.D. 15 4,509’ GR 3,712' 3.500 8.380 Overshot, 5-3/4” w/ Over Size Guide Lower Existing Completion I (LS) 4,900’ 4,022’ Bridge Plug w/20’ cement (10/08/00) II 5,954’ 4,983' Packer, Dual, Baker A-5 III 5,999’ 5,026' 2.813 Nipple, “X” IV 6,060’ 5,084' Carbide Blast Joints V 6,957’ 5,947' Snap Latch, S-22 VI 6,958’ 5,948' Packer, 9-5/8” x 3-1/2”, Baker, “SC-1” (6’ Seal Bore ext) VII 6,969’ 5,958' Crossover, 6-5/8” x 3-1/2” VIII 7,003’ 5,991' 2.813 Nipple, “X” IX 7,034’ 6,022' Wireline Entry Guide A (SS) 4,980' 4,088' EZ Drill Plug w/ 20' cement (10/08/00) B 5,954’ 4,983' Packer, Dual, Baker A-5 C 5,970’ 4,998' Nipple, “XN” D 5,979’ 5,007' Wireline Entry Guide E 7,198' Cement Retainer PBTD = 4,900’ TD = 7,510’ MAX HOLE ANGLE = 44q RKB to TBG Head = 68.5’ Tree connection: 4-1/16” 5,000# B C D-16 D-7 D D-17 III 1 2 9 10 11 C-3 D-2 D-4 V II VI VII IX 12 13 14 15 3 4 IV A-6 B-1 B-3 B-5 6 7 8 5 13-3 at 1,9 I A-5 A-5 A-5 ECP @ 1750 MD Tbg Punch 7/25/96 A E VIII TOC 4,740' CBL 10/07/00 D-15 Lowe XNX X X X Cement Details 20”Tagged ToC at 104’, then topped off ToC at surface 13-3/8"17-1/2” Hole: Pumped 780sxs of 15.8ppg lead cement followed by 473sxs of 15.8ppg tail cement. ToC assumed at surface 9-5/8" 12-1/4” hole: Pumped 1900sxs lightweight lead cement followed by 1900 sxs Class G tail cement. Inflated ECP at 1750’ MD with cement. Circ’d 930sxs to surface. ToC at ~1900’’ MD from 10/12/00 CBL. ***The plug with cement cap shown in the long string above D-2 perfs will not be installed. -bjm Updated by: JLL 05/09/24 PROPOSED PHASE II Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 PERFORATION DATA (DIL) ZONE TOP (MD) BTM (MD) TOP (TVD) BTM (TVD)AMT Condition Date Middle Kenai Gas ±2,200 ±3,375' ±2,016' ±2,876' ±1,175' Proposed Future A-5 3,465' 3,475' 2,941' 2,948' 10’Isolated Future A-5 3,497' 3,505' 2,965' 2,971' 8'Isolated Future A-5 3,518' 3,598' 2,979' 3,036' 80’Isolated Future A-6 3,660’ 3,692’ 3,082' 3,105' 32’Isolated Future B-1 3,885’ 3,924’ 3,246' 3,274' 39’Isolated Future B-3 4,020’ 4,095’ 3,345' 3,401' 75’Isolated Future B-5 4,336’ 4,415’ 3,582' 3,641' 79’Isolated Future Short String C-3 5,000’ 5,060’ 4,108' 4,161' 60’ Isolated (10/08/00) 8/10/96 D-7 6,060’ 6,112’ 5,084' 5,133' 52’ Isolated (10/08/00) 1987 Long String D-2 5,558’ 5,598’ 4,614' 4,651' 40’ Isolated (10/08/00) 08/04/96 D-4 5,754’ 5,794’ 4,796' 4,833' 40’ Isolated (10/08/00) 08/04/96 D-15_Lower 7,082' 7,090' 6,065' 6,073' 8' Isolated (10/08/00) 09/08/95 D-16 7,136’ 7,172’ 6,121' 6,156' 36’ Isolated (10/08/00) 1987 D-17 7,227’ 7,293’ 6,210' 6,274' 66’ Abandoned w/ cement retainer 1987 KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. 1 McLellan, Bryan J (OGC) From:Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent:Thursday, May 23, 2024 9:34 AM To:McLellan, Bryan J (OGC) Cc:Davies, Stephen F (OGC); Roby, David S (OGC) Subject:RE: [EXTERNAL] TBU M-02 (Permit 187-061, Sundry 324-289) - Question No plug planned down low, you are correct. Yes, ok to leave all in communication. Ryan Rupert 907-301-1736 -------- Original message -------- From: "McLellan, Bryan J (OGC)" <bryan.mclellan@alaska.gov> Date: 5/23/24 9:32 AM (GMT-09:00) To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: "Davies, Stephen F (OGC)" <steve.davies@alaska.gov>, "Roby, David S (OGC)" <dave.roby@alaska.gov> Subject: RE: [EXTERNAL] TBU M-02 (Permit 187-061, Sundry 324-289) - Question Thanks, Your Phase II proposed diagram shows a plug and cement cap in the long string above the D2 perfs. There’s no mention of that in the program so I assume that won’t be there. Is it OK to leave all the perfs from A-5 through D-16 in open communication and crossflowing until these sands have reached pressure equilibrium? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Thursday, May 23, 2024 9:24 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: FW: [EXTERNAL] TBU M-02 (Permit 187-061, Sundry 324-289) - Question Only pool in m-02 is the middle Kenai Gas pool. Ryan Rupert 907-301-1736 -------- Original message -------- From: Matthew Petrowsky <mpetrowsky@hilcorp.com> Date: 5/14/24 3:59 PM (GMT-09:00) To: "Davies, Stephen F (OGC)" <steve.davies@alaska.gov> Cc: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: RE: [EXTERNAL] TBU M-02 (Permit 187-061, Sundry 324-289) - Question Hey Steve, No problem, the top of the Middle Kenai Gas Pool is in M-02 is approximately 1,496’ MD. Best Regards, Matthew J. Petrowsky |Geologist, Cook Inlet Offshore|Hilcorp Alaska, LLC|(w) 907.777.8404|(c) 814.421.6753|Office: 13090| |3800 Centerpoint Dr. Suite 1400|Anchorage|Alaska|99503| From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Tuesday, May 14, 2024 2:45 PM To: Matthew Petrowsky <mpetrowsky@hilcorp.com> Cc: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: [EXTERNAL] TBU M-02 (Permit 187-061, Sundry 324-289) - Question Matt, Could Hilcorp please provide a measured depth for the top of the Middle Kenai Gas Pool in TBU M-02? Cheers and Be Well, Steve Davies AOGCC CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 4,980 (LS) Total Depth measured 7,510 feet 4,980 (SS)feet true vertical 6,485 feet N/A feet Effective Depth measured 4,900 feet See schematic feet true vertical 4,022 feet See schematic feet Perforation depth Measured depth 3,465 - 4,415 feet True Vertical depth 2,941 - 3,641 feet 3-1/2" 9.2 / L-80 3,508 MD 2,972 TVD Tubing (size, grade, measured and true vertical depth)5-1/2" 15.5 / J-55 3,538 MD 2,993 TVD Packers and SSSV (type, measured and true vertical depth)See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD 755 measured true vertical Packer 9-5/8" 20" 7,510 MD 755 1,907 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 70 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 187-061 50-733-20389-00-00 Plugs ADL0018730 Trading Bay Unit M-02 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-310 10 Authorized Signature with date: Authorized Name: 0 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 261 N/A Oil-Bbl 175 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 1,018 McArthur River Field / Middle Kenai Gas PoolN/A measured 508 7,002 Size 36 Production Casing Structural Liner Length 755 1,907 Conductor Surface 3,810psi 13-3/8" 10-3/4" 508 6,450psi 907 777-8376 6,330psi 1,796 507 6,485 Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,540psi 4,020psi 3,090psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:36 pm, Aug 24, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.24 08:41:53 -08'00' Dan Marlowe (1267) RBDMS HEW 8/27/2020 DSR-8/24/2020 Perforate SFD 8/28/2020gls 9 28/20 Updated by: JLL 08/21/20 SCHEMATIC Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) 20” 91# Structural Surface 755’ 13-3/8” 61 K-55 BTC 12.515” Surface 1907’ 10 3/4” 55.5 N-80 BTC 9.760” Surface 508’ 9-5/8” 43.5 N-80 BTC 8.755” 508 5668’ 9 5/8” 47 N-80 BTC 8.681” 5668’ 7510’ Tubing 3-1/2” 9.2 L-80 Hydril 563 2.992 Surface 3,508’ 5-1/2” 15.5 J-55 Csg Butt 4.96 3,511’ 3,538’ JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 1 470' 470' 2.813 5.37 Baker TE-5 SCSSV, Tubing Ret. W/ Profile 2 1,654' 1,523’ 2.867 5.313 GLM 1 3,403’ 2,898’ 2.867 5.313 GLM 2 3 3,461’ 2,940' 4.750 8.36 S-3 BOT 5" Packer TC II box x pin 4 3,487' 2,958' 2.813 X nipple profile 5 3,508' 2,973' 5.664 8.220 7" csg BTC Overshot 6 3,528' 2,988' 2.813 5-1/2" Perma Packer w/ X-Nipple 7 3,538’ 2,995' 4.000 7.000 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) A-6 Gravel Pack 8 3,543’ GR 2,998' 2.813 5.37 Packer, SC-1R, Inclusive Gravel Pack Assembly 9 3,643’ GR 3,070' 2.867 5.313 Screen, 5-1/2” with 20/40 gravel pack sand down to 3,707’ 10 3,710’ GR 3,118' 2.867 5.313 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-2 and B-3 Gravel Pack 11 3,704’ GR 3,114' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 12 3,881’ GR 3,243' 4.892 5.970 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,103’ 13 4,105’ GR 3,408' 4.000 5.600 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-5 Gravel Pack 14 4,106’ GR 3,409' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 15 4,309’ GR 3,561' 4.892 5.500 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,420’ 16 4,422’ GR 3,646' 4.000 7.000 Snap Latch, Seal Assy. W/ 80-40 Seal Ext (4.000” I.D.) 17 4,424’ GR 3,648' 6.000 8.210 Sump Packer, FB-1 18 4,465’ GR 3,679' 2.813 4.500 Nipple, ‘X’ 2.813” I.D. 19 4,509’ GR 3,712' 3.500 8.380 Overshot, 5-3/4” w/ Over Size Guide Lower Existing Completion I 4,900’ 4,022’ Bridge Plug w/20’ cement II 5,954’ 4,983' Packer, Dual, Baker A-5 III 5,999’ 5,026' 2.813 Nipple, “X” IV 6,060’ 5,084' Carbide Blast Joints V 6,957’ 5,947' Snap Latch, S-22 VI 6,958’ 5,948' Packer, 9-5/8” x 3-1/2”, Baker, “SC-1” (6’ Seal Bore ext) VII 6,969’ 5,958' Crossover, 6-5/8” x 3-1/2” VIII 7,003’ 5,991' 2.813 Nipple, “X” IX 7,034’ 6,022' Wireline Entry Guide A 5,954’ 4,983' Packer, Dual, Baker A-5 B 5,970’ 4,998' Nipple, “XN” C 5,979’ 5,007' Wireline Entry Guide PBTD = 4,900’ TD = 7,510’ MAX HOLE ANGLE = 44q RKB to TBG Head = 68.5’ Tree connection: 4-1/16” 5,000# A B D-16 D-6 C D-17 VII III 1 2 7 8 9 C-4 D-2 D-3B V II VI VII IX 10 11 12 13 14 15 16 17 18 19 IV A-6 B-2 B-3 B-5 4 5 6 3 13-3/8” at 1,907’ SS - BP @ 4,980’ I A-5 A-5 A-5 XNX X X A-5 A-5 A-5 Updated by: JLL 08/21/20 SCHEMATIC Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 PERFORATION DATA (DIL) ZONE TOP (MD) BTM (MD) TOP (TVD) BTM (TVD)AMT Condition Date A-5 3,465' 3,475' 2,941' 2,948' 10’ Open 07/29/20 A-5 3,497' 3,505' 2,965' 2,971' 8' Open 07/29/20 A-5 3,518' 3,598' 2,979' 3,036' 80’ Open 07/28/20 – 07/29/20 A-6 3,660’ 3,692’ 3,082' 3,105' 32’ 7”, 18 spf B-2 3,885’ 3,924’ 3,246' 3,274' 39’ 7” 18 spf B-3 4,020’ 4,095’ 3,345' 3,401' 75’ 7” 18 spf B-5 4,336’ 4,415’ 3,582' 3,641' 79’ 7” 18 spf Short String C-4 5,000’ 5,060’ 4,108' 4,161' 60’ Isolated D-6 6,060’ 6,112’ 5,084' 5,133' 52’ Isolated Long String D-2 5,558’ 5,598’ 4,614' 4,651' 40’ Isolated D-3B 5,754’ 5,794’ 4,796' 4,833' 40’ Isolated D-16 7,136’ 7,172’ 6,121' 6,156' 36’ Isolated D-17 7,227’ 7,293’ 6,210' 6,274' 66’ Abandoned w/ cement retainer A-5 3,465' 3,475' 2,941' 2,948' 10’ Open 07/29/20 A-5 3,497' 3,505' 2,965' 2,971' 8' Open 07/29/20 A-5 3,518' 3,598' 2,979' 3,036' 80’ Open 07/28/20 – 07/29/20 Rig Start Date End Date Eline 7/28/20 7/29/20 07/29/20 - Wednesday PJSM, M/U GR, CCL, Gun #2 - 20' 2 3/8" carrier w/Razor low swell 11gr. charges, 60 deg phasing, 6 SPF. RIH pull correlation log & verify good, pull into position CCL @ 3550.2', CCl t/top shot 7.8' CCL to Bottom Shot 20.8', placing shots @3558-3578', fire shots good indication on surface guns fired, ICP 7 psi flowing @ .8 FCP 7.7 flowing @ .93 Log up 200', POOH all shots fired. M/U Gun #3 - 20' 2 3/8" carrier w/Razor low swell 11gr. charges, 60 deg phasing, 6 SPF, RIH pull correlation log & verify good, pull into position CCL @ 3530.2', CCl t/top shot 7.8' CCL to Bottom Shot 20.8', placing shots @3538-3558', fire shots good indication on surface guns fired, ICP 7.7 psi flowing @ .93 FCP 7.7 flowing @ .93 Log up 200', POOH all shots fired. M/U Gun #4 - 20' 2 3/8" carrier w/Razor low swell 11 gr. charges, 60 deg phasing, 6 SPF, RIH pull correlation log & verify good, pull into position CCL @ 3510.2', CCl t/top shot 7.8' CCL to Bottom Shot 20.8', placing shots @3518-3538', fire shots good indication on surface guns fired, ICP 7.7 psi flowing @ .93 FCP 7.7 flowing @ .93 Log up 200', POOH all shots fired. M/U Gun #4 - 15 &7' tandem 2 3/8" carrier w/Razor low swell 11gr. charges, 60 deg phasing, 6 SPF. RIH to pull correla tion log, unable to pass 3415' attempt to wk through, unable to get good correlation, decision was made to drop 7' gun (6' loaded) POOH l/D 7' section. RIH w/Gun #4 - 15' 2 3/8" carrier loaded 8' w/Razor low swell 11gr. charges, 60 deg phasing, 6 SPF. Pull correlation log & verify good, pull into position CCL @ 3489.2', CCl t/top shot 7.8' CCL to Bottom Shot 15.8', placing shots @3497-3505', fire shots good indication on surface guns fired, ICP 7.7 psi flowing @ .93 FCP 7.7 flowing @ .93 Log up 200', POOH all shots fired. Build 10' 2 3/8" carrier loaded w/Razor low swell 11gr. charges, 60 deg phasing, 6 SPF. M/U & RIH pull correlation log & verify good, pull into position CCL @ 3452.3', CCl t/top shot 12.7'' CCL to Bottom Shot 22.7', placing shots @3465-3475', fire shots good indication on surface guns fired, ICP 7.7 psi flowing @ .93 FCP 10.2 flowing @1.3 Log up 200', POOH all shots fired. RDMO, pack up unit & de-mobe crew. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-02 50-733-20389-00-00 187-061 R/U Lubricator. M/U GR, CCL, Gun #1 - 20' 2 3/8" carrier w/Raz or low swell charges, 60 deg phasing, 6 SPF. Stab lubricator P/T 250/1500 good. Had issues RIH, troubleshoot & clean line good. RIH t/3710' log up t/3390, send in for correlation. Decision made to Log longer interval & make adjust ments to CCL. RIH t/3890', log up t/3090', send in logs for correlation adjustment, made 4' adjustment & resent log for verification by Geo, good, pull into position CCL @ 3570.2', CCL t/top shot 7.8', CCL t/ BTM shot 27.8', placing shots @ 3578-3598', fire guns, good indication guns fired, ITP 7PSI flowing @ .68, FTP 7.7psi flowing @ .95, POOH all guns fired, Bull plug dry & clean. Install night cap & turn over to production. 07/28/20 - Tuesday M/U Gun #3 - 20' 2 3/8" carrier w/Razor low swell 11gr. charg es, 60 deg phasing, 6 SPF, RIH pull correlation log & verify good, pull into position CCL @ placing shots @3518-3538', shots @3558-3578', placing shots @3538-3558', Gun #1 - 20' 2 3/8" carrier w M/U Gun #4 - 20' Gun #2 - 20' 2 3/8" carrier w/Razor placing shots @ 3578-3598', f 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7,510'N/A Casing Collapse Structural Conductor Surface 1,540 psi Intermediate 4,020 psi Production 3,810 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 6,450 psi 4,900 (LS)/4,980 (SS) 755' COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 187-061 50-733-20389-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-02 CO 228A 9.2 / L-80 & 15.5 / J-55 TVD Burst 3,508 & 3,538 6,330 psi Tubing Size: MD 3,090 psi1,796' 507' 1,907' 755'755' 20" 13-3/8" 10-3/4"508' 1,907' 7,510' Perforation Depth MD (ft): 508' 3,660 - 4,415 7,002' See schematic Tubing Grade:Tubing MD (ft): 3,082 - 3,641 Perforation Depth TVD (ft): Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 8/3/2020 3-1/2" & 5-1/2" Daniel E. Marlowe See schematic 6,485'4,900'4,022'228 psi 6,485'9-5/8" Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 4:09 pm, Jul 21, 2020 320-310 Daniel Marlowe I am approving this document 2020.07.21 15:30:15 -08'00' Daniel Marlowe 10-404 DSR-7/21/2020 X VTL 7/23/20 X DLB 07/21/2020 Comm. q es 7/23/2020 dts 7/23/2020 JLC 7/23/2020 RBDMS HEW 7/24/2020 Well Work Prognosis Well Name:Trading Bay Unit M-02 API Number: 50-733-20389-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:8/3/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:187-061 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Office: 907-777-8384 Cell: 907-570-1801 Current Bottom Hole Pressure:128 psi @ 3,120’ TVD 0.04 psi/ft SIBP Maximum Expected BHP:228 psi @ 2,850’ TVD 0.08 psi/ft high case for new perfs Maximum Potential Surface Pressure:228 psi Brief Well Summary: Well M-02 is a gas well currently completed in the A, B, C and D grayling sands. The current plan is to add ±118’ of perforations into the A-5 sand. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate per the program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated by: JLL 07/21/20 SCHEMATIC Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) 20” 91# Structural Surface 755’ 13-3/8” 61 K-55 BTC 12.515” Surface 1907’ 10 3/4” 55.5 N-80 BTC 9.760” Surface 508’ 9-5/8” 43.5 N-80 BTC 8.755” 508 5668’ 9 5/8” 47 N-80 BTC 8.681” 5668’ 7510’ Tubing 3-1/2” 9.2 L-80 Hydril 563 2.992 Surface 3,508’ 5-1/2” 15.5 J-55 Csg Butt 4.96 3,511’ 3,538’ JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 1 470' 470' 2.813 5.37 Baker TE-5 SCSSV, Tubing Ret. W/ Profile 2 1,654' 1,523’ 2.867 5.313 GLM 1 3,403' 2,898' 2.867 5.313 GLM 2 3 3,461’ 2,940' 4.750 8.36 S-3 BOT 5" Packer TC II box x pin 4 3,487' 2,958' 2.813 X nipple profile 5 3,508' 2,973' 5.664 8.220 7" csg BTC Overshot 6 3,528' 2,988' 2.813 5-1/2" Perma Packer w/ X-Nipple 7 3,538’ 2,995' 4.000 7.000 S-22 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) A-6 Gravel Pack 8 3,543’ GR 2,998' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 9 3,643’ GR 3,070' 4.892 5.500 Screen, 5-1/2” with 20/40 gravel pack sand down to 3,707’ 10 3,710’ GR 3,118' 4.000 7.000 S-22 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-2 and B-3 Gravel Pack 11 3,704’ GR 3,114' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 12 3,881’ GR 3,243' 4.892 5.970 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,103’ 13 4,105’ GR 3,408' 4.000 5.600 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-5 Gravel Pack 14 4,106’ GR 3,409' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 15 4,309’ GR 3,561' 4.892 5.500 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,420’ 16 4,422’ GR 3,646' 4.000 7.000 S-22 Snap Latch, Seal Assy. W/ 80-40 Seal Ext (4.000” I.D.) 17 4,424’ GR 3,648' 6.000 8.210 Sump Packer, FB-1 18 4,465’ GR 3,679' 2.813 4.500 Nipple, ‘X’ 2.813” I.D. 19 4,509’ GR 3,712' 3.500 8.380 Overshot, 5-3/4” w/ Over Size Guide Lower Existing Completion I 4,900’ 4,022’ Bridge Plug w/20’ cement II 5,954’ 4,983' Packer, Dual, Baker A-5 III 5,999’ 5,026' 2.813 Nipple, “X” IV 6,060’ 5,084' Carbide Blast Joints V 6,957’ 5,947' Snap Latch, S-22 VI 6,958’ 5,948' Packer, 9-5/8” x 3-1/2”, Baker, “SC-1” (6’ Seal Bore ext) VII 6,969’ 5,958' Crossover, 6-5/8” x 3-1/2” VIII 7,003’ 5,991' 2.813 Nipple, “X” IX 7,034’ 6,022' Wireline Entry Guide A 5,954’ 4,983' Packer, Dual, Baker A-5 B 5,970’ 4,998' Nipple, “XN” C 5,979’ 5,007' Wireline Entry Guide PERFORATION DATA (DIL) ZONE TOP (MD)BTM (MD)TOP (TVD)BTM (TVD)AMT Condition A-6 3,660’ 3,692’ 3,082' 3,105' 32’ 7”, 18 spf B-2 3,885’ 3,924’ 3,246' 3,274' 39’ 7” 18 spf B-3 4,020’ 4,095’ 3,345' 3,401' 75’ 7” 18 spf B-5 4,336’ 4,415’ 3,582' 3,641' 79’ 7” 18 spf Short String C-4 5,000’ 5,060’ 4,108' 4,161' 60’ Isolated D-6 6,060’ 6,112’ 5,084' 5,133' 52’ Isolated Long String D-2 5,558’ 5,598’ 4,614' 4,651' 40’ Isolated D-3B 5,754’ 5,794’ 4,796' 4,833' 40’ Isolated D-16 7,136’ 7,172’ 6,121' 6,156' 36’ Isolated D-17 7,227’ 7,293’ 6,210' 6,274' 66’ Abandoned w/ cement retainer PBTD = 4,900’ TD = 7,510’ MAX HOLE ANGLE = 44q RKB to TBG Head = 68.5’ Tree connection: 4-1/16” 5,000# A B D-16 D-6 C D-17 VII III 1 2 7 8 9 C-4 D-2 D-3B V II VI VII IX 10 11 12 13 14 15 16 17 18 19 IV A-6 B-2 B-3 B-5 4 5 6 3 13-3/8” at 1,907’ SS - BP @ 4,980’ I XNX X X Updated by: JLL 07/21/20 PROPOSED Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) 20” 91# Structural Surface 755’ 13-3/8” 61 K-55 BTC 12.515” Surface 1907’ 10 3/4” 55.5 N-80 BTC 9.760” Surface 508’ 9-5/8” 43.5 N-80 BTC 8.755” 508 5668’ 9 5/8” 47 N-80 BTC 8.681” 5668’ 7510’ Tubing 3-1/2” 9.2 L-80 Hydril 563 2.992 Surface 3,508’ 5-1/2” 15.5 J-55 Csg Butt 4.96 3,511’ 3,538’ JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 1 470' 470' 2.813 5.37 Baker TE-5 SCSSV, Tubing Ret. W/ Profile 2 1,654' 1,523’ 2.867 5.313 GLM 1 3,403’ 2,898’ 2.867 5.313 GLM 2 3 3,461’ 2,940' 4.750 8.36 S-3 BOT 5" Packer TC II box x pin 4 3,487' 2,958' 2.813 X nipple profile 5 3,508' 2,973' 5.664 8.220 7" csg BTC Overshot 6 3,528' 2,988' 2.813 5-1/2" Perma Packer w/ X-Nipple 7 3,538’ 2,995' 4.000 7.000 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) A-6 Gravel Pack 8 3,543’ GR 2,998' 2.813 5.37 Packer, SC-1R, Inclusive Gravel Pack Assembly 9 3,643’ GR 3,070' 2.867 5.313 Screen, 5-1/2” with 20/40 gravel pack sand down to 3,707’ 10 3,710’ GR 3,118' 2.867 5.313 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-2 and B-3 Gravel Pack 11 3,704’ GR 3,114' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 12 3,881’ GR 3,243' 4.892 5.970 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,103’ 13 4,105’ GR 3,408' 4.000 5.600 Snap Latch, Seal Assy. W/ 5” R Nipple (4.000” I.D.) B-5 Gravel Pack 14 4,106’ GR 3,409' 6.000 8.450 Packer, SC-1R, Inclusive Gravel Pack Assembly 15 4,309’ GR 3,561' 4.892 5.500 Screen, 5-1/2” with 20/40 gravel pack sand down to 4,420’ 16 4,422’ GR 3,646' 4.000 7.000 Snap Latch, Seal Assy. W/ 80-40 Seal Ext (4.000” I.D.) 17 4,424’ GR 3,648' 6.000 8.210 Sump Packer, FB-1 18 4,465’ GR 3,679' 2.813 4.500 Nipple, ‘X’ 2.813” I.D. 19 4,509’ GR 3,712' 3.500 8.380 Overshot, 5-3/4” w/ Over Size Guide Lower Existing Completion I 4,900’ 4,022’ Bridge Plug w/20’ cement II 5,954’ 4,983' Packer, Dual, Baker A-5 III 5,999’ 5,026' 2.813 Nipple, “X” IV 6,060’ 5,084' Carbide Blast Joints V 6,957’ 5,947' Snap Latch, S-22 VI 6,958’ 5,948' Packer, 9-5/8” x 3-1/2”, Baker, “SC-1” (6’ Seal Bore ext) VII 6,969’ 5,958' Crossover, 6-5/8” x 3-1/2” VIII 7,003’ 5,991' 2.813 Nipple, “X” IX 7,034’ 6,022' Wireline Entry Guide A 5,954’ 4,983' Packer, Dual, Baker A-5 B 5,970’ 4,998' Nipple, “XN” C 5,979’ 5,007' Wireline Entry Guide PBTD = 4,900’ TD = 7,510’ MAX HOLE ANGLE = 44q RKB to TBG Head = 68.5’ Tree connection: 4-1/16” 5,000# A B D-16 D-6 C D-17 VII III 1 2 7 8 9 C-4 D-2 D-3B V II VI VII IX 10 11 12 13 14 15 16 17 18 19 IV A-6 B-2 B-3 B-5 4 5 6 3 13-3/8” at 1,907’ SS - BP @ 4,980’ I A-5 A-5 A-5 XNX X X Updated by: JLL 07/21/20 PROPOSED Trading Bay Unit Well: M-02 Last Completed 9/25/09 PTD: 187-061 API: 50-733-20389-00 PERFORATION DATA (DIL) ZONE TOP (MD) BTM (MD) TOP (TVD) BTM (TVD)AMT Condition A-5 ±3,456' ±3,480' ±2,936' ±2,953' ±24' Proposed A-5 ±3,497' ±3,505' ±2,965' ±2,971' ±8' Proposed A-5 ±3,512' ±3,598' ±2,976' ±3,038' ±86' Proposed A-6 3,660’ 3,692’ 3,082' 3,105' 32’ 7”, 18 spf B-2 3,885’ 3,924’ 3,246' 3,274' 39’ 7” 18 spf B-3 4,020’ 4,095’ 3,345' 3,401' 75’ 7” 18 spf B-5 4,336’ 4,415’ 3,582' 3,641' 79’ 7” 18 spf Short String C-4 5,000’ 5,060’ 4,108' 4,161' 60’ Isolated D-6 6,060’ 6,112’ 5,084' 5,133' 52’ Isolated Long String D-2 5,558’ 5,598’ 4,614' 4,651' 40’ Isolated D-3B 5,754’ 5,794’ 4,796' 4,833' 40’ Isolated D-16 7,136’ 7,172’ 6,121' 6,156' 36’ Isolated D-17 7,227’ 7,293’ 6,210' 6,274' 66’ Abandoned w/ cement retainer From:Katherine O"connor To:Loepp, Victoria T (CED) Subject:RE: [EXTERNAL] TBU M-02(PTD 187-061, Sundry 320-310) Perforation Sundry Date:Thursday, July 23, 2020 12:57:54 PM Correct, the plan is to shoot through that second packer (@3543’) and through the overshot on the schematic. This is a final push for more production and to test those A5 sands before a costlier RWO may be pursued. Thanks Katherine From: Loepp, Victoria T (CED) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, July 23, 2020 11:15 AM To: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Subject: [EXTERNAL] TBU M-02(PTD 187-061, Sundry 320-310) Perforation Sundry Katherine, The plan is to perforate through the overshot and the packer? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. 1 (~ r~,_ (~)~ j_ Well History File Identifier Organization (done) RESCAN Color items: Grayscale items: Poor Quality Originals: Other: DIGITAL DATA [] Diskettes, No. Other, No/Type TOTAL PAGES: NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE OVERSIZED (Scannable) Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds rn Other Is~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ Scanned (done) SCA..EO~: ~BREN V,.CENT S.ER~L MA.,, LOWELL DA.E: Is~ RESCANNED BY; BEVERLY BREN~SHERYL i--- General Notes or Comments about this file: PAGES: MARIA LOWELL DATE: Quality Checked (done) UNSCANNED, OVERSI7Ell MATERIALS AVAILABLE: .~; ~~ ~ FILE # To request any/all of the above information, please contact: Alaska Oil & Cas Conservation Commission X333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1.433 -Fax (907) 27b-7542 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS I~JG/1r- ~d~tol Zoof 1. Operations Abandon Repair Well Plug Pertorations Stimulate Other ~ Run 3-1/2" Completion Performed: Alter Casing ^ Pull Tubins0 Pertorate New Pool ^ Waiver ^ Time Extensior~] Change Approved Program ^ Operat. Shutdowr~ PerForate ^ Re-enter Suspended Wel^ 2. Operator Union Oil Company of California 4. Well Class Before Work: . Permit to Drill Number: Name: Development ^' Expioratory ^ 187-061 Stratigraphic^ Service ^ . API Number: 3. Address: PO Box 196247, Anchorage, AK 99519 50-733-20389-00 Property Designation (Lease Number): Well Name and Number: ADL0018730 Trading Bay Unit (Steelhead Platform] Trading Bay Unit M-02 . Field/Pool(s): McArthur River Field ! Middle Kenai Gas 11. Present Well Condition Summary: ' ' ~~~~ar~~~ ~ BP in LS (a~ 4,900 Total Depth mea ~' 7,510 feet Plugs (measured) BP in SS ~ 4,980' feet true vertic~t 6,485 feet Junk (measured) N/A feet Effective Depth measured 4,900 feet Packer (measured) See Below feet true vertical 4,021 feet (true vertical) See Below feet Casing Length Size MD TVD Surst Collapse Structurai Conductor 727' 20" 727' 726' Surface 1,895' 133/8" 1,895' 1,787' 3,090 psi 1,540 psi Intermediate 508' 10-3/4" 508' 507' 6,450 psi 4,020 psi Production 7,002' 9-5/8" 7,510' 6,485' 6,330 psi 3,810 psi Liner Perforation depth: Measured depth: 3,660'-3,692', 3,885'-3,924', 4,020'-4,095', 4,336'-4,415' True Vertical depth: 3,082'-3,105', 3,245'-3,274', 3,345'-3,400', 3,581'-3,640' ~I~v 3'fbl ~ Tubing (size, grade, measured and true vertical depth): 3-1/2" x 5-1/2" 9.2# L-80 / 15.5# J-55 3,508' MD 2,973 ND Packers: Baker SC-1, Baker A-5, Packers: 6,958', 5,954', 4,424', Packers: 5,947', 4,983', Packers and SSSV (type, measured and true vertical depth): Baker FB-1, Baker SC-1R, Baker S-3 4,106', 3,704', 3,543', 3,528', 3,647', 3,409', 3,140', 2,998', SSV: Baker 5-1/2" TR TSME 3,461'15SV: 455' MD 2,987', 2,939'SSV:454' ND 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 1,500 0 120 psi 110 psi Subsequent to operation 0 ~ 2,500 0 185 psi 144 psi 14. Attachments: . Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development Q Service ^ Daily Report of Well Operations X Well Status after work: Oii Gas ~ WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-430 Contact David Ross 263J696 Printed Nary~GTimothy C. Brandenburg Ij/ Title Driliing Manager A Signature ~~ ,~ Phone 276-7600 Date 10/14/09 .~ .~ R ~~~~ ~~'~~° ~ ~ ~°~- Form 10-404 Revised 7/2009 Submit Original Only @VI'O Trading Bay Unit Steelhead Platform M-o2 ~ M-O~ Last Compieted 9/25/09 RKB to TBG Head = 68.5' CASIN G AND TUBING D ETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) 20" 91# Structural Surface 755' 13-3/8" 61 K-55 BTC 12.515" Surface 190T 10 3/4" 55.5 N-80 BTC 9.760" Surface 508' 9-5/8" 43.5 N-80 BTC 8.755" 508 5668' 9 5/8" 47 N-80 BTC 8.681" 5668' 7510' Tubing 3-I/2" 9.2 L-80 Hydri1563 2.992 Surface 3,508' 5-1/2" 15.5 J-55 Cs Butt 4.96 3,S11' 3,538' JEWELRY DETAIL NO. Depth ID [tem 1 470' 2.813 Baker TE-5 SCSSV, Tubin Ret. W/ Profile 2 1,654' & 3,430' 4.653 3-1/2" GLM 3 3,461' 4.765 S-3 BOT 5" Packer TC II box x in 4 3,487' 2.813 X ni le rotile 5 3,508' 2.992 7" cs BTC Overshot 6 3,528' 2.813 5-1/2" Perma Packer w/ X-Ni le 7 3,538' 4.000 Sna Latch, Seal Ass . W/ 5" R Ni le (4.000" I.D.) A-6 Gravel Pack 8 3,543' GR 4.800 Packer, SG1R, Inclusive Gravel Pack Assembl 9 3,643' GR 4.892 Screen, 5-1/2" with 20/40 ravel ack sand down to 3,707' 10 3,710' GR 4.000 Sna Latch, Seal Ass . W/ S' R Ni le (4.000" I.U.) B-2 and B-3 Gravel Pack I1 3,704' GR 4.800 Packer, SG1R, Inclusive Gravel PackAssembl 12 3,881' GR 4.892 Screen, 5-1/2" with 20/40 ravel ack sand down to 4,103' l3 4,105' GR 4.000 Sna Latch, Seal Ass . W/ 5° R Ni le 4.000" I.D. B-5 Gravel Pack 14 4,106' GR 4.800 Packer, SC-IR, Inclusive Gravel PackAssembl 15 4,309' GR 4.892 Screen, 5-1/2" with 20/40 ravel ack sand down to 4,420' 16 4,422' GR 4.000 Sna Latch, Seal Ass . W/ 80-40 Seal Ext (4.000" I.D. 17 4,424' GR 6.000 Sum Packer, FB-1 18 4,465' GR 2.813 Ni le, `X' 2.813" I.D. 19 4,509' GR 2.992 Overshot, 5-3/4° w/ Over Size Guide Lower Existin Com letion I 5,954' Packer, Dual, Baker A-5 II 5,999' 2.813 Ni le, "X" III 6,060' Carbide BlastJoints IV 6,95T Sna Latch, 5-22 V 6,958' Packer, 9-5/8" x 3-l/2", Baker, "SGP' 6' Seal Bore ext V[ 6,969' Crossover, 6-5/8" x 3-1/2" VII 7,003' 2.813 Ni le, "X" VI11 7,034' Wireline Ent Guide A 5,954' Packer, Dual, Baker A-5 B 5,970' Ni le, "XN" C 5,979' Wireline En[ Guide PERFORAT ION DATA DIL ZONE TOP BTM AMT Condition A-6 3,660' 3,692' 32' 7", l8 s f B-2 3,885' 3,924' 39' 7" 18 s f B-3 4,020' 4,095' 75' 7" 18 s f B-5 4,336' 4,415' 79' 7" 18 s f Short Strin C-4 5,000' S,060' 60' Isolated D-6 6,060' 6,112' S2' Isolated Lon Strin D-2 5,558' S,598' 40' Isolated D-3B 5,754' S,794' 40' Isolated D-16 7,136' 7,172' 36' Isolated D-17 7,22T 7,293' 66' Abandoned w/ cement rehainer MAX HOLE ANGLE = 44° M-02 Actual Well Schematic 10-12-09.doc Uadated by CVK 10-15-09 PBTD = 7,204' TD = 7,510' ~Chevron ~ ~ ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M-02 TRADING BAY UN IT M-02 ADL0018730 5073320389 IM1894 ~~ 163.00 ~_,,..~ ~ ,. ~ ~,. ~., . .... . ,_, ~~W..~ . ~.-~~~:ti ~ ~ ~, Primary Job Type Job Category Objective Actual Start Date Actual End Date Tubing Repair Major Rig 7/24/2008 9/26/2009 Work Over (MRWO) M-02 5073320389-00 1870610 ~' ~~. "~"~ '" 7/2M2008 OO:E)~~''~f2~E~4~ 00:00 Operations Summary Mobe equipment to platform, s~23i2eoa nn~nn . sr~2nna no~nn Y . ti. RU slickline. Pressure tested 250 low/ 1800psi high. RIH w/ GS puiling tool to 455' RKB SLM. Latch storm coke assembly and POOH 8/?.412008 00:00~- 8/25I200$ OO:Ofi~ ~ ~ ~~ ~ ~ ~ ~~~ ~ ~ ~ ~ ~ ~;", ~ ~'~~ Operations Summary RIH w/ 4.62" no go and set down on SSSV nipple at 450' RKB SLM. POOH. RIH w/ 4.559" swedge and 4.62" no go. Swedge sat down at 450' RKB SLM, and fell thru to 454' RKB SLM. POOH and rigged down slickline until camera available to run in hole. ~ 4~Qt00 - 8/30/2U08 Q0:00 . M~~~~~x., ~~ <: ,._. a; Operations Summary ~ RU slickline, Pressure test lubricator 250psi low/1500psi high. RIH w/ 4.62" no go, set down at 450' RKB SLM, POOH. ~~i~~~' `f~ ~~-,8t31 00:00 ~n ~~°~,~ ,~~ . Operations Summary RIH w/ camera on memory mode to 455' RKB SLM, POOH, download same, no good pics. RIH w/ camera on memory mode to 455' RKB SLM, POOH, downioad same, sent data to town. RIH w/ lockout tool, set across SSSV at 455'. Pulled body out of lockout tool. RIH w/ 4.5" swedge to 550', POOH. Made attempt to fish K-valve assembly @ 3,539' RKB SLM w/ GS pulling tool. Secure well for crew rest. ~,. ~; ~ ~:, ,, < , 8/31i2008 OQ:OQ - 9l1/2008 OO:OQ; `" - ~ r~~.. ~ ~,; ~-_ - Operations Summary Pressure test lubricator 250psi low/1500psi high. Made several attempts to fish K-valve assembly @ 3,539' RKB SLM w/ GS pulling tool, POOH w/ fish. ~ ~ ~ ~,; ~ ~f~~'~ ~~..11Q~ OQ:00 - 9/2/2008 00:00 ~ ~ ~ ~ ~ ~ ~ y ~ . ~ ~;h ~~ ~ " ~~~~~.,,. Operetions Summary RIH and set storm choke at 450' RKB SLM. RD 8~ Turned well over to production. ,... ~.~ ~. 10J11/~d08` OO:t1{~ -101'k~t~2A08 OO:W} ~.~ ~ „~. ~, Operations Summary RU Slick line puil Storm Choke drift tubing w/ 4.54" Swage, SDFN. „~ ~ w . : ~, ~ ~ ~. ~~ k ~., '~ ~ ~ ~Q4~.QQ -10/93l2~08 00:04 ° ~: 3 r: Operetions Summary Rig up E-line , Pressure test lubricator 250psi low/2500psi high, and set HES Packer assembiy at 3528' RKB, Rig up Slick line and set Storm Choke, Test and turn well to Production. ~ ~ M .,.,.,. 9/1~T/2009~OOt~0~-9/18/2009 00.00 ~~ ~ ~ ~ ~ ~~ ~ ~. ~a=~~ ~~~ ~ ~ Operations Summary Accepted rig @ 12:00 and skidded rig over well M-02. ~ ts.- 9/18/2009 t10:00 - 9/19l200~ ~:t~0 `~~~`~ ~ ~ ~ ~ ~ ` -. ~ ~~'~~~~ ~ .;~ ~ v ,$~ ~ r .,~ ~. ~ Oparations Summary Finish securing rig. R/U slick line and test lubricator to 250 psi low, 2500 psi high, good test. RIH and retrieved PB valve in SSSV,POOH. RIH with tubing brush and brushed X nipple below the 5 1/2" packer, POOH. P/U and RIH w/ PX plug body and set in x nipple, POOH. P/U and RIH w/ PX prong and set in plug body, POOH. R/D slick line. Circulate FIW via annulus through gas lift valve. Pump down tubing and PT same to 1500 psi for 10 minutes. Good test. Notified AOGCC of upcoming BOP test. ~! F 9/19t200$ 00:00 - 9/20/2009 OOt00 V .. ~ , ° `` ; : , =;~ #~~`;; „ ` ~ `'` , ~' „~ ~. Operations Summary Flow checked well, no flow. N/D tree and N/U BOPs . Change out 5" rams to 5 1/2" rams. Function test BOPs and M/U 5 1/2" test joint. Test BOPs witnessed by Lou Grimaldi of AOGCC, Hydril 200 low / 1500 psi high, all other components 200 low / 300Q psi high. Test accumulator and function test remote unit. R/D 5 1/2" test joint. 9120/2pbS 00.00~- 9/21~2008 OQ;Q#, ; ~~~ ~ ~ x ~~ ~ ~ ,~~ a~ ,~~~~ Operations Summary M/U 3 1/2" test joint and test annular w/ 200 low / 1500 psi high witnessed by Lou Grimaldi of AOGCC. Passed low test but high test failed. Test 3 1/2" rams to 200 low / 3000 psi high, good test. Test blind rams to 200 low / 3000 psi high, good test. Changed out annular element, eventually achieved an acceptable annular test on 3 1/2". R/D 3 1/2" head pin and pup. - ~ ~ ~,x . ~. r~~ 9121/2bb9 4EYttIQ~-~9/22I2009~-00:Od ~ ~;=~~~ ~;~ ~ ~ :~ ~+~h: ~ ~ -> Operations Summary R/U E-line and RIH to punch tubing at 3503'-3509', POOH all shots fired. Circulated FIW thru holes and observed a restriction. Reverse circulated @ 8 BPM and cleared holes. RIH w! a radial cutting torch to sever tubing at 3505', no cut on 1st attempt. RIH w/ tbg punch and punched additional holes from 3508'-3514', POOH all shots fired. RIH w/ radial torch and successfully severed pipe @ 3508'. POOH R/D E-line and prepare to pull 5 1/2" tubing. ~ / ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UVN ChevNo Original RKB (ft) Water Depth (ft) M-02 TRADING BAY UNIT M-02 ADL0018730 5073320389 IM1894 163.00 r .~ ~ ~5.. w Dai O ~ ratifsi~s ~. ` , ~ ~ ~ ~" , , '~ ~ _~ ~. ~~~,~ . k . :,. ~ . ,~ . ~ : , ; r~ ~ ~ ; ; • , ~ ,_ ~~ _.,. ~ ~ a..„~ ~ ~: `~~ ~~ 9/22/2009 00:00 - 9/23/2009 OOc00 ~ '` ' z~~~° :~ ~ . Operations Summary Pulled tbg hanger and prepared to pull 5 1/2" tbe completion. Monitored losses, hole taking 2 BPH. POOH with 5 1/2" tbg and LD same. Recovered 3510.96' by RKB measurement. Attempted to test casing packerand plug to 1500 psi w/o success. Waited on orders from town. P/U overshot assembly and RIH with 3 1/2" completion drifted to 2.867". R/U to circulate down tbg. to wash over stub. ~ ~ ~ r, ~ ~, t =4 <, , , ~ 4~~1z4Q - 9/24/2t?08 00:00 , ` Operations Summary RIH with overshot assembly and tagged out @ 3524', PU to 3046' to install the SSSV control line and tested same to 5000 psi. Bled the pressure to 2000 psi to run in the hole. Run back in hole to top of tbg. stub. Circulate 265 bbls of packer fluid into well and displace with 30 bbls of 6% KCI. Landed hanger with overshot mule shoe @ 3523'. R/U slick sline and RIH to set top loading prong and PT same to 500 psi, POOH artd R/D slick line. Set S-3 packer @ 3461' w/ 2500 psi. Performed jug test via the annulus to 1500 psi and recorded on chart for 30 mins. Good test. Break out landing joint, set BPV and close SSSV. ;~ ~ <,x; ~9l2412009 OQ:OQ - ~9/25I2009 t~t~ . ~~`;~ ~ _ ~ ~ ~.. ~ Operations Summary N/D BOPs and N/U tree, Test hanger void t 300psi low/5000 psi high for 30 mins, good test. Pull BPV and install 2 way check and tested tree 200psi low/5000 psi high for 30 mins, good test. Pulled 2 way check and prepare rig to skid to M-32, NW leg. 9/26/2009 A0:00 . 9/26[2009 00:00 ~~" ~ Operations Summary ~ No Activity on M-02, skidding rig to leg B-1 ~~ 1 b!1'tt2009 OQ:00 -10112I2009 00:00 ~ ~ „ ~~' ~ ` ~:: ~ ~~ ~~ ~ k '~ Operations Summary R/U slickline and PT lubricator to 300psi low/2500 psi high. RIH with 2" JDC pulling tool to 3533' and worked to 3537', unable to latch prong, POOH. Made two trips with a 1.75" DD Bailer to 3540' , recovering scale debris, PX prong mark on bottom of pulling tool after second run. Secured well for night. ~10/12I2009 00:00~-10/1312~~i1Ck:t~~{+~ ' ; ~~ ` " ~ `~ ~;~~ ~ ~ ~ ~~' ~ "~ ` ~ ~ ~ Operations Summary R/U slick line and make two trips w/ 2.5" DD bailer to 3540 with no recovery of fill. RIH with 2.5" JDC pulling tool assembly w/ knuckle joint and centralizer. Latch and pull PX prong, POOH. RIH w/ 2.5" DD bailer and work to 3545' POOH , recovered scale. RIH w/ 1.75" DD bailer to 3545' POOH recovered scale. RIH w/ 3.5" GS pulling tool to 3545' latched PX plug and POOH successfuly. R/D slick line and turned well over to production. / ~ Page 1 of 2 Aubert, Winton G (DOA) From: Aubert, Winton G {DOA) Sent: Wednesday, September 23, 200910:D3 AM To: 'Ross, David A. [Petro Technieal Resources of AK]' Subject: RE: M-02 Workover ~~~J` D~ I Mr. Ross, ~~ AOGCC hereby approves changes to approved Sundry No. 308-434, forwelt TBU M-02 {PTD 187-061}, as described below and in the attachments. AIE other sundry approval stipulations appty. Winton Aubert At)GCG 793-1231 From: Ross, David A. [Petro Technical Re.sources ~ AK] [mailto:rossda@chevron.com] Sent: Wednesday, September 23, 2009 9:54 AM To: Aubert, Winton G (DOA) Cc: Nienhaus, Doug R; Bonnett, Nigel (Nigel.Bannett) Sub]ect: M-02 Workover , , ~:°~ y.. r "~ ` °~ -~.~.x.. ~s;. Mr. Auber, 1~vcrs dr~f~irag this e-rn~ii at ~he tirs~e f recegve~` yaur call t~is rrrt~rning, so it ~ui~~ sar~~~y ser~re czs tr~c~~lc~tnr up ~r~ c~ur c€~raversatiorr in. ~rhic~ y~~r ~rovided c verbc~l v~rricr~ce to the procedure referencee~ be~~~r. As discussed Chevron Alaska is currently performing the tubing change out on well M-02 as per the approved sundry dated 11-28-08 and the revised procedure summary submitted ta you on 8-10-09. Unfortunately, we have experienced problems with the PX prong and plug set below the WS Perma Packer in the 5%:" tubing. The plug is passing fluid which will make it impossible for us to pressure test the underside of the packe~ as per step 13 on the revised procedure summary. In lieu of performing the pressure test below the packer we will perForm a jug test on the well to 1500 psi above the packer which will test the annular seal of the padcer from above instead of below. FYI, I have attached a copy of the 10-403 su~dry approved on 11-28-08 in addition to the updated procedure summary which indicates the changes I have stated above. We are seeking a variance for step 13 of the updated procedure based on the jug test that will be performed to test the integrity of the new completion packer. Thank you far your time and cooperation of this matter. Regards, David Ross • Alaska Wellbore Maintenance Team 9/23/2009 ~hevrt~n OBJECTIVE: Steelhead Platform Weil # M-2 48110/49 Change-out 5-1/2'" completion tubing to 3-1l2" completion tubing without ~posing subnormal pressured gas reservoirs to work-over fluid. PROCEDURE SUMMARY. 1. Set wireline conveyed packer w! XN profile ~a f3530' (Completed 10-11-08 actually set ~,a? 3428') 2. Slickline set plug in profile_ 3. Fill tbg wl f% KCI Fluid. P`unch tubing @~3494' (Tubing will be punched @ 3503'-3509') 4. Circulate/fill well with 6% KCI. Pressure test wellbore to 1500 psi 5. Move in rig and equipment over well M-2 6. N/D tree, NJU BOPE, test (250psi lowI3000psi high) test annular (250psi low/1500psi high) • 20-3/4" BOPE to be used 7. MU landing joint, unseat hanger, circulate well w15% KCI. Pull 1QK tension on the tubing 8. RI w/ 5 1/2" radial cutting torch an Eline_ Cut tbg @ 349f)'. CBU. R/D Eline (Tubing to be cut @ 3505') 9. POOH LD 5 1/2" tbg string_ 10. PIU 5 1J2" over shot, X profile, mill aut ext., S-3 packer, gas lift mandrels and SSSV, RIH on 3 1/2" tbg. To swallow 5 U2" tubing stub, space out and circulate in packer fluid, land tbg. 11. RU slickline. RIH set plug in X profile, below S-3 packer, pressure set gacker_ Test test S-3 packer to 1500 psi against plug_ 12. I'er#~r~t~ a,ju~ test ab€~~e ~ac~er [~ 1~{3~ ps~ b~T press~zrir~~ up t1~e ~a~i~~ ~~~ tubin~ a~~~~~as ~--~-~~-~~;~-~-~~~~~€~-~-,~~:z~~ ~~~~~~-~ ~~~~=-~~~~t~~~~~T-~~ ~~~~~-~~;i- 13. N/D BOPE, N/U tree, rig up production lines & pressure test. ~ 14. Release Rig. Secure Well. 15. Ga.slift 3 1/2" tubing string dry. 16. P/L7 GS pulling tool and RIH to recover top loading prong and plug below the S-3 packer. 17. RIH to recover the PX prong and plug below the 5'/Z" Perma Packer 18. Turn well over to production. M-2 REVISED BY: SLT 9/30/08 Ctlevr+ : • ~ ~ 1 ~ ~O ~ + `~~eelhead Platform ~ Oi e!I # E~~1-2 Q8110l09 OBJECTIVE: Change-out 5-1/2" completion tubing to 3-1/2" completion tubing without exposing subnormal pressured gas reservoirs to work-over fluid. PROCEDURE SUMMARY: 1. Set wireline conveyed packer w/ XN profile @ f3530' ~ ,~~ted 10-1 I-08 actually set @: 2. Slickline set plug in profile. 3 . Fill tbg w/ 6% KCl Fluid. Punch tubing @ f3494' ~, : ~ ? %-~ : ~ ~~ , ~ ; ; n ~ - , 4. Circulate/fill well with 6% KCI. Pressure test wellbore to 1500 psi 5. Move in rig and equipment over well M-2 6. N/D tree, N/U BOPE, test (250psi low/3000psi high) test annular (250psi low/1500psi high) 7. MU landing joint, unseat hanger, circulate well w/6% KCI. Pull l OK tension on the tubing 8. RI w/ 5 1/2" radial cutting torch on Eline. Cut tbg. @ 3490'. CBU. R/D Eline 9. POOH LD 5 1/2" tbg string. 10. P/U 5 1/2" over shot, X profile, mill out e~ct., S-3 packer, gas lift mandrels and SSSV, RIH on 3 1/2" tbg. To swallow 5 1/2" tubing stub, space out and circulate in packer fluid, land tbg. 11. RU slickline. RIH set plug in X profile, below S-3 packer, pressure set packer. ,t test ~-_~ pac-:~~ ~u 12. RIH to retrieve plug. 13. .,~,~;, f~ ! ;~n ,~~i 14. N/D BOPE, N/U tree, rig up production lines & pressure test. 15. Release Rig. Secure Well. 16. Gaslift 3 l/2" tubing string dry. 17. P/U GS pulling tool and RIH to recover profile plug set in lo~ver packer assembly. 18. Turn well over to production. S'~,~l~D AUG 14 20D9 M-2 REVISED BY: SLT 9/30/08 • • "~w£ 1 `~ ~ ~} SARAH PALIN, GOVERNOR ALASSA OIL Al`D ~`zA-5 ~ 333 W. 7th AVENUE, SUITE 100 CO1~T51'.RQA'rIO1~T COMMI55IO1~T '~~ pHONE~ 907)279-14339501-3539 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 ~~~~ '~~ ~ ~~ ~ ~~Q Re: McArthur River Field, Middle Kenai Gas, TBU M-02 Sundry Number: 308-430 Dear Brandenburg: 1 ~~~lo~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Comnussion an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy . Foerster Commissioner ,~,,RR~ DATED thisl~ day of November, 2008 Encl. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 e.y ~m ter.. .~~ -~~~ae 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ^ Waive^ Other Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension^ Change approved program^ Pull Tubing 0 - Perforate New Pool ^ Re-enter Suspended Well^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ~ Union Oil Company of California Development ^ Exploratory ^ ~ 187-061 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20389-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Tradin Ba Unit M-02 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0018730 Tradin Ba Unit Steelhead Platform 68.5' McArthur River /Middle Kenai Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,510'. 6,485'- 7,204' 6,187 Bridge Plug in LS@4,900' ' N/A BP in SS @ 4,980 Casing Length Size MD TVD Burst Collapse Structural Conductor 727' 20" 727' 726' Surface 1,895' 13-3/8" 1,895' 1,787' 3,090 psi 1,540 psi Intermediate 508' 10-3/4" 508' 507' 6,450 psi 4,020 psi Production 7,002' 9-5/8" 7,510' 6,485' 6,330 psi 3,810 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 5-1/2" 15# J-55 3,538' Packers and SSSV Type: Packers and SSSV MD (ft): Packers: Baker SC-1, Baker A-5, Baker FB-1, (3) Baker SC-1 R / Packers: 6,958', 5,954', 4,424', (1) 4,106',(2) 3,704', (3) 3,543' SSV: Baker 5-1/2" TR TSME SSV: 455' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch Q Exploratory ^ Development Q - Service ^ 15. Estimated Date for 12/2/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas Q ~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ P -7600 Date 11/25/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ } Other. `3~'OO~st ~Jo~ ~t'rc.'~~ '~~~ Subsequent Form Required: ;£,y~~b~ ~. -~rr ~4 ~ ~ao~ ~ ~ APPROVED BY ~ Approved by: COMMISSIONER THE COMMISSION Date: ~~ 7i8 'V Form 10-403 R~(iised 06/20p6 ~ ~ ~ ~ ~ ~ t ~ ~ Submit in Duplicate Chevron ~ • Steelhead Platform Well # M-2 11/25/08 OBJECTIVE: Change-out 5-1/2" completion tubing to 3-1/2" completion tubing without exposing subnormal pressured gas reservoirs to work-over fluid. PROCEDURE SUMMARY: 1. Set wireline conveyed packer w/ XN profile @ (3530' 2. Slickline set plug in profile. 3. Fill tbg w/ 6% KCl Fluid. Punch tubing @ X3494' 4. Circulate/fill well with 6% KCI. Pressure test wellbore to 1500 psi 5. Move in rig and equipment over well M-2 6. N/D tree, N/U BOPE, test (250psi low/3000psi high) test annular (250psi low/1500psi high) • 16-3/4" BOPE to be used if change out to 20-3/4" BOPE not done. • 20-3/4" BOPE to be used pending arrival of riser. 7. MU landing joint, unseat hanger, circulate well w/6% KCI. Pull l OK tension on the tubing 8. RI w/ 5 1/2" radial cutting torch on Eline. Sever tbg. @ 3490'. CBU. R/D Eline 9. POOH LD 5 1/2" tbg string. 10. P/U 5 1/2" over shot, X profile, mill out ext., SAB-3 packer, gas lift mandrels and SSSV, RIH on 3 1/2" tbg. To swallow 5 1/2" tubing stub, space out and circulate in packer fluid, land tbg. 11. RU Slickline. RIH set plug in X profile, below SAB-3 packer, pressure set packer. RIH to retrieve plug. 12. N/D BOPE, N/U tree, rig up production lines & pressure test. ~ ~Q~csSv rcc ~C S 13. Release Rig. Secure Well. ~ 14. Gaslift 3 1/2" tubing string dry. ~ `~~~'^~~ G~nJ~`~ 5 15. P/U GS pulling tool and RIH to recover profile plug set in lower packer assembly. 16. Turn well over to production. M-2 REVISED BY: SLT 9/30/08 Chevron . Trading Bay Unit Well M-2 Proposed CASING AND TUBING DETAIL RKB to TBG Head = 68.5' S17.F, WT GRADE CONN ID "TOP BTM. Long String ezsv @ 4,900' DIL Short String Ezsv @ 4,980' DIL 13-3/8" 61 K-55 Surf 1,895' 10-3/4" 55.5 N-80 Surf 508' 9-5/8" 43.5-47 N-80 Butt 8.681 508' 7,510' Tubin 3-'h" 9.2 N-80 TC-ll 2.992 Surf TBD NO De th ID JEWELRY DETAIL Item 1 73.78' 5.040 l 1" x 5-1/2" FMC TC-60 Han er, CIW T e H 2 TBD 2.813 Model TE-5 size 3-1/2" Tubing Retrievable Safety Valve 5.38" OD x 2.875" ID a TBD GLM's b TBD Model 194-47 SB-3 Retainer Production Packer w/MOE c TBD 2.813 Model X Profile Seatin Ni d TBD Cs Overshot e TBD Eline set Pkr f TBD 2.75 Model XN Profile Ni le 7 3,538' 3.000 Sna Latch, Seal Ass . W/ 5" R Ni le 4.000" [.D. A-6 Gravel Pack 8 3,543' GR 4.800 Packer, SC-I R, Inclusive Gravel Pack Assembl 9 3,643' GR 4.892 Screen, 5-1/2" with 20/40 ravel ack sand down to 3,707' 10 3,710' GR 5.000 Sna Latch, Seal Ass . W/ 5" R Ni le 4.000" I.D. B-2 and B-3 Gravel Pack 11 3,704' GR 4.800 Packer, SC-1R, Inclusive Gravel Pack Assembl 12 3,881' GR 4.892 Screen, 5-1/2" with 20/40 ravel ack sand down to 4,103' 13 4,105' GR 5.000 Sna Latch, Seal Ass . W/ 5" R Ni le 4.000" LD. B-5 Gravel Pack 14 4,106' GR 4.800 Packer, SC-IR, Inclusive Gravel Pack Assembl 15 4,309' GR 4.892 Screen, 5-1/2" with 20/40 ravel ack sand down to 4,420' 16 4,422' GR 4.000 Sna Latch, Seal Ass . W/ 80-40 Seal Ext 4.000" I.D. 17 4,424' GR 6.000 Sum Packer, FB-1 18 4,465' GR 2.813 Ni le, 'X' 2.813" I.D. 19 4,509' GR 2.992 Overshot, 5-3/4" w/ Over Size Guide Lower Existin Com letion I 5,954' Packer, Dual, Baker A-5 II 5,999' 2.813 Ni le, "X" III 6,060' Carbide Blast Joints IV 6,957' Sna Latch, S-22 V 6,958' Packer, 9-5/8" x 3-1/2", Baker, "SC-1" 6' Seal Bore ext VI 6,969' Crossover, 6-5/8" x 3-1/2" VII 7,003' 2.813 Ni le, "X" VIII 7,034' Wireline Ent Guide A 5,954' Packer, Dual, Baker A-5 B 5,970' Ni lc, "XN" _ C 5,979' Wireline Ifntrv (iui~lc PERFORATION D:~T:~ (DIL) /.one 'fop Btm Amt (~undiliun A-6 3,660' 3 692' 32' 7", 18 s f B-2 3,885' 3,924' 39' 7" 18 s f B-3 4 020' 4,095' 75' 7" 18 s f B-5 4,336' 4 415' 79' 7" 18 s f Short Strin C-4 5,000' 5,060' 60' Pro osed Isolated W/ Retainer D-6 6,060' 6,112' S2' Plu ed Lon Strin D-2 5 558' 5,598' 40' D-3B 5,754' 5,794' 40' D-16 7 136' 7,172' 36' D-17 7,227' 7,293' 66' Abandoned w/ cement retainer M-02 Proposed Sept08.doc DRAWN BY: SLT PBTD = 7,204' TD = 7,510' MAX HOLE ANGLE = 44° Chevron . Tradin y Unit Well M- Completed 11/7/00 RKB to TBG Head =68.5' Tree connection: 4-1/16" SIZE WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Surf 1,895' 10-3/4" 55.5 N-80 Surf 508' 9-5/8" 43.5-47 N-80 Butt 8.681 508' 7,510' Tubing: 5-1/2" 15 J-55 Csg Butt 4.960 Surf 3,538' JEWELRY DETAIL NO. Depth ID Item 1 73.78' 5.040 11" x 5-I/2" FMC TC-60 Hanger, CIW Type H 2 455' 4.562 SSSV, 5-1/2" Baker, TSME-6 Tubing Ret. W/ X-Profile (Has Baker lock open spring set in flapper) 3 1,124' 4.653 GLM, 5-1/2" MM SFO-2, RK Latch, R-2 Valve 4 2,250' 4.653 GLM, 5-1/2" MM SFO-2, RK Latch, R-2 Valve 5 2,847' 4.653 GLM, 5-1/2" MM SFO-2, RK Latch, R-2 Valve 6 3,483' 4.653 GLM, 5-1/2" MM SFO-2, RK Latch, R-2 Valve 7 3,538' x.000 Snap Latch, Seal Assy. W/ 5" R Nipple (4.000" I.D.) A-6 Gravel Pack 8 3,543' GR 4.800 Packer, SC-lR, Inclusive Gravel Pack Assembly 9 3,643' GR 4.892 Screen, 5-1/2" with 20/40 gravel pack sand down to 3,707' 10 3,710' GR 4.000 Snap Latch, Seal Assy. W/ 5" R Nipple (4.000" LD.) B-2 and B-3 Gravel Pack 11 3,704' GR 4.800 Packer, SC-1R, Inclusive Gravel Pack Assembly 12 3,881' GR 4.892 Screen, 5-1/2" with 20/40 gravel pack sand down to 4,103' 13 4,105' GR 4.000 Snap Latch, Seal Assy. W/ 5" R Nipple (4.000" LD.) B-5 Gravel Pack 14 4,106' GR 4.800 Packer, SC-1R, Inclusive Gravel Pack Assembly 15 4,309' GR 4.892 Screen, 5-1/2" with 20/40 gravel pack sand down to 4,420' 16 4,422' GR 4.000 Snap Latch, Seal Assy. W/ 80.40 Seal Ext (4.000" I.D.) 17 4,424' GR 6.000 Sump Packer, FB-1 18 4,465' GR 2.813 Nipple, `X' 2.813" LD. 19 4,509' GR 2.992 Overshot, 5-3/4" w/ Over Size Guide Lower Existing Completion I 5,954' Packer, Dual, Baker A-5 II 5,999' 2.813 Nipple, "X" 111 6,060' Cazbide Blast Joints IV 6,957' Snap Latch, 5-22 V 6,958' Packer, 9-5/8" x 3-1/2", Baker, "SC-1" (6' Seal Bore ext) VI 6,969' Crossover, 6-5/8" x 3-1/2" VII 7,003' 2.813 Nipple, "X" Vlll 7,034' Wireline Entry Guide A 5,954' Packer, Dual, Baker A-5 B 5,970' Nipple, "XN" L 5,979' Wireline Entry Guide D-6 6,060' 6,112' S2' Plugged Long String D-2 5,558' 5,598' 40' D-3B 5,754' 5,794' 40' D-16 7,136' 7,172' 36' D-17 7,227' 7,293' 66' Abandoned w/ cement retainer ZONE TOP PERFORATION DATA (DIL) BTM AMT Condition A-6 3,660' 3,692' 32' 7", 18 spf B-2 3,885' 3,924' 39' 7" IS spf B-3 4,020' 4,095' 75' 7" 18 spf B-5 4,336' 4,415' 79' 7" 18 spf Short String C-4 5,000' 5,060' 60' Proposed Isolated W/ Retainer } R$Z131~ti~2b47 -7-~~ (la®'ta~t~lObC REV~ISL'~D~^I C A\If'_I C - AAo DRAWN BY: TCB M-02 16 3/4" BOP Stack up 71.81' ~ ~ Drip Pan ~ ~ ~ 38.25' 8.75' 18 3/4" 5M Hydril Annular 5.40' 6.03' 18 3/4" tOM Mud Cross 2.45' ALL Wing valves 3" 5M 3/4" 5M BX 162 Upper well Bay Floor 18 3/4" 5M Riser Hub Connec on top 60' F\ ~ Top of 18" 5 M Tbg Spool 59.76' Spool SECTION AA ~k ALL YALYES IN FLOW PAT1i ARE 3-1/16' 5000 PSl CAMERON GATE TYPE M-02 20 3/4" BOP Stack up • Removal of Storm Choke from S~M-2 gas well Page 1 of 2 Re James B DOA • 99, ( ) From: Greenstein, Larry P [Greensteinlp@chevron.com] ~ ~ ~~~~ Sent: Wednesday, March 05, 2008 1:50 PM ~~ ~~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: RE: Removal of Storm Choke from SHP M-2 gas well Thanks Jim. This all sounds good to me. We`II make sure to keep the SSV intact and make sure the timing deadlines are met. The results of our testing, bailing, treatment, etc might lead to a redesign for the storm choke or it might not. We°II know a lot more when we see what the downhole condition of the well really is. If a redesign is warranted; we'll make sure that ail that paperwork goes through you guys for reviewlapproval. Thank again for the quick turnaround, Jim. Larry (~7-~~t From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, March 05, 2008 1:27 PM To: Greenstein, Larry P Cc: Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay ~~~ ~~~ Q Z~Q~ Subject: RE: Removal of Storm Choke from SHP M-2 gas well Larry - Thank you for the notice. As we discussed this morning via phone, it was appropriate for Chevron to contac# us about the planned activities to make sure the scope of work is consistent with the Commission's existing policy regarding removal of SSSV. TBU M-02 does have aCommission-approved storm choke due to the failure of the surface controlled SSSV. I understood you to say that the wail is loading up and requires periodic blowdowns to remove water so gas production can be restored. As part of the fix, Chevron will need to redesign the M-02 storm choke. Our existing guideline allows for the removal of a SSSV for not longer than__15 days for routine well work subject to a properly functioning surface safety valve. I agree that the work contemplated while the storm choke is out of well M-02 constitutes routine well work necessary to restore gas production. Please make sure the we44 is tagged showing the date and reason for removal of the storm choke. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Wednesday, March 05, 2008 11:20 AM To: Regg, James B (DOA) Subject: Removal of Storm Choke from SHP M-2 gas well Jim, 3/5/2008 Removal of Storm Choke from S M-2 gas well Page 2 of 2 Due to some remedial work engine has planned for M-2, the storm choke wed to be pulled from the well to allow wellbore access. It will be sent to the beach for redressing and reinstalled in the well within 14 days. Shortly after reinstallation, the platform will be arranging for an inspector to witness a performance test of the reinstalled storm choke. While the storm choke is out of the well, a number of different events may occur. These include blowing down the well to remove a column of water off the perfs, running a gauge ring to tag fill, running a bailer to either gain some extra depth or at least grab a sample of the fill, performing flow tests on the well to see if unloading rates can be maintained, etc. Depending on the analysis of the fill, a chemical treatment may be warranted. Throughout the duration of these events, the SSV functions will be maintained. Thanks Jim. Larry 3/5/2008 e /'?7¿?¿1 FRANK H. MURKOWSKI, GOVERNOR A"~ASIiA OILAIWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 March 31, 2006 Mr. Jeff Smetanka Reservoir Engineer U nocal Alaska PO Box 196247 Anchorage, AK 99519 ""Ii" Re: Trading Bay Unit ("TBU") M-2 (187-061) Subsurface Controlled Subsurface Safety Valve ("SCSSV") Dear Mr. Smetenka: Unocal Alaska ("Unocal") requested by letter dated March 14, 2006 Alaska Oil and Gas Conservation Commission ("Commission") approval of an alternate subsurface safety valve as allowed in 20 AAC 25.265 (a)(2) for the subject well. Unocal's request to employ a subsurface controlled subsurface safety valve ("SCSSV") is GRANTED. Due to a control line failure, it is not possible to employ a standard subsurface control valve in TBU M-2. Since the well has an offshore surface location, a surface controlled subsurface valve is required. As an alternate, Unocal proposed to employ a SCSSV. As detailed in their application letter, a valve has been deployed and successfully demonstrated the ability to halt gas flow from the well when the pressure above the valve is reduced below the established set point. Unocal has also provided a proposed testing procedure for the SCSSV in M-2. " The Commission has completed its review of your request and finds that the proposed SCSSV is capable ofh ing flow from the well and is hereby approved to be used in TBU M-2 (187-061). ~þ of i pproval should be maintained on Steelhead Platform. / ~ Daniel T. Seamount, Jr. ömmlSSlOner cc: Larry Greenstein, Unocal Chevron e e Jeff W. Smetanka Reservoir Engineer Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7622 Fax 907 263 7847 Email smetankaj@chevron.com 2006 March 14, 2006 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 M-2, MCARTHUR RIVER FIELD SSCSV APPROVAL REQUEST Dear Mr. Maunder: As we have discussed, Union Oil Company of California has successfully installed and tested a subsurface-controlled subsurface safety valve (SSCSV) in gas well M-2 on the Steel head platform, and now respectfully requests the Commission's approval of this installation under regulation 20 MC 25.265(a)(2). Well Historv The M-2 well shut in on November 20, 2005 due to an apparent problem with the surface- controlled subsurface safety valve (SSSV). After various diagnostic tests, it was determined that the control line to the SSSV had lost its integrity. Notification was made to the Commission at this time and the well was left shut in. After discussion with the Commission, a plan was approved to lock open the SSSV so that the well could be flow tested and various pressure transient and gradient surveys could be performed. The initial test was made on December 29, 2005. Based on that information, it was determined that an extended test was required to properly assess the well performance, and this was performed from January 26, 2006 through February 4, 2006. The extended test indicated that sufficient gas rate and flowing tubing pressure could be maintained from the well such that a storm choke could be utilized to provide automatic shut-in capability to prevent an uncontrolled flow. Several attempts were made in February 2006 to install and test a storm choke in M-2. The early attempts failed due to either mechanical problems with the equipment or incorrect set pressures. On February 28, 2006, a ilK" type storm choke was installed in M-2 and successfully closed when the flowing tubing pressure dropped to 140 psig. The closing test was repeated twice, with the well shutting in at 143 psig and 135 psig. Notification was made to the Commission that the storm choke had been successfully installed and tested and a request was made to the Commission to schedule a witnessed test. Attached is the test sheet for the closing test conducted on February 28. Union Oil Company of California I A Chevron Company http://www.chevron.com Mr. Maunder _ Alaska Oil and Gas Conservation Commission March 14, 2006 Page 2 e Test Procedure The following test procedure is provided to the Commission for suggested future testing of the M-2 well. We recommend that the M-2 well be tested along with the other Steelhead wells on the normal 6 month interval. Note that the well needs to be directed to flare before testing the SSCSV to avoid shutting down the compressor due to low suction when the valve closes. The recommended procedure is as follows: 1. Shut in the well and line up M-2 header to the test separator. 2. Isolate the test separator from the process and line it up to the high pressure flare. 3. Bypass the surface safety pilot. (This valve could be tested at this time if required.) 4. Adjust the separator pressure as required to allow adequate differential for well to flow properly. 5. Start flowing the well through the separator and out to the flare. 6. Using a trending chart, bring the tubing pressure down until the K-Valve closes. Document closing pressure. 7. Close the wing valve on the flowline. 8. Monitoq~ressure on the swab valve gauge to verify valve is holding. 9. Inject gas pressure into the tubing through the swab valve to re-open the K-Valve. 10. Remove the bypass on the surface safety pilot control. 11. Realign well to process. Thank you for your efforts in working with us on this project. If you have any questions, please contact me at 263-7622. cc: Dave Whitacre Johnny Santiago Glen Paÿment Larry Greenstein Union Oil Company of California I A Chevron Company http://www.chevron.com ~ka Oil and Gas Conservation commisw' n . Safety Valve System Test Report Submitted By: Steve Tanner Field/Unit/Pad: TBU / Steelhead Platform Separator psi: Oil Date: 2/28/2006 Operator: UNOCAL Operator Rep: Steve Tanner AOGCC Rep: None Gas 85 Well Dl,ta Pilot.'ì SSV SSSV Test/Rete.\·tISl Date Well Type Well Permit Separ Set LIP Test Test Test Date Tested and or GINJ, GAS, Number Number PSI PSI Trip Code Code Code Passed Retest or SI CYCLE, SI M-01 1870460 M-02 1870610 85 140 140 LIP Trip @ 140/143/135 GAS M-03 1891110 M-04 1900710 M-05 1891330 M-07 1920590 M-09 1961270 M-12 2011760 M-13 1890490 M-14 1890570 M-14RD 2011710 M-15 1901090 M-16 1971620 M-19RD 1931170 M-25 1870860 M-28 1900190 M-29 1910270 M-31 1931900 M-32RD 1990970 Wells: Components: 1 Failures: o Failure Rate: 0.00% 090 Day This is a "K" valve installation. No AOGCC rep present. Remarks: Page 1 of 1 M-2 SSSV Test Re: Steelhead Safety Valve Test for M-2 Gas Well e ~~ 1~7-0fol Subject: Re: Stcclhead Safety Valve Test for M-2 Gas Well From: James Regg <jim_regg@admin.statc.ak.lls> Date: Wed, 08 Mar 200613:27: II -0900 To: "Tanner, Steve L" <tanncsl@chevron.com> CC: Charles M Scheve <chuck..ßcheve@admin.state.aklls> According to our records, the platform should be due for its 6-month SVS testing this month. We would prefer to witness the M -02 test at that time. We have requested a formal test procedure from Jeff Smetanka. Our preference would be to test the entire Steelhead SVS sometime the week of 3/20/06. Please advise. Jim Regg AOGCC Tanner, Steve L wrote: \j Steelhead Platform M-2 Gas Well SSSV 3-2-06 Mr. Regg and Mr. Fleckenstein We have just gotten our M-2 gas well back to production and stabilized with the installation of a "K" valve. Please at you convenience, choose a time you may wish to come out and witness this SSSV. Thank You, Steve Tanner Lead Operator Steel head Platform 907-776-6834 I of I 3/8/2006 I :27 PM FW: M-2 procedure: Diagnostics and install storm choke e e ~ ..0t 5 r- Obi Subject: FW: M-2 procedure: Diagnostics and install stonn choke From: "Smetanka, JeffW" <smetankaj@unocal.com>., Date: Fri, 01Feb 2006 14:13:14.,.0900, Ìío: James R imhregg@a '. ..·....._maurið~~@åQ:rµiÌ1.ståte.:~.u~:;?\ ëc: "payme n A" <pa~ . aLcom:>\. '; anner, , "J~:6taríneseaLco "Whitacre, p . whitacred@uriocaLêöm>,'~Santiªgo, Johnny T"<sanf . nocal;;,. >,.. "Darkwah, ..."" <darkwah~@ut1ocaLcom~,,'.~MYers, C~,i~.'~kmYerscriocaLcöm> Jim, As per our discussion this afternoon, the following is our plan for M-2. Glen and Steve - this is our approved plan forward. Pollard will be coming out at 7 AM tomorrow to run a flowing gradient survey and 24 hour pressure buildup. We will also be making a tag for sand and inspecting surface equipment for sand, scale, iron sulfide, etc. All of this information will be used to determine the set pressure for the storm choke. If all looks well, we will set the storm choke following the buildup and then return to production. If it appears that the well has scale/iron sulfide in the tubulars, we plan to flow the well at higher rates for a day or two prior to running the storm choke. This will be done to clean the well prior to installing the choke. I will contact you Monday if that is the case. Note that our procedure did not get executed earlier this week due to a problem with M-31 that required a rig skid which interfered with slickline operations. Thank you, Jeff Smetanka C c.> [' (.' From: Smetanka, Jeff W Sent: Wednesday, February 01, 2006 12:06 PM To: Payment, Glen A; Tanner, Steve L; Chivers, Mike W; Brown, Glynn B; Butler, John -Pollard Wireline; Myers, Chris S; Santiago, Johnny T; 'Stone, Todd Do' Cc: Darkwah, Samuel A; Tyler, Steve L; Bindon, Phil E; Whitacre, Dave S; Hillegeist, Tony K -PRA; Novcaski, RichW Subject: M-2 procedure: Diagnostics and install storm choke Attached is a procedure to conduct diagnostics work on M-2 and to install the storm choke. Also attached are results from higher drawdown flow period today. Note that the well was tested today at higher drawdowns and showed some sand on the sand monitors. The diagnostic work in the attached procedure includes a flowing gradient, pressure buildup, drop leg inspection, flow control valve inspection and bailer sample. Please email/call back with any comments or questions. Thanks, Jeff Content-Description: M2 slickline_020106.doc Content-Type: applicationlmsword Content-Encoding: base64 Flow test for storm choke.ppt Content-Description: M-2 Flow test for stonn choke.ppt 10f2 2/6/2006 9:26 AM FW: M-2 procedure: Diagnostics and install storm choke e 20f2 Content-Type: Content-Encoding: e applicationlvnd.ms-powerpoint base64 2/6/2006 9:26 AM e e Date: 2/1/06 Version 1 M-2 Flowina aradient survey, PBU, Check sand lea and FCV, Run storm choke Objective: Conduct diagnostic work on well. Install storm choke. Notes: The high drawdown test of the well on 2/1/06 (down to 118 psi FTP) led to high sand readings on the monitor. The sand leg needs to be inspected for evidence of formation sand, gravel pack sand, iron sulfide, etc. The flow control valve needs to be inspected for same and for evidence of erosion. The flowing gradient survey will assist in determining flow characteristics of the well for unloading purposes. A pressure buildup will improve knowledge on inflow performance for the well. The storm choke needs to be installed after the diagnostic work as per AOGCC regulations and communications. Minimum ID's are 2.813" "X" Nipple at 4465' 2.992' at 4509' 4.000" at 3538',3710',4105',4422' Effective PBTD is fill tagged at 4405' Contacts Name Sam Darkwah Jeff Smetanka Office 263-7864 263-7622 Home 248-9825 346-3320 Cell 301-0811 223-6058 Procedure 1. Rig up lubricator and pressure test to 1,000 psi. 2. RIH with dual gauges to 4000' for flowing gradient survey, making 5 minute stops at lubricator, 300', 400', 1000', 1500', 2000', 2500', 3000', 3500', 3600', 3700', and 3850'. 3. Flow well for 30 minutes with gauges at 4000'. 4. Shut well in for pressure buildup with bombs at depth. 5. Leave well shut in for 24 hours. During this time, inspect sand leg on flowline for solids. Take photo of solids and send in to Jeff and Sam. Save sample of M2 slickline 020106-l.doc e e solids - may request to send to Anchorage. Inspect flow control valve for solids and for evidence of erosion. 6. After 24 hour shut-in, POOH with pressure bombs, making stops at 3500', 3000', 2000' and the lubricator. 7. RIH with 2-1/2" bailer and tag. (Note: last tag was at 4405' KB) Bail sample. 8. Contact Jeff or Sam with information on depth and bailed material and to discuss next steps. Based on all information, additional higher drawdown flow periods may be made prior to storm choke installation to ensure that wellbore is cleaned up first. 9. RIH and pull isolation sleeve across SSSV. 10. Brush SSSV profile as necessary to enable set of lock-out spacer tube and storm choke. Note: Unless modified by information obtained in flowing gradient survey, storm choke should be set to close at 140 psig. 11. Fax WSR's in daily to Jeff Smetanka and Sam Darkwah's attention at 263-7847. 12. Rig down slick line unit and contact Jeff Smetanka or Sam Darkwah. M2 slickline 020106-1.doc e M-2 Flow test for storm choke 2/1/06 M2 low FTP results Dropped FTP on M·2 from 170 to 118 psi to determine rate and if sand production Sand monitor jumped from 0 to 150#lday at about 125 psi FTP Pinched well back - sand began to drop off within about 30 minutes Platform personnel are concemed about having the storm choke closing point too close to normal operation conditions - want to avoid a sudden SID of the well and possibly taking down a compression train. Based on this information, recommend setting storm choke to an effeclive 140 psi FTP (15 psi above high sand event and 30 psi below normal operating pressure) Will make final determination of set pressure after receive all diagnostic information e 1 Re: M-2 flow testing f"J \ 1't1lD 4' Subject: Re: 1\1-2 nov\'o testing . ~t21q \ From: James Rcgg <jim_rcgg(i:(:admin.statc.ak.lIs> Date: Fri, 27 Jan 2006 17: 13:30 -()900 To: "Smctanka, JefTW" <smctankaj@unocal.con':> CC: Tom Maunder <tom.. mallnder@admin.state.ak.lIs> prt"#- ~7-o~, Thank you for the call and email. Since stabilized flow and representative pressures are critical to the settings of the subsurface controlled safety valve (storm choke), additional time is appropriate. Your request is approved. Please advise when you have installed the storm choke or if you encounter any difficulties. Jim Regg AOGCC t... ., 1?'i ::jçt'\NÌi:'~cL' " Srnetanka, JeffW wrote: Jim, As we discussed today on the phone, we started our flow test of the M-2 well yesterday about 2:30 PM. The well is currently flowing at 4 mmcfd and 172 psi flowing tubing pressure, with about 20+ bwpd. We request approval to continue the flow test over the weekend and into next week. Our plan is to let the water rates stabilize and then run a flowing gradient survey on Tuesday or Wednesday, which would be followed by the installation of the storm choke. If the extreme cold weather continues, we would like to continue to flow for a few more days prior to shutting the well down for any slickline work. Thank you, Jeff Smetanka Reservoir Engineer Union Oil Company of California 909 West 9th Avenue, Anchorage, AK 99501 Tel 907 263 7622 Fax 907 263 7847 Mobile 907 223 6058 smeta n kaj@chevron.com 1 of 1 1/27/20065:13 PM Re: FW: Steelhead M-2 SSSV e - ~ I ít)\Ob - ~t11 )C/\V Suhject: Re: FW: Steelhcad \·1-2 SSSV From: James Regg <jim..rcgg({(aclmin.statc.ak.lIs> Date: \Vcd, 28 Dcc 2005 16:39:05 -0900 To: "Chivers, Mike W" <chivenwII·@lInoca1.com> CC: Tom ~v1aundcr <tom_maundcr@admin.statc.ak.us>, "Santiago, Johnny T" <santiagon~illnocal.com>, "Paymcnt, Glen A" <paymcgagunocal.com>, ''Tanncr, Steve L" <tanncsl':fl;:unocal.com>. "Smctanka, JeIT \V" <smetankqj~~t)m()cal.coI11>, "Darkwah, Samllcl X' <dark\,,·ahs·~~~}unocal.com>, "\/lcycr, Todd S" <meycrtsgllnocal.com>, "Gardner, Kim D" <kgard ner(ª~unoca1.com> Mike and others - .prþ~ 187-ð(p Thank you for the notîce and procedure planned for TBU M-02. My read of the Commission's regulations at 20 AAC 25.265(a)(2) [excerpt attached] indicates the installation of anything other than a fail-safe automatic surface-controlled subsurface safety valve (SCSSV) requires Commission approval. When Unocal makes its decision regarding the type of valve to replace the SCSSV, we will need an approval request and information that demonstrates the new valve's equivalent capability for preventing uncontrolled flow ifit is other than a SCSSV. >Prom my understanding, there exists legitimate concern about the proper set up of subsurface controlled subsurface safety valves. The models used to "size" the valve can result in significant errors because ofthe variability and uncertainty of inputs (mechanical configuration of valve; fluid flow composition; pressures), resulting in the device not providing the intended (required) level of protection. The type of test and testing frequency are also questîons that are different with subsurface controlled valves; we expect would testing to also be addressed as part of a request. Your request should come to the Commission in writing. While email may be sufficient (with supporting information), a letter (with supporting information) addressed to the Commissioners would be more appropriate. Jim Regg AOGCC Chivers, Mike W wrote: ~"". fpGA)!~~~EU ' <I> Mr. Fleckenstein and Mr. Regg Our engineering staff has a plan to do wire line work on Gas well M-2. It witl require shifting the SSSV open manually with slick line, then pinning it open temporarily for some testing. I will attach the procedures for your review. This will be for testing purpose only and will be shut back in until a storm choke or equivalent is set in place before flowing on a permanent basis. We will keep you informed of our progress. Please note that we have a successful test of the SSV last month. «M2 slickline_121605.doc» «M-2 Actual 11-7 -OO.doc» Sincerely Mike Chivers Steel head Platform 907-776-6834 lof2 12/28/2005 4:39 PM Re: FW: Steelhead M-2 SSSV I e e From: Chivers, Mike W Sent: Friday, December 02,200511:00 AM To: Robert Fleckenstein; Jim Regg AOGCC Cc: Payment, Glen A; Santiago, Johnny T; Tanner, Steve L Subject: Steel head M-2 SSSV Mr. Fleckenstein, Mr. Regg We shut down Steel head Gas Well M-2 due to the control line going to the SSSV has parted somewhere under the hanger. We are unable to flow the well due to this. We will keep you informed of any work we plan to do on this problem. Sincerely Mike Chivers Lead Steelhead Platform Cook Inlet Alaska Chevron Mid Continent Div. . (907) 776-6834 Content-Type: application/pdf 20AAC25-265.pd Content-Encoding: base64 2of2 12/28/2005 4:39 PM FW: Steelhead M-2 SSSV e e p¡t:#¡2>7-00 { Subject: FW: Steelhead M~2 SSSV From: "Chivers, Mike WIt <ehivemw@unoeal.eom> ~ate: Fri: 16 Dee 2005 16:06:41 -0900 '" .. '" '4i.l,Q.j..:.·.k...:.::......~;IZ~..~.:.¡tft{\Jç ~~~ Fl~ekens::t:.:::;fle~kenst:~ìÌ1@a~Ì1ih)tate.~.us:>~.. ~~gAOGCC ~ l' qç: riYT" <santiagoj@üno >,"Paym nt, Glen i" <paymega@unoeal.eo .' .. .. . .. .".'.... . ::t "t t .,,·<tannesl@unoeali~~m>; . ..... etånka, Jeff sme~ånkaj@unoea1.eom;:>, <". "mar. ah, Samuel A" <darkThs@lioeal;toIll>, "Mey " II <meyerts@'aLeOln>~. "parq;n~r, Ki:m:Ð'~<kgardner@unoei1.eo~t .. . <~ Mr. Fleckenstein and Mr. Regg Our engineering staff has a plan to do wire line work on Gas well M-2. It will require shifting the SSSV open manually with slick line, then pinning it open temporarily for some testing. I will attach the procedures for your review. This will be for testing purpose only and will be shut back in until a storm choke or equivalent is set in place before flowing on a permanent basis. We will keep you informed of our progress. Please note that we have a successful test of the SSV last month. «M2 slickline 121605.doc» «M-2 Actual 11-7-00.doc» Sincerely Mike Chivers Steelhead Platform 907-776-6834 ~"'h~Ijj\,.~~\ßCI·"· . ~~V1D1Jti \!l1;;;~:.-. ( From: Chivers, Mike W Sent: Friday, December 02,200511:00 AM To: Robert Fleckenstein; Jim Regg AOGCC Cc: Payment, Glen A; Santiago, Johnny T; Tanner, Steve L Subject: Steel head M-2 SSSV Mr. Fleckenstein, Mr. Regg We shut down Steel head Gas Well M-2 due to the control line going to the SSSV has parted somewhere under the hanger. We are unable to flow the well due to this. We will keep you informed of any work we plan to do on this problem. Sincerely Mike Chivers Lead Op Alaska Mid if (907) 776-6834 Content-Description: M2 slickline _121605.doe slickline 121605.doc Content-Type: applieation/msword Content-Encoding: base64 lof2 12/19/2005 12:49 PM FW: Steelhead M-2 SSSV e e Content-Description: M-2 Actual 11-7-00.doe Actual 11-7-00.doc Content-Type: applieation/msword Content-Encoding: base64 20f2 12/19/2005 12:49 PM e e Date: 12/16/05 Version 1 M-2 - Lock open SSSV. taa. run static aradient. flow test. continaent flowina aradient Objective: Measure static reservoir pressure and look for fluid level. Determine if well will flow and at what pressures. Determine if a storm choke can be used in place of the tubing retrievable SSSV. Notes: The M-2 well has been shut in since 11/22/05 due to an apparent parted control line below the hanger, which has closed the SSSV. The well has 5-1/2" tubing and produces some water. It is possible that a storm choke could be installed to restore subsurface safety capability, but it is unknown whether the well is capable of unloading and flowing on its own. To make this determination, we plan to lock open the SSSV, find the fluid level and measure reservoir pressure, and attempt to unload and flow the well with the SSSV locked open. Based on these results, a longer term plan can be made. The SSSV or a storm choke will be reinstalled following this procedure. Minimum ID's are 2.813" "X" Nipple at 4465' 2.992' at 4509' 4.000" at 3538',3710',4105',4422' Effective PBTD is top of cement at 4880' (20' on top of EZSV) Contacts Name Sam Darkwah Jeff Smetanka Office 263-7864 263-7622 Home 248-9825 346-3320 Cell 301-0811 223-6058 Procedure 1. Rig up lubricator and pressure test to 1,000 psi. 2. Pressure up on tubing to equalize pressure across the SSSV. 3. Run and install 5-1/2" tubing lock and 2-7/8" spacer pipe and set in top profile of 5-1/2" tubing retrievable SSSV, to lock open the SSSV. 4. RIH with 2" bailer and tag bottom. Record depth on WSR. (expected tag depth is top of cement at 4880') M2 slickline 121605-l.doc e e 5. RIH with pressure gauges for static gradient survey, making 5 minutes stops in the lubricator, 1000',2000',2500',3000',3500',3660',3885',4020', and 4335'. 6. After 30 minute stop with gauges at 4335', POOH with gauges. 7. RD Wireline and prepare for flow test of well. 8. Line up well to test separator and prepare hot sheet to record gas and water rates and tubing and casing pressures every 15 minutes. 9. Flow test well. Attempt to establish production from well at rates above the unloading rate (see chart on last page). Approximate unloading rates are 3.1 mmcfd at 200 psi, 2.7 mmcfd at 150 psi, 2.2 mmcfd at 100 psi, and 1.5 mmcfd at 50 psi. 1 O.lf unable to flow well to compression, direct well to flare to attempt to unload. 11. Utilize gas lift on well if necessary, to establish production. 12.lf sustainable production cannot be established, then shut well in, pull X lock and spacer pipe, and go to step 22. 13.lf sustainable production is established and flowing tubing pressures never drop below 50 psi, then shut well in, pull X lock and spacer pipe, and install storm choke, and go to step 22. 14.lf sustainable production is established, but flowing tubing pressure had to be dropped to below 50 psi, then proceed with next step to run flowing gradient survey. 15. Shut well in. 16.RU Wireline. RIH with pressure gauges to 315'. 17. Unload and flow well with gauges located just above SSSV. 18. Continue to flow well for 2 hours after stable production rates are established. 19. Shut well in. POOH with gauges. 20. Pull X lock and spacer pipe from SSSV. 21.lnstall storm choke with closing pressure set based on analysis of pressure gauge data. M2 slickline 121605-l.doc e e 22. Fax WSR's in daily to Jeff Smetanka and Sam Darkwah's attention at 263-7847. Email gauge data to Jeff and Sam as well. 23. Rig down slick line unit and contact Jeff Smetanka or Sam Darkwah. Minimum Flow Rates for Unloading Water (.56 gravity gas, 55 F) 3.0 . 4.0 . c u. o ::;¡ ::;¡ i '" II: ~ 2.0 . o ¡¡: E " E ï= :¡¡ 1.0 1" 0.0 o 50 100 150 200 250 Surface Pressure, psi M2 slickline 121605-l.doc UNOCAL8 9 10 11 12 B-2 B-3 15 16 17 18 19 ~" . ~M·-·-- - C-4 D·;; . -- . . D->!! ~.~ i :~ . ~ ~L v ~:, ~ VIII K¥-!9\Ž;ttr~P1'I-7 -00-1 Jße 7,510' RE~OLE ANGLE = 44° DRAWN BY: TCB e All three KOIV's knocked out Long String EZSV @ 4,900' DIL Short String EZSV @ 4,980' DIL SIZE 13-3/8" 10-3/4" 9-5/8" Tubing: 5-1/2" ~:I~i~Y Unit Completed 11/7/00 CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. 1,895' 508' 7,510' Surf Surf 43.5-47 N-80 Butt 8.681 508' 15 J-55 Csg Butt 4.960 Surf 3,538' .JEWELRY DETAIL NO. Depth ID Item 1 73.78' 5.040 11" x 5-1/2" FMC TC-60 Hanger, CIW Type H 2 333' 4.562 SSSV, 5-1/2" Baker, TSME-6 Tubing Ret. WI X-Profile 3 1,124' 4.653 GLM, 5-1/2" MM SFO-2, RK Latch, R-2 Valve 4 2,250' 4.653 GLM, 5-1/2" MM SFO-2, RK Latch, R-2 Valve 5 2,847' 4.653 GLM, 5-1/2" MM SFO-2, RK Latch, R-2 Valve 6 3,483' 4.653 GLM, 5-1/2" MM SFO-2, RK Latch, R-2 Valve 7 3,538' 4.000 Snap Latch, Seal Assy. WI 5" R Nipple (4.000" J.D.) A-6 Gravel Pack 8 3,543' GR 4.800 Packer, SC-l R, Inclusive Gravel Pack Assembly 9 3,643' GR 4.892 Screen, 5-1/2" with 20/40 gravel pack sand down to 3,707' 10 3,710' GR 4.000 Snap Latch, Seal Assy. WI 5" R Nipple (4.000" J.D.) 8-2 and 8-3 Gravel Pack 11 3,704' GR 4.800 Packer, SC-IR, Inclusive Gravel Pack Assembly 12 3,881' GR 4.892 Screen, 5-1/2" with 20/40 gravel pack sand down to 4,103' 13 4,105' GR 4.000 Snap Latch, Seal Assy. WI 5" R Nipple (4.000" J.D.) 8-5 Gravel Pack 14 4,106' GR 4.800 Packer, SC-IR, Inclusive Gravel Pack Assembly 15 4,309' GR 4.892 Screen, 5-1/2" with 20/40 gravel pack sand down to 4,420' 16 4,422' GR 4.000 Snap Latch, Seal Assy. WI 80-40 Seal Ext (4.000" I. D.) 17 4,424' GR 6.000 Sump Packer, FB-l 18 4,465' GR 2.813 Nipple, 'X' 2.813" J.D. 19 4,509' GR 2.992 Overshot, 5-3/4" wi Over Size Guide Lower Existing Completion I 5,954' Packer, Dual, Baker A-5 II 5,999' 2.813 Nipple, "X" III 6,060' Carbide Blast Joints IV 6,957' Snap Latch, S-22 V 6,958' Packer, 9-5/8" x 3-1/2", Baker, "SC-l" (6' Seal Bore ext) VI 6,969' Crossover, 6-5/8" x 3-1/2" VII 7,003' 2.813 Nipple, "X" VIII 7,034' Wireline Entry Guide A 5,954' Packer, Dual, Baker A-5 B 5,970' Nipple, "XN" C 5,979' Wireline Entry Guide PERFORATION DATA (DIq ZONE TOP BTM AMT Condition A-6 3,660' 3,692' 32' 7", 18 spf B-2 3,885' 3,924' 39' 7" 18 spf B-3 4,020' 4,095' 75' 7" 18 spf B-5 4,336' 4,415' 79' 7" 18 spf Short String C-4 5,000' 5,060' 60' Proposed Isolated WI Retainer D-6 6,060' 6,112' 52' Plugged Long String D-2 5,558' 5,598' 40' D-3B 5,754' 5,794' 40' D-16 7,136' 7,172' 36' D-l7 7,227' 7,293' 66' Abandoned wi cement retainer Steelhead M-2 SSSV e e $- .Prt) ìß7- ð6{ Suh,jeet: Stcelhead M-2 SSSV From: "Chivcrs, Mike W" <chivcmw@lIl1ocal.com> ,I ,\ ¡ç' Datc: Fri, 02 Dce 2005 11 :00:22 -0900 ..{&~ \~ \1. L To: Robert Fleckenstein <bob_tleckcnstcin@admin.statc.ak.lIs>. Jim R~gg AOGCC <j im _rcgg@admin.statc.ak.us> cc: "Payment, Glcn A" <paymcga@:unocal.com>, "Santiago, Johnny T" <santiagoj@unocal.com>, "Tanner, Steve L" <tanncsl@unocal.com> Mr. Fleckenstein, Mr. Regg We shut down Steel head Gas Well M-2 due to the control line going to the SSSV has parted somewhere under the hanger. We are unable to flow the well due to this. We will keep you informed of any work we plan to do on this problem. Sincerely Mike Chivers Lead Op Steelhead Platform Cook Inlet Alaska Chevron Mid Continent Div. ir (907) 776-6834 5CANNED DEC 1 ß 2005 1 of 1 12/2/2005 12:50 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION Ct.,wlMISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: Gravel Pack 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 163' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: McArthur River field P.O. Box 196247, Anchorage, AK 99519 Service: Grayling Gas Sands 4. Location of well at surface 8. Well number 1,043' FNL, 603' FWL, Sec. 33, T9N, R13W, SM M-2 At top of productive interval 9. Per'mit number/approval number 2,600' FNL, 1,050' FWL, Sec. 33, T9N, R13W, SM 87-61/300-203 At effective depth 10. APl number Same 50-733-20389-00 At total depth 11. Field/Pool 922' FSL, 1,221' FWL, Sec. 33, T9N, SM Grayling Gas Sands 12. Present well condition summary Total depth: measured 7,510' feet Plugs (measured) Bridge Plug in Long String @ 4,900" true vertical 6,396' feet Bridge Plug in Short String @ 4,980' Effective depth: measured 7,204' feet Junk (measured) true vertical 6,183' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 727' 20" 1,395 sx 727' 727' Surface 1,895' 13-3/8" 1,253 sx 1,895' 1,860' Intermediate Production 7,500' 10-3/4" x 9-5/8" 3,800 sx 7,500' 6,390' Liner R~' ,,~., Scab Liner Perforation depth: measured See Attached true vertical F~-~ ,~ ~7 See Attached Alaska Oil & Yas Co~.,.;. Tubing (size, grade, and measured depth) - 4nchorag, e Packers and SSSV (type and measured depth) Baker SC-1 @ 6,958; Baker A-5 @ 5,954'; Baker FB-1 @ 4,424', Baker SC-IR @ 4,106', 3,704', 3,543';SSSV Baker 5-1/2" TR TSME @ 455' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 9~26~00 4,930 16 0 psi 625 psi Subsequent to operation 2/18/01 11,070 10 500 psi 384 psi 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Sign~ 1~ ./!O~m§gn Title: Ddlling Manager Date: Form 10-404 R~v 0~ ~'5/~'8 -- RIIRMIT RKB to TBG Head = 68,5' Tree connection: 4-1116' 5,000# ~B-5 __ A B C D-16 DRAWN BY: TCB All three KOIV's knocked out SIZE 13-3/8" 10-3/4" 9-5/8" 43.5-47 Tubing: 5-1/2" 15 73,78' 2 455' a 2.250' 5 2.847' 6 3.483' 3.538' 8 3.543' GR 9 3,643' GR l0 3.710' GR [ 1 3.704' GR [2 3,881' GR [3 4.105' GR Tradin Unit Well Completed 11/7/00 CASING AND TUBING DETAH, GRADE CONN ID TOP [4 4,106' GR [ 5 4,309' GR 16 4,422' GR 17 4,424' GR [8 4.465' GR 19 4,509' GR 1 5,954' I1 5,999' HI 6,060' IV 6,957' V 6,958' VI 6,969' VI] 7.003' A 5,954' B 5,970' C 5.979' Surf 1,895' Surf 508' 508' 7,510' N-80 Butt 8.681 J-55 Csg Butt 4.960 Surf 3,538' JEVOgLRY DETAIL ID Item 5.040 11" x 5-1/2" FMC TC-60 Hanger, CIW Type H 4.562 SSSV, 5-1/2" Baker, TSME-6 Tubing Ret. W/X-Profile 4.653 GLM. 5-1/2" MM SFO-2, IlK Latch, R-2 Valve 4.653 GLM. 5-1/2" MM SFO-2. RK Latch, R-2 Valve 4.653 GLM. 5-1/2" MM SFO-2, RI{ Latch~ R-2 Valve 4.653 GLM, 5q/2" MM SFO-2, RK Latch, R-2 Valve 4.000 Snap Latch, Seal Assy. W/5" RNipple (4.000" I.D.) A-6 Gravel Pack 4.800 Packer. SC-iR, Inclusive Grovel Pack Assembly 4.892 Screen. 5-1/2" with 20/40 gravel pack 6and down to 3.707' 4,000 Snap Latch, Seal A~sy, W/5" RNipple (4.000" I.D.) B-2 and B-3 Gravel Pack 4.800 Packer, SCqR, Inclusive Gravel PackAssembly 4.892 Screen, 5-1/2" with 20/4O gravel paak sand down to 4,103' 4,000 Snap Latch, Seal Assy. W/5" RNipple (4.000" I.D.) B-5 Gravel Pack 4.800 Packer, SC-tP~ Inclusive Grovel Paak Assembly 4.892 Screen, 5-1/2" with 20/40 gravel pack saud dowa to 4,420' 4.000 Snap Latch, Seal Assy, W/80-40 Seal Ext (4.000' I.D.) 6.000 Sump Packer, FB-1 2.813 Nipple, 'X' 2.813" I.D. 2.992 Overshot, 5-3/4" w/Over Size Guide Lower Existing Completion Packer. Dual, Baker 2.813 Nipple, "X" Carbide Blast Joints Snap Latch, S-22 Packer. 9-5/8" x 3.1/2", Baker, "SC-I" (6' Seal Bore ext) Crossover. S-5/8" x 3-1/2" 2.813 Nipple. "X" Wireline Entry Guide Packer, Dual. Baker A-5 Nipple, "XN'' Wireline Entry Guide 3,660' 3.692' 3,885' 3.924' 4.020' 4,095' 4.336' 4,415' String 5~000' 5~060' 6.060' 6,112' String 5.558' 5~598' 5~754' 5.794' 7.136~ 7,172' 7.227' 7.293' 9 7 18 spf 79' 7" 18 apl Steelhead M-2 Actual Perforations 11/7/00 Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments A-6 3,660' 3,692' 3,081' 3,105' 32' B-2 3,885' 3,924' 3,244' 3,273' 39' B-3 4,020' 4,095' 3,344' 3,400' 75' B-5 4,336' 4,415' 3,581' 3,641' 79' C-4 5,000' 5,060' 4,108' 4,160' 60' Isolated D-2 5,558' 5,598' 4,614' 4,651' 40' Isolated D-3B 5,754' 5,794' 4,795' 4,832' 40' Isolated D-6 6,060' 6,112' 5,080' 5,131' 52' Plugged D-16 7,136' 7,172' 6,119' 6,154' 36' Isolated D-17 7,227' 7,293' 6,209' 6,273' 66' Plugged 519' Well Work Summary Steelhead M-2 10/7/00 (Day 1) ~ RU E-Line on Short String. Test Lubricator to 2,500 psi. RIH and set 3-1/2" EZ- Drill at 4,980'. POOH. Move to Long String. Test lubricator to 2,500 psi. Attempt to run bridge plug. Bridge plug damaged at surface. Move to Short String. Bleed short string and fill with 6% KCI. RIH with CBL. Tag plug at 4,980'. POOH and Icg to 4,500'. Tyop of cement at 4,740' in tubing x casing annulus. POOH. Mu 2-1/8" Bailer. dump bail 20' of cement on plug. 10/8/00 (Day 2) Move lubricator to Long String. Test to 2,500psi. RIH and set 3-1/2" Bridge Plug at 4,900'. POOH. MU 2-1/8" Dump Bailer. Dump bail 20' of cement on plug. RD e-line. Bleed long string and fill w/fresh water w/6% KCI. Set BPV's. Nipple down tree. Nipple up BOPE. 1019/00 (Day 3) Cont. NU BOPE.. 10/10/00 (Day 4) Pressure test BOPE. Pull BPV's. Test Long and Short String plugs to 3,000 psi. Good Test. 250psi/3,000psi. RU to cut tubing. Rih and cut Short String at 4,550'. POOH. 10/11/00 (Day 5) RU on long string. RIH and cut at 4,516'. POOH. RD e-line. Circ. well to 6% KCI. Pull both hangers to floor w/150K. LD hangers. POOH dual to SSSV. LD SSSV. POOH and lay down long string. POOH with and lay down short string. Install 3-1/2" single rams. 10/12/00 (Day 6) Test 3-1/2" and Blinds 250psi/3,000psi. RU E-Line. Run CBL from 4,509'. RD e-line. MU 8-1/2" Mill, 9-5/8" casing scraper. RIH PU 3-1/2" DP. Tag long string stub at 4,517' DPM. Circulate well clean. 10113100 (Day 7) Cont Circ. Pump 75 bbl caustic sweep. Displace well to 10 NTU 6% KCI fresh water. POOH. MU Overshot Assembly, Tail Pipe and 9-5/8", Baker FB-1 Sump Packer. RIH on drill pipe. Overshot 3-1/2" long string tubing stub. Set Packer at 4,424'. POOH. MU packer plug, RIH. 10/14/00 (Day 8) RIH and set packer plug in packer at 4,424'. Dump sand on plug. Tag sand at 4,422'. POOH with running tool. Pre job safety meeting. PU Schlumberger, 7", 18 spf Tubing Conveyed Perforators. RIH and tie. Fill drill pipe for 400 psi underbalance. Set champ packer at 4,097'. RU Surface lines. Perforate B-5 4,336'-4,415'. Slight blow to bucket. PU and reverse circulate. Pull packer loose. Hole taking 12 BPH. 10115100 (Day 9) POOH. LD perforating BHA. RIH with casing scrapper. Reverse circulate and tag plug. POOH. MU packer plug pulling tool. RIH. Reverse circulate and engage plug. Drill pipe plugged. POOH wet with packer plug. 10/16/00 (Day 10) LD packer plug and pulling tool. MU Gravel Pack Assembly No. 1. RIH. Tag sump packer at 4,424'. Set SC-1 Packer at 4,106'. Pressure test lines to 6000psi. Slight leak at pump discharge. Pickel drill string. Repair leak. Re-pressure test lines to 6,000 psi. Good test. Perform injectivity test and design job parameters. Pump gravel pack. 10/17/00 (Day 11) Complete gravel pack with a total of 3,540 lbs of 20/40 sand, calculated sand top at 4,249' (15' above top screen). Circulate clean. POOH. LD gravel pack tools. RU E- Line. RIH and log top of SC-I. Packer at 4,105' GR. POOH. RD E-Line. PU Schlumberger, 7", 18 spf Tubing Conveyed Perforators with packer plug on bottom. 10118/00 (Day 12) RIH and tag SC-1 at 4,105' GR and drop off packer plug. Fill drill pipe for 400 psi underbalance. Set champ packer. RU Surface lines. Perforate B-2 and B-3 3,885'- 3,924' and 4,020'-4,095'. PU and reverse circulate. Pull packer loose, circulate out some gas through choke. Hole taking 8-10 BPH. RIH w/packer plug retrieving tool and casing scrapper. PU packer plug. POOH. Pulled tight at 4,062'. Work area with scrapper and clean up. POOH. 10119/00 (Day 13) LD packer plug and pulling tool. MU Gravel Pack Assembly No. 2. RIH. Tag SC-1 packer at 4,105'. Set SC-1 Packer at 3,704'. Pressure test lines to 6000psi. Pressure test lines to 6,000 psi. Good test. Perform injectivity test and design job parameters. Pump gravel pack. Attempt to shift crossover tool to reverse circulate position. Unable to move work string. Mobe fishing tools and APRS E-Line unit. 10/20/00 (Day 14) RU APRS. RIH with 2-1/4" chemical cutter. Severe drill pipe at 3,672'. POOH. RD APRS unit. POOH with 3-1/2" drill pipe work string. RIH with overshot. Engage fish at 3,672'. Attempt to jar free at 80K over and pull to 150K over. Move fish 3'. 10/21/00 (Day 15) Cont. jarring. No progress. Release fish. POOH. PU 6-1/4" drill collars and jars. RIH and re-engage fish. Attempt to jar free with out success. Release fish. POOH. 10/22/00 (Day 16) Add intensifier to BHA. RIH and re-engage fish. Jar 120-150K over with no movement. Release fish. POOH. MU 8-1/8" Shoe and Wash Pipe. RIH and wash over fish from 3,667'-3,691' (top of crossover tool). Reversed out 5 cf of sand off of crossover tool. POOH. F'EB 2 ? 200 Alaska 0il & Gas .Cons, (i}ornmissior~ 10/23/00 (Day 17) Anchorage Cont. POOH. MU overshot/jarring assembly. RIH and engage fish. Jar at 200Kover up weight and pull to 450K. Release from fish. POOH. Test BOPE 25013,000 psi. (Test waived by Lou Grimaldi w/AOGCC). 10/24/00 (Day 18) Complete BOPE test. MU 8-1/8" Burn Shoe and Wash Pipe. Mill Packer Setting Sleeve from 3,694'-3,695'. Circulate and POOH. Shoe in good shape. MU 8-1/2" Shoe. RIH. 10/25/00 (Day 19) Cont. RIH. Mill from 3,695'-3,697'. POOH. RIH w/overshot on 6-1/4" jarring assembly. Engage fish and jar. Pull to 450K. Pull fish free. POOH. Recovered crossover tool, seals, and 3ea. 3-1/2" pups. Left 345' of 3-1/2" inner string in hole. New TOF at 3,751' 10/26/00 (Day 20) MU spear to spear ID of 3-1/2" workstring. RIH. Work spear into fish. PU with 5-10K drag. POOH. No recovery. RIH w/4-1/16" O.D. overshot. Unable to latch 3-1/2" Inner String. POOH. Add extension to overshot. RIH. Engage fish at 3,751'. Jar fish 145K over string wt. Had 10' of movement then no more. 10/27100 (Day 21) Cont. jar on fish with no movement. Release fish, POOH. MU packer retrieving tool. RIH. Engage paker at 3,705'. Release packer and shear gravel pack safety joint. Losses at 65 bph. Pump 50 bbl flpovis pill. Losses down to 35 bph. POOH. LD SC-1 Packer. MU 7-5/8" Wash Pipe. RIH and washover screens from 3,755'-4,105'. 10/28/00 (Day 22) Circulate and recover 7 bbls of sand at surface. POOH. LD BHA. RIH withg overshot and engage screens at 3,739' DPM. Jar on fish to 290K. Pulled free. Monitor well, stable. POOH. LD fishing assembly and screens. Found washout in top screen. 10/29/00 (Day 23) Complete LD of screens. RIH w/3-1/2" Mule Shoe. Enter SC-1 Packer at 4,106'. Wash to 4,144' DPM. Circulate well clean to 6% KCI filtered to 25 NTU's. Losses at 8-12 bph. POOH. PU Gravel Pack assembly No 2 (repeat). 10/30/00 (Day 24) RIH with GP Assy No. 2 (Repeat). Latch into SC-1 at 4,106'. Set SC-1 Packer at 3,704'. Pressure test lines to 6000psi. Pressure test lines to 6,000 psi. Good test. Perform injectivity test and design job parameters. Pump gravel pack with a total of 8,984 lbs of 20/40 sand, calculated top of sand 3,871' (10' above top screen). POOH with toolstring. RU Schlumberger. 10/31/00 (Day 25) RIH and tag SC-1 at 3,708' GR. POOH. RD E-Line. PU Schlumberger, 7", 18 spf Tubing Conveyed Perforators. RIH and tag SC-1 at 3,704' and drop off packer plug. Fill drill pipe for 400 psi underbalance. Set champ packer. RU Surface lines. Perforate A-6 3,660'-3,692'. PU and reverse circulate. Pull packer loose, circulate out some gas through choke. POOH. Hole taking 4-8 BPH. Shell test BOPE 250/3,000 psi. per communication with Blair Wondzell AOGCC. MU packer plug retrieving tool. RIH w/packer plug retrieving tool and casing scrapper. PU packer plug. 11/1/00 (Day 26) POOH. Some damage noted on Packer Plug. Make dummy run with snap latch to ensure no damage to SC-1 Packer. RIH with S-22 Snap Latch. Engage SC-1 at 3,704'. Snap in and snap out w/10k per design. POOH. No damage to snap latch. RIH with GP Assy No. 3. Latch into SC-1 at 3,704'. Set SC-1 Packer at 3,543'. Pressure test lines to 6000psi. Pressure test lines to 6,000 psi. Good test. Perform injectivity test and design job parameters. 11/2/00 (Day 27) Pump gravel pack with a total of 3,901 lbs of 20/40 sand, calculated top of sand at 3,643'. POOH with toolstring. PU 2-7/8" Drill pipe and RIH to knok Out KOIV isolation valves. Clean out to 4,380'. 11/3/00 (Day 28) Stuck 2-7/8" clean out string at 4,321'. Attempt to jar free at 75k over PU. Straight pull to 150K. RU APRS. RIH to free point. Came free while free pointing. POOH with APRS. RD APRS. 11/4/00 (Day 29) POOH w/2-7/8" x 3-1/2" drill pipe. RIH w/2-7/8" DP and mule shoe. Creverse circulate to 4,150'. Plugged mule shoe. POOH. Clear KOIV debris from mule shoe. RIH w/ reverse circ. junk basket. Work junk from 4,150 to 4,155'. POOH. Recovered remnants of KOIV's. MU mule shoe. RIH. 11/5/00 (Day 30) Tag at 4,153', reverse to 4,157'. Plugged off. POOH. KOIV piece in mule shoe. RIH w/ 3-3/4" Tapered Mill. Work to 4,175'. POOH. MU Shoe with finger basket. RIH. Tag at 4,147' 11/6/00 (Day 31) Reverse circ. to 4,166'. POOH. Recovered 1 piece of KOIV. RIH. Reverse to 4,180'. Packed off. POOH. Recovered additional pieces of KOIV. RU to run completion. RIH with seal assembly, 5-1/2" Gas Lift Completion. MU SSSV. Rotate string to get seals into SC-1 Packer. 11/6/00 (Day 32) Stab seals into packer. Land hanger. Seat TWC. ND BOPE. NU tree. Test 250/5,000 psi. Release rig. 12/20/00 (Day 33) Alaska Oil & Gas C,~) :,:~, ¢:; ~ ~;rn :.;,~j,),,, Anchorag~ Move rig to M-2 ro repair failed SSSV. RU on M-2. RU E-Line. MU 2-1/8" Inflatable Bridge Plug. RIH to 3,598'. Attempt to set. Motor on inflate pump locked up. POOH. Packer had not initiated setting sequence. RD E-Line. 12/21/00 (Day 34) Fill tubing with 156 bbls Fresh Water w/6% KCI. Fill annulus w/195 bbls 6% KCI. Set BPV. ND tree. NU BOPE. Test BOPE 250/3,000psi. 12122100 (Day 35) Pump 100 bls 6% KCI down tubing. Retrieve BPV. Pull seals from packer w/130K. Pull tubing hanger to floor. Found control line had pulled out of connection below tubing hanger. Pulled to SSSV. Removed blanking assy. From valve. Function tested at surface. Re-run SSSV. Land Hanger. ND BOPE. 12/23/00 (Day 36) NU tree. Test 250/5,000 psi. Release well to production. Alaska Oil & Gas Cons. Comrnissior~ Anchorage 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: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: X Other: X Gravel Pack 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: X 163' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: McArthur River field PO BOX 190247 Anchorage, Alaska 99519 Service: Grayling Gas Sands 4. Location of well at surface Leg B-2, Cond. 3, Steelhead Platform 8. Well number 1,043' FNL, 603' FWL, Sec. 33, T9N, R13W, SM M-2 At top of productive interval 9. Permit number 1,420' FSL, 1,119' FWL, Sec. 33, T9N, R13W, SM 87-61 At effective depth 10. APl number 50-733-20389-00 At total depth 11. Field/Pool 922' FSL, 1,221' FWL, Sec. 33, TgN, SM Grayling Gas Sands 12. Present well condition summary Total depth: measured 7,510' feet Plugs (measured) true vertical 6,396' feet ORIGINAL Effective depth: measured 7,204' feet Junk (measured) None true vertical 6,183' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 727' 20" 1,395 sx 727' 727' Surface 1,895' 13-3/8" 1,253 sx 1,895' 1,860' Intermediate Production 7,500' 10-3/4" x 9-5/8" 3,800 sx 7,500' Liner Perforation depth: measured See Attached true vertical See Attached , , , Tubing (size, grade, and measured depth) Long String: 3-1/2", 9.3#, N-80, EUE @ 7,043'; Short String: 3-1/2", 9.3#, L-80, CS Hydril @ 5,979' Packers and SSSV (type and measured depth) Long String: SSSV Otis Series 10 @ 470', Short String: Same @ 440'; Baker SC-1 Packer @ 6,958', Baker Dual A-5 Packer @ 5,954' 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 9/15/00 16. If proposal well verbally approved: Oil: Gas: X Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. $igned.'~~~~DanWilliamson Title: DdllingManager * ' ~ FOR COMMISSION USE ONLY Conditions of approval:Notify Commission so representative may witness I Approval No. Plug integrity BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commissioner D Taylor ~mn, ,nf Commissioner Date -- Form 10-403 Rev 06/15/88 Approved Copy l~,~rned SUBMIT IN IPLICATE Steelhead M-2 Actual, Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments C-4 5,000' 5,060' 4,108' 4,160' 60' D-2 5,558' 5,598' 4,614' 4,651' 40' D-3B 5,754' 5,794' 4,795' 4,832' 40' D-6 6,060' 6,112' 5,080' 5,131' 52' Plugged D-16 7,136' 7,172' 6,119' 6,154' 36' D-17 7,227' 7,293' 6,209' 6,273' 66' Plugged 294' Steelhead M-2 Proposed Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments A-6 3,660' 3,692' 3,081' 3,105' 32' Proposed B-2 3,885' 3,924' 3,244' 3,273' 39' Proposed B-3 4,020' 4,095' 3,344' 3,400' 75' Proposed B-5 4,336' 4,420' 3,581' 3,644' 84' Proposed C-4 5,000' 5,060' 4,108' 4,160' 60' Proposed Plug D-2 5,558' 5,598' 4,614' 4,651' 40' D-3B 5,754' 5,794' 4,795' 4,832' 40' D-6 6,060' 6,112' 5,080' 5,131' 52' Plugged D-16 7,136' 7,172' 6,119' 6,154' 36' D-17 7,227' 7,293' 6,209' 6,273' 66' ~Plugged 524' Jnocal Alaska Business Unit Steelhead Platform Well No. M-2 Recompletion/Gravel Pack UNOCAL ) No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) ***Estimate does not include any facility costs.*** Pre -Rig slickline/E-Line RU slickline, run GR in short and long string. RU E-Line on short string. .RIH and set Bridge Plug at 4,990'. POOH. Rig down E-Line. Move Rig Prepare rig for workover. Leg move to M-2 Rig Workover 1 ND tree, NU and test BOPE 24.0 24 1.0 2 Engage SS Hanger. 1.0 25 1.0 3 RU APRS 1.0 26 1.1 4 RIH cut SS at 4,500'. POOH. 3.0 29 1.2 5 RD APRS. 1.0 30 1.3 6 POOH w/short string. 6.0 36 1.5 7 RU APRS. 1.0 37 1.5 8 RIH cut LS at 4,450'. POOH. 3.0 40 1.7 9 RD APRS. 1.0 41 1.7 10 RIH with 9-5/8" casing scraper while PU 5" drill pipe to 4,450'. 6.0 47 2.0 11 Circ displace well to comp. fluid and POOH with scraper 6.0 53 2.2 12 RU Schlumbeger and run CBL from 4,450' to 1500'. 6.0 59 2.5 13 No squeezing is anticipated in this AFE Estimate 0.0 59 2.5 14 RIH with SC-1 sump packer and tailpipe 6.0 65 2.7 15 Engage stub at 4,450' and set new sump packer at 4,429'. 2.0 67 2.8 16 Pickle drill pipe. 4.0 71 3.0 17 POOH with drill pipe 3.0 74 3.1 18 RIH with TCP guns on drill pipe 8.0 82 3.4 19 RU Schlumberger to tie-in guns at 4,336'-4,420' (84'). 5.0 87 3.6 20 Set packer, fire guns, release packer, circ to kill well. 6.0 93 3.9 21 POOH with spent guns 8.0 101 4.2 Page 1 of 2 8/4/00 ,Jnocal Alaska Business Unit Steelhead Platform Well No. M-2 Recompletion/Gravel Pack UNOCAL ) No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) 22 MU and RIH with 1st gravel pack assembly to 4,429' 20.0 121 5.0 23 Set packer at 4,105', pump gravel, circ drill pipe clean. 12.0 133 5.5 24 POOH with drill pipe and inner string 12.0 145 6.0 25 RIH set Packer Plug. Dump Sand. 6.0 151 6.3 26 MU TCP guns, RIH on drill pipe. 12.0 163 6.8 27 RU Schlumberger to tie-in guns at 3,885'-3,924' & 4,020'-4,095'. 5.0 168 7.0 28 Set packer, fire guns, release packer, circ to kill well. 6.0 174 7.3 29 POOH laying down guns 8.0 182 7.6 30 RIH, reverse out sand and recover plug, POOH. 6.0 188 7.8 31 MU and RIH with 2nd gravel pack assembly to 4,105' 20.0 208 8.7 32 Set packer ~ 3,704', pump gravel pack, circ drill pipe clean. 12.0 220 9.2 33 POOH with drill pipe and inner string 12.0 232 9.7 34 RIH set Packer Plug. Dump Sand. 6.0 238 9.9 35 MU TCP perfguns, RIH on drill pipe. 12.0 250 10.4 36 RU Schlumberger to tie-in guns at 3,660'-3,692'. ~ 5.0 255 10.6 37 Set packer, fire guns, release packer, circ to kill well. 6.0 261 10.9 38 POOH laying down guns 8.0 269 11.2 39 RIH, reverse out sand and recover plug, POOH. 6.0 275 11.5 40 MU and RIH with 3rd gravel pack assembly to 3,704' 20.0 295 12.3 41 Set packer ~ 3,548', pump gravel pack, circ drill pipe clean 12.0 307 12.8 42 POOH, laying down drill pipe and inner string 20.0 327 13.6 43 PU and RIH with 5-1/2" tubing completion to upper packer at 3,548' 8.0 335 14.0 44 Stab into upper packer, space out, land hanger 3.0 338 14.1 45 ND BOPE, NU tree 12.0 350 14.6 46 RU Coiled Tubing. 12.0 362 15.1 47 RIH, unload well with N2, POOH. 8.0 370 15.4 48 RD Coiled Tubing. 6.0 376 15.7 49 Release rig to move to M-5. Page 2 of 2 8/4/00 RKBto TBG Head = Tree connection: 4-1/16" 5,000g -- C4 F G H Dq~ =-D-16 WT Tradin ~ Unit Well Completed 10/87 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 43.547 N-80 Butt 8.68 Surf 1,895' Surf 508' 508' 7,510' Tubing: LS 3-1/2" SS 3-1/2" NO. 9.3 L-80 EUE 8rd 9.3 L-80 CS Hydril JEWELRY DETAIL Depth ID 2 3 4 456' 5 6 5,954' 7 5,999' 8 o.060' 9 6.957' 12 7,003' A B C D 423' E F 5.954' G 5.970' H 5,979' 2.813 2.813 2.992 Surf 7,034' 2.992 Surf 5,979' Item 1 l" x 3-l/2" Dual FMC TC450 Hanger, CIW Type H Long String Flow Coupling, Otis Sliding Sleeve, Ohs, "XXO' Flow Coupling, Otis SSSV, Otis Series "I 0" Flapper Flow Coupling, Otis Packer, Dual, Baker Nipple, "X" Carbide Blast Joints Snap Latch. S-22 Packer. 9-5/8" x 3-1/2% Baker, "SC-l" [6' Seal Bore ext' Crossover, 6-5/8" x 3-1/2" Nipple, "X' W~reline Entry Guide Short String Flow Coupling, Otis Sliding Sleeve, Otis. "XXO" Flow Couphng, Otis SSSV~ Otis Series "10' Flapper Flow Coupling, Otis Packer, Dual. Baker Nipple, "XN" Wireline Entry. Guide Annulus/tubing cemented to 4,630' to allow for C-4 Sand Perf PERFORATION DATA ZONE TOP BTM Short String C-4 5.000' 5,060' D-6 6.060~ 6.112' Long String D-2 5.558' 5,598' D-3B 5.754' 5~794' D-16 -.136' 7.172' D-17 7,227' 7.293' AMT Condition 60' 52' Plugged 40' 40' 36' 66' Abandoned w/cement returner PBTD = 7,204' TD = 7,510' M-2 ~'e~LE ANGLE = 44° REVISED: DRAWNBY: TCB RKB to TBG Head = Tree connection: 4-1/16" 5,000# iB-2 B-5 -- C--4 A B C -= D-6 D-16 -D-17 PBTD = 7,204' TD = 7,510' NJ-9 ~o~E ANGLE = 44° S[~E W~ Tradm y Unit Well M~ Proposed CASING AND TUBING DETAII~ GRADE CONN ID TOP BTM. 13-3/8" 10-3/4" 9-5/8" 43,5.47 Tubing: 5-1/2" 17 Depth 2 3 3.547' 4 3,548' 5 3,647' 6 3,703' 7 3,704' 8 3,872' 9 4,104' 10 4,105' Il 4,318' 12 4,429' N-80 Butt L-80 LT & C JEV~ELRY DETA][L ID Item Surf 1,895' Surf' 508' 8.681 508' 7,510' 3,546' 11" x 5-1/2" FMC TC-60 Hanger, CIW Type H SSSV, 5q/2' 4.000 Snap Latch, Seal Assy. W/5" R Nipple (4.000" I.D.) A-6 Gravel Pack 6.000 Packer, SC-I R, Inclusive gravel pack sliding sleeve 4.892 Semen, 5-1/2" with 16/20 gravel pack sand down to 3,703' 4.000 Snap Latch, Seal Assy. W/5" R Nipple (4.000" I.D.) B-2 and B-3 Gravel Pack 6.000 Packer, SC-1 R, Inclusive gravel pack sliding sleeve 4.892 Screen, 5-1/2" with 16/20 gravel pack sand down to 4.104' 4.000 Snap Latch, Seal Assy. W/5" R Nipple (4.000" I.D.) B-5 Gravel Pack 6.000 Packer, SC-I R, lnclusive gravel pack sliding sleeve 4.892 Screen, 5-i/2" with 16/20 gravel pack sand down to 4,429' 4.000 Snap Latch, Seal Assy. W/5" R Nipple (4.000" I.D.) 13 15 IV V Viii B C ZONE TOP BTM A-6 3,660' 3,692' B-2 3.885' 3,924' B-3 4,020' 4,095' B~5 4.336' &420 Short String C-4 5,000' 5,060' D-6 6,060' 6.112' Long String D-2 5.558' 5.598' D-3B 5.754' 5,794' D~I6 7,136' 7~172' D47 7.227' 7.293' 4,430' 6.000 Sump Packer, FB-I w/MOE 4.460' 2.813 Nipple. 'X' 2.813" LD~ 4.480' 2.992 Oversho[. 5-3/4" w/Over Size Guide Lower Existing Completion 5.954' Packer, Dual Baker A-5 5.999' 2.813 Nipple, "X" 6.060' Carbide Blast Joints 6,957' Snap Latch, S-22 6,958' Packet. 9-5/8" x 3-i/2", Baker."SC-l" (6' Seal Bore ext/ 6,969' Crossover, 6-5 8" x 3-I 2" %003' 2~813 Nipple, "X" 7,034' Wireline Entry Guide 5,954' Packer. Dual, Baker A-5 5,970' Nipple, "XN" 5.979' Wireline Entry Guide PERFORATION DATA AMT Condition 32' Proposed 39' Proposed 75' Proposed 84: Proposed 60' Proposed lsolated W/Retainer 52' Plugged 40' 40' 36' 66: Abandoned w cement retainer P,.EVISED: DRAWN BY: TCB Kill Line Line M-32 BOP Drawing.doc Revised by MWD 9117/99 Mud Return Equalizer Agitator Mud Gun Steclhead Pit Drawing~doc Revised by IVBVD 9/17/99 ----- STATE OF ALASKA '-' ALASKA O,,_ AND GAS CONSERVATION UOMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: NRWO 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL Development: X 163" KB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: McArthur River Field PO Box 190247 Anchorage, AK, 99519-0247 Service: Grayling Gas Sands 4. Location of well at surface 8. Well number 1043' FNL, 603' FWL, Sec. 33, T9N,SM M-2 At top of productive interval 9. Permit number/approval number 1420' FSL, 1119' FWL, Sec. 33, TN9, SM 87-61 At effective depth 10. APl number 992' FSL, 1221' FWL, Sec. 33, T9N, SM 50-733-20389-00 At total depth 11. Field/Pool Grayling Gas Sands 12. Present well condition summary Total depth: measured 7510' feet Plugs (measured) true vertical 6396' feet Effective depth: measured 7204' feet Junk(measured) ORIGINAL true vertical 6183' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 727 20" 1395 sx 727' 727' Surface 1859' 13-3/8" 1253sx 1895' 1860' Intermediate Production 7500 10-3/4" x 9-5/8" 3800 sx 7500' 6390' Liner Perforation depth: measured Short: C-4; $,000'- 5,060' Long: D-2; 5,558'- 5,598' D-3B; 5,754'-5,794' D..6; 6,060'-6,112' D-16; 7,136'-7,172' true vertical Short: C-4; 4,108' - 4,160' Long: D-2; 4,614'-4,651' D-3B;4,795'-4,832' D-6; 5,080'-5,131' D-16; 6,119'-6,154' Tubing (size, grade, and measured depth) Long: 3-1/2", 9.3#, N-80, EUE @ 7,034 & Short: 3-1/2", 9.2#, L-80, CS Hydril @ 5979' Packers and SSSV (type and measured depth) LS: SCSSV OTIS SERIES 10 (~ 470', SS: SAME (~ 440', BAKER SC-1 PKR ~ 6958', DUAL BAKER A-5 PKR (~ 5954' I'~ r' ~' I"' ! t I ~ ~ 13. Stimulation or cement squeeze summary Seventy (70) bbls 15.9 ppg cement placed in 9-5/8" x dual 3~,2[~ ~ r' ~ V ~' L) annuli for packerless completion. TOC calculated ~ 4,630'. Base of Intervals treated (measured) cement on top of dual packer (~ 5,954'. NO V 2 ~ '~996 Treatment description including volumes used and final pressure Alaska 011 & Gas Cons. Commission 14. Representative Daily Average Production or Injection Data A,uhuragu OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Attached Subsequent to operation 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: S. igned: Dale Haines Title: Drilling Manager Date: 11/19/96 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE M2 L&S Flow Data Production Test Prior to Recompletion: INTERVAL MMSCFD BWPD FTP (PSI) Csg (PSI) Date Long String: 4.51 0 548 0 7/21/96 D-16 Sand Short String: 7.7 0 559 0 7/21/96 D-6 Sand Production Test Prior to Recompletion: Long String: 14.64 0 550 0 8/28/96 D-2 Sand D-3B Sand D-6 Sand D-16 Sand Short String: 6.33 0 591 0 11/28/96 C-4 Sand RECEIVED Alaska 011 & Gas Cons. CommisBion Anchorage Page 1 Unocal Corporation ~ P.O. Box 196247 Anchorage, Alaska 9951Y 907-263-7676 UNOCAL Dale Haines Drilling Manager Thursday, August 1, 1996 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell' Steelhead Platform M-2 Unocal is submitting a new Sundry 10-403 form for previously approved well work on Steelhead Platform well M-2. The previous Sundry 10-403,96-137, was approved 15-July-96. Please note the top of cement change in the 9-5/8" by dual 3-1/2" annulus and the addition of the C-4 gas interval in the short string. If you have any questions, please contact the undersigned at 263-7676 or Steven Lambe at 263-7660. Sincerely, Dale Haines Drilling Manager GRS/leg RECEIVED AU(; 0 5 1996 Alaeka Oil & 6a8 Cmt~ ~ ----, STATE OF ALASKA ~-- ALASKA L,,,_ AND GAS CONSERVATION ~OMMISSION APPLICATION FOR SUNDRY APPROVALS ~'l'~1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator UNOCAL 3. Address P.O. Box 19-0247 Anchorage, AK 99519-0247 5. Type of well: Development: X Exploratory: Stratigraphic: Service: 4. Location of well at surface 1043' FNL, 603' FWL, Sec. 33, T9N, SM At top of productive interval 1420' FSL, 1119' FVVL, Sec. 33, T9N, SM At effective depth 992' FSL, 1221' FWL, Sec. 33, T9N, SM At total depth 6. Datum elevation (DF or KB) 163' KB above MSL feet 7. Unit or Property name McArthur River Field Grayling Gas Sands 8. Well number 9. Permit number 87-61 10. APl numbero~o~.~ ~--O<~ 50- 733~ 11. Field/Pool Grayling Gas Sands 12. Present well condition summary Total depth: measured true vertical 7510' feet Plugs (measured) 6396' feet Effective depth: measured true vertical 7204' feet Junk (measured) 6183' feet Casing Length Structural Conductor 727' Surface 1895' Intermediate Production 7500' Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 20" 1395 sx 727' 727' 13-3/8" 1253 sx 1895' 1860' 10-3/4" x 9-5/8" 3800 sx 7500' 6390' D-6, 6060' - 6112' D-16, 7136' - 7172' true vertical D-6, 5080' - 5131' D-16, 6119' - 6154' Tubing (size, grade, and measured depth) Long String: 3-1/2", 9.3~, N-80, EUE @ 7034' Short String 3-1/2'', 9.2~, L-80, CS Hydril ~ 5979' Packers and SSSV (type and measured depth) RECEIVED AUG 0 5 1996 Alaska 011 & 0ss Cons, ~mmi~len LS SSSV Otis Series 10 {~ 470', SS same type @ 440', Single Baker SC-1 pkr ~ 6958', Dual Baker A-5 pkr @ 5954' 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Blair Wondzell Name of approver 31 -July-96 Date approved Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ,,~~.-. ~,~~ Title: Drilling Manager Date: 01-Aug-96 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- ~O~ I Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston Ar~3rove~ CoPY ~eturned IApproval No. Commissioner Date SUBMIT IN TRIPLICATE Steelhead Platform Well M-2 Cement tubing strings in place to complete in shallower intervals By: T.E. Maunder / Revised by: S. Lambe Date: July 31, 1996 Revision #: 6, Final .Objective: Well M-2 is a dual completed well on Steelheack The long string presently is completed in the D-16 interval. The short string, completed in the D4 interval, has a fish lodged in the X nipple below the dual packer. It is intended to cement both tubing strings in place by plugging the short string near the packer, perforating the tubing, and coil tubing cementing below a retainer. This will allow shallower zones to be accessed in the short string by utilizing Schlumberger's POT-C oriented perforating system. Production from the D4 interval will be returned by perforating the long string above the blast rings opposite the production perforations. This procedure details: * Cementing the tubing strings in place above the dual packer. * Restoring the D-6 production by perforating the long string. * Completion of shallower intervals in the short and long string. Orient each crew to overall project scope and hold tailgate safety meeting at every operational changeover. NOTE: On June 23 - 24, 1996 a 2.70" gauge ring was nm mto both tubing strings on this well. 5925' WLM was reached in the short string and 6110' WLM was reached in the long string. According to Halliburton, the SL tool was "zeroed" at the tubing hanger.. The tubing hanger is approximately 34' below the skid deck which is about 38.4' below RKB. On this basis, the short string was gauged to 5997' RKB and the long string was gauged to 6182' RKB. These calculations indicate a discrepancy for the short string since a gauge ring is reported stuck in the X nipple at 5970' MD. A GR/CCL/TDT/ATC was then nm in the short string from 5900' - 3400' DIL. It is important to note that correhfion with the CCL proved to be difficult due to the same length of the tubing joints. A GR shenld be used for definitive EL correlation's. NOTE: SCSSV should be isolated with an auxiliary pressure source prior to commencing downhole operations to prevent wire cutting in the event of a Platform ESD. Take SCSSV off platform system and isolate with hand pump with control line pressure set at 3,800 psi. Fusible cap to be installed on master manumatic valve. NOTE: Prior to arming explosives and until exploMve~ are 300' in hole, establi~ all Unocal saf~ for handling explosives. Review and complete Perforating/Explosive~ Standard & Cheekl~ I M-2 7/31/96 2:39 PM Perform EL Work on Short and Long Strings: 1) Assure 9-5/8" annulus is full. Pressure test annulus to 1500 psi. Record test o~~leed pressure back to 50 psi. 2) RU E-Line umt, lubricator, and BOPs on long string. Pressure test to 2500 psi. 3) Bleed pressure and drain liquids. MU 35' of 1-9/16" 4 spf tubing puncher. SI long string and short string. Record pressure in both. RIH and perforate the long string between the X nipple at 5,999' and the blast joints at 6,052'. Pull GR & CCL correlation log from 6,100' up to 4,500' to verify jewelry prior to perforating. Monitor tubing pressure for communication. POOH with tubing punch and verify all shots fired. RD E-line from long string. 4) RU electric line, lubricator, and BOPs on short string. Pressure test to 2500 psi. Measure up a Baker bridge plug on an E4 setting tool dressed for 3-1/2' 9.3 # tubing. RIH and set bridge plug 25' above the dual packer ( 5, 954') at +/- 5,929'. Move bridge plug either direction to avoid collars. POOH and RD E-line. 5) Blow down short string to the low pressure production train and monitor for pressure build up. Fill short string with FIW. Pressure short string to 2500 psi. Bleed pressure back to 750 psi. 6) RU slickline on short string. Measure up Kinley tubing punch dressed with 1/2" punchers for 3- 1/2" 9.3 # tubing. RIH and punch robing above bridge plug with 3 ~ 1/2" holes. Use bridge plug as base for tubing puncher. Monitor tubing pressure to ensure communication to annulus. POOH and RD slickline. NOTE: Prior to pumping any non produced fluids, notify Trading Bay Production Facility of intent to pump FIW and Biozan. Fill out non produced fluids form and receive confirmation of acceptance. Notify TBPF when job is completed. 7) RU choke mainfold to ptunp down annulus or short string with the option of taking returns form short string or annulus to production Pressure test choke rrm_nifold to 4000 psi. Line out to pump FIW down casing taking returns from robing to production. Route M-2 short string to test separator to handle water returns. Circulate 75 bbls FIW down _annulus taking retuI~ from abort string to production. Ensure adequate circulation rates ~f 2 bpm. 8) RU electric line, lubricator, and BOPs on short string. Pressure test to 2500 psi. Measure up a Baker model H-1 cement retainer on an E4 setting tool dressed for 3-1/2" 9.3# tubing. RIH and set cementing retainer between C & D series sands at 5,300'. POOH. RD E-line. Lay in Annular Cement Plug: 9) lO) RU 1.75" coil robing unit on short string. RU hard lines from both low pressure FI source and suction line from batch mixer. RU injector, BOPs, and lubricator. Pressure test all surface lin~__ to 4500 psi. ~ test coil and lubricator to 4500 ps/. Fum:tion and pressure test BOP'~ MU retainer stinger and coil connector to the 1.75" coil R.IH with aasembly ciro~!_nting FIW lit 1/2 BPM. Shut down pung~ and stab stinger into Model H-I retainer. Set down 8,000 #. ~ 3-1/2" X 1-3/4' cot annulus to 800 psi to ensure seals are holding Line om reamm 2 M-2 7/31/96 2:39 PM from annulus to production. Establish circulating rates down coil with returns from annulus at 1, 1.5, and 2 bpm. The cement volume is sufficient to fill the casing to about 4,700' MD. Highest anticipated production zone is the C series sands at about 4,944.' 11) Mix 326 sx (68 bbls) 15.8 ppg, 1.17 yield class "G" cement with additives for a 6 hour set time, fluid loss not exceeding 80 mi per 30 minutes, and compressive strength of 4,000 psi in 12 hours. Test fluid loss prior to pumping. Contaminate displacement water with 10 bbls of 1.2 #/bbl Biozan. Pump Schedule: 15 bbls FIW preflush 62 bbls 5 bbls 10 bbls 50 bbls XXbbls Class "G" 15.8 ppg (1.17 yield) cement with .010 GAL/SK D110, 0.150 GAL/SK PAKD145A, 0.60 GAL/SK PAKD300 with a 5hr55mn set time (including 2-hour batch mix) and calculated AP1 fluid loss of 53.0 mid 30 mm. Fresh water spacer 1.2#/bbl FIW based Biozan cement contaminate FIW 1.5 x bottoms up FIW Coil displacement 12) With all cement displaced from the coil, shut down pumping and ensure check valves are holding. Block in annulus and open coil by 3-1/2 tubing annulus. Unsting from assembly and PU 15'. Pump Biozan out coil plus 50 bbls F1W to clear any residual cement in the coil and displace to production. POOH circulating at 1/2 BPM. SD pumps and block in coil at 750'. POOH. Shut in tubing and rig down coil. WOC 48 hours. Pressure test annulus to 1500 psi to ensure plug is holding. 13) Rig up slickline mt, lubricator and BOPs on short string. Pressure test to 2500 psi against swab valve. Bleed pressure and dram liquids. RIH wi 2.70 GR and tag retainer. Record fluid level. RD slickline. Perforate Upper Zones: NOTE: Prior to arming explosives and until explosives are 300' in hole, establish all Unocal safeguards for handling explosives. Review and complete Perforating/Explosives Standard & ChecklisC 14) RU electric line, lubricator, and BOPs on long stung Pressure test to 2500 psi. Measure up GR and CCL. RIH and pull correlation log from 6,000' to 4,000'. Correlate GR to DR, and flag line on depth at 5,550'. POOH. Measure up 2-1/2" HC with 6 spf Ultrajets, 60 phase. RIH and perforate the following intervals: 15) D3B 5,754' - 5,794' 40' D2 5,558' - 5,598' 40' Measure up long string isolation packer assembly consisting of 1.9" WLEG, 2' 1.9" pup.joint, I-lES 1.25" "X" landing nipple w/WLR plug installed, 4' 1.9" pup joint on a 3-1/2" 9.2//"RCI~ pack~. Running tool to b~ pinned with Bran sbetr SCFeWS and Blue Lokflte. DO NOT USE BRASS SltgAR STOCK, RIH and set at 5,400'. POOH. RD E-Lin~ Bleed tubing ~ tO 5oo psi to ensure pins is holdin~ 3 M-2 7/31/96 2:39 PM REVISED PAGE # 4:: Note Changes in step #17. 24-Jui-96 16) RU electric line, lubricator, and BOPs on short string. Pressure test to 2500 psi. Measure up GR and CCL. RIH and tag retainer. Pull correlation log from retainer to 4,000' Correlate GR to DIL and flag line on depth at 5,000'. POOH. 17) Measure up SWS's POT-C perforating system with .615" grippers on the rollers. Measure up 2- 1/8" HyI>erdome carrier guns loaded with 4 spf Ultra Jets, 0- phase. RIH and perforate away from the long string per the runs noted below: Run #1 C4 sand 5,045' - 5,060' DIL 15' Tubing SI Allow well to unload water m robing at 3 MMSCFD max rate. Run #2 C4 sand 5,030' - 5,044' DIL 15' Run #3 C-4 sand 5,015' - 5,029' DIL 15' Run//4 C4 sand 5,000' - 5,014' DIL 15' Flowing 4 MM or 8% DD Flowing 4 MM or 8% DD Flowing 4 MM or 8% DD NOTE: Stop program here if the long string has been perforated. Lead time will be required to obtain the tubing patch for the long string. Do not pull isolation plug in long string if the perforations in the short string penetrate the long string. 17c) RU electric line, lubricator, and BOPs on long string. Pressure test to 2500 psi. Measure up GR and CCL. Correlate GR to DIL and identify perforations from long string. Measure up lIES 3.5" Retrievable tubing patch with main mandrell of adequate lenght to cover holed long string. Rl~l and set tubing patch. POOH. Bleed tubing pressure to ensure patch is holding. RD E-Line. 18) Rig up slictdine unit, lubricator and BOPs on long string. Pressure test to 2500 psi against swab valve. Bleed pressure and drain liquids. Measure up 1" tool string and pulling tools dressed to pull the prong and plug dressed in the 1.25" X nipple at 5,400'. Recover prong and plug. 19) Note: Omit this step if the long string was perforated in step # 17. Measure up 1.875" tool string and 2-7/8" nominal GS pulling tool. RIH and recover RCP packer at 5,400'. RD slickline 20) Release well to production group for well testing. 4 M-2 7/31/96 2:39 PM TRADING ]~AY UNIT s'ri~£LHE:AD '"'""~'-'R.M ~ II-E: CURRF. NT CL.. --~:DN~ ASS[I4JILY 10/1t7 TES/ne~' · -t/a', %El, L-lO 7~7' CIqD) 13-~ I Boker' A-5 .ils~L..Packer' I 5'S~4' 'to 5cj67' (:HZD -_~ 3-:1/~, ~ [LIE L-80 TI~ Cf' overtep above & b4to~ perfs) Cr~ssov'~, 3-1/'~ AM Iq,,rt'la,"ess ! &gSl' <1~pedese 0.'30 ~ , 7.~1' - $, Tq q TRADING BAY UNIT ' CURRENT I0/87 TE,~/net~ ~.~ I O. Us ~ Couptm~ I ~ serMw '10' L. 4S6' to 483' ; I 0.1(' % t 'J// . ~ f '"/ 7. oz c E 3-1/~; ~O, ~ L-Sa Tbg BGke~- A-$ ])~G,t _Pc~cke~- ~ ~"~4' 'tO ~967' (HO3 D-'L ~-3~ 3-I./8; 9.30, EIJE L-80 1'bO a't!s. _ X .ntpp(e (F..813' fen I~ ~ ~99' CMl)) 3-t/~o ~ ~E C-O0 TbG BOX x D~t~ess f~n Cr~'ssove~. 3-1/~' Am4 ~ess 930 L~JE L-M Tbg '; o · LO~ER PA~CER A~ 411, .... b'I-E]RT_ STRING 2-.t/~', 'J~l. L-O0 ,bg i. pup .; 7E7' <:HID L,. ~ to 44i)' (ND) c.'(3:.1/a,, 9.am cs Hyd,-d L-OO Tb · 0'46 7136"?178' IILL ky,,13.0 ~lJ~qr PITI I' 7804' a4~ Cenefl, r.e'tem, r' e D-t7 'J'~'7'-TL'FJ' ¢Squeez~ ....... I m _mil __ m - m _ _: i m ii Sid~ Port ~Kill Port) SluO-u~ FI~ T~ ¢onn~"~Jo~. Port B~n~.R~ Ec~.mJ~'~g Loc= Hancile - 91~cl Rams (RamNo. 1) · -, Shear Rams (Rill ~. 3) .- (FIm~4) Pk~e-~am E~u~ veve RECEIVED Alllkl Oil & gas ¢on~. Comml~lon Anchorage -" STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator UNOCAL Abandon: SuSpend: Operation shutdown: Alter casing: Repair well: Plugging: Change approved program: Pull tubing: Variance: 3. Address P.O. Box 19-0247 Anchorage, AK 99519-0247 4. Location of well at surface 1043' FNL, 603' FWL, Sec. 33, T9N, SM At top of productive interval 1420' FSL, 1119' FWL, Sec. 33, T9N, SM At effective depth 992' FSL, 1221' FWL, Sec. 33, T9N, SM At total depth 5. Type of well: Development: Exploratory: Stratigraphic: Service: ORIGINAL Re-enter suspended well: ~me extension: Stimule[e~: Perforate: "~ther: X ,. 6. Datum elevation' (DF or KB)~j X ~'~' KB above MSL feet 7. Unit or Property name McArthur River Field Grayling Gas Sands 8. Well number M-2 9. Permit number 87-61 10. APl number 50- 733-30389-00 11. Field/Pool Grayling Gas Sands 12. Present well condition summary Total depth: measured true vertical 7510' feet Plugs (measured) 6396' feet Effective depth: measured 7204' feet Junk (measured) true vertical 6183' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 727' 20" 1395 sx 727' 727' Surface 1895' 13-3/8" 1253 sx 1895' 1860' Intermediate Production 7500' 10-3/4" x 9-5/8" 3800 sx 7500' 6390' Liner RECEIVED Perforation depth: measured D-6, 6060' - 6112' D-16, 7136' - 7172' true vertical D-6,5080'-5131' D-16,6119'-6154' JUL I 1 1996 Tubing (size, grade, and measured depth) Alaska 011 & ~a~ Cons. Commission Long String: 3-1/2", 9.3~, N-80, EUE ~ 7034' Short String 3-1/2", 9.28, L-80, CS Hyddl (~ 5979' Anchor~,ge Packers and SSSV (type and measured depth) LS SSSV Otis Series 10 @ 470', SS same type ~ 440', Single Baker SC-1 pkr @ 6958', DLal Baker A-5 pkr @ 5954' 13. Attachements Description summary of proposal: X Detailed operations 13rogram: BOP sketch: X 14. Estimated date for commencing operation 16. If proposal well verbally approved: Name of approver Date approved 15. Status of well classif'~afion as: Oil: Gas: X Service: Suspended: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: .~r~.~(~ ~ ct,,.,.- Title: Drilling Manager FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Date: ~j '3r-~. I~.~. [ I^""r°va' / Plug integrity Mechanical Integrity Test BOP Test ~ Location clearance Subsequent form required 10- '~/'(~ ~'~ Original Signed By David W. Johnston Approved by order of the Commissioner Form 10-403 Rev 06115/88 Commissioner Approved Copy Returned SUBMIT IN TRIPLICATE Steelhead Platform Well M-2 RECEIVED Cement tubing strings in place to complete in shallower intervals JUL '1 1 19Bg By: T.E. Maunder and Grayling Gas Completion Workshop Date: June 28, 1996 Revision #: 3 Alaska Oil & Gas Cons. Commission Anchorage .Objective: Well M-2 is a dual completed well on Steelhead. The long stnng presently is completed in the D-16 interval. The short stnng, completed in the D-6 interval, has a fish lodged in the X nipple below the dual packer. It is intended to cement both tubing stnngs in place by plugging the short string near the packer, perforating the tubing, and coil tubing cementing below a retainer. This will allow shallower zones to be accessed in the short string by utilizing Schlumberger's POT-C oriented perforating system. Production from the D-6 interval will be returned by perforating the long string above the blast nngs opposite the production perforations. NOTE: On June 23 - 24, 1996 a 2.70" gauge ring was run into both tubing strings on this well. 5925' was reached in the short string and 6110' was reached in the long string. A GR/CCL/TDT/ATC was then run in the short string from 5900' - 3400' DIL. It is important to note that corrolation with the CCL proved to be difficult due to the same length of the tubing joints. A GR should be used for definitive EL corrolations. NOTE: Prior to arming explosives and until explosives are 300' in hole, establish all Unocal safeguards for handling explosives. Review and complete Perforating/Explosives Standard & Checklist. Perform EL Work on Short and Long Strings: 1) Assure 9-5/8" annulus is full. Pressure test annulus to 1500 psi. Record test on chart. 2) RU E-Line unit, lubricator, and BOPs on long string. Pressure test to 2500 psi. 3) Bleed pressure and dram liquids. Using tubing puncher, perforate long string above blast rings at about 6,040'. Punch sufficient holes to equal 100% of tubing cross-sectional area. Based on a puncher loaded 4 spf, producing holes with 1/4" diameter, 36' of gun are necessary. 4) RU electric line, lubricator, and BOPs on short string. Pressure test to 2500 psi. RIH and set tubing plug above packer at about 5,950'. 5) Blow down short string to production. Fill short string with FIW. Pressure short string to 2500 psi. 6) RU 2-1/8" tubing puncher, 4 spf, 2' gun and RIH. Log gun into position at about 5,940' I M-2 7/1/96 2:56 PM 7) 8) Rig return line to platform cleanout tank in case of oily returns. Open 9-5/8" R E C E IV E D annulus. Pressure up on short string to 1,000 psi and perforate short string. Note pressure loss when communication is established. POOH. JUL 1 1 1996 Note: Monitor long string while shooting short string. Puncher charges should not have sufficient energy to penetrate the long string. Alaska 0il & Gas 0ohs. 00remission Anchorage Run Baker model N cement retainer on EL and set in short string at about 5,930'. POOH. Lay in Annular Cement Plug: 9) RU 1.5" coil tubing unit on short string. RU hard lines from both low pressure FIW source and suction line from batch mixer. RU injector, BOPs, and lubricator. Pressure test all surface lines to 4500 psi. Pressure test coil and lubricator to 4500 psi. Function and pressure test BOP's. NOTE: A crescent flange X-over spool is needed to allow the CTU riser to be rigged up to the tree. lO) MU retainer stinger and coil connector to the 1.5" coil. RIH with assembly circulating FIW at 1/2 BPM. Shut down pumps and stab stinger into Model H-1 retainer. Set down 5,000 #. Pressure 3-1/2" X 1-1/2" coil annulus to 1000 psi to ensure seals are holding. Unsting from retainer. 11) Mix 700 sx (145 bbls) class "G" cement with additives for a 8 hour set time, fluid loss not exceeding 80 ml per 30 minutes, and compressive strength of 4,000 psi in 12 hours. Use double batch mixer due to volume. Test fluid loss prior to pumping. Pump 15 BBL fresh water preflush and cement down coil at maximum rate taking returns from 9-5/8" annulus. Contaminate displacement water w/.5 #/bbl Barazan_ This cement volume is sufficient to fill the casing to about 3000' MD. Highest anticipated production zone is A-6 at about 3660'. Based on 15,100' of 1-1/2" coil at 1.597 bbi/1,000' (24.1 bbl total), and an initial rate of 1.5 bpm, following is the pumping schedule. ACTIVITY DELTA MINUTES CUM MINUTES VOLUME Start Preflush -- Finish Preflush/Start Cement 10 Preflush exiting CTU 6 Cement exiting CTU 10 50 bbl cement out of coil 33 100 bbi cement out of coil 33 112 bbl cement out of coil ' 8 Finish cement/Start Displacement 6 124 bbl cement out of coil 2 136 bbl cement out of coil 8 139 bbl cement out of coil 2 142 bbl cement out of coil 2 145 bbl cement out of coil 2 0 0 10 15 16 24 26 39 59 89 92 139 100 151 106 160 108 162 116 174 118 176 120 178 122 181 3-1/2' x 1-1/2" capacity is .00652 bbI/ft giving 38.7 bbls from 5,930' to surface. 2 M-2 7/1/96 2:56 PM 12) 13) 14) 15) With all cement displaced from the coil, shut down pumping and ensure check valves are holding. Unsting from assembly and circulate down coil to clear any residual cement in the coil. POOH circulating at 1/2 BPM. Shut in tubing and rig down coil. WOC. Rig up slickline unit, lubricator and BOPs on short string. Pressure test to 2500 psi against swab valve. Bleed pressure and drain liquids. RIH w/ 2.70 GR and tag retainer at 5,930'. RD slickline. Open 9-5/8" annulus. RU and pressure test short string to 2500 psi. Observe annulus for any returns. RU 1.5" coil tubing unit on short string. RU hard lines from nitrogen unit. RU injector, BOPs, and lubricator. Pressure test all surface lines to 4500 psi. Pressure test coil and lubricator to 4500 psi. Function and pressure test BOP's. 16) MU jet nozzle on CTU. pressure on well. Perforate Upper Zones: RIH jetting FIW from wellbore. POOH leaving 1000 psi nitrogen 17) RU EL on short string, pressure test lubricator to 2500 psi. Perforate using Schlumberger POT-C ~'stem. Maximum gun length should not exceed 15'. Intended perforation depth are: D3B 5754' - 5794' DIL 40' D2 5558' - 5598' DIL 40' NOTE: A GR must be included to corrolate gun depth since all tubing joints are about 30' in length. 3 M-2 7/1/96 2:56 PM R£C£1V£D Alaska Oil & Gas Cons, commit~sion Anchore. ge Side Pon (Kill Port) Stud-UO Flange ToD Connection~.. Pressure Port Blind-Ram E~lualizing Valve Manual Lo~ Handle - Bllnci Rams (RamNo. 1) - Shem Rams (Ram No. 2) - SILo Rams (Ram No. 3) - P~e Rams (RamCo.4) Pipe-Ram EeluaJizing Valve Hyclmu~ Aclua~ Ram Position Bottom Flange Connm::aon Bottom Pin ami Collar Connecaon TRADING BAY UNIT '~ STEELHEAD PLATFORM WELL ~URRENT CDMPLETIDN A~EMBL~ :0/87 TES/nef FMC Duo~ SDlit Honge~ (TC-60) w/EUE x C$ _LDNG STP, lNG 3-I/B', 9.3# N-80 EUE Tb9 Pup Jts. 10-3/4' Csg changover to 9-5/8' 8 508' (MD) 9-5/8' Csg: 43.5 & 47t~ N-80 Buttress Csg, -~.~tis Flow CouplinQ tis 'XXO' sliding- sleeve Methanol injection port I ~tis Ftow Coupling (75') I Otls series '10' Fl~pper lolls Flow Coupling (5l') 4~6' to 483' 3-1/2", 9.3#, EUE L-80 Tb9 Bc~ker A-5 Dual Packer 5954' to 5967' 3-1/2". a3#. EUE L-80 Tip,-., Otis x hippie @ 5999' (MD) 3-1/8', 9.3#, EUE L-80 Tb9. Crossover 3-1/~', 8¢d NodiFied EUE Box x Buttress Pin Corbide blest joints os required on 3-~/8', 9.8~, N-80 tog w/ABN special ctearance buttress Connect,ons (8' ovenlop above & belo~ pelfs, : Crossover. 3-i.~" ABM BL~tt,-ess Box ~- 3-1/2'. S"~.~ EUE :,n ,, ',. 3-1/2' 9.31~ EUE L-BO Tbg S-22 snap latch ~A w/2 seat un,ts 8 6957' (MD) ~O~E~ PACKE~ Bcker 9-5/8' x 3-1/8', 47W, 2C-~ re~r;evobte packer w/6' 3BE 6958' (~D) 6-5/8' x 3-~/8" X-over sub 8 6969' <MD) :HORT STRING 3-i/8'. 93~. L-80 tbg & pup jtS 20' 727' (MD) ECP ~ 1750' (HD) _+ 3-3/8' 8 1895' (MD) Otis Flow Coupling (75') Otis 'XXO' sliding steeve methanol injection port Otis Flow Coupling (75') Otis series "10' Flopper SSSV Otis Flow Coupling (51') 483' to 449' (ND) /~'. 'gel~ C~ Hyar,i L-80 Tag Baker snap latch @ 5953' (MD) Otis XN Nippte @ 5970' (MD) r.tauge F?ing Tool Strmg '~tuck ~n '(N' Nipple Bake,- shear-out Sub 8 5977' ,MD., Baker hotF-c,,~t mute s~oe ~/WL re-entry guide 5979' D-6 b060'-6112' DLL Der=lO.5 ' ~ JSPF NE]TF~ Ati ShOrt Str,r, L3 :SS~ assembly Ali Measured depths ,.HO) ur'e bose~ on tong string measurement D-16 7136'-7172' DLL Dev:13.O 12 JSPF I Jt 3-1/2" 8F,'D ABC - ] '--. Plain ~,~ 7204' ,MD,, Otis XN Niopte ,.; -'003' ,.MD) i ! ...... · - .c ;]emer, t ,'eto,r,e,- i_~ 7309' ,.MD, 1 Jt 3-1/2'. 8P..D ABC ~to9 i D-!7 7237'-7.2'93' *Squeezea] Bc~ker Muleshoe *, ~/L ,~e-entry i' 9uicle e 7034' (ND) t '"' ""' . . / / ' _ .' ' · ' ....' . '~ 5/8' Cs9 8 7500 (ND) TD [~ 7510' (ND) STEELHEAD PLATFORN WELL CURRENT CCMPLETIE'~ ASSEMBL */CUE x CS Crossovers LONG STR[N~ S-i/es 9.3# N-80 CUE Tb9 & Pup Ors. ~0-3/4' C$9 chon§over to 9-5/8' 8 508' (MD) 9-5/8' Csg: 43.5 & 47~ N-80 Buttress Csg. .t;s Flow CouplinQ (75") tis 'XXO' st;ding- sleeve methanol injection port I _Otis Flow Coupling (75°) I _Otis series 'lO' Flopper S~SV I 01;is Flow Coupling (5]') 456' tO 483' (ND) 3-1/8', 9.3~, CUE L-80 Tb9 Baker A-5 Dual Packer 8 5954' to 5967' 3-1/8'. c~ 3#. CUE O~is X nipple @ 5999' (MD) 3-1/8'. 9.31~, CUE L-80 Tb9. Crossover 3-1/2', 8rd Mooti£iect CUE Box x Buttress Pin Carbide blast joints as required on 3-1/2', 9.2#. N-BO tbg w/ABM speciat clearance buttress connections (8' Overtop oloove & below perFs, ISrossoYer. 2-;. 2" ABM Buttress Box -. 3-1~2'. S,-~.~ EUE pin 3-!/8°. 93t~ CUE L-BO Tbg S-22 snap latch SA w/2 seal un,ts @ 6957' (ND) _LOWER PACKER ASSY Baker 9-5/8' x 3-1/2', 47#, rel:rievalote packet- w/6' SBE 8 6958' (MD) 6-5/8' × 3-1/2° X-over sub 8 6969' ,'MD) I Jt 3-t/2" ~31;.'D ABC TL,9 Otis XN N~opte ,~ =003' ,.MD) I Jt 3-1/2', 8P..D ABC rog Baker Muleshoe w. ~L re-entry 9u~cie e 7034' ~ND) "HART STRING E D 20" 8 727' (ND) ECP t~ 1750' .0¢YL 1 1 1996 13-3/8' 8 ]895' (MD) Alaska Oil & Gas Co~. ~tmr~ge ~t;s Flow Coupling (75') JOtiS "XXO' sliding sleeve methanol injection port I ~tis Fto~ Coupling (75') I Otis series 'lO' Flapper SSSV ~ Otls Flow Couotln9 423' to 449' 3-I/2°. '.~2N CS Hyclr,I L-80 Tbg Baker snap latch @ 5953' (MD) Otis XN Nipple e 5970' (MD) C. ouge Ring Tool Str,ng Stuck ~n '~N' Niople Bake? Shear-out sub ~ 5977' ,MD., Boker hotf-C,.,t mute Shoe ~/'~/L re-entry guide 5979' D-6 °060'-6118' DLL Dev=le.5 ;~ JSPF ,NOTI~ At; Short strir, q ':,-,nnec~.,,Dns ore ']] H,/Or,I :~[20v6 12uCl-.~r' e ~C6'pl: F'ir ']2 S~' oSSerqbly All meosL~r-ed depths ,.MD., ~r'e baseo on long str,n9 measurement ' q ~ D-16 7136'-7178' DLL Dev=l$.0 12 JSPF ~ Fill t~ 7197' WLMKB 7,"6/92 I Cement ,'eta;ne,-I_~ 7209' ~MD, [;-t7 z227'-72'93' ~ Squeeze~ // ' '"' "" 9-5/8' Csg 8 7500 <MD) TD ~ 75]0' (HD) Alas~,.. ~;egion Domestic Production Marathon Oil Company February 1, 1994 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Mr. David W. Johnston Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Steelhead Well M-2 Dear Mr. Johnston' Attached for your approval is the AOGCC "Application for Sundry Approvals" to plug Steelhead Well M-2 in preparation for a proposed recompletion later this spring. The new perforations will be addressed in a separate application. At this time, M-2's recompletion is tentative. However, an approved plugging procedure is required before any additional project evaluation or planning can be done. It is proposed to convert M-2 from a dual Grayling Gas Sands D-6 and D-16 gas producer to shallower dual C3/C4 and D-2 gas producer. Because there is no future wellbore utility below the existing dual packer, the preferred cement plugging method would be to down squeeze through each tubing string separately and then jet cut each string above the dual packer. Please call me at 564-6443 if you have any questions about the application. Sincerely, Zn~C//~,. c~~u~le~_'.M Production Engineer RECEIVED JCM/cah FEB - 9 1994 Enclosure Nasl~ u, & Gas Cons. Commission Anchorage H:~wp\Sundry A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation shutdown Re-enter suspended well__ Alter casin'"~- Repair w'~' Plugging X -- Time extension Stimulate Change approv'--ed program -- Pull Tubing -- Variance P~rforate Oth~..._ 1. Type of Request: 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development X Exploratory -- Stratig raphic -- Service -- -- 4. Location of well at surface Leg B-2, Cond. #3 Steelhead Platform 1043' FNL, 603' FWL, Sec. 33-9N-13W-SM At top of productive interval 1420' FSL, 1119' FWL, Sec. 33-9N-13W-SM At effective depth At total depth 992' FSL, 1221' FWL, Sec. 33-9N-13W-SM 12. Present well condition summary 6. Datum elevation (DF or KB) 160' KB above MSL feet 7. unit or Property name Trading Bay Unit 8. Well number M-2 9. Permit number/approval number 87-61 0. APl number 50- 733-20389-00 1. Field/Pool Grayling Gas ~al~l~ie~l ~ ~ r- r r~EL. EI VEL Total Depth: measured 7510' feet Plugs (measured) true vertical 6485' feet Effective depth: measured 7204' feet Junk (measured) true vertical 61 85' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 7204' None Length Size Cemented Measured depth FEI3 -9 1994 u, ~ Gas Cons. C0rllrl ~chorage True ve~ical depth 727' 20" 1,395 SX 727' 727' 1,895' 13-3/8" 1,253 SX 1,895' 1,787' 3,800 SX 7,500' 6,476' 7,500' 10-3/4"X 9-5/8" D-6 6,060'- 6,112' MD 5,080'- 5,131' TVD D-16 7,136'- 7,172' MD 6,119'- 6,154' TVD Tubing (size, grade, and measured depth) Short String: 3-1/2", 9.2# L-80 @ 5979' Long String' 3-1/2", 9.3# N-80 @ 7034' Packers and SSSV (type and measured depth) Dual Pkr: Baker A-5 @ 5954'; Single Pkr: Baker SC-1 @ 6958'; SCSSV's Otis Flapper: (SS) @ 446', (LS) @ 479' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X Estimated date of commencing operation April 1, 1994 If proposal was verbally approved Name of approver Date approved 15. Statis of well classification as: Oil Gas X service Suspended I hereb~'~rtjfy th~tl~he fore~o~g~ tr~e anj;;Le~m~ct~to the be~t of my knowledge. '~ ~"' '~/ ~(~~ Title ~ ~'~t~ ~'~~- Signea ]~ - ~~ ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test __ '-~ubsequent form required 10~ L/O 7 Approved by order of the Commision Original Signed By David W. Johnston IAppr°va' N~_., ~,~ ~pproved Copy Returned Form 10-403 Rev 06/15/88 Commissioner Date 'L./{ d,,/~ V SUBMIT IN TRIPLICA:rE STEELHEAD WELL M-2 PLUGBACK PROCEDURE OBJECTIVE: Plugback long string and short string perforations with cement by the down squeeze method [20 AAC 25.105 (h) (1) (B)] in preparation for the recompletion of M-2 to a shallower gas producer (above the existing dual packer). The new completion will be proposed in a separate Application for Sundry Approval. ® ® · ® · · · · · 10. 11. Conduct pre-job meeting with pumping personnel. the SCSSV control lines and pressure to 4500 psi. caps on master manumatics. Install handpumps on Install fusible RU pumping lines to long string. Pressure test lines to 3,000 psi against swab valve. Kill long string by bullheading 100 BBLS drill water (fresh H20). SD pumps and monitor pressure. Repeat as necessary to kill well. Mix and bullhead 110 sxs Class G cement + additives down the long string, and displace with 55 BBLS drill water. ETOC @ 6350'. SI well to hold pressure on squeeze. WOC. Pressure test squeeze to 2,500 psi. Monitor bleedoff for 30 minutes.- Resqueeze long string as necessary. RU pumping lines to short string. Pressure test lines to 3,000 psi against swab valve. Kill short string by bullheading 100 BBLS drill water (fresh H20). SD pumps and monitor pressure. Repeat as necessary to kill well. Mix and bullhead 80 sxs Class G cement + additives down the short string, and displace with 50 BBLS drill water. ETOC @ 5800'. SI well to hold pressure on squeeze. WOC. -- Pressure test squeeze to 2,500 psi. Monitor bleedoff for 30 minutes.'~ Resqueeze short string as~cessary. RD pumping lines. RU electric line on long string. RIH with jet cutter and cut long string at 58___10'. POOH. Establish circulation through long string cut and 9-5/8" annulus. RU electric line on short string. RIH with jet cutter and cut short string at 5800'. POOH. Establish circulation through short string cut and 9-5/8" annulus. RD electric line, NOTE: Following rig mobilization, tubing above ei~~t~~~be pulled· All equipment below the cuts willIY~m~nl~n~e hole. FEB -9 1994 Alaska 0il & Gas Cons. Commission Anchorage Wireline Lubricator w/Associated BOPE - GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP ,. !1 12 X-4018-K-REV. 2 MARATHON OIL COMPANY TRADING BAY UNIT '~ STEELHEAD PLATFBRM WELL k, CURRENT CBMPLETION ASSEMBLY 10/87 TES/ne¢ FMC Duo( Sp(it Hangem (TC-60) w/EUE x ES: Cmossovem~ LBN6 STRING 3-1/2", 9.38 N-80 EUE Tb9 8~ Pup .Jt;s. 10-3/4" Cs9 changover to 9-5/8" @ 508" (MD) 9-5/8" Csg= 43.5 ~ 47~ N-80 Butteess Cs9, Iitis FLow Coupling (75") tis "XXB" stldln9 sleeve methano~ injection pont tis Flow Couptin9 (75") tis series "10" FLapper S:SSV tis Flow Coupiln9 (51'9 456' to 483' (HD) SHBRT STRINO 3-]/2", 9,2~t, L-80 tb9 & pup ..its PO" 8 727' (MD) ECP ~ 1750' (MD) + 13-3/8" @ 1895' (MD) Iitls Flow Coupling (75") tis "XXO" stidln9 sleeve methanol injection por't tis Flow Couplin9 (75") tls series "]0" Flopper' tls FLow Couptln9 (51") 4~3' to 449' 3-1/P", 9.38, EUE L-80 Tb9 3-l/O", 9.B~l CS Hydri[ L-80 Tto9 Baker" A-5 Dual Packer @ 5954' to 5967' (MD) 3-1/~", 9.3~, EUE L-80 Tb9 Otis X nlppte (2,813" mln ID) @ 5999' (MD) 3-1/2~', 9,3:1:I, EUE L-80 Tbg, Crossover 3-1/2% 8rd ModiFied EUE Box x Buttress Pin Corblde blast jolnts os required on 3-I/P", 9,2~4, N-80 tb9 w/ABM special clearance bu~c-bress connections (8' over'tap above & below per£s) Crossover, 3-1/2" ABM Buttress Box x 3-1/2% 8rd EUE pin 3-1/2% 9.3~ EUE L-SO Th9 S-PO snap tatch SA w/2 seal. units @ 6957' (MD) LOWER PACKER ASSY Baker 9-5/8" x 3-~/2", 47~, SC-1 re~crlev~bLe packer' w/6' SBE @ 6958' (MD) 6-5/8" x 3-1/8" X-over sub @ 6969' (MD) 1 St 3-1/2" 8RD ABC Tb9 Btls XN Nippl.e @ 7003' (MD) 1 Jt 3-1/3", 8RD ABC Th9 Baker Muteshoe w/WL re-en~cr-y 9~ide @ 7034' (MD) Baker snap torch @ 5953' (MD) '~t~s XN NippLe @ _%970' (MD) Gouge Ring Tool Strin9 Stuck in 'XN' Nipple Baker shear-out sub e 5977' BoRer' hufF-cut mu[e shoe w/WL ce-entry guide e 5979' D-6 6060'-611~' DLL Dev=lS,5 12 JSPF NOTE: ALI short strin9 connections ore CS Hydr'it above pocket except FOr 'l. he S~V assembly. ALI measured depths based on ion9 string rneosurernen~ D-16 7136'-717~' DLL Dev=13.0 12 JSPF .. 7t'~ ~ Fill @ 7197' WLMKB 7/6/92 PBT~ 9 7204' (MD) Cement r'e(oinec /~ 7309' D-17 7227'- 7293' (Squeezed) 9-5/8" Cs9 @ 7500 (MD) TD @ 7510' (MD) TRADING BAY UNIT STEELHEAD PLATFE]RM WELL PROPOSED PLUGBACK 10-3/4" cs9 changover to 9-5/8~ ~ 508~ (MD) 9-5/8~ Csg= 43,5 & 47~ N-80 Buttress Csg, 7~7' (ND) E£P @ 1750' (MD) ± 13-3/8" ~ 1895' (MD) Long String Baker A-5 Dual Packer @ 5954' to 5967' (MD) Otis X nlpp[e (2.813" mln ID) e 5999' (MD) Short String Estimated TOC = 5800' Baker snap torch ~ 5953' (MD) Fltls XN NippLe I~ 5970' (MD) Gauge Ring Tool String Stuck in 'XN' Nipple Baker shear-out sub 8 5977' (MD) Baker' halF-cut mule shoe w/~L re-entry 9uide ~ 5979' (MD) Capblde blast joints as ¢equlned on 3-1/i~", 9.2t~, N-SO tb9 w/ABM special cteopance buttress connections (8' over[ap above ~ betow perFs) D-6 6060'-611B' DLL Dev=iS.5 1L° ]SPF Estimated TOC = 6550' S-P~ snap latch SA w/3 sea[ units ~ 6957' (MD) LB~/ER PACKER ASSY Baker 9-5/8" x S-i/at 47fL SC-1 retrievable packer' w/6' SBE @ 6958' (MD) 6-5/8" x 3-i/~" X-over sub e 6969' 1 J~ 3-1/3" 8RD ABC Tbg B~is XN Nippte 8 7003' ~ J~ 3-1/3% 8RD ABC Tb9 Baker Nu(eshoe w/~L re-entry 9uide ~ 7034' D-16 7136'-717~' DLL Dev=13,O lB JSPF Fill @ 7197' WLMKB 7/6/92 PBTD (~ 7~04' (MD) Cement r'etalner @ 7~09' (MD) D-17 7~B7'-7~93' (Squeezed) 9-5/8" Cs9 @ 7500 (MD> TD ~ 7510' (MD) ',. STATE OF ALASKA ..... '-. (~/g~/ ALASK¢ .....AND GAS CONSERVATION ~. _ .zllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG ¢''g 1. Status of Well Classification of Service Well OIL [] GAS I~l SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number UNOCAL (Marathon Oil Company - Sub-Operator ) 87-61 3. Address 8. APl Number P. O. Box 190247 Anchorage, AK 99519 50- 733-20389-00 4'. Location of well at surface 9. Unit or Lease Name 1043' FNL, 603' FWL, Sec. 33 - 9N - 13W - SM Trading Bay Unit At Top Pro_ducing Interval 10. Well Number 1420' FSL, 1119' FWL, Sec. 33- 9N- 13W- SM M-2 At Total Depth 11. Field and Pool 992' FSL, 1221' FWL, Sec. 33 - 9N - 13W - SM Mc Arthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 163' KB above MSL ADL 18730 Grayling Gas Sands 12. Date. Sp.udded8/4/87 13. DateT.D. Reached8/21/87 14"Date'C°mp' Susp' °r Aband' 115'Water Dept-h'if°ffsh°re 116' N°' °f C°mpleti°ns9/13/87 ' 183' feet MSL 2 17. Total Depth (MD+TVD) 18. Plug Back Depth (M_D+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7510'..-& 6485' 7204' & 6185',.. YES M NO [] SS=446' L,~9~' N/A 32. Type Electric or Other Logs Run CAsed' Hole - GR - CCL - CBL Open Hole - GR - SP - CAL - DLL - MLL - FDC - CNL - LSS - FMT - Dipmeter 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNTP_U_LL,,E~D~ ,, 20= 9t.b X-56 ~ur~ace 7z/: 26;;- i395 sx Class u )),uuu '13-3/8*~ 61.0 K-55 Surface 1895' 17-1/2" 1253 sx Class G SO,000 10-3/4" 55.5 N-80 Surface 508' 12-1/4" 3800 sx Class G 225,000 # 9-5/8" 43.5 N-80 508' 6159' 12-1/4" 9-5/8" 47 .O N-80 6159' 7500~ l Z-£/4;; 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) D-6 6060' - 6112' MD 5080' - 5131' TVD 3-1/2" 59/9' 5954: 3-1/2" 7034' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED D-16 7136' - 7172' MD 6119' - 6154' TVD 7227' - 7293' 48 sx Class 27. PRODUCTION TEST See Attachment #1 Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ . Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) Press. 24~HOUR RATE I~ 28. CDR E DATA Brief description of tithology, porosity, fractures, apparent dj.ps and presence of oil, gas or water. Submit core chips. [CEiVEJ) JAN i ~ ~one Abska 0il & Gas Cons, Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ ~ ,.. ~ ~' '.. ...". 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. "A" Zone Top 3057' 2635' "E" Zone Top 7350' 6328' 31. LIST OF ATTACHMENTS Attachment #1, Item #27, Production Test; Attachment #2 & 3, Daily Summary of Operations; Attachment #4, Directional Survey 32. I hereby certify that the fbregoing is true and correct to the best of my knowledge I~~Signed ~0~~_ . Title Environmental En~E, 12/18/87 ! ~oy ~. ~omerts 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), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 A chment I em Shor~c S'cr~nQ (D-6) 87 PRnDUCTIrlN TEST , ])~e Flrs~ Production J He~hod o¢ nper~lon (i~owlniD 8ns LI~, e~c.) .9/13/87~ Flowing Gas Well 9 / 5 / 87 13.5 TEST PMR]OD NA 4500 NA NA~ NA , FLow Tubing C~slng Pressure ~LCULATEO ~-~JL ~-MCF VATER-B~L OIL GRAV]TY-~] (corr) Press. 1875 500' 84-~uR ~TE NA 8000 NA NA Long S~crlng (I)-16) 87 PRODUCTION. TEST ])~e FIr~-t Procluc~lon I Methoel of nper~tlon (FLowln~ go_s Lief, etc.) 9/13/87I Flowing Gas Well D~te of Tes~ Hours Tested PRn~uc~nN r~ n~L-~9L ~-HC~' WATER-BgL ~K~ SIZE OAs-n~L RATIO 9 / 3 / 87 11 TEST P~Q~ NA 3670 NA NA NA ,, Flow Tubing C~lng Pressure ~LCULAT~ DlL-~L ~-MCF WATER-gBL BIL GRAVITY-APl (corr) Press. i940 500 ~4-~R RATE ~i ~000' ~i ~ , Long S'cr~ng (3-17 CM~C Squeezed) '- 87 PRDDUCTIDN TEST ])~ce First produC~clon ' J Hethod of nper~on (Fgo~lnl~ g~s IJ~'l;, e~c.) C~ SqueezedJ Flowing , DG~e of Tes~ Ho~s Tes~ed PR~gUC~N F~R O~-JJL ~-M~ VATER-S~L ~KE S~E J GAg-DIL RA~I~ 9/1/87 2 TEST PMRmO NA 0 8 10/64"J NA ~ow Tubing C~g Ppessupe ~LCULAT~ ~L-~SL G~-MCF VATER-9~L DIL GRAVITY-API (copt) Press. 0 , 500 ~ 4-HDUR ~TE NA 0 96 NA Attachment 2 TBU Well M-2 Daily Well Operations Summary 8~4~87 Skid rig from M-1 to M-2, NU diverter & function test. PU BHA, RIH. Spud M-2 @ 0600 hrs 8/4/87 8~5~87 Drl 26" hole 436' - 755'. CBU. Short trip to collars. PU 16 j ts new drl pipe. RIH. POH. PU 9 its new drl pipe. RIH to CBU. 8~6~87 CBU, POH. Ran 19 jts of 20", 91#, X-56, ERW, w/Vetco RL-4C connections. Pipe stuck @ 737'. Could work up, not down. Worked pipe to 727'. Cut off 20" csg to rotary table. RIH w/ d.p. Mixed & pumped 800 sx "G" w/2% extender & 2% defoamer & 500 sx "G" w/ 1% CaCi? & 2% defoamer. Had cement returns after pumping 15 bbl of tail slurry, gost returns after pumping 45 bbls of tail slurry. Could not regain returns. Drained 20" csg & cut off. Presently LD 20" cutoff jts. 8~7~87 Fin LD 20" cutoff jts. Tagged top of Cement @ 104' K. B. w/ 1" tbg. Performed 95 sx top job. NU & function tested 30" riser & diverter. PU 17-1/2" bit & RIH, drl float equipment & hard cement. Drl 755' - 804'. CBU. POH. PU kickoff assembly, RIH. Dyna-drill 804' - 814'. 8/8/87 Dyna-drill 814' - 1493'. POH. LD dyna-drill. Presently PU building assembly. 8/9/87 RIH. Ream dyna-drill run. Drl 1493' - 1907'. CBU. POH for wiper trip. 8110187 Fin short trip. CBU. POH. Rig up & run 44 jts 13-3/8", 61#, K-55. Buttress csg w/shoe @ 1895'. Cement w/ 780 sx of "G" & additives mixed @ 15.8 ppg followed by 473 sx of "G" and additives mixed @ 15.8 ppg. ND diverter & riser. Cut off 13-3/8" csg. Install FMC adapter. Presently installing starting head. 8/11/87 Installed starting head & tested welds to 800 psi. NU BOPE. Tested BOPE. 8/12/87 Fin testing BOPE. MU BHA & RIH. Test csg to 2000 psi. Drl float collar, hard cement & shoe. Drl to'1917'. Displace hole w/ 9.4 ppg KC1/ poly-plus mud & test 13-3/8 shoe to 13.7 ppg EMW @ leak off. Drl 1917'-2840'. 8/13/87 Drl 2840'-3193'. CBU, POH. PU mud motor, RIH. Orient motor. Drl 3193'-3461'. CBU, POH. 8/14/87 PU new bit & locked BHA. RIH. Ream 3170'-3461. Drl 3461'-4243'. 8/15/87 Drl 4243'-4427'. Trip for bit & BHA change. Drl 4427'-4684'. 8/16/87 Drlg 4684'-4754'. Trip for bit & BHA change. Drl 4754'-5082'. 8/17/87 Drl 5082'-5208'. Trip for bit & BHA change. Drl 5208'-5598'. 8/18/87 Drl 5598'-5977'. Short trip to shoe. Dr1 5977'-6260'. 8/19/87 Drl 6260'-6787'. Short trip to shoe. Dr1 6787'-6876'. 8/20/87 Drl 6876'-7070'. Make 12 std short trip. Drl 7070'-7350'. 8/21/87 Drl 7350'-7510'. CBU. Short trip to 13-3/8" shoe. RIH. Hit bridge @ 4593'. Wash through bridge RIH. CBU. POH. Hit ledge @ 4947'. Work up to 4940', can go down & rotate, but can't go up. 8~22~87 Work stuck pipe @ 4935'. RU wireline, RIH w/ free point indicator. Jars free 4690'-4725', drl collar 60% free @ 4755'. Backoff drl string @ top of jars @ 4690'. POH. Make up screw in assembly, RIH. 8123187 RIH w/ screw in assembly. Screw into fish & jar down 15'. Fish came free. Circ. POH. LD fish & fishing tools. LD rental tools, Monels & MWD. MU clean out assembly. RIH, ream tight spots @4808', 4715', 5028', 5844', 7345'. Presently circ & conditioning mud. 8-24/87 Circ & condition mud. POH to 13-3/8" shoe. RIH. Work tight spot @ 4034'. Circ, POH no problems. RU wireline. Run log #1 (GR-SP-CAL-DLL-MLL) from 7500'-1895'. Tight from 7500'-7480', rest of run OK. 8/25/87 Fin running DLL-MLL-GR-SP-CAL log. Ran FDC-CNL-GR-CAL 7480'-1400'. Ran LSS-GR-CAL 7480'-1898'. RIH w/ bit, CBU. POH. 8/26/87 Ran GR-FMT log from 1.2 sd @ 2035' through E-1 sd @7440'. POH. RU dipmeter. Ran dipmeter from 7480'-1895'. 'RD wireline. RIH w/ drlg assembly to 1895'. Stringing blocks to 10 lines. 8/27/87 Fin stringing 10 lines on the blocks. RIH. Circ & condition mud. POH. RU casers. Presently running 9-5/8"-10/34" production csg. 8/28/87 Fin running 9-5/8" & 10-3/4" csg. Circ & conditioned mud while reciprocating csg. RU cementers, mixed & pumped 1900 sx Trinity liteweight w/ gas-block, followed by 1900 sx "G" w/ gas block. Displaced w/ 122 bbl mud. Bumped plug to 2300 psi, opened ECP port, filled ECP w/ cement. Checked floats. Had good returns &circ 930 sx cement to surface. ND riser, set slips w/ 225 M#, cut off 10-3/4" csg. Install tbg spool, NU riser, presently testing BOPE. 8/29/87 Tested BOPE to 3000 psi. RIH drl cement 1434'-1828', POH. PU scraper RIH. Clean out cement to 7419'. Circ & displace mud w/ seawater. 8/30/87 Fin displacing csg w/ seawater. POH. RU wireline, run gyro & CBL-GR-CCL (7408-500'). PU bit & scraPer. PU & RIH w/ 3-1/2", PH-6 tbg work string. 8/31/87 Fin PU 3-1/2" work string. Pressure tested csg to 3000 psi for 30 min. OK. Reverse hole clean w/ 150 bbl "Dirt Magnet", 150 bbl drl water, 150 bbl "Dirt Magnet" and 150 bbl drl water. Circ & filtered completion fluid. POH. MU 5" TCP guns, firing head, pkr & pressure gauges. RIH w/ guns. RU wireline. RIH w/ CCL-GR to correlate TCP guns. 9/1/87 Fin correlating TCP guns. RU test lines & test to 3000 psi. Perf D-17 from 7227'-7293' DLL w/ 5" guns 12 jspf. Tbg pressure increased to 36 psi. Opened well to production on 10/64" choke. TP dropped to zero. Monitored well w/ bubble bucket. TP built to 12 psi w/ H?O to surface Shut well in. Initial TP=17 psi. Final TP=36 psi. Released ~kr. RO 72 b~l. Took samples every 10 bbl. Circ long way. Well taking 34 bph. POH. MU cement retainer. RIH set retainer @ 7209 DPM or 7198 DLL. Batch mix 100 sx "G" cement. 9/2/87 Perform hesitation squeeze on D-17 perfs w/ 48 sx of Class "G" & additives w/final pressure of 2510 psi. Squeeze 10 bbls cement below retainers. RO 2 bbl slurry, POH. MU bit & scraper on d.p. Displace hole w/ inlet water. Drl cement from .7167'-7204'. Circ. POH. RIH w/ bit & scraper on 3-1/2" tbg. Displace hole w/ filtered brine. POH. Presently PU 5" TCP guns. 9/3/87 Fin PU pkr &~pressure gauges, RIH. Filled 58 stds w/ 9.0 ppg brine for 500 psi under balance. Correlate pkr & guns w/ GR-CCL. Set pkr @ 7110'. Flowed well for annulus & fired guns. Perf D-16 w/ 12 jspf from 7136'-7172'. Flowed well for cleanup. Well stabilized @ 8 MMCFD @ 1940 psi FTP w/ a system pressure of 1400 psi. SI for buildup. SITP = 2309 psi. Released pkr & RO to production. Presently circ. 9/4/87 Circ to kill well. Spot 50 bbl polymer pill w/ 12 hr breaker. POH. LD gauges, PKR & TCP guns. Ail charges fired. MU tail pipe & pkr. RIH, set pkr @ 6956' DPM. POH. RIH w/ pkr plug & set plug in pkr. Spot 5 sx 20/40 sd on top of pkr. Tagged sd @ 6946'. Presently filtering fluid. (Bottom gauge @ 7091 MD, 6062' TVD. FBHP = 2420 psi @ 8 MMCFD. SIBHP = 2650 psi. FTP = 1940 psi. SITP = 2309 psi). 9~5~87 Fin filtering brine. POH. LD plug setting tool. Tested BOPE. MU 5" TCP guns w/ 12 jspf, pressure gauges & pkr, RIH. RU wireline & run GR-CCL to correlate guns. Set pkr. Perf D-6 sd from 6060'-6112'. Presently flowing well for cleanup @ 8 MMCFD @ 1861 psi FTP. 9/6/87 Continued flowing well @ 8 MMCFD. FTP stablized @ 1875 psi @ 0830 hrs. SI well. SITP = 1987 psi. Unseat pkr RO. POH. All shots fired. RIH w/ 3-1/2" workstring. Circ to raise brine wt. 9/7/87 Raise brine wt to 9.3 ppg. POH. Run GR/CCL from 7100'-5500'. RIH w/ 5" DP. 9/8/87 Fin RIH w/ 5" DP. POH. LD DP. RU to run production tbg. PU seal assembly, blast its, and dual pkr. Presently PU 3-1/2" tbg. 9/9/87 RIH w/ 3-1/2", 9.3#, N-80, EUE long string to SCSSV. RIH w/ 3-1/2", 9.2#, L-80, CS hydril short string to SCSSV. Stab short string into dual pkr. MU SCSSV's, methanol injection sleeves & 4 control lines. Presently RIH w/ 3-1/2" production tbg. 9/10/87 RIH w/ dual strings of 3-1/2" tbg. Space out. Filled annulus w/ completion fluid w/ .75% KONTOL-KW-132 corrosion inhibitor. Landed tbg in tbg spool. Set dual pkr. Attempted to test annulus. Hanger seals leaked. Presently checking tbg hanger. 9/11/87 Landed tbg hangers. Tested hanger seals & csg to 2000 psi 30 min, OK. ND BOP stack. NU xmas tree. Tested tree to 5000 psi. Presently fabricating flowlines. 9/12/87 Fin hooking up control lines. Unloaded long string w/ CTU & N2. Flow testing long string @ 8 MMCFD @ 1949 psi FTP. 9/13/87 Fin flow testing long string. Unloaded short string w/ CTU & N^. Flow tested short string @ 9.9 MMCFD @ 1880 psi FTP. Rigged down CTU. RELEASED RIG to M-25 @ 1200 hrs 9/12/87. em/56/sundr3 Attachment #3 -~. TRADING BAY UNIT STEELHEAD PLATFORM WELL M-2 CURRENT CDMPLETION ASSEMDLY 10/27 TES?ne? FMC I)u~L SpLlg; H~nger (TC-GO) e/EUE x CS Crossovers LONG STRING 3-I/;:, 9.3# N-BO EUE & Pup J-ts. 10-3/4' Csg changover 'to 9-5/B' · 50B' (HID 9-5/B' Csg= 43.5 & 47# N-80 Bu't'tr'es~ SHORT STRING 3-1/E', 9.2#, L-BO -tbs & pup 20' 8 727' (Mn) ECP ~ 1750' (MD) ± 13-3/8' e 1895' (MD) Ii'tls FLow Coupling (75') -tls 'XXO' sliding sleeve me-I:hnnol InJec-tlon por-t -tls Flow Coupling (750 tls series '10' Flapper SSSV tls Flow Coupling (51') 423' 9;0 449' (MD) 3-1/E; 9.3#° EUE L-BO Tbs 3-1/2', 9.25 CS Hydril L-BO Tbg Baker A-5 ]]uat Po~cker ~ 5954' 'to 5967' 3-1I;:', 9.3#, EUE L-BO Tbs O'~s X nipple (E,B13' rain ID) E 5999' (MD) 3-1/E', 9.3#, EUE L-80 Tbs. Cpo~ovem 3-1/25 8md Mod~]e~ EUE Box x Bu~es~ P:n ~bide ~a~ J~s aS re.Ired on 3--1/~ ~.~J, N-BO ~g w/~N special cLear.ce ~ress connec%~ons (8' over[ep ~bove ~ below per?s) Crossover. 3-1/;:' ABM Bu'ctress Box × 3-1/2; Brd EUE p;n 3-I/2% 9.3# EUE L-80 Tb9 S-EP snap ta.tch SA w/2 seat unrl:s 8 6957' LOWER ,PACKER A, SSY Boker 9-5/B' x 3-1/;:', 47~,. SC-I ~ 6952' 6-5/8' x 3-I/E' X-ovem sub ~ 6969' (MD) i J~ 3-I/E' 8RD ABC Tbs O~ls XN Nipple I J~ 3-~/E', 8RD ABC Bakem Mu[e~hoe w/~L me-en~py gu{de ~ 7034' ?// / / /////////4. ///×/×//';, ///// / / /// ///I/ //// Baker snap La±ch 8 5953' (MD) 09;Is XN Nipple 8 5970' (MD) Baker shear-oug; sub 8 5977' (MD) B~ker h(zL~-cug; mule shoe w/WI re-en~;ry ~ulde @ 5979' (MD) D-6 6060'-6112' DLL Dev=18.5 12 JSPF NDTD ALI shor.t s%rlng connec.tlons are CS Hydrll above packer excep.t ?or ~he SSSV assembly, ALL measured dep'ths (MD) are based on long s~rlng measureMen~ D-16 7136'-717;:' DLL Dev=13.0 12 JSPF PBTI] @ 7204' (MD) Cemen~ reg;alner 8 7209' (MD) D-17 7287'-7293' (Squeezed) 9-5/8' Csg 8 7500 (MD) TD 8 7510' (MD) Attachment #4 REPORT of SUB- SURFACE DIRECTIONAL · SURVEY JOB NUMBER MARATHON Oil Company .. Leg B-2, Slot 3, Well Number: M-2 .. . · STEELHEAD Platform, McArthur R~ver Field, Cook Inlet .,. '.' ..ALASKA "" .. TYPE OF SURVEY DATE 450-347 SEEKER Gyro Multi-Shot 29-AUG-87 SurVey By J OCHOA Office Anchorage, Alaska EF;STME:tN CHRISTE;NS;N 6324 Nielson Way, P.O. Box 190454, Anchorage, Alaska 99519-0454, Phone: (907)563-3269 August 31,.1987 MARATHON Oil Company 3201 C Street Anchorage, Alaska Attn: Mr. Guy Whit~ock Well Number: Leg B-2, Slot 3, Well No: M-2 Location: STEELHEAD Pltfm, McArthur River Field, Cook Inlet Type Of-Survey: SEEKER Gyro Multi-Shot .. Date: 29-AUG-87 Mehod'of Calculation:' Radius of Curvature ' ,. Surveyor: ' J OCHOA '. Job Numb'er: 450-347 Dear Mr. Whitlock, We.are enclosing the original and three (3.) copies of the SEEKER Gyro SurVey.run on Well M-2 on Aug. 29, 1987 To date, the following distribUtion has been completed: A. Original and 3 copies, to MARATHON Drilling Dept. B. 2 copies to UNOCAL - Anchorage office C. 1 copy .for E/C permanent survey files We would like to thank you for using EASTMAN CHRISTENSEN's SEEKER Survey services. We look forward to serving MARATHON in the future. ES- District Planning Engineer cc/file cc: Vicki Lytle - UNOCAL - Anchorage, Alaska FILE:' ~LATFOR,M COORD D! UNDo~K CMS T[~IESHAR]~ - C~SL ~.19 - 87.320 " ....... ~ ........... . ................ ~ ~ · . . . .. ; ,..;,~'<:~ , 1 ~.'L ,,..' . ':;. ::;., ~':; :_ '..~':.'. ~.~ ".:. ' ."];:.t;. :.:' '.' -' "':: ;;:'::': '""~ "~'~;-'~:~':t:~:~2~ "~:=;"~*"':~;~;~:;;;'~:-:.:~'?:':..:::~'~'2,:::Z~:.~:.t;.~:'....-~ .... ~,~ .~;.:'..;t:;~.~:~:.'+.::,-:.-.:(.:~;~.~..~ .... :- - ~:~--~ ........ ;.' ......... :~'"'~.~'".f':' ..... ',,,-.,L ................ ~-..'-<.,,. ........ ;*-, --~ ............ t,-~-~.--':'.~-~'~ '¥'.. :-'; v :.'~ ~.' ';:.':.:' v ::':-,.¥'..-:.v, 'v v .,:::. ';'-' '. v:':~;::.':.':'-~::. :iT:-:::':'?:..%',:v;t ~-v ': :.:':. 4': :. '..;-;. s.t';~-.:~.;: ~.~{::.~ ~:~ ?' ~'::::~?~,~ ~.'}??? ~:~ }~:~ :.:.~'.:..} - .v.,.:~::. :.; .,..::: ..:?.: ~-4. ': .' · ',: '' · ':~ .~.':.' ':? :]': ' ;: ;. x.~} ~..;'. :'. :: '. ~.~:,,,., ~t';;;%. :,.:, ::. ....... 5 (Log datu- elevation for all Steelhead ~ells is erroneously reported as ~b~' on ~-~..E ~-~"logs~.but tha~.,~,?,~, uit~.._~:..~ ............. g : ::':'"':' ..:..".:: [ F i'nal surv'-~'~:.:'da~:~3':.::'ngt "' '::" .... ......... °t e'.".tha t'-'::':-.' X . i ncr e'a's:e s:,}:':..[6':::-~--e"~'~ [?::'an'd~:?.Y-..'-:'i nc r eases.::.: t 0-n'b;':th ~' ~:.;;~: ~':7:':~'..... "' ::] "X" COORD "Y" COPRg FNL FNL ..... ~[, ..... ......-..........:.:...:.~.." -: ~'./:~.: .. :~ .~..;:::~::: :: :..E.~ 7.. :::../::::::':~ .....:........: .... ~[~] LEG L~TA-1 ( ~e s t er'n~0s t } :(in OD9: HH: S S · S SS ): ..... 2' I~'~ O 76 ' a 27 2, ~ 99 ~ ~ 56, ~02....~.' .... '"'"::" :;''. ... :...... ;':'~' ~"':"?:~:?~:~:?::: '/... :" ' ¥" ':' ' ':'~:" :';?~?~:~':.. ...' .. '~':'"3'!~tT;~?':~'~"~.. j CONDUCTOR WELL NAHE "X" COORD "Y" 4 2,4991456.01 33 34 35 1 2147069.8 2 ...... ' ....... :'.' 214." 071,2 3 ...... ":'":'.'.'.".'::..'! '::.':.':-~:::?:.: 2 lZ~:i075 ;22'.:'."-:':':':.::'2'~ 499146.]~"~j'22 4 . z z, 5 214,083.26 2~ 499~459.16- 6 214,083-53 2,499,454-38 7 2~4~090.25 2,499,4,50.29 ~ 0 :~'-' ' ' '.;.':?;"?'.:; :~'.~';.'::;:/~':q"':" ::':':":.:::?' 21 ~, 0 7 7 · 2 0 ?..'~.~;;~:~:::;:~.2'i 4 9 ~'"~"~'~"~'5 5 11 214,079.59 2,49g,454.85 :;'"~ ' 12 214,073.78 2,499,455.54 --~ :. ~3j L~G-"A-2" Southernmost) ............. '." 214'~'-151,417 ...... '-Zt4'~gi389:~.'798 ....-"":-:'.:-!i':~!~!'"i~ ...... ~'"~ .... :.: ..:t :.:. , TT., . ': [ ................ r.-::.....~.::::. .................. : ......:::. .... · . ....... ::': - -::......:. ......... ;~,?~ .................... · :"::' ......... ': "...:~!~..~:? ~: ~' ~';~: ..7. ...... .... ~ ...... : ...... :" · .:.- u '- · -.... ~ :¢. .~'- --'-' ~ .:: :' .: :-'¥: '-:'~:":: ................ "~' :.'~:.~:;;:'::':: ~:.':.:..'?~:;:'..?:.~:~!~;;~7.'?.~;%: ..... '. ':' :'. ........................ · '::~'"'?'.?':~-':":""': ?:~t':':':~'~:'~:'~::::'"F~?~?':'~:~:~.~f~~ '~'""~:'.~:: ~:.'.:":.';' ' .~:.::."4~ ':':....:~:,:: :::~:'.:.~,i.:~:.' ========================= ~: :~.'...: '.:: '.::.'::...~..~:. :: .~::.. .: ::' ..:.::' :.~?. .' .' --: .' '.'..:? .: '. · ..F.-::......:-:. ',~,:?~, ~ ......... ~1'~ ....... '~'"'"'""':? .......... ~71':::"::~.:::::"TS;::7':::¥:':T:"': .... ::::' ' ........ :' ~.::'.:::' :"2 14~ 1 ~ 1 '3 Z :' Z, .4 ~ 9,3 8 Z - 8 0 '...' ?:'~.: . ~.~: .... .,..:: ............... s~J 3 214,144.51 2,499,388 67 ~j4. 4 ' 214~145.17 2,4~9,392.g5 ~.-~ .<. FILEt ,,~.LATFORM COOP. D5 O1 UNO,AK CMS TIMESH~RI - £M~L ~~~ ~t ~~.. 9 ' 214,155.46 2,4~°, 384.08 ' :'':'~' ......... '..- · ....... ..::' :~ ' : ::': : '::' ::': ': ' : ;::: ' ' ' ~: ~.:;~ :~::.: ::::::':'.':: ~ :::':': :~ :: ';;¥ :::':::::: ::::'5'.: ' : :" :' :'?:.:~:;:'::::"'::7':': :'. LEG :B:I (Northernmost) :::':.~--~::::2.1~'1q3'~31;.::?::::...~, ~99,530,992 '~': ..: '?1 1 214, ~4'3.28 2,~90,5.37.99 52~.6 964.-5..~. '~, 2 Zl~, 1~-?. 6~_ ?_iq99,536.60 -...~.. .:7'::Z.-. · '!':: : .... ::: · .!: ' :5:. :":::.:7)::':::.: "'-':--:/:::.': "':':7::: ..... :': · ::: :::: '::.,:. ·: : ~ :: :' ' :;7:;;i:!!??~*;' ' '. ::.;':: ;",:'::: ' 5. ' ........ ': ' ......": :: .............. ·' 214 · 1 ~ 6, 19 .:::::-::: :' 2, ~ 99,52 ~ · 56 ' ::::: ':: ? :' '::! ':;: : :::.:?:.:::;::!:~!~i ' ...:..':..:.': '......' :;: .! ....... ~ ...... z~,~.~ .z,~,s~.zv ....... ' :.~.'~' ...... 7 Z14,13T.S8 Z,49g,SZT.16 .... .~ ................ 9.. ...... .. ~;~:: ~:~.~:~. ~'~::.::~ ~:.:'~ ~ ~::::~5.~: ~ .~ -: :~.~::: Z ! ~" 138, ~ 6~:~.:~::~ ~ ~ 99., 535 ' 9 Z ~:':~'-:~::.. ::.~ '. '..~ ::~.::::~/~?~ ~' ?~.....~. :/::... ' ' ' ' ........... LEg B,Z. [Eas.yern~ost) :. Zl~,zzs.0Zl 2,~99,46q.388 '::~i , LAT (in:~DOO:~,~:SS.SSS): ...: : : ~: :: :': :':.:: ':' ': :':."::: :. ,: " :: CONDUCTOR NELL N~H~ "X" COOqD ,'Y" ~pORD FNL FN~:~' EASTMAN cHRISTENSEN RECORD OF ~::LIRVEY FOR OPERATOR · : MARATHON OIL COMPANY STRUCTURE : STEELHEAD Pl att:,:,r-m WELL : M-2 S;LOT : B2-3 LOCATION : McApthup River. Field, Cook Inlet, ._lOB NUMBER : RIO : DECL I NAT I ON RKB TO SEA : 163.0 ~ PLANE OR VERTICAL SECT ' DIRECTION EC DISTRICT : Ar, chor. a~Je, A1Ast.'.& 7-7Eastman ~ ~-~, Whipstock ~_~ MARATHON OIL COMPANY STEELHEAD PlatFc, rm McArthur. River. Field, Cook Inlet, AK MEASURED DR I FT DR I FT COURSE TRUE GE _.T I ON DEF'TH ANGLE DIREE:TIEIN LENGTH VERTIC:AL ~' c' D I'1 D M DEPTH 0.00 0 0 N 0 0 E 0.00 0.00' 100.00 0 13 S 48 38 E 100.00 100.00 200.00 0 24 S 78 I E 100,00 200.00 300.00 0 24 N $/ 7 E 100,00 300.00 400.00 0 6 S 87 I W 100.00. 399. 500.00 0 29 8 53 3 W 100.00 600,00 0 28 S 26 29 W 10C).O0 700.00 0 31 8 28 45 W 100.00 800.00 2 8 S 2 21 W 100.00 900.00 4 40 S 7 14 E 100.00 SLOT : 32-3 DATE PRINTED : 31-AUG-87 PAGE NO. 2 WELL : M-2 OUR REF. NO. : S06827.8MA F'BHL : S 1(])47 E dOB NUMBER : /_../Z,C'¢..,.Z¢'7 · VERTICAL SIJB'.Z;EA R E C' T A N O U L A R: C L 0 S ~J R E DOGLEG TVD C: 0 0 R D I N A T E S DISTANCE DIRECTION SVRTY 0.00 -163.00 0.00 N 0.00 E 0.15 -63.00 0.13 8 0.14 E 0.47 37.00 0.36 S C).62 E 0.22 137.00 0.01 S 1.13 E - O. 10 236. '-?. 9. 0.27 N 0. o'",_,° E 499,99 -0.02 336.99 597. ?9. O. 49 436.99 699.97. : 1,17 536. 7'P'P. 96 3, 23 636.96 ,:,; f/ 77 S/ C)c/ 736 77 0.10 N 0.41 E 0.52 S O. 11'.'W 1.29 S 0.51 W 3.50 S 1.13' W ?.42 S ' 0.88 W D M O. O0 S 90 0 E 0.19. c.._, 48 37 E 0.72 S 5'P 27 E 1.13 S 8'.-? 26 E 0.92 N 72 50 E 0.42 N 76 11E 0.54 S 12 2 W 1,39 S 21 40 W 3.68 S 17 52 W 9.4-6 S 5 19 W 0.00 0.22 0.24 0.58 0.43 o" 40 0 '-" ''') I" -'. 0.05 1.69 2.59 1000,00 7 58 S 18 24 E 100.00 9..o9,15 1100,0C) 12 58 S 10 30 E 100.00 1097.46 1200.00 16 36 S 16 14 E 100.00 1194.1:3 1300.00 21 58 S 1/_-, 16 E 100.00 1 ~'..,:,,:, ~''-'.49 1400.00 25 44 S 19 10 E 100,00 1379.93 20.06 836.15 38.17 934,46 63.65 1031.13 96.51 1125.47 136.64 1216.~3 20.13 S 1.56 E 37.70 S 6.09 E 62.51 S 11.98 E 94.21 S 21.22 E 132.71 S 33.52 E 20.19 S 4 26 E .: ..... lC/ :--' '.--/ lC) E 63.65 .'_=; 10 51 E S/6,57 S 12 42 E 13/_-..8:3 S 14 10 E 3.51 5.1'.-7, 3.91 5. :::7 :3.94 500.00 29 26 E; 18 2 E 100.00 1468.55 600.00 33 15 S 17 39 E 100.00 1553,94 700.00 36 28 8 17 12 E 100.00 1635.99 800.00 39 30 S 16 53 E 100,0(:) 1714,80 '..700.00 4.1 ' 5 S 17 43 E 100.00 1791.07 182.5£) 1305.55 234.11 1390.94 290.88 1472.99 352.0~ 1551.80 4.16.29 1628.07 176.59 S 226.09 S 280.62 8 339.45 S 401.19 S 48.29 E 64.22 E ol.33 E 9,o. 37 E 118.60 E 183.07 S 15 18 E 235.04 S 15 51 E 292.17 S 16 10 E 35:3.70 S 16 19 E 418.35 8 16 28 E o 7z 3. :32. '.3.2.'.' .-, (-) I 2000.00 41 35 S 17 10 E 100,00 1866.16 2100.00 41 27 S 17 20 E 10C),00 1941.03 2200.00 41 11S 16 54 E 100.00 2016.14 2300.00 41 3 8 17 i E 100.00 20~1,48 2400,00 41 17 S 17 35 E 100.00' 2166.74 481.8~ 1703.16 54.7,75 1778,03 613.37 1853.14 678.75 1~28.48 744.17 2003.74 464.20 8 527,50 S 590.60 S 653.5¢) 8 716.37 S 138.39 E 484.39 S 16 36 E 158.05. E 550.67 S 16 41E 177,48 E 616,6~ S 16 44 E 1~6.66 E. 682.45 8 16 45 E 216.24 E 748.30 8 16 48 E 0,6: 0.1: 0.3': 0. 1.. 0, 44 2500.00 41 52 S 17 36 E 100.00 2241.53 810.11 2078.53 779.67 S 2600.00 42 7 S 17 35 E 100.00 2315,85 :376,56 2152.85 843,46 S 2700,00 42 27 S 18 16 E 100.00 2389,83 S/43.:31 2226.83 907.47 S 2800.00 43 12 S 18 38 E 100.00 24.63, J. 8 1010./--.8 2300.1:3 971,95 8 2..000, 00 43 12 S 18/ 51 E 100,00 25.]:6. £)7 1078, 3? 2373,07 1036.58 S ;CONTIN~.IED ON NEXT PAGE" .. · =.~.30 E 814 69 S 16 52 E 0.5~ 25/.-, 52 E .. ,_,ol.61 S 16 .~5 E 0.2., 277.m.?. E 94:=: ~-,o c. .._ ..... : ....... 16 59 E 0 2'P :3.74 E o.-,1 3('~ E lo:::F, ...4 S 17 1:3 E 0 ¢" ..i.¢.. . . . - I · '-" [/"'/ · MARATHON OIL COMPANY STEELHEAD Plmt~orm M,=Apthup River. Field, Cook Inlet, AK MEASURED DR I FT DR I FT COURSE TRUE DEPTH SLOT : B2-3 WELL : M-2 PBHL.' c.._, i0 47 E ANGLE DIRECTION LENGTFI VERTIC:AL SECTIOIq D M D M DEPTH DATE PRINTED : 31-AUG-87 OUR REF NO · ¢.nAo'~v. ......... .. .... =_ 8MA dOB NUMBER : ~Z,~0_5¢Z PAGE NO. 3 VERTICAL RI IB'.=;EA R E C T A N O LI L A R' C L 0 S U R, E DOGLEG TVD C: 0 0 R D I N A T E S DISTANCE DIRECTION SVRTY .. D M 3000.00 4:3 57 S 18 41 E 100.00 2608.52 1146.56 2445.52 1101.65 S 3100.00 44 49 S 19 52 E 100.00 2677.79 1215.74 2516.9'F.~ 1167.68 S 3200.(.30 44 13 S 18 14 E 1(.30.00 2751.29 1285.12 2588.29 12:}3.94 S 3300.00 43 20 S 12 1 E 100.00 2823.50 1354.07 2660.50 1300.7A S 3400.00 44 0 S 6 47 E 100.00. 2895.83 142:3.07 2732.83 1368.79 S 344.05 E" 1154.13 S 17 21 E 367.13 E 1224.'~'~.).:, '='._, 17 27 E 390.02 E 1294.11 S 17 32 E 408.06 E' 1363.20 S 17 25 E 419.35 E~' 1431.59 S 17 2 E 42 ' ~'~^~ 00 44 27 c. e~ ~o .-,o · :,._,vu .... 4 11E 100.00 2767...5c) 14~z.~= ~,=,04.50 1438.21.. ~ A_ 04 E 1499.. .99.. c.._, 16 30 E 3600.00 44 3 S 5 9 E 100.00 3039.13 1561.90 2876.13 1507.76 S 431.71',.E 1568.34 S 15 59 E 3700.00 43 53 S 4 55 E 100.00 3111.10 I630.~7 2948.10 1576.91'S' 437.81E 1636.56 S 15 31E 3800.00 43 29 S 5 35 E 100.00 3183.42 16~9.72 3020.42 1645.67 S 444.13 E 1704.57 S 15 6 E 3900.00 42 47 S 5 3 E 100.00 3256.37 1767.80 30~3.37 1713.77 S 4,50.46 E 1772.00 S. 14 44 E 1 · 10 1 · 20 1.29 4.39 -_.. _!._, I ,2,'.:' 0.7E O. 2.2 0.61 0.7~ 4000.00 42 18 S '4 13 E 100.00 3330'03 1835.04 3167.03 1781.20 S 4100.00 41'31S 3 23 E 100.00' 3404.45 1901.34 3241.4.5 1847.84 S 4200.00 4I 21S 3 26 E 100.00 347?.42 1966.96 3316.42 1713.90 S 4300.00 41 23 S 2 47 E 100.00 3554.47 2032.45 3391.47 1779.88 S 4400.00 41 15 S 2 36 E 100.00 3629.58 2077.81 3466.58 2045.83 S 455.93 E 1838.62 S 14 21E 460.35 E 1904.32 S 13 59 E 464.28 E 1769.41 S 13 38 E 467.87 E 2034.41 S 13 18 E 470.97 E 2099.34 S 12 58 E O. 7/_- 0. ?/= 0.17 O. 4:2 0. 1 :E 4500.00 40 30 8 2 5~ E 100.00 3705.1~ 2162.62 3542.19 2111.19 S 474.15 E 2163.78 S 12 39 E 4600.00 3'B 57 S 3 1E 100.00 3781.54 2226.61, 3618.54 2175.67 S 477.54 E 2227.48 S 12 23 E 4700.00 38 47 S 2 42 E 100.00 3858.85 2289.43 3695.85 223~.04'S 480.70 E 2290.06 S 12 7 E 4800.00 35 30 S 3 20 E 100.00 3~38.55 2349.25 3775.55 22~.32 S 483.88 E 2347.6~ S 11 5:3 E 4~00.00 31 42 S 4 16 E 100.00 4021.83 2404.17 3858.83 2354~53 S 487.54 E 2404.48 S 11 42 E . · .. . . ~4._,4 3~45. 10 5000.00 29 2 S 4 6 E 100 O0 4108 10 -~ = .3,~ 2404.95 S · "l ¢-! · . 5100.00~26 5 S 3 59 E 100.00 41~]6.75 2500.32 40.:..:,. 75 2451 5200.00 24 46 S 4 21 E 100.00 4287.06 .~,~c,~.__~.?,7 4124.06 249:3.~'1. S ="'] 4 ~A E 100 00 ~=o 05 -,~o~ 20 4215 0.5 2535 · _.c, L0.00 24 15 S ....... 4._~16 35 %~6 S 5400 00 23 54 S 4 26 E 100 00 446~.35 2624.74 ~'~ 4..ol.23 E 2454.60 S 11 33 E 494.49. E 2500.47 S 11 24 E 47.7.61 E 254:::.07 S.11 17 E 500.76 E. 2584.26 S 11 10 E 503.8:3 E 2624.7:3 S 11 4 E 0.7~ 0.5? 1.1:~ '=-:, :3] ) 8:: 5500.00 23 18 S 4 1E 100.00 4560.~? 2664.52 4397.~ 2615.88 S 5600.00 22 48 S 3 12 E 100.00 4653.00 2703.36 44?0.00 2654.~6 S 5700.00 22 1S 3 45 E 100.00 4745.4.5 2741.17 4582.4-5 26~3.01S 5800.00 20 46 S 2 36 E 100.00 483:3.56 2777.32 4675.56 272?.42 8 5~00.00 1~ 58 S i 6 E 100.00 4~32.31 2811.70 476~.31 2764.21S CONTINUED ON NEXT PAGE ... 506.83 E 2664.53 S 10 58 E 0.6: 50.9.29 E 2703.36 .'3 10 52 E 0.5! 511.60 E 2741.17 S 10 45 E 0.8 513.62 E 2777.33 S 10 3'.~ E 1.3: 514.75 E 2811.73 S 10 33 E 0.?, (7-7 Eastman MARATHON OIL COMPANY STEELHEAD Platform McAnthuv Riven Field, C. ook Inlet, AK ~ F .-4_JT : B2-3 WELL : M-2 F'BHL : S 10 47 E MEASURED DRIFT DRIFT COURSE, · TRUE DEF'TH ANGLE DIREE:TION LENGTH VERTICAL SEC:TION B M D M DEPTH 6000.00 19 4 S I 28 E 100.00 610£).00 17 45 S I 54 E 100.00 6200.00 17 4 S 0 24 E 100.00' 6_-,300.00 16 32 S 1 4?/ E 100.00 64.00.00 16 19 S 0 27 E i00.00. 6._,00 00 15 41 c. 0 4-9 E 100,QO 66.00 00 14. ~ 8 0 '-' ~ , . ._4 .:,.., W100 00 6.700.00 14 25 S 2 2 W 100.00 6800.00 1._, = 17 S 4 10 W 100.00 6,900 00 14 4 ~ 3:M9 W 100 00 . ._1 _ . 7000.00 13 28 S 5 33 W 100.00 7100.00 13'21 S 7 56 W 100.00 7200.00 12 42 S 12 17 W 100.00 7300.00 12 31 S 13 0 W 100.00 7400.00 12 5 S 16 19 W 100.00 DATE PR I NTED. '. .:,'" 1-AUG-87 ! ' . . ' '-'('/_-,'-"-' . OI_R REF NO . .=, ).,:,z. 7 8MA ,JOB NUMBER : VERTICAL SUBSEA R E C T A N G LI L A R TVD PAGE NO. C: L 0 S U R E DOGLEG ri_: 0 0 R D I N A T E S .DI'.'_-;'FANCE DIRECTION SVRTY 4863.56 2797.61 'S 4958.44 2829.17 S 5053.86 2:--:59. (:)8 S 5149.5?/ 2887. ?8 S 5245.51 2916.25 S 5026.56 2844.65 5121.4-4 2875.84 5216.86 ·27/05.33 5312.59 2933.82 5408.51 2961.70 , . 5504.64 2988.83 5341.64 2943.81 S 5601.10 3014.75 5438.10 2970.18 S 56'P7.84 ,3039.49 ~,-,~ ~.~ ._! .=; ,:',~ , · _ 7 .-. 4.50 :.1:064.37 = / '" . · · _, :,.:, 1 50 3021 07 ._:: · ~,'::-."-"~1 23 .--,c)oo ~,/. i M '-'~' ':".:, ........... ,_ ..... . :, :, ._ 7..c,. 2."'" 304/-,. _..34 .:,'"' D M · 515.49 E .,_,44.70 S 10 26 E ,:,:,7._ 10 21 E 51.6 42 E '-"-' .=, 92 '=' ' . . . ._il· 517.02 E 2"?C)5...._.45 ..,'=' 10 1~._ E 517 F,'-' --, c,~ ,:,-:, C/9 c. ._ . ,.: ........... 10 10 E 51,.,'='. 15 E .,_'.--":.'/. /',_ 1 . 'P. 2 S 10. 4 E 518.46 E 2989. i2 S 9 59 E 518.52,..E 3015.10 S ? 54 E 517.94 E 3039.93 S 9 4.9 E 516.55 E 3064.~1 S 9 42 E 514.75 E .308~.52 S 9 35 E 0.91 1.32 O. 82 0.67 0.4:.!: L,, / 6 4 0. R7 O. 61 1.02 1.2] 512.78 E 3112.58 S 9 29 E 510.05 E 3134.85 S ~ 22 E 506.10 E 3156.1(} S 9 I4 E 501.32 E 3176.37 S 9 5 E 475.~3 E 31~5.88 S 8 56 E 0.71 0.5/_- 1.1:.2 0.24 C). 8:-- 5988.36 3111.78 5825.36 3070.05 S 6085.63 3133.89 5922.6.3 3093. C)8 S 6183.06 3154.95 6020.06 3115.26 S o~_,: ..... ~.., .:.1:174. .9R. _ 16,117. AS_ _ 317: /-, .. .. 5A_ c.~, /_-378.35 :3194.21 !6215.35 3157. 17 S ~ .~o 3197,75 741.9,00 12 5 S 16 19 W 19.0C) 6o;~6.~ ' CLOSURE - DISTANCE : 31~. 48 DIRECTION : S 8 54 E /. o.':.,~ 93 3160.9.9 'E_-; 494. ~-' .=, ._,4 E ol E 31':'-¢o 48 ":'-' ':-' : ~.;i.i.- ........., .... l . REPORT UNITSFeet SURVEY CALC:UI...ATION ME'FHOD : Radius of c,Jr. vm.t,Jne 0,0¢ SURVEY RUN INFORMATION 0-741~ MD, SEEKER GYRO MLILTI-SHOT SLIRVEY DATE RUN: 29-AUGr-87 SURVEYOR: d OCHOA dOB NO: 450-347 NOTE: 74.19 MD IS: F'ROdECTED DATA ONLY ~ASTMAN CH~ISTENSEN RECORD OF SURVEY FOR OPERATOR : MARATHON OIL E:OMPANY ' STRUCTLIRE : STEELHEAD F']~t~¢,r.m WELL : M-2 SLOT : B2-3 LOCATION : M,:Arthur. Riven Field, Cook Ir, let, AK .lOB NUMBER : g~0-5¢~ RIG : DECLINATION : 23.85 E RKB TO SEA : 163.0 , PLANE OF VERTICAL SEE:TION DIRECTION : S 10 47 E .: EC DISTRICT : Ar, chorm~e, Alm.$ka Eastman/ MARATHON OIL COMPANY STEELHEAD PlatF,:,pm McArthur Rivep Field, Cook Ir, let, AK MEA.=.L RED DR I FT DEPTH ANGLE D M 1~3. O0 0 20 2~3.00 0 24 3~3.01 0 13 463· 01 0 20 5~3.01 0 28 DR I FT. COURSE D I RECT I ON ' LENGTH D .M , · · S 65 : 4 E O. O0 N 43 28 E' 100.00 N 69 44 W 10£). 00 S 70 48 W ': 100.00 S 37 7 W , 100.00 663.01 0 30 763.02 1 32 863.13 3 44 963.55 6 46 1064.76 11 12 1167.61 15 25 1272.66'' 20 30 1381.26 25 2 1493.64 29 12 1610.86 33 36 1733.82 37 30 1862.93 40 30 1995.78 41 34 2129.29 41 22 2262.22 41 6 SLOT : B2-3 WELL : M-2 F'BHL ' '-' . .=, 10 4.7 E TRUE VERT I CAL VERT I CAL .=,E ..T I ON DEPTH DATE PRINTED : 31-AUG-87 OUR REF. NO. : I06827. T ¢] ,JOB NLIMBER : ' ¢'5'0 -~ 5/7 RUBSEA TVD 163.00 0.36 0.00 ~ 263.00 0.43 100.00 36:3.00 -0.07 200.00' 463.00 -0.10 300.00 563.00 0.25 4.00.00 R E C T A N G U L A R fi.: 0 0 R D I N A T E._,° ' .29 c. 0 .'=,c'_,, E · ., , .-~ .. ' 0 24 c. 1 c)2 E . ..m . . 0.26 N 0.98 E O...~°~ N 0.64 E 0. ~-o'-' =- L-,~ 0.06 E ._,c. 27 53 W 100. C)O /-,/-,2_ _ _. 00 0.91 .=;-,(')(')_... 00 1 . (')0. c.._, 0 .35 W · _,'=' 15...,'="".. W 10(').. (7.)1 763, (')() 2· 1'":'= /=,O,C) .00' 2'.~ 33 S 0 .94 W 'S .~. =o' i 11 W · .- ._,..:. E 1 ¢)0 1 C) , o/..=, C) 0 6 40 700 00 6 73 ._,c. . ~ I_! _s,_~. . mm · · 1 ._. 41 i 64 0 o 13 39 E 100.42 96:3 00 .=, 800.00 5. S .27 E ._,o 1 c,j 43 E 101.21 1063.00 :=:_ 0 . :=:_ 0 9. 00.00 R_ o.. 49 .=, ~' 4 .54 E ,_,9 9 64 E R 14 14 E I02.'~= · .... o.., 1163.00 .J4.74 1000.00 5~. '=' ._~ . P, 16 1M E 10F, '~= '-'/- 65 1100.00 84. 8. ..... [.., 12A2 00 70 c. .... = ........ i 44 E '=' 18 35 E 108.60 1363.00 lz'-',=,. '~ 69 12AA 00 lO-M 11 R 30 92 E ._m . # . ~._ . -_ · . f" ~. '--~ · :, 1° 7 F llO ~"~' .._~_ ........o,:, 14 :,.:,. 00 179 41 1300 00 173.6.3 '-':, 47 ':-:':.' E · .=, 17 36 E 117, .-_':*'=' ~.._,_..~.'=/-,~ 00 240.05 1400 .0() 27,! .79 S 6/._. (:)3 E S 17 6 E 122.96 1663.00 311.09 1500.00 S 17 24 E 129.11 1763.00 392.24 1600.00 S 17 11E 132.85 1863.00 479.11 1700.00 S 17 12 E 133.51 1963.00 567.00 1800.00 S 16 58 E 132.94 2063.00 654,.07 1900.00 2163.00 740.91 2263.00 82?. 25 236:3.00 919.02 o./o 00 101C) ~2 2563.00 1103.49. 2395.02 41 18 S 17 33 E 132.80 2528.85 41 56 S 17 36 E 133.83 2663.67 42 20 S 18 1E 134.82 2799.76 43 12 S 18 38 E 136.09 2937.02 43 29 S 19 25 E ' 137.26 3076. 10 44 37 S 19 35 E,' 139.07 3216 32 44 4 S 17 13 E,' 140 .r,.~ ~'3M4-..:._ .47 43 42 S Ye 12 E lY4° 16 3493.71 44 25 S 4 21 E 13'~.2:3 50 ':'/- '='~ 2C) 44 0 ~-' . ,=, 5 4 E 137/ ,--~ h.,~ ---' ..~ · · , COhlTINUED ON NEXT PAGE ... 2000.00 2100.00 2200.00 2300.00 2400.00 F'AGE NO. '~. '~ DOGLEG SEV E R I TY 0.00 0 4'" 0.52 C). '"'-' 0.7'"') C) · ')'-' (~ o . (.)._~ 2.33 4.10 4.87 ...._~ 3.72 3.76 300.06 S 87.33 E 3 1° :378.10 S 111.29 E 2,3:3 461.52 $ 137,56 E 0.81 ._,4=,,00 S 163 80 E 0." 629.76, S 189,40 E 0,2._." 2663.00 1199.12 2500.00 2763.00 12~6.40 2600.00 2863.00 1391.57 2700.00 2963.00 1488.14 2800.00 3063.00 1584.86 2900.00 713.24 S 215.25 E 0.33 798.04 S 242.14 E 0.48 884.20 S 269.60 E 0.36 971,80 S 298.69 E 0.71 1060.52 S 329.84 E 0.44 1151.84 S 361.46 E 0.82 1244.77 S 3~3.48 E 1.24 1337.56 S 414.~6 E 4.¢)3 1433.82 S 425.71E 2.47 1530.74 S 433.77'E 0.47 777 Eastman/ MARATHON OIL COMPANY STEELHEAD Plmtform McArthur River Field, MEASUREB DR I FT DEPTH ANGLE · D M 3771.84 43 36 3?09.03 42 46 4044.45 41 57 4178.11 41 23 4311.37 41 22 4.444.34 40 55 4575.7'2 40 5 4705.32 38 37 4829.82 34 22 4948.06 30 25 Cook Inlet. AK SLOT : WELL : F£HL B2-3 M-2 · _.c' 10 47 E DRIFT COURSE TRUE DIRECTION LENGTH VERTICAL D M DEPTH 138.63 137.20 135.42 1 ":"":' 66 133.26 132.97 131.45 129.53 124.50 118.24 S 5 24'E ':' 4 5:=: E S 3 51 E , · .,c' 3 .,..._ E · -,'=' 2 46 .E S 246E S 3 1 E S 2 44 E .S 3 37 E S 4 11E VERT I CAL .=.ECT I ON 3163. 3263. 3363. '3463. 3563. O0 O0 O0 00 O0 1680.40 1773,90 1864.65 1952.63 2039.90 3663.00 3763.00 3863.00 3963.00 4063.00 2126.66 2211.18 2292.73 2366.19 2428.'-'¢ [,ATE F'RINTEB : 31-AUG-87 OUR REF. NO. : I06827. T 0 ._IDB NUMBER :~ r/~/~-=S~ '.:;UBSEA R E C T, A N G U L A R T VD ' C 0 0 R D I N A T E._,° 3000. O0 3100.00 3200. O0 3300. O0 :_--:400.0(} 35()0. O0 3600. O0 3700.00 3800. O0 3900. O0 PAGE NO. DOGLEG SEVER I TY · 16'26..38 S 442.27 E 0.33 1719.9C2 S 451.00 E 0.64 4..,=, 02 E r) :--:'-..: 1810, 94:3 .~'-'. ..... 1,'~,,-.~o c. ,:,~ ..-. 47 ._, 463.42 E . 0'. 47 1 ¢~ q o ~ A'=' 2:3 E ...... .'. ,:. 7. :3'2 ..,, -._ ,_,. ("~ . --.,o 2074 92 c: 472 21./:,('),.. 14 S 476.71 E ('). 6,5 2242 36 '=' '-' . o6 E 1 15 4c',0 "~' ._l . 2316.37 ._,c.484.91 E ._.°,. 43 237'2.26 ':' '-' 9 4. ,:, .~ 5062.25 27 12 5173.47 ' 25 7 5283.4? 24 20' 5393.05 23 55 5502.19 23 17 S 4 2 E S 4 15 E S 4 20 E S 426E S 4 0 E 114.18 111.22 110.02 109.56 107.14 4163. 4263. 4363. 4463. 4563. O0 00 O0 O0 2483.51 2531.85 2577.44 2621.94 2665.38 4000. O0 .. 4100.00 4200.00 4300.00 4400.00 2434.20 ._.c.4'23.31 E _'--'. :]-:2 2482.75 '='._, 4¢?/-,, _. 77 E 1 .87 · --~ .~'~ --~ ~'m · -'~-',=, 49 o 500..-,=' ...., ~.., E 0.71 257:3.14 8 503.66 E 0.38 ~A 1 ~.. ..... 75 S ~,(.>' 6.89 E 0.60 5610.84 22 43 5718.91 21 47 5826.12 20 33 5932.63 19 40 6038.50 18 34 S 3 16 E S 3 32 E S 2 12 E S 1 13 E S 1 38 E 108.65 108.07 107.21 106.50 105.87 4663. 4763. 4863. 4963. 5063. O0 00 O0 O0 00 2707.52 2748.17 2786.44 2822.61 2856.91 4500. O0 4600. O0 4700.00 4800. O0 4900. O0 2659 15 ¢' =¢'~-' 53 E 0 , ..m ._1 .z ~'/. m '... 2700.05 S 512.(i)5 E ' , 0. :37 2738.63 S 514.01 E 1.22 2775.27 .='~ ._,~14.97 E 0 . :qo_ 2810 02 S 515 o~ E t '- i 6143.60 17 27 6248.23 16 49 6352.57 16 25 6456.72 15 57 6560.55 15 13 S 1 14 E S 1 5 E S 1 7 E S 0 40 E S 0 2 W 105.10 104.63 104.3:3 104.16 103.83 5163. 5263. 5363. 5463. 5563. O0 O0 O0 00 00 28:38.85 2919. 17 294.8.53 2'277.21 3004.69 5000. O0 5100.00 ' 5200. O0 5300. O0 5400. O0 2842.35 S 516.78 E 1.06 2873.13 S 517.21E 0.62 2902.88 S 517.96 E 0.3:7 2932.01S 518.31E 0.46 2759.94, S ~ 518.57 E 0.74 6664.01 14 35 6767.37 15 0 6870.87 14 25 6973.91 13 37 7076.74 13 23 S 1 31 W/ S 3 27 W,' S 4 2 W S 5 9 W S .7 23 W 103.46 103.36 103.50 103.04 102.82 ~CONTIN~.~ED ON NEXT PAGE '... 5663. 5763. 5863. 5963. 6063. O0 00 OD 00 00 3030.70 3056.12 3o81.93 8105.91 3128.79 5500. O0 5600. O0 5700.00 5800. O0 57¢00.00 2~86.47 S 518.22 E 0.70 3012.56 S 517.12 E 0.62 303~.19 S 515.25 E 0.58 3063.97 S 513.34 E 0.82 3087.75 S 510.77 E 0.56 Eastman MARATHON OIL COMPANY STEELHEAD Platform McAr-th,Jp River Field, Cook Ir, let, .AK MEASURED DR I FT DEPTH ANGLE D M 7179.43 12 50 7281.72 12 33 7384.30 12 9 7419.00 12 5 DRIFT. COURSE DIRECTION ~'' LENGTH D M ., ~;, :. · S 11 24 'W 102.67 S 12 52 W 102.49 S 15 48 W 102.38 S 16 19 W 34.70 CLOSURE - DISTANCE, : 3199.48 DIRECTION : S 8 54 E SLOT : o ~ WELL : i'1-2 PBHL : ._.¢' 10 47 E TRUE VERT I CAL VERT I E:AL SECT I ON DEF'TH 6163.00 6263.00 636:3.00 6396.93 DATE F'R I NTED :'..,":'- 1-Al__~n-~:7_ OIIR REF. NO. : IO~,_,~7.T 0 ,JOB NUMBER :. · :,LB.:,EA R E C T A N G U L A R T VD E: 0 0 R D I N A T E ¢' ..~] 3150.75 6000.00 3110.81 S 3171 '-"-' . ,:,,:, 6100.00_ :3132.74 S 3191.27 6200.00 3154.00 S 3197.75 6233.93 3160.99 S ., REPORT UNITS : Feet ~. ,, , 507.03 E 502.20 E 496.84 E 494.81E SURVEY CALCULATION METHOD :' Radius o~ curvature PAGE NO. .4 DOGLEG SEVER I TY 1.03 0.42 0.73 0.37 7-7 Eastman 500 1000 ............................ 1001 2179 . . , .. ~ ......... ...-. ..:_. 0 "-: .................... .'- ........... i .......... : ............. i .............. . .................... .......... i ............. ;, ......................... i .......................... 2851 .................. i .~..<._L :.-~--..:--L-'.. : , , i_,., .: .. ' ' l ................ : ............. 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' ~..,..:.!..~I LL;~. !4;'/-:-f' ...___.,_: .t..:.__.:.., ._ L..:._,'.,_L,_:..~_.L.~._,.Z':_:::_...:.~..:_ ~.___:'_.L-__- .... ::: .... '.~ :_..:._~_.:__.'_._:._: ......... .'~_~F;_.~.-J;~_-.---.-'_!: . ..,..:, .... i ...... .~-:--:..i ~-.-~'~-y-!'--~.~-!-4.-- -;- ......... ~-L~.L'---i-; .:- =:4-L-:. ..... ::.! ..... .:5 .... L.';_:_.:; .... ~-'~. ' , , ' i ' '. ..... · ' ' : _:_,-%______ ....... ~ ....... :_ ._, ..... __. _-__: .............. ~ ....... ~~_~ ..... :. · ...... : ................ ..: ..... ........ ~ i'~ 15:36 _ · ,..., _--.,__. H .... '_L ....... -4.: ~- --~_ ..... -:-~ .... ='i'4--F~X- .... !-~- ........ {~ .... ' 4- ........... ~ .......... ~ .......... ~ ........... . ...... : ........... ----=-~ ..... d'-----'"'" .......... ' ........ '-" ......... ; .............. -- .................................... _:~_: i ' ' L.:. ' I ' :--~ ----\' ' i- : ' ~ ' I ' ' : ' ' .... -] . , --..'--~--~-':--"-~'.~--._ _ ~,~ ........ .'--~', ..... '".- ........ -"'i .... ~ ............ :' ........................... :'- .................; ,_ --.f'-~.:-~--"-'k:----:NL-~i'7'~_~... .... :---:'q-----:' ..... ! .... ':' ...... -d ..... : ............ 4~_? ......... ---:- ~_.2000.. --i ~ ~ ,. t : ! ,=~-~,~C-'----i-------'~' --; ',.." ...... ~ ..... ~-:----~ ........ i .... \ .;. ...... i ..... ; ......... ~ .... ' .... {_ .................. i ............ ~ ...... ............................ ~ ............. ~ .................. 285~ ''~ ........... : .......... :. ....... ' ....... 'L.X_.Z'.';:.:L._L/_L'L. ............. ,--4 .... ; · t'· ...; ................................. ~ .......... . ..... ' ...... -~ ................ ~ ................. : .................... i ......................... ! ....... 487'4 ....... .. _ ~ ......... .'.._: ...... · ~ J __ ..... ~ ~-:3000 i' :3545 ..................... i ............................................ .......................... ;": ........... ; .................... ; .................................................. . 543:3 -' ' - ': ' ......... /- .............................. ~ · .. :- ............ · ~_ ~~.._· . __ _ _ .._ .,_.. ..... .......... =:- ]'VD :.L_ ............. : ...... : ...... ~ ........ ~-: ......... : ' '"' :-""---'L---'-----';'--'--"--'" .............. ~ ' __ 422?' ' .! ......... .... ! ........................... : ......................................... .597':~ ....... ; ...... . . , ...... -;--~-- ~- ~ ....................... i ....................... -r. ..... L ......... , · -r- .......................... ' ........... '- ......... ' ........... ' __...._~' L..24000' ' ' .!. :____, r .... ,: ........... .':., x_ ...... 487'4' --- i ....... -, .......... -6495 T ..... __~' ..... ......... : ~ - , : ~ i -- ~- -7'012 -~ ..... ~: -- ~' ---:---,-. f', .4. ' ,. : ~ .......... · ' ' - ..... --:..4 ..... ~ '-'i .... :- ......... :'~ $43~_ ............................. ' ' {, ' · : i ! .' -F~ ,-4-- 4-~:--~--~--- H - _._/_-'..~.. L.:_L.~_ --r .... !. .................... : :--,.--: .- ........ ,,. ~-'-'~.:_.~ .'_5ooo. ;500 1000 · . _ . . 1 SO0 · . 2000 ...... 2500 ............ . · · . :3000 ....... · :3500 ._ ..... 4O0O .~.-';~'";'.-r ";T~:-:" t ; · ' ,. ___ ' : .... 6495 · ' ' ' : · :' , , F-' ,' :' .._:.:;'.;_;_.-:_~.~:,_ - -~-- .~ '...: '. ,: : ' ~ ........... ~.._ .- - , - · · : ?-i- · ,--':"'- _____ ~-c :"T' :- , ' .................................................. : ............................ ~ ...... ,~...: ..... :. t._:_.:Li-'_:L.i..:_'~_:d.t. · I : · :- . , - : · : i : , - I · ...... · . · .................................... .L ..................... z ......... i ........................ ................. 1000 .......... 0 ......... 1 000 .......... : 2000 ...... 3000 ......... 4000 .................... ' -'i ........ bURVE¥,SO6B20~7'I'i^....... :~' ................ :1-- I"IARATHON .OILCOMPANY" ~_-'. ~.T:._-Z~..---~ SURVE¥~ $o~827'. 8~^ /'"~---i._._ ,L~-...'~..-Y_Y'.T. 5.'..-. I .... i ............. ." STEELHEAD P I ' ~ .... ld'~L, ' ~ 2 I ' 'I ............ SLOT' B2:3 .. ** MARATHON OIL COMPANY ** ** STEELHEAD Platform ** ** 'McAr. thur River. Field, Cook Ir, let, AK ** Clearan,ze Re~or.t (S~her. ical Method) Ellipse dimensions NOT included in calcula¢ions Casin~ dimensions.NOT in,:ltJded in calculations PpoximitY pmdius is 200. feet All de~ths are in feet and mr.e referenced to the REFERENCE WELL RKB StePwise vertical de~th stmtions ~un fpom 0, to 10000. at intervals of 100. feet ReferenCe Slot Name.'- ~.~"--'-~..- .., Reference Well Nmme :- M-2 ObJect Slot Names ObJect Well hlmme$ Date :- 31-AUG-87 Revision No :- 1 Prepared BY :- T OONES Our Ref . :- DD1:[300,003]SO6820.7MA . 7-7 Eastm. an L___., · P o s i t i o n 0 I-I MD TVD NS '"CALCULATION OF L~'~T DISTANCE . BETWEEN WE.~S - . M-2 Closest Position on wel 1 M-2 EW MD TVD NS EW Distance Direct Between Bmtwee Wells Wells 100.00 100. O0 200. CiO 200.00 300.00 300.00 400.00 400. O0 0.08 S .0..17 hi 0.02 S 0.66 S 0.20 W 100.00 lO0.(ICI 0.35 W 200.00 .' 19?,. '?';-' 0.11 W .300.00 298/. 9'.-? 0.1.8 W 400.01 400.01 0.13 S 0.36 S 0.01 S 0.27 N 0.14 E 0.62 E 1.13 E 0.88 E 0.35 S 82 4 E 1. I 1 S60 19E 1.24 NS? 37E 1.41 hl48 55E 500. O1 500.00 600.01 600.0 ssi .-qO. 02 700.00 (' .,0.0:3 :300.00 1.?,'-- S · 54 S · - . 3.34 ,.. ¢' 4.5::: '.~ 0.06 W 500.02 500.01 0.38 W 600.03 600.02 0.71 W 700.06 700.05 1.0'? W 800.11 800.06 0.10 N s].52 S 1.29 S 3.51 S 0.41 E · ' 0.11 W :.' 0.51 W 1.13 W 1.68 N 16 8E 2.04 N 7 26E 2.06 N 5 33E 1.07 N 2 11W 700.12 900.00 1000.58 1000.00 1101.96 1100.00 1205.11 1200.00 1310.75 1300. (iCi 1420. O'P 1400. CIO 1533.49 1500.00 1652.20 1600.00 8.75 8 17.86 S 33.64 S 58.04 S 90.64 S 132.5:3 S 182.45 S 242.1:3 S 0.88 W 900.15 899.93 1.49 E 1000.43 999.58 6.30 E 1101.4.6 1098.87 12.4.5 E 1204.17 1198.06 21.98 E 35.86 E 54.87 E 77.59 E' 1309.26 1296.95 1418.06 1395.93 1530.82 1494.87 1648.86 1574.03 9.43 S 20.20 S 38.06 S 63.83 S 97.77 S 140.64 S 191.85 S 252.73 S '.· 0.87 W 1.58 E 6.18 E 12.37 E 22.36 E :_--:6.19 E ~ 20 E 72.58 E 0 A9 c- 0 50E 9~. 38 .:,'"' 2 18 E 4.57 S 1 ~-'~, 6. 11 S 0 48k 7.76 S 3 OE 9'07 S 2 20E 10.83 S 10 5 ~ 13. 12 S25 24k 1776.40 1700.00 1906.90 1800.00 2040.22 1900.00 2173.72 2000.00 (. 2o07.03 2100.00 2440.52 2200.00 2575.47 2300.00 2711.22 2400.00 2847.99 2500.00 2985.32 2600.00 3125.09 2700.00 3265.78 2800.00 3404.32 2900.00 3544. 14 3000. CI0 '3684.05 31CI0.00 ':,oo'~ ,':'-= ~"~c)n C)0 312.56 S 392.67 S 476.51S 560.67 8 644.26 S 727.86 S E:l.3.o; .., 900.23 S 988.38 $ 1076. '.-'.'0 S 1168.09 S 1261.66 S 1355.55 S 1452.80 S 1550.22 S 1646.17 'S 206.32 E 235.13 E 265.04 E 2~4.81E 325.43 E 357.44 E 392.35 E 424.41E 443.53 E 453.03 E 462.19 E 471.55 E 1772.48 1693,11 1902.37 1792.85 2035.64 1892.84 2169.16 1992.97 2302.49 20~3.35 2435.93 2193.61 2570.77 2294.12 2706.57 2394.65 2843.48 2494.:37 2'P80.77 25'.-.74.5'.-.-, 3120.31 2694.47 325'P. ?'0 27~,4.55 33~6.73 2893.47 3534.96 29~2.54 8675.04 8093.13 '3814.16 31~3.75 323.26 402.6? 486.76 571.14 655.07 739.11 824.81 ~11.71 1000.05 1089.14 1181.14 1273.~3 '13'66.56.=~ 1462.52o" 1559.65 S 1655,34 S 94.40 E 119.07 E 145.40 E 171.48 E 13.60 S24 13.20 :325 13.76 '.:_:27~ 1 14.29 S32 56~ 197.15 E 223.45 E 250.61E 278.64 E 15.65 S40 18~ 17.43 S46 4b 19.32 S51 20.54 S54 37~, .; ....0 .... 55 E 21.16 .: ....... ' "~" '='5~''-, 26~, 3:3'~.C-,7 E ~2 24 371.78 E 24. .'.-,:,. '.E',57 ':"6~.., 400.8:3 E 27. 14 '._~;62 cALCULATION OF L~"%T DISTAN6E BETWEEN WE'uL8 Position o n wmll M-2 :' " Closest Position On well M-2 MD TVD 7:?60.96 3300.00 40?6.66 3400.00 4230.66 3500.00 4364.34 3600.00 N'S EW MD TVD N'S 9.~, ~., ':-,'?gzt 1740.73~,° . 481.87 E c .... ~.01 ~,~._.A,°,__ 1748.85 ,. l:~l.:m~_ _ S 492 ..... 00 E 4o87 45 .~'-"-'~.z,~._, 11 1839.4:3 1920.85 S . 4.98 40 E 4221 ~'/-, "~*= '-'~' 927 ....... :,~; ._,..z,,:, 1 .92 2009.._,':' 7 S ' ~_ 04 .0 A_ E 4.z,._ 4 ,77 .z, ._, ;, ._, . 60 2016.00 .. S S S S EW 453.30 4.~'-.? 4 :)._,. 05 46.9.56 Distance Dide,:t Between Betwee Wells Wells 30.17 S74 7W 33.45 S76 43W 2:4.41 S78 2~ 2:.5.40 S 7 ';? ,,E: W 4497.51 3700.00 4629. 08 :3800. 00 ."'--,8 32 3900 00 4999.14 4100.00 5112.75 4200.00 ~.~,~. ~"'--',..~.,... 97 4300.00 5333.87 4400.00 20?7. '2182.6 2264, 2336.74 . . 2397.62 o -'4._ 1. 34 .:, 24.99 ~"-' . ,--,~. S 2q~q 26 S 508.40 E 4488.03 3696.14 2103.37 512· 58 E 4619.76 3796.82 2188.21 516.99·E 4749.22 3:'-:98.08 2268.71 522.40 E 4873.27 3999.57 2339.77 527.47 E 4990.65 4100.04 2400.23 531.84 E 5104.21 4200.55 2452.89 536.04 E 5215.43 4301.10 2500.29 539.72 E 5325.32 4401.16 2545.58 S S S S 473.77 478.16 482.26 · 486.56 4eO. 89 494.62 4~. ..o. 10 501.55 E 35.38 S77 55g, E 35.02 :_--::BO 45~ E 35.05 :E;82 50~ E 35.96 S85 1 E 36.67 S85 55b E :37.25 S87 37b E 37.96 S87 17b E 38.18 S:3'P 32b ~44o.65 4500.00 5553. 16 4600.00 566'2. 11 4700.00 5770.17 4800.00 5877.47 4900.00 5984.14 5000.00 6090.14 5100.00 6195.43 5200.00 ( 6~:C)0.16 5300. O0 6404.55 5400.00 6508.73 5500.00 6612.63 5600. ¢)0 2590.40 S 2634.84 S 2677.93 S 2718.78 S 2757.63 S 2794.72 8 2829.84 S 2862.7~ S 2893.~0 S 2~23.85 $ ~ ~.- .~,. ,~, 2781.22 $ 543.45 E 5435.02 4501.4-4 2589.94 547·4.6 E 5544·31 4601.76 2633.20 551.14 .E 5653.16 4702.15 2675.19 553.?8 E 5761.04 4802.28 2715.23 555.~2 E 557.51E 558.88 E 559.74 E 560.17 E 561.00 E 561.78 E 561.76 E 5867.89 4902.20 5974.31 5002.35 6080.26 5102.71 6185.28 5202.81 6289.89 5302.92 63~4.23 5402.97 6498.23 5502.93 6601.48 5602.5:3 ~'~M~-' 04 278'P. C)3 2822.94 2854.68 2885.06 2914.62 2943.32 2970.56 S S S S S S S $ S S 504.91E 507.92 E 510.52 E 512.84 E 38.57 N89 39.61 N87 40.76 N86 41.36 N85 o14.39 E 41.85 N ..... 4.2~ 515.30 E · 42.66 N82 l'Pb 516.24 E 43.28 NSC) 48~ 516.'P4 E 43.66 N79 16)., 517.53 E 43.65 N78 17t 518.12 E 43.96 N77 51~ 518.46 E 44.50 N77 2C)t 518.51E 4.4.62 N76 9~ 6716.27 5700.00 681'~. 80 5:300.00 6923 18 ._,;00 00 7026.27, 6000.00 7129.08 6100.0C) 7231.72 6200.00 · .-I ~' · 73:2:4 18 6.z, 0) 00 7436.40 640C).00 561.19 E 560.28 E 558..72 E 556.40 E 553.60 E 549..72 E 544.85 E 538~. 43 E 6704.82 5702'49 6808,12 5802.35 6911.22 5902.13 7013;89 6001.87. 7116.04 6101.26 7218.20 6200.82· 7320.29 6300.47 7419.C)0 6396.93 2996.71 3023.12 3049.00 3073;25 3096.64 3119.14 3140.74 3160.99 S S S S $ 517.87 E 44.96 N74 4.8t 516.41 E 45.58 N74 33t 514.53 E 45.95 N74 1 512.40 E 45.95 N73 24~ 508/.42 E 4.6.1 505.23 E 46.58 N72 5C)~ 5¢)0.23 E 46.74 N72 421 4 c o- ,- 46. S/0 N7'." ~,~71 Eastman r .,\\ · STRATIGRAPHIC HIGH RESOLUTION DIP METER LOCATED IN THE APPENDIX ~[Inocal Oil & Gas Divi~''~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Tele,~hone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL September 15, 1987 HAND DELIVER TO: Bill Van Alen FROM: R.C. Warthen R. B. Stickney LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting: MARATHON TBU M-2 McArthur River Field Cook Inlet, AK Sec. 33, TgN, R13W (SM) AP1 #50-733-20388-00 1 sepia and 1 Olueline of the indicated logs: DLL-MLL-GR-SP DEN-NEU-GR-CAL Comp DEN-GR-Corr Computed Diplog x~Diplog FMT 'X~Mudlog 1898 to 7502 1400 to 7502 1400 to 7502 1898 to 7480 1898 to 7480 2035 to 7440 1200 to 7510 '~',/'1 listing of Diplog data ~ 1 directional survey /~L~' ~~__ ~ ~ 1 Final LIS tape w/listing ~~,~~~ TRANSMITTAL. THANK YOU. //~-]~t~~t~" DATED' MEMORAN D,.,,vi State Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Co V. Ch~~n DATE: August 27, 1987 Chairman ~-' ~/ roLE NO: D. EWS. 61 TELEPHONE NO: THRU: Lonnie C. Smith / SUBJECT: Commissioner BOP Test Marathon TBU Steelhead M-2 Permit No. 87-61 McArthur River Gas Pool FROM: Edgar W Sipple, Jr Petroleum Inspector Monday,. August 10, 1987: I traveled this date from Anchorage via ERA to"~Ken~i'"'to ~arath°n's"Steelhead platform Rig SH to witness a BOP test. The drilling contractor was in the process of nippling up the BOP. Tuesday, August 11, 1987: The test commenced at 4:10 a.m. and was '~Enc'iUded '~t 8 :r0'51'"[ There was one failure. The hydraulic lines on the HCR were hooked up backward. They were changed and tested satisfactorily. I filled out the AOGCC BOP inspection report which is attached. In summary, I witnessed the BOP test on Marathon's TBU Steelhead M-2, Rig SH. Attachments 02-001A (Rev. 8/85) - . 0&G #4 ,5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Representative '~/..]1 Location: Sec ~':' T - R M DrillinE Contractor Location, General General HousekeepinR__ Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors Well Sign Visual Rig Audio . BOPE Stack Pipe Rams Blind Rams ChOke nine Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Permit f/ ~"{~ :C ./Z - ):Casing Set Representative ACCUMULATOR SYSTEM .~. Full Charge Pressure ' Pressure After Closure,; ''':'~ ':, ' Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: ~¢.. Controls: Master psig. ' psig ~:? ~ min. sec. min sec. \ . Remote '/ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly ,7~.>', Test Pressure Lower Kelly C' f::' ~Test Pressure Ball Type .... ? i-< '~'~est Pressure Inside BOP ~3 ;% "/~est Pressure Choke Manifold ' /" No. Valves No. flanges Adjustable Chokes Test Results: Failures Repair or Replacement of failed equipment to be made within Commission office notified. / ,~ . , .... ,... /.~t , Remarks: /~ ,! ~ , ~,,: ' /'. ~.~' ?'~ i'~.>, :;- ~ Hydrauically operated choke Test Time .' hrs. -? days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspectcr . MEMORAN ' - State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION To: C.V./Z~te~rton DATE: August 27, 1987 Chair~~' F,LENO: D.EWS. 53 THRU: Lonnie C. Smith Commissioner TELEPHONE NO: SUBJECT: Diverter Test Marathon TBU M-2 Permit No. 87-61 Middle Kenai Gas Pool McArthur River Field FROM: Edgar W. Sipple, Jr. Petroleum Inspector Thursday, August 6, 1987: I traveled thzs date from Shell s Platfo "A",' s~b]ect-of another report, to Marathon's Steelhead platform to witness the diverter system. The functioning of the diverter commenced at 4:00 p.m. The 29~" annulus preventer closed in one minutel the 10" hydraulic block valve opened in two secondsl and the hydraulic diverter valves opened in two seconds. There was a problem with the lights on the remote control located on the rig floor. When the diverter was activated, all the lights came on. Jim Winslip, Marathon rep, said he would call our office when the remote station is fixed. In summary, I witnessed the diverter test on Marathon's Steelhead platform well M-2, Permit No. 87-61. 02-001A (Rev. 8/85) June 26, 1987 I~r. Roy D. Roberts Environmental Engineer Union Oil Company of California P. O. Box 190247 Anchorage, Alaska 99502 Telecopy.' (907) 276-7542 Re: Trading Bay Unit M- 2 Union Oil Company of California Permit No. 87-61 Sur. Loc. 1043'FNL, 603'FWL, Sec. 33, TgN, R13W, SM Btmhole Loc. 992'FSL, 1221'F~, Sec. 33, TgN, R13W, SM Dear Mr. Roberts- Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter 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. V~tru.~y~yo~,? ~ ~ ~. V. Chatt~rt~ ' Chairman of Alaska Oil and Gas ConServation Co~ission dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux Alaska strict Produchon United States Marathon Oil Company RO. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 June 10, 1987 Mr. Mike Minder Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Minder: Attached with this letter is the application for the Permit to Drill Well M-2 from the Steelhead Platform and the filing fee. Should you have any questions concerning the application please contact me at 564-6325. Regards, Guy R. Whitlock Drilling Superintendent GRW/RLH / skb/DD5 / 19 At tachment s . ' ' ~ STATE OF ALASKA ALASKA Oi_ AND GAS CONSERVATION CO,.,,,IISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [J~ Redrill FiI lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Ell Re-Entry [] Deepen[]1 Service [] Developement Gas 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California * 163" KB feet McArthur River 3. Address 6. Property Designation P. O. Box 190247, Anchorage, AK 99519 ADL 18730 Middle Kenai Gas 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1043' FNL, 603' FWL, Sec 33, T9N, R13W, SM Trading Bay Steelhead Platform, Leg B-2, Conductor #3 _ At to.p of productive interval 8. Well nu .mber Number @ 4660' TVD: 1580' FSL, 1105' FWL, Sec 33 M-.2 B-2-165-724-1 @ 6010' TVD: 1100' FSL, 1200' FWL, Sec 33 At total depth 9. Approximate spud date Amount @ 6313' TVD: 992' F'SL, .1221' FWL, Sec 33 7--15--87 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line Well M-1 14' to NW 7404 TMD 8170 feet @ surface feet 3085 6313 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 800 feet Maximum hole angle 490 Maximum surface 2331 psig At total depth (TVD) 2630 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 26 20 91.5 X-56 RL~-4C 675 75 75 750 750 1600 sx 17-1/2 13-3/8 61.0 K-55 butt 2355 75 75 2430 2240 1800 sx 12-1/4 10-3/4 55.5 N-80 butt 501 69 69' 570 570 2200 sx 12-1/4 9-5/8 43.5 N-80 butt 4334 570 570 4904 3992 12-1/4 9-5/8 47 N-80 2500 4904 5460 7404 6313 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~'~ Surface Intermediate Production Liner Perforation depth: measured true vertical * Marathon Oil Company - Sub?operator 20. Attachments Filing fee Drilling fluid program ~,,, Time vs depth plot [] 'Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed,.,~'~'~;?~,/~/ ~/~/~¢,¢~ Title Environmental Engineer Date 6/19/8: · " ~oy ]3. Roberts Commission Use Only Permit Number I APInumber ] ISee cover letter ~ 7 "- ~ / 50-- '~ .~_~ ~- ¢2 ~(~ ~' Approval, 9_~ 8 7 for other requirements Conditions of approval Samples required [] Yes ~ No Mud log required L-] Yes ~ No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] No Required wo~p,~.~~~~M; [] 10M; ~ 15M ~./.~,.~..~(:~ Other: by order of Approved by,k,- '~ '"/',-' k ~~_.//~~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Sup :ate 13 Il ADL 17602 · . 3O e-Ii' · *.a.m' -tt<~- KING SALMON ADb 17594 + GRAYLI TRADING BAY UNIT BOUI% ADL 17594 OATUM: ALAIKA JTAIT PLANE COORDMATE I¥ITEIJ, ZONE 4 DCLLY VAKDEN w. Ne- ,I.eme' ,a.lte* 0D-!1 + + 4 ',OM el-omo 33 · t,-Iio-t 32 .-. · l-~l la,mi.' ePtMo i-MO0 u.,e.. .4- · e-m1 ,,(~P~LAm e~MNIL- 1 ADL 18729 ., · · lib ,m,,.' ,-,+ I I I I ! ADL 18772 · K-mm + ADL 18730 +.mJiml~eOT IT.=1 I · ADL 17579 I I H 35 -!- 15 LEGEND o WILL. LOCA"m)N~ ~ ~ WILL · (M. WILL ~O~II~J~CTID I~i w~ ~ O~ re.OW ~ ~ sam ~oo~ ~ ~Y~L! ~ ~TFOnM MARATHON OIL COMPANY TRADING BAY UNIT McARTHUR RIVER FIELD ICAL~; I' · 1H9' AUTNORt OATI: Au;~ Ills PILE II10~__ STEELHEAD PLATFORM BOP Schematic WELL: M- 2 FROM MUD PUMPS HYD. CHOKE ADJUSTABLE CHOKE PRESS. SENSOR CHOKE MANIFOLD DRILLFLOOR at TO MUD SEPARATOR 3' TO DERRICK VENT TO SHALE SHAKER W LINE . 3' KILL LINE Co FLEXIP HOSE IPE RAM RAM: 3' CHOKE LINE Co FLEXIP HOSE IPE RAM,~ RAM PREVENTORS ARE HYDRIL TYPE V 13 5/8' X 5000 PSI --~, . 13 5/8' -5000 PSI RISER 13 3/8' - 5000 PSI 5000 CASING HEAD 30' DRIVE PIPE 20' CONDUCTOR 13 3/8' SURFACE CASING S .T~EELHEAD PLATFORM DIVERTER SYSTEM SPECIFICATIONS 1. Riser -- 30" OD, rated to 500 psi. 2. BOP = 30" Hydril Annular, rated to 500 psi. 3. Block valve = 10", 300 psi, full opening ball valve 'w/hydraulic actuator.* 4. Diverter line = 250 mm nominal schedule 40. ID = 9.80", OD = 10.53". 5. Direction ~lves = 10", 300 psi, full opening ball valves w/hydraulic actuators. * Block valve is hydraulically manifolded to annular BOP such that block valve will automatically open when annular BOP is closed. ++Direction valves hydraulically manifolded together such that one valve is always open. NOTE: Ail turns in line are targeted. TBA/skb/DD3/2 4 S t~EELHEAD PLATFORM DIVERTER SYSTEM OPERATIONAL PROCEDURE TO CLOSE AR~ULAR BOP Push "close" button on diverter system BOP control panel. Diverter block valve will automatically open. TO CHANGE DIRECTION OF VENT Push appropriate button on diverter system control panel. If west venting is desired, push "west". If east vent is desired, push "east". The hydraulically actuated valves are connected such that opening of one valve closes the other valve. Therefore, it is not possible to close both direction valves. ACTUATION OF BOP EQUIPF-H~NT The BOP equipment on the Steelhead can be actuated from the main control panel on the rig floor or from two remote panels which are located on the bottom level at the southwest and northwest corners where the l~ittaker Emergency Escape craft are located. Also, a monitoring panel is located in the drilling foreman's office. TBA/mcc/MISC/t STEE:L-HEAD PLATFO .t DIVERTER sYSTEM SCHEMATIC ANNULAR BOP DIVERTER SPOOL 30' RISER , BLOCK VALVE 10' DIVERTER LINE W DIRECTION vALVES ANNULAR SCH VIATIC 153' g' BOTTOM OF FLOW NIPPLE FLOW NIPPLE SLIP JOINT 59-5/8' 29 1/2' HYDRIL 500 PS! BOP I j j~ DIVERTER SPOOL t N DIVERTER LINE 132' 9' TOP OF PIPE RACK RISER SPOOL 110' 9' PIPE RACK FLOOR 10' OUTLET 88' WELLROOM FLOOR 67' JACKET TOI~' RISER SPOOL STARTING HUB 1 CONDUCTOR EXTENSION STEELHEAD PLATFORM OPERATIONAL PROCEDURE FOR LOST CIRCULATION Should lost circulation occur during the drilling of the 26" hoIe from 0 to ± 800' TVD returns will be taken at the 88' level above MLLW rather than at the rig floor at 162' level above MLLW. There is a 10" outlet on the 30" riser at the platform's 88' level for returns to go overboard if lost circulation does occur. The valve on this outlet will be manned continously during drilling and circulating operations. Personnel at this location will be responsible for opening and closing the valve and monitoring drilling fluid returns. TBA/mcc/MISC/2 T-_BJ2LL E¥ RAIL._ InS CHLI~_ ~ .MUD. CL£ANEA, ~ MU AG I TATOR j (TYR). ,."l (N=I3).~ FUTURE-/ MUD CLEANER 27.0' (822§]6) · ~ d.o' r I Pj~2_) .. (3,962.4)' ] ( 5,962.4 ) tRUSS CENTRIFUG£ 1 I ii (4,267. ~') TRUSS IOd. O~ <$qaao) ~]//' PARTS RH, ' ~ LOCK (I 2,4-g6~ 8 ) 2 8'- O' NCC.4 \ /' G.D 14'- O' (4~ 67. 2 ~ I : GAS TIGIIT 8k8' ' . UOLT. ED ltAIgJ ~'r I, I_~- ~l [tOll,TIGHT '~ 'DO0 AIR ,, JkooHzY SP_AmE CONTROL] FUTURE KOOHEY ~ KOOMEY J REMOTE -/-'REMOTE KOOMEY CONIROL MUD M 0 D U !_ e .~u~p.p_.g ~....p_i==,._6_N.._._.' EL. 84'-0" ( 25,6q..5.2 ) TflUS'S~ ,,, TRUSS SOLIDS C"CI~U TE TRUSS TRUSS WEATIIER-TIGIITDoOR ~ I CElll'nlFUC~ 07. B~ " 1t0.1 I4DO.C~L ~'~ N£R LiUD PUkl P. '1t' 4t0. I O HUD PIT RH MUD MODULE-LOWER; PL'AN EL. 70'-0' ~(21153~i MARATHON OIL COMPANY WELL PROGRAM Well Field Steelhead Platform Well M-2 McArthur River AFE 8309-7 Coord i nates: Surface Top of Objective 1043' FNL & 603' FWL (Est.) Sec. 33, T9Nr R13W S.M. Leq B-2 Conductor #3 D-2 @ 4660' TVD 1580 FSL & 1105 FWL Sec. 33, T9N, R13W, S.M. D-16 @ 6010' TVD 1100 FSL & 1200 FWL Sec. 33, T9N, R13W, S.M. KB Elevation 163' MLLW Tota] Depth 6313' T~D 7404' MD GEOLOGICAL PROGRAM Mud loggers on location from conductor shoe to TD. Ground Elevation MLLW Avg. Angle 20© Course510°47'E Estimated Fm Tops MD TVD A-1 3146 2710 D-2 5587 4660 D-3A 5700 4760 D-3B 5806- 4860 D-4 5892 4940 D-6 6030 5070 D-16 7082 -6010 Estimated Tots] Depth 7404 6313 Sub-Sea Potentially Productive -2550 yes -4500 yes -4600 yes -4700 yes" -4780 yes -4910 yes -5850 yes -6150 Coring Program None planned DST P rog ram N/A Logging Program: Conductor Not logged Surface Not logged I n te rme d i ate DIL/SP (DLL)/LSS or Production FDC/CNL/GR (Run to surface) Dipmeter RFT (25-50 sets if hole conditions permit) Liner N/A Well Program P~ge 2 Conductor DRILLING PROGRAM Drill 26" hole to 750' MD Run & cement 20" casing Surface Drill 17-1/2" hole to 2430' MD Run & cement 13-3/8" casing Intermediate Drill 12-1/4" hole to 7404' MD o'r Production Run & cement 9-5/8" casinq w/500' of 10-3/4" casinq ~.Dn top Liner * Provides adequate clearance for dual 3-1/2" SCSSVs DIRECTIONAL PROGRAM Drill vertical hole to 800'; build angle at 3°/100' to 48.9° and hold to 3087' TVD; drop angle at 1.5°/100' and hold at 20° to 6313' TVD on a course of S10°47'E CASING PROG.~ Hole Size Set At Wt. Footage Grade Thrd Size 20" 750' 91.5 675 X-56 Vetco 26" RL-4C 13-3/8" 2430' 61 2355 K-55 butt 17-1/2[' 10-3/4" 570 ' 55.5 500 N-80 butt 12-1/4" 9-5/8" 4904' 43.5 4334 N-80 butt 12-1/4" 9-5/8" 7404' 47 2500 N-80 butt 12-1/4" WOC Time Cement 1600 sx 1800 sx 2200 sx Liner MUD PROGR3=M From To TVD Wt. PPG Vis.sec/QT W.L. cc's pH 0 750 8.6-8.8 100-150 N.C. 750 2000 8.6-9.0 40-100 N.C.-12 2000 6363 9.2-9.6 40-60 12-4 Type Mud Treatment Fresh wtr. low solids non-dismers~ Fresh wtr. low solids non-disDers Water base co-ployme¥.. Remarks: COMPLETION PROGRAM Run 9-5/8" prod. csg to TD w/500' of 10-3/4" csg as top section. Cement w/2200 sx of cla~ "G" cement. Clean out csg, run gyro & CBL. RIH w/bit & scraper. Displace mud w/completJ fluid. RIH w/tbg conveyed perf guns. Perf D-16 w/12 SPF. Kill well. RIH w/production · packer w/plug. RIH w/tubing conveyed perf guns. Perf D-2; D-3A; D-3B; D-4; D-6 sands w/12 SPF. Kill well. RIH w/dual string of 3-1/2" tubing, set packer & displace annulus w/pkr fluid. Land tubing, ND BOPD, NU tree, and displace tubing w/nitrogen. .. REF/21 ' ' ~ I ' . - I ........... ,' - ; ..... ..---HARATHON OIL~- COHPANY ~ ..... ~'"'-: .... :"~' .... ' i'":': ...... t ........ I ...... ~ .... -/~:~ ,,-~ '~--' STEEQHEADjPI'~m,'"H~A~'~hu~-'~~:"FI-eld ........ f ........... i ....... ~---j ..... '~ "' '~} ...... ..... ~ ~ ~ .. , · ~ATHON~ .... ~" ~ ................... ' ......... 'r .... l ....... ~ ...... ? ......... ~ ......... · ' "l, ...................... [ f, ......... ~ ?~ ........ t .................................................. · ~ · ~ ? . ~ ..... ~ ---/~ '" ' ' ' I' - i '' ! ~ ......... ' ........... t ~ .... ~' · . .... .........,, .----__ ........... , ................. _..,_, .............: .... ..................... ..... ........ i: ,::-::-:.- . :';--i ....... ~ ........ ..... ~. .... ~..._ .~ :"t.':::; I_':'..'.:'.._'.._'...t:: ' ' ' ] ...... 1 I ~ ' ' I .~ ..... I ....... ........ ~ ............. t .............. ~ ........... t ........ : .... ~ .............. I ............. ~ ............. i ..... : ..L ...... i ... : IN =~ 1000 FEET ~" ?--t ............ t ........... l ............... ~ .......... ~ ........ ~'-~ t .......... ~ ............... ~ .............. + ...................... ~ ............. ~ ......... ~ ......... - - i ...... ~-~-~ .... ~ ..... ~.-~ ..... t .......... ....... I ............. ~ ............ ! .......... ~ ............. '~ .............. t .............. ~ ................... ' ":::::';-:-T ~ ..................................... .. ~.. ~ ~ ~ ~ - .................... ]:_.~__ · .............. ] ......... .0 ' · ~~Ec~v~o~.~, :':- - ! "-:-": ~ '. '.._:, ,.. _ ~[ _ ...... : ~ _ . , .,,. .... ......... ~ ................ , ............ ~ ......... ~ ~ ..... ~ ........................ ~ .............. ; ..................................................... '- '~ .......... 20'~ CSO PT"' TVD=750 ......... ~ .......... ~ .............. -:-~ ....... : ' KOP~ .... TVD~8OO'TMD=8OO'DEP=O . ~ :T.. ~-:' 't ........ .... , ..... i . ' ].00.~ 3 ~- -- ~ -~-- - ~ .... i . , , .. ' ~ ~ - - - --~ - ' i ............ ~ ~-i ~ ..... ~ .- .~ .... ~ .... ,.. ,. ~:] :..~.L~.:.i .... :~s j-.-~-~-'~O~D 3:6Ee ~ ....:.~:--~'-': i ' ........ ~ ......... ~' '' ~ .... ........ , ........ ,oo-~ ....... ~ ....... ~ ...... ~ ........ :~-~-:-...~ ::-:-::'.:.-.::-:-:.: ....... ~ ................... ~ ~ .... ..... LS_~_"__.:~~ .... ::..:-. ............. , l, ............... ._ . ......... i ............. t .......... ~ ..................... ~ ............... ..- ~ .......2z .... _.~ ..... . :-.. ~. ..~.:~.:_~ ~.. ~:::::-:-: ........... I ' :'-':---'.:': :"-:'-I I .... ' :.-: ~: :":' ' ' , D~ ~ ~_4 ~4 ........... - TVD=2238:TMD=2428 DEP=853' ' ': t ~ - ' ~ I - · -- ~ - -- I -~ ~ ~ I ':._ ~... :_ I.~.~':.:: ....... ~ ' ' .... ~ ........ :--- ~ ..... ~ --- t ~ . . ..................................... I ............ ~ ..................... ~ .: ............ ~ .......... i ---i ...... I ..... 48 :DE~":51:'MI'N ............. ~'.:...' '-'.l_. :::~':': ' ~ - ~ .... ~ ................. I ...... I ........ ~__ ............... ~ ........ : ........ i ........ ~ ...... t ........ ~ ............... : ......: ..... ~..~ ..... :, ...... i _ IP. ~-. - ~EP=1825... I ...... + ......... ~ ...... ~ .... ~'" t , I':'":'::: ........... ~ ......... ' ........ ' ........ ~ .... i , ~ -i ................... ~ ..................... ~ ........... ~ .... ' - ................ ~ ................ + .......... ~ .......... 3: t--: ........ ~ ............ L:_.~ ...... 4 ...... : ....... : :~- _~_--:'- m.., ........ ~ ....., .....i .... ! ..- ~ ..i ......... ~ ................ ~ .... ' ' ' ..... ' .............. i ~'"~ :':I~'~:?--;~-.:-~-'.~ .... ~"' ..... m --t ................ ~ ' DROP~ 1 1/2]DE~ .... ~- :~ - ...... ; ........ PE~' 100 ~ ..... ~- - ~ ~ J ~4~ ~ ." . . ."~ ~:~ ~ ~[ . .............. ' ................ , ............. , ............ ~ ........... ~1~ --END~'A'N~L-ESDEO~VD'~4-65~MD~-56'42~DEP~270T~ ...... ~ ................. t ' ' - ' ..... ' ................................... , .......... ~ ......... t ......i---- TARGET ~ (D-2)~ ....................... [ .... , ................ 4 .... ...... ~ ........................................ , ....... , ..... : i-'-----~v .~:.:~~'~' ,_._:_...:._~.__:~- :,: ...... . ...... ~ ...... ~ .................... ...... :~D,~o D~P.-:~O~' .'. :" ~ ...... ~-'' -.'_ ....... ~ ..... :~. .__ ~ ....... ~ .... [-.- - I ...... ~ ........ .......... I ............... I ............... ~ ....... I -'l ...... ~ ...................... ! ......... I ........~ ...... i ............ I i ''' i :~'~-~:LTi ._: .............. -:- ~ V .... ' ' j ..................... :, ...... ...... :_::~'.'j~: ~_' LL:.:-_: ~_.: .:._:: .:.:.~._'::; ......... ...... ,! ...... ...... i ..... T~D=60~ 0 TMD=7082. DEP, 3193' .... ?--: ............ ~ ...... : ....... , ............... , ........... ~ ...... TD':/: 9--5/8~-CS~ 1PT'" ~ ...... ~. ::-.' ' .-' ........ ~ .......... i ''_~ :-,_[ :': L '~._ _:~- .......... i ....... TVD=631'3 TMD=7404 DEP=.3303 '-- ....... ~ ................ l--- .... ~ ..... ~--~ ......... ~ ................. i ........... ? .............. ~ ........ , ......... ~ ............. , ...... ':'-'-'"'--'::'~"~: ........ ?-:':-:'--: .... ~ ........ ....... ~-~ ........... 1 ........... + ........... ~ ...... i .......... ~ ...... ~ .... l .... i ........ , ...... ~ ..... l ...... ~ ........ ~' '~' '~' ~ .... t' ~' I ~ ...... ; ' ' : ~O0_O.' -'~ .............. ~' ' ~ -- ~ '''~ : .... t' '-: ...... ~ : I I I ' ~ 0' :.: ...... i'~;:~._~:.~:~.~000~-;~ .... 2000 ~': ''~000~' ~" 0 0 ~ - ~ ........ ~ ~' ~ i . VERT-t-GAL+--SE-QT-t-ON .... : .. ' .... ~ ' ' ' _. ~_ 5 - ' '5' '__L ....... ' ' ..................... ~ .......... l ............. ~ ..... ~ ............... I ......... ~ ......... ; ........I .......................... ::': .~ ::'. :';-i ............ .~ .......... .......... ................ ....~ ......... : ~ ..... ~ ....... ~: - , ............ ~ ~ ...~ .......... ~_ ..I. . i .... ..................{ ]~. -~:"':-' ..... :":---'~ ! ~- -J ' '~: ' ~ ....... t ' ...... ~":-"" .................. --~ ........ l ~--"'!/~_~:! ''-' ...... .... : ........... : ....-:' ................ I ...... ~- -- ' ............ 1---:- .... : ' ' : ~ : { ~ ' : - -,--:--: ~-'~'-' ~ ' : '- ~ 1~~ - ..... / ' ; ; J ' '-':.-t'-' ] t t~ ' ' ' I .... i "'"' : ' I ' ' ' Jt ~"' { ..... { .... F/' ..~__~ 7 - : ................ :.: ..... ~ ........... ~ .......... ~: ..... . ........... ~ .............. - ..... ? .......................... ~ ...................... ~---,.-. ........ :-- /W'!~ :::,"7.::TI."7__T:~':'.-:.-:. 1', . ~ ; ; .... l .~ ..... ~ ........ : .... I~-'-;--~ .... -:--~ - .: --i ......t--'i ...... i ....... ~ i~ : /~ : :_:.l :.:-:. :.i ~ :._, i:,:", i :': ...+,-' ^~^:~o,:"0'~,. co~%'~i-:-- .... :-i'. :-. ':.{ ........ :':i'- .... ::i ....... i ........ t'":'::'."-i.:.':' .......... ]--'-~-~-~'-~--j---? ..... i-"-':-,~-k-e~' B~2,',Sl * ~": 3;':_We I I'::N~',T-"M~2 j-:"P_FOP'0"*'e~ ::::::::T.::::::::::::::::[-.:::::::::::::: ': l':':::"::I':'.:: :'t':-:: :'i: :-::::STEELHEAD Pl~rm~ McAr~hur IR~veq I-~ei.d. Cook .tn:let .A_:k · 'i- :j'.. I _: ~ .i----, ...... :_,____:_...--p----~ ..... i------?----~ ......... . ........... : ....... ~ .......... , -, .~--- ....... : ............. ~ ......... ' ............... i ......................... : ......................... :"f ....... : ............... i":'-'~-': ....... ~-:':' ":-': .... : .............. : ............. ............ ~ ............ : ...... i - .-,.- ' ' ! ................ ~ --~---~ ............. : .... t .......... i"-' ................... :': :-7'! :'::.: i ::': J :::. : :::: ~/~,'~a~-'i: .... :':i:: t'.-:: ~"-:':" ::. :.:: i. ::. j ........................ , ......................................i ............ ~ ............ i .......... i ...... : .... ; .......... ~ ..... ; ~ : ~ ~ :. .... ~ ' .. . . I ........ ! ..... i . ~ .... : ' .................... ! ..... : .............. : ....... i' ...... ~' ~ i ~ ~. I I . .. ............ -i ................. ~ ............. ! ........... J , '', ' ' ' ! ' ' ' ~ ~ I ...... ------4 ........ .L ....... ~ ........ i-~---4 ..... i ~ .--~WEST-EAS T-'~ .......... ! .......... , ......... i ............ : ........... : .......... : ...... ............... ~ ......... ! ....... : ........ ! ....... ', ........... i ............ i .... i .... i ....... ~ .--i ..... .~ .... :''' ~ ....... :'' i ! ~ i -..':~_ooo.: :' I'-' : :--:': .:-::-:;:.:'--.::'::::..-:-i':.-::-:-: ::: :':2000 :.. ~ooo. i: :.. O..'.: i. : ~ooo. ! ............... ~ ..... :-!-.::--:,~.o_o---i ....... ' .... i ........ : -'-~--i" '" . -:::--:::::---:- 4 ...... ! .... I ..... ~ .... ; I ! ..... TARG'ET' (Dr i 6)' :.'i : '-: -.:: ! ......... ': .... : - _F_~ ~L_.~ ...... { - - SEC.-S3.. ,,TEN. R 3W.-SM · - ........... ' ................. ... i' :.' ~ .:'":' ':-:-! ':'::' · . . i .... i - INTERFERENCE WITH M-2 PLANNED WELL COURSE Well M-2 wellbore crosses an abandoned Grayling wellbore on its planned course to the bottom hole location in Section 33, T9N, R13W, SM. An interference program was run to determine the separation between Well M-2 and the existing Grayling wells. Well M-2 does not approach within 1,000' of the abandoned G-23 wellbore, the closest Grayling well. RLH / skb/DD5 / 18 18 I I I I I I ! 30 - 27 31 13 / ~.-11 , :32 o i,..tl 33 · UID<)Ul T lT.-1 .. - L+ , el) II 19 20 '~ *1 I' r" ............ 16 ' I I i i i i I I i 15 WILL LOCA~044 ,~'14JL~:'TIlD C)IL W~I.L IJ.I wlu. ..4)r- &iJ~ ML FqK)OUCE~ O~L I#OW ~ A~AMDIC)#~O 4l&l flC)~C.~R DI~Y HOLE F"]P~.~TFORId MARATHON OIL COMPANY IIITIIC'I TRADING BAY UNIT McARTHUR RIVER FIEL[ ICALI: 1', looo' Au TI4On:~ PRESSURE DETERMINATION MIDDLE FdENAI POOL, D-16 SAND The formation pressure for the D-16 Sand was determined by testing Well G-18 deepening on the Grayling Platform in October, 1983. The formation pressure was determined to be 2672 psi at 5882' subsea. When this pressure is corrected to a datum of depth of 5790' subsea, the format/on pressure is 2630 psi. The maximum surface pressure calculated for the D-16 sand is 2337 psi. This pressure was calculated using the follc~ing formula: Ratio = 1 - (.018 x TVD) 1,000 Ratio = 1 - (.018 x 6182) = 0.8887 1,000 surface press~e =Ratio x Formation Pressure = 0.8887 x 2630 psi = 2337 psi Perforations' 8,316' to 8,328' & 8,350' RTTS ~ 8,258' DtL HP Recorder @ 8,275' DIL TBUS G-18 DPN D-16 SAND AiT'ACHMENi ~1 to 8,360' DIL (5,946' to 5,958' & 5,967' to 5,977' VD) TBG BBLS WATER PRESS. BHP TEMP Q RECOVERED SIHCE TIIIE (PStG) (PSIA) (°F) MMSCFPD LAST READING 11/17' 2:30 1,931 2,516 123.0 7.900 1.6 2'45 1,937 2,499 123.8 6.161 .7 3:00 1,897 2,482 124.1 6.721 .9 3:15 1,909 2,484 124.0' 6.721 .3 5:05 2,254 2,632 124.3 1.683 4.4 5:20 ' 2,198 2,633 125.6 1.682 0 5:35 2,198 2,633 125.7 1.665 0 5:50 2,198 2,634 125.9 1.653 0 7' 05 2 080 2,~8 126 0 3 566 5.0 7'20 2,070 2,604 126.0 3.510 0 7:35 2,077 2,610 126.9 3.367 0 7:50 2,076 2,6il 127.1 3.268 0 11:08 1,821 2,416 124.4 7.780 6.7 11:48 1,814 2,410 123.8 7.005 .5 12:15 1,815 2,394 123.5 7.317 1.4 12:45 1,813 2,425 124.4 7.245 .4 13:15 1,953 2,438 124.4 7.604 .5 13:35 1,936 2,403 122.4 - .2 15'15 1,943 2,439 t24.9 6.870 .1 15'45 1,946 2,449 125.2 6.757 0 16'15 1,984 2,466 125.7 6.480 0 16'45 1,992 2,466 125.8 6.520 0 17'15 1,999 2,467 125.9 6.520 0 17'45 2,008 2,467 125.9 6. 520 0 18'15 2,014 2,471 126.0 6.520 .1 BHP PRIOR TO FL OW 2,658 2,661 2,663 2,660 2,672 2,672 NOTE' All Blip were measured ~ 8,275' DIL and are not adjusted to datum. LIS~ OF SOLIDS CONTROL EQUIPMENT 2 each - Brandt Dual Tandem Shale Shakers 1 each - Brandt Desander 1 each - Brandt Mud Cleaner 1 each - Swaco Centrifuge 1 each - Swaco Degasser A Yotco E-mud system has been designed, into the driller's 'conSole. Each of the six active pits are equipped with probes which actuate both visual and audio alarms at the driller's console. A monitored trip tank is located iht he substructure of the rig to accu- rately gauge fluid volumes required to fill the hole on trips. T.VAK---OFF TEST FOR CONDUCTOR SHOE Under the Alaska Oil and Gas Conservation Cc~mission Regulation 20 ACC 25.030, Casing and Cementing, c(3); an Operator is required to perform a leak-off test after not more than 10 feet of new hole has been drilled be- low the conductor to determine the fracture gradient. In accordance with Paragraph h of 20 ACC 25.030, Casing and Cementing, Marathon requests a blanket waiver frcm Paragraph c subsection 3. The 20' conductor is being set at approximately 750 feet TVD due to antici- pated problems with lost circulation. A 30" amnular will be employed by the diverter system which can not be used to shut-in the well. The purpose of a leak-off test is to determine the integrity of the casLng shoe. If the well can not be shut-in, there is no sound reason for performing the test. Telecopy No. · (907) · 276-7542 May 14, 1987 Mr. Roy D. Roberts Environmental Engineer Union Oil Company of California P. O. Box 190247 Anchorage, AK 99502 Re: Waiver of Formation Leak-off Tests Desr Mr. Roberts: We have your letter o.f May 8, 1987 requesting a blanket waiver of the requirements for formation leak-off tests during ·drilling of 'the hole for the conductor casings from the Steelhead platform. The Alasks Oil and Gas Conservation Commission hereby authorizes, under section 20 AAC 25.030(h), waiver of formation leak-off tests resulted by 20 AAC 25.030(c)(3) for all wells drilled from Marathon s Steelhead platform, Trading Bay Unit, McArthur River Field. .. -.d"', . c; Paul Mazzolini, Drilling Engineer, Marathon Oil Company jo/F.LCS.8 ITEM AP~VE DATE YES NO (1) Fee ~ ~, r; 1 permit f ttached ~-- -- ,--~-'~.- . Is the ee a .......................................... (2) (3) Aam~n ~.-;- ~ ~2 9. 13)- 10. (i0 mid 13) 12. 13. (4) Casg. ~f.~f'. ~ ~P~z~ (14 thru 22) (23 thru 28) (6) OTHER (A//9 ~thru 31) (6) Add: ~.~.~z~ ~_~_~ rev: 01/28/87 6.011 2. Is well to be located in a defined pool ............................. ~ 3.. Is well located proper distance from property line .................. 4. Is well located proper distance frcm other wells .................... · 5. Is sufficient undedicated acreage available in this pool ............ '~ 6. Is well to be deviated and is wellbore plat included .... ~.~ 7. Is operator the only affected parry ................ 11::: :' : '1:' ' 8. Can permit be approved before fifteen-day wait ..... l..".~" ' "l' il i 14. 15. 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force Is a conservation order needed Is administrative approval-needed Is the lease number appropriate ........... Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cemmnt used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............ : Is old wellbore abandommmt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24 25. 26. 27. 28. For 29. 30. 31. Is a diverter system required . ~ Are necessary diagrm~ and descripti~ of diverter and BOPE attached..~ Does BOPE have sufficient pressure rating - Test to 3Od, D psig .. ~ Does the choke ~Fold comply w/API RP-53 (May 84) .................. ~ Is the presence of ~S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............. If an offshore loc., are survey results of seabed conditions presented "-~' ,, 32. Additional requirements ............................................. INiTiAL GEO. UNIT ON/OFF POOL CLASS SrAIUS AREA NO. SHORE E Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. MARATHON OIL CO. STEELHEAO M-2 MCARTHUR RIVfR KENAI e8/24/87 ALASKA INTmRVAL 1000 C TO RUN 1 RL~C ENGINEER J.$CHOENNER-SCGTT T.SKINNER MAG DE,., ~, 0 0 C 9 0 * **FORMATION DIP** DEPTH WL ANG AZ 5EARING GRADE r~ CAZ = =A~TN ~ 1906.0 8.90 17.0 356 N 4 W 1C0 1908.0 8.00 15.8 282 N 78 W 100 1910 ~' , .u 8.00 3C.~ l~v S 11 ~ 1C0 1912.0 8.0C 31.6 1aa s 1 191~.0 8.00 26,8 265 S ~:5 w 73 1918.0 8.00 19,7 233 S 53 W 100 1920,0 8,00 13,8 124 S 56 ~ 1~ 1922, , O. ~.~, CC 1~ , ~ 1~0 S 1926 0 8 CC 47 7 ~10 1936.,3 8.0C a.~ 291 N ag ~; 103 19~ 0~. 8.00 ~.3 31,3 N 1940.0 8.0C 15.8 2:80 N ~:C W 19 1942.0 8.0C tC.~ 327 N 1944 0 8.0'~ E.7 20~ S $~ W 100 19C6,~ :~ GC 5.3 1954.0 8.C:0 :~.7 191 S 11 w 63 I 958. C ~. OC 6 . 9 I 71 1960 0 $: ~r r'~ S 1 = 100 ....... c=~ 9.4 t 1962.0 8.00 7,6 204 S 24 ~ 1C0 1964.0 8.00 13.9 1966.0 8.00 7.8 141 S 39 E 60 196:8 0 8 On 5 0 1~2 !~76.0 8.0C ~.5 110 S 70 E 100 1978.0 8.00 1~.7 7~ k 72 ~ 51 1~:0 0 ~ CC ~ 9 30~ N 56 W 1nO 1982.0 8.00 19.3 325 N 35 W 53 19.~4.,. .0 8.00 12.~ ~ 18 N 1~,~ E 100 1992 0 8 nm ~6 ~ 71 N 71 c 73 ~!. I 359 N 1 w z, 1.1 25Z S 72 W '~1.! 217 S 37 W 41.1 215 S 35 W ~!.1 lg3 S .7.. 41.1 I?E' S 2 E ~,!.2 ~2 .S ~ ~ :" ~1.2 79 N 79 ~1,3 11 5 S 65 4!,7 14E~: S 32 41,~. 1~9 S 31 E 41.~ 151 S 4t.~ 152 S 2~ E &l.g t53 S 4!.9 1'94 S 26 E 41.9 155 S 41.9 1~4 S 26 E 41.9 155 ~1.~ 155 S 25 41 . ,~. 155 S 25 41.9 1 55 S ~ S 25= 41.9 I 5., _ 4!.9 155 42.0 155 ,S 4!.m 155 S ~4 E ~2.1 156 S ~AR&TMON OIL CO'. qTEF'LMEA~ MCARTHUR RIVER 08174187 D~PTH WL **FORMATION DIP** ~NG AZ BEAR~NU ~RAD~ ****SOREHCLE***** 1996,0 8,00 2000.0 8,0C: 2002.0 8.0C 2004,0 8,00 '2006,0 8,06 2008.0 8,06 2010.0 8,00 2012,0 2014.0 8.00 20t6.0 8,00 2018,0 8,00 2020.0 8.00 2022.0 8,00 2032.0 8.06 ~..~ 8.00 2036.0 8,00 '~03~ 0 8 00 ~. ~ ! . . 20~0.0 8.0C 20~2.0 8.00 2046.0 8.0C 2050,0 8.00 £052.0 8,00 2054.0 8,00 2056,0 8.00 2058.0 8.00 2064,0 8,0C 2066.0 8.0C 2068.0 8,0C 2070,0 8,00 2072,0 8,00 2074,0 2076,0 8.,00 2078,0 8.00 ~~08C,0 8,On 2082.0 8.0C 2084.0 S,OC 2086,0 8,00 2088.0 8,06; 2090,0 8.00 20~2.0 15 c,, 9~ S ~2 E 57 13.9 1,39 S 71 E 100 6.5 194 S 14 ~ 77 ~.,¢.: 203 S Pz W I~~ ~.~ S 26 W 1 7,8 210 S 8,5 301 N 59 w 100 ~ 2 289 N 71 w t 8.5 278 N 82 7.0 271 N d.4 t6~S S 12 E t00 10,2 198 S la w 100 1C,1 175 11,4 225 S 45 N 100 10,7 22t S 41 w 1C0 1C.9 212 S 17.2 10~ S 76 E 14 0 108 8.4 115 S 85 E 60 3 2 &9 N 49 26.6 58 N 58 E 9.2 72 N 7~ 5 97 18.5 6~ N d5 E 100 8.2 12 N 12 E t60 -~ 3 14 N 14 E 1~' 2~.5 42 N 42 ~ 100 12.0 118 S C2 ~ 100 12.3 1t9 S al E !00 9.3 12~ S 51 E 100 ~ :~ 111 S ~g E 1~ 4,8 104 S 76 E 1CC. 5,7 77 N 77 E 100 4.5 111 S ~ ~ 3~ N ~4 ~ 100 7,0 340 N 20 w 100 15.,~ 72 N 72 ~ ~ 53... 1 5.4 7~ N 74 E 73 5,8 172 S :~ E 100 2,~ 111 S 69 2.8 92 S 88 E 100 42.2 155 S 24 --- 42.3 t56 S 2~ ~2 . 4 156 S 24 /,2.4 156 S 24 E 42.4 156 S 24 E 42.4 156 S 42.4 156 S 42.4 156 S 24 E &2.5 156 S 24 42.5 156 42 5. 1~,, S 24 E 42.5 1 q6 42.6 t55 42.5 15b S 24 E 42.5 156 S 24 E 42,5 156 S 24 ~2 ~ 156 S 24 ~2.3 156 S 24 42.a 15~ S 24 ~2.4 156 S 24 42.~ 156 S 42.5 155 S 2~ 42.4 155 S ~2,3 15b S 42.3 1~6~, S 24 =_ 42,3 15~ S 24 4,*.3 156 S 24 ~2.4 155 S ~S 42.~ 15~ S 24 42,4 155 S 25 E 42,4 155 S 25 42,4 1 5= ~2,4 1 $~ S 25 42,3 155 4~,& 1~5 S 42.3 I 55 S 25 42,3 155 S 25 RECEIVED SEp i 6 Naska Oil & Gas Cons. Commission Anchorage MARATHON OIL CO. STEELHE~C M-.2 MCARTHUR RIVER KENAZ C8/24/87 ALASKa. DEPTH WL **FORMATION DIP** ~NG ~Z 6EARING 2094.0 Z096,0 8,0C 2098,0 2102.0 8,00 2104.0 8.0C 2106.0 .8,00 ?108,0 8,00 2112.0 8.00 2114.0 2116.0 8.0O 2118.0 8.00 2120.0 8.0C 2122.0 8.00 2t24.0 8.00 2126.0 8.00 2t28.0 8.00 2112,0 8,0C 2134.0 8.00 2140,0 8,00 2142,0 8.0C 2144.0 8,00 21 4.6.0 8,0C 2148,0 ,~ f,, ,-, ,- 15,.,. 0 8,uC 2152,0 8,00 £154,0 8.00 2t56,0 8.0C 21 58.0 8, OC 7t .50,0 8.0C £162,0 8,00 2168.0 8,00 2170,0 2172,0 8,00 2174,0 8.06 2176,0 8.00 2178.0 8.00 2180.0 .8,00 2152.0 2184,0 8,00 2186.0 8.0C 6.2 88 N 88 E 60 11.3 199 S 19 w E;1 5.-~ 307 :N 53 W 1C'*,,~ 11.3 357 N 3 W 7'2 1~.5 302 N 58 ~ 8.5 9. I 63 N 63 E 97 19.2 6~, N 68 E 59 .9 107 S 73 E 100 , 7.5 153 S 27 E 72 7. 3 146 S 16:· 5 lP0_ S 13.4 65 N 8.8 111 S 69 E 5Z 4.1 113 S 67 11,8 127 S 58 E 76 7,7 t93 S 1~ ~ 1C0 26.3 220 S 40 ~ 100 6. 2 161 S 19 F 1 10.1 18C .S 11.3 252 S 18.9 288 N 72 w 58 1t.6 271 NE¢ W 100 13,2 130 S 50 e 91 16,¢~ 75 N 75 12.5 127 S 53 E 12.2 129 S 51 9.1 t54 S 26 E 1CC ~.2 144 S ~6 E 100 11.6 147 S Z3 E 54 11.1 153 S 27 E 42 6.7 168 S 12 E 100 7.2 !70 S 10 E 100 8.2 171 9.3 163 S 17 E 100 t I. 3 205 S 10.~ 166 7 2 143 S 37 E ~6 7.1 148 S 32 E 100 7.2 136 S 44 E 7.4 170 S 10 5 10C 42,3 155 $ 25 42.3 t55 S 25 E 42.3 155 S ~5 E ~2. Z I 55 S 25 E ,42.2 155 S 25 E 42.2 156 S 24 E ~2..2 155 42.2 155 S 25 E ~2.2 155 S 25 4Z,2 155 S 25 E 42.2 I 56 S 24 E 42.2 155 S 2~ E 42.2 155 S 25 ~2.2 156 S 24 E 42.2 155 S 42.2 !5~ S 42.1 155 S 25 42.1 155 42.1 155 S 25 ~Z.1 155 S 25 42.1 155 S 25 ~2.1 1 55 S 25 E 42.1 156 S 24 42.1 155 42.0 156 S 42.1 155 42. I 1 56 42,0 15~ S 24 42,0 155 S 42 I 155 42.1 1 55 42.0 155 S 25 42.1 156 a~ .~ 155 S 25 .c~ 156 4~.0 155 S 25 42 O 1~6 S 2~ 42.0 155 42.1 155 S 25 MAR&THON OiL CO. STEELHEAB 08/24/87 AL~SK~ DEPTH WL **FORMATION DIP** ANG AZ BEARING GRAD- 2188.0 8,0C 2190,0 8.0C 2192,0 8.0C 2t94,0 ~8,0C 2196.0 8.00 2t98,0 8,0C 2200,C 8.0C ~202.0 8.00 i~204,0 8,00 2206.0 8,00 ~208,0 8.00 2210.C 8.00 2212,0 8,00 2214.0 8.00 2216,9 8.0C 2220 .G 8, 2222,0 2224.0 8.0C 2226,0 8.0C 223C.0 8.00 .~34 0 ~ OC 2238,0 8.0C 2240,0 8.00 22~2.0 8.0C 2244,0 8.00 2246 m 8 0C 2248,0 8.00 225C.0 8,,30 2252.0 8,00 2254,0 8.0C 2~58,0 8,00 2260,0 8.0C 22~2 .C 8,00 226.4.,3- -$.00 22,58.0 8.00 2270,0 ~:,OC 2272.0 &,O0 2274,0 8.00 2276.,0 8.00 2278.0 8.06 11,7 201.¢~ 21 W 1P.~O = 9 1 8 o 8.9 42 N 42 E 100 1t.6 55 N 55 E 100 10.~c, 59 N .,~'~, E 100 ~.9 227 S 47 W 100 ¢. 5 222 S ~.3 172 9.1 177 S 3 e 100 ~ ~ 16~ S 8,7 160 S 20 E 1CC 16,1 93 S 87 E 10C 9,9 94 S 86 ~ 100 11.1 9S S 87 ~ 61 : 0 211 1~ . 2 ~30. ~.~ ~cO W 100 11.4 147 S 33 E 8.! 2.6 114 S 66 E 70 ~,1 179 S I E 106 ?,7 1 41. 17,7 _m46 S .6~ N 10nu 1C,2 198 S 1~ w 100 4.2 180 S C E I C0 6.3 22~ S 44 W 100 ],4 354 N 5 W tC0 9.6 64 N 64 E 12 I g~ N 86 E 13 7.9 78 N 78 E 1C0 11.7 130 S 5C E 11.7 89 N a9 E 2.5 7,~ 1 50 S 3C ~.6 1 79 .S 1 a,8 176 S 11.5 133 S 47 E 39 7 3 9~ ~ ~6 E 1~ 8:.6 14~ S 31 E 53 5.9 ~03 S 23 ~ 1~ ~.9~ 129 ~'~ .~,1 ~,. tC2 ~.4 tll S ~9 E 1C0 9,7 109 S 71 ~ 98 '42.2 155 S 2S E &2,0 155 S 25 E 42,0 1,~'~., S 25 E 42.0 15,5 S 25 E ~2,0 155 S 2~ E 42.0 155 S 25 E ~2.0 1 55 S 25 E 42 O lC5 S ;5 ~ ~2.0 155 S 25 E ~2.3' 155 S 25 E 42.C 155 S 25 a 42,0 155 S 25 E 42.0 155 S 25 E 42,0 155 S 25 E 42.C 155 S 25 E 41.~: 155 S 25 ~ C2.C 155 S _Pc~.~_ 42.0 155 S 25 ~ ~2.0 155 S 25 E 41,9 1S5 S 25 E ~1.9 156 S 24 E 41.9 155 S 25 ~ 4!. 9 1 5~ S 24 E 41,z] 156 S 24 E ¢1.8 155 S 25 E 41.:~ 155 S 25 E ~1.7 1 55 S Z5 ~ 41.7 155 S 25 E 4!.7 155 S 25 E ~1.7 155 S 25 ~ 41 6 I~= S 25 = ~1 .6 1 ¢5 S 2~ ~ ~1 7 1 ~5 ~ ~$ ~ 4!.7 15~ S 25 ~ 41.7 15S S 2~ ~ 41 * 1~; S 2~ E P~GE 5 MAR~THC, N STESLHEAD MCflRTHUR KENAI 08124187 OTL~. ,., M-2 RIVER ~L$.SKA DEPTH WL **rORM~TZON Dz. ~NG AZ BEARING GREBE 2280.0 2282.0 2286.0 2288.0 2290.0 229a.0 2296.0 2'298.0 2302.0 2304.0 2306,0 2308.0 2310.0 2312,0 2314,0 2318,0 2324,0 2326,0 2328.0 2330.0 2332,0 2336,0 2338.0 2 '3/,2.0 2344.0 2348 ,C 2350.0 2352.0 2354.0 2356.0 2358,0 236C.0 7364 O 2S66,0 2368.0 237C,0 2372,,0 2376,0 2378.0 8,0C 8,00 8,00 8.00 8,0C 8,00 8 8.00 8,0C 8,GO 8,0C 8.00 8.0C 8.00 8.00 8,0C 8,06 8.00 8.0C ~.OC 8,0C 8.00 8 8.00 8.00 8 8.00 8.00 8.0C 8,00 8,00 8.00 6.9 224 S 44 w 8,3 179 S I E lC,6 203 S 23 ~ i~.2 46 N 46 E 8.4 46 N ~6 E 22.6 267 S 87 ~ ~.9 290 ~ 70 W 1.7 55 N 55 E 5.7 62 N 62 E lC,5 133 S 47 E 5,9 91 S 89 E 11,9 88 N 8.~ , 7,4 177 S .~ E 4.5 179 S 1 E 5,2 176 S 4 E 4.~ 183 $ 3 W !0.4 139 S 41 E 13,2 139 S 41 E 10,3 14t S ~9 E ~ 9 ~1 N ~1 ~ 8.0 ~9 N 39 E ?.9 2~8 S 78 W 1~.9 227 S 47 w 17.0 2~6 S 76 N 10.1 11& S 66 ~ 1~.6 71 N 71 ~ ~.0 ~0 N 50 ~ 3.1 72 N 72 ~ ~ ~ 175 S 5 E ~ i 7,7 157 S ~5 E 7,5 15~ S 2~ E 18.5 49 N 49 ~ a.3 4~ ~'j 4~l~ ~ -- 4.t 2~' N Z~ ~ 4.4 94 ~ ~6 ~ 9 10,3 63 78 100 100 ¢8 100 1 CO 100 82 100: 100 100 100 lOC uu 1 O0 1C0 1CC 100 76 1 Gu i75 lOC 41.9 155 S 25 41.9 155 S 25 E · ~2.C 155 S 25 42.C' 155 S 25 42,0 155 S 25 E 4~ r 155 S 42.1 155 S 25 42,1 1 55 42,1 !55 S 25 42 , I 15.5 S 25 42,2 15~ S 25 E 42,2 I 55 $ 25 42,2 155 42,2 155 S 25 42,2 155 S 42,2 155 S 42,2 15=.., $ 25 42.t 155 $ 25 42,! 155 S 25 4i,1 1 55 S 25 42,C 155 S 25 42,0 155 S 25 42,C !55 S 25 41, ~ I 5a S 24 41,B 155 S 25 E 4!,~' 156 S 24 41.5 156 S Cl.7 156 S 24 41 . 8 156 S 24 E 41 ~ 15~ S ~!.7 155 S 41.7 1 56 S 24 41,7 156 S 41,7 156 S 24 C1.,5 155 S 25 E 41.9 15~ 4t.9 155 S ~..,' =- 4t 0 1~5 S 41 .'? 156 S MARATHON ST~ELHEAO MC~RTHUR KEN&I 08/24/87 OIL CO, M-2 RIVER DEPTH WL **~ORNATION DIP** ANG ~Z BEATING GRADE D~. ~A7~ ==~RiNG 2380,0 8,00 _2382,0 8,0C 23.84, O 8,0O '2386,0 8, OrJ 23.$8,0 810C 239G,0 23~2 3 ~ OC 23~4,0 239'6 , 0 8, 2398,0 2400,0 8,00 2402,0 2404,0 8,00 2~08,0 241 C, O 8 · SC 2~18 , 0 8 , OC 242C,0 8,0C Z42Z,O Z4Z4,0 8,00 242~ ,0 8 , OC 242~,0 Z430,0 8,OC 2432,0 8,0C Z434,0 2438,0 :~442.C 8.0C 2444.0 2446,0 8,0C 2448.0 8.00 2452,0 8,00( 2454,0 8,00 ~458,0 2452,0 8,06 2468,0 8,00 Z47G,0 8,06 2472,0 8,00 2474,0 8,00 e.3 86 hi r;6 = 100 1C,4 57 N 57 E 61 12.0 89 N 89 E 53 1G,6 90 N c,~ 100 S 8~3 E t00 12,1 9'2 S 28 a 73 10,~ 1~I S 17,0 234 S 54 N 93 1C.7 166 S 14 E 12.4 34 N ~4 ~ 10~ ~ 6 317 N 20. 5 232 S 23,2 235 S 55 W 89 21,4 24Z S 62 W 50 1C.O 149 S 3t E 11. 2 19~ S 13 W 7.8 187 S 7 11.2 _~3~:,., 7.5 7~ N 7'~ E 1~0 2.7 13t S 49 E 15.9 72 N 72 E 106 14.8 73 N 16.1 71 N 7t E 100 18.4 73 N 73 E "~1 12.7 57 N 57 E 100 12,6 83 N 83 E 53 1~.6 75 N 75 t4.9 45 N 4~ E 57 ~,5 154 S 2~ E 100 10,3 121 S 5~ E 7! 2C,4 317 N 48 N t00 2?,4 307 N 53 ~ 7~ 14 0 ~77 14,0 277 N 83 w 65 14,3 277 N 9.3 P4~, S ~ w 1On 2,5 7 N 7 ~,1 23 N 23 : ~'~ .~,7 lm8 S Ig W 72 ~1.9 156 S /-1 c~ I ~6 S 24 = 4t,9 '~!,9 156 41.C 156 S ~4 41.9 156 S 24 41.m 15~ S 24 ~1.9 156 S 24 ~t.9 156 S ~1. c 1 41.9 1 56 S 24 42.0 156 S 24 42.~ I 55 S 25 ~2.2 155 S 42,2 150 S 42,0 156 S 42,1 156 S 24 ~2,1 t55 S 25 42,1 1 56 S 24 L2,1 155 S 25 c2,1 15~ S 42,1 156 S 42,1 15~ S ~2,t I~. S 25 =_ ~2,t 156 S 24 42,1 ~2,t 155 S 25 ~2,2 155 S 25 ~2,3 1 ~2.~ 15~ S ~2,3 155 S 24 E 42.3 156 S 24 E ~2,3 1 42, ~ 1 5~ S 24 42,4 I 56 S ~2,5 156 S 47,5 156 S 42.5 1 ~2,o 135 S 25 p ,~G E 7 M~RATHON OiL CO. STYELHE&C ,',.- 2 ~CARTHUR R~VER KEN~I O~/~4187 ALASKA DEPTH NL **FORM~TIO:N DIP** ~NG AZ ~EARiNG O~ 3~Z E:aRiNG 2476,0 2478.0 2480,0 2¢~:~ 0 :2z, 84.0 24186.0 2488,0 ~92 .O ~9~.0 2502 .C 2504.0 2506.0 2510.0 25t4.0 2516.0 2518.0 2522.0 2~2~ 2526.C 2530.0 2532.0 2536.0 2540 .O 2542,0 2544.0 2546.0 2548,0 255C,0 2558.0 2562.0 25~4.0 2566.0 2568.0 8.0C 8 . ~.-, ~.,., · a. 0 C 8.00 8,CC 8.OC 8.00 8.00 8.0C 8.00 8 .CC 8.0C 8.0C 8.OC ,8.0 'C 8,0C 8.06 8.00 8,0C 8. OO 8.00 8.00 8. ~ 8,00 ~.r~: 8.uC 8.0C 8.00 8.mr ~.0~ 8.0C 8.00 8,00 8.0C 8.0C 8.00 8.0C '~ I $1'~' ~ x," 8.6 247 S ~7 ~ 9.5 101 S 79 ~ 9.6 104 S 76 E 5.8 160 S 2~ E 5.7 I 56 S 24 ~ 8,4 ~0'~_ ~ S _PC W '~ ~ ~14 .S ~4 W 8.9 1 89 S 9 W 7.8 179 S I ~ & 5 91 S ~9 E 3.6 120 S 6C ~ 1:. 2 71 N 71 E 9.Q 79 N 79 ~ 4.au 15n ¢ 30. = 5.8 t49 S $1 E 1=~,.3 116 S ~4. E 1C,3 1t2 S 6=,.,E 7,7 11~ S ~, .~ a:.8 112 S 68 E ~.O 111 S a~ E 10.1 107 S 75 ~ 8.0 110 S 7C E 1.3 2 N 2 E 4.6 255 S 75 w 7,~ 1~3 S 13 N 5,0 P3 S ~7 ~ 5.4 76 N 76 ~ 2.0 57 N 57 ~ 1.6 54 N 5~ ~ 2.5 $5~ N 7 W 1$ 6 7$ N 75~ ~ 6,2 126 5 5~ ~ 11.5 57 N 57 ~ 15. I 55 N ~5 :~ t8,0 65 N ~5 ~ !1,4 72 N 72 ~ 15,7 6& N ~ ~ 100 100 68 60 100 10.0 100 1C0 ~0 10C 10:7, 61 100 1C 0 100 78 10u 100 100 180 100 lC0 100 1 C0 100 ~0 63 100 100 100 100 42.6 155 S 25 42.6 !55 S 25 E 42.6 155 S 25 E 42.6 156. S 24 E 42.6 1 55 S 2.5 42,7 155 S 2S E 42.6 t56 S 2~ 42.6 156 S 74 42.6 155 S 25 42.a 155 S 25 42,6 1~ S 24 42.5 1 56 S 24 42.5 155 S 25 42,5 155 S 25 42.5 155 S 25 42.~ 155 S 25 4i.6 1 55 S 25 E 42,5 15~ S 25 42,0 155 S 25 42. ~ 155 ~ 2~. 42,7 155 S 25 42.7 1 55 S 25 42.~ 155 S ~5 42.6 155 S 25 ~2.7 155 S 25 42.7 155 S 25 ~2.7 t55 S 25 42.7 155 S ~5 42.~,~, 155 S ~ - ~2.7 155 S ~5 42,7 155 S ~5 42.6, 1~.~ S 25 =_ ~2.6 155 S 75 ~.~ 1~... S 25 _ 42,7 155 S 25 ~2 7 15= S 25 42, ~2. !54 S $~6 42,7 155 5 25 42.~ 155 S 25 42.7 15= S 2~ MARA. THOiN OIL CC. STEELHEAD M-2 MCARTHUR RIVER KEN~I 03124187 DEPTH NL **FORMATION DIP** ANG AZ BEARING GRACE *~**=CRE~CL=*~***_, 2570,0 8,0C 2572,0 8 2574,0 8,00 2~76 0 2580 · 0 2582,0 8,00 2584.0 ~586.0 8.CO ~588,0 8.00 ~590.0 ~59~.0 8,0C ~596.0 ~598.0 8.00 ~60G,O 8,00 ~60&.O 8.00 ~606.0 2612,0 8.0C 2614,0 8,0C 2616,0 8,0C 2618.0 8,0C 2620,0 8,00 2622,0 8,0C 2626,0 8,0G 2628,0 8,0C 2632,0 2634,0 2636.0 8.0 2638.~ 8.00 264G.0 8.0~ 26~2,0 2646.0 8,00 2648.C 8,0C 265C.0 8,00 2~52 ~' 8. OC 2~54,0 8,00 2656.0 8,0C 2658,0 ~66g.0 8.CC t].3 335 N 25 ~ 90 1~,7 271 N 89 W 3~ 14.7 3~z~ N 1,5 w 59 14.~: 356 N 4 W 22 5.0 54 N 54 ~ 1 CC 4:.7 14 N 14 E 4,2 21 N 21 ~ lOC 3,1 352 N 8 W 100 ~,0 125 S 57. 6 4 118 ~ ~ ; 1~ i 5,9 128 S 52 ~ 100 4~1 1~9 S 4,7 114 S 66. E 86 9,4 206 S 26 W 1 12. 8 21~ 1C.5 86 N 7,1 85 N ~5 E 100 3G.3 71 N 71 E 3 ~,O 124 S 55 E ~C~ 7.2 89 N ~g E 100 ~.9 104 S 76 E 8.8 10.9 159 4.1 353 N 7 W 100 4.8 315 N ~.9 t71 S 9 ~ 100 1~.6 217 S 3~ W 54 7 8 130 S 5C E 1~'~' 7 5 t~e 5 =1 ~ 103 7.7 169 S 11 E 1C0 ~.1 16t S 19 7.5 140 S 4g ,E 100 4,6 101 S 7¢ 1C,3 90 N 9C E 100 12.7 45 N 45 E 1,~ 17 ~ 324 N 36 W 6A 16,0 3Z2 N ~8 w 59 27.5 71 N 7t E 1CC 42,$J 155 S 25 E 42,$: 155 S 25 E Z~2 ~ 155 c, ~c r- Z, 2.; 155 S 25 E c-2.g 155 S 25 ".~ 9 !55 S 25 43.0 155 S 25 4~,C. 1~5~ S 25 4~ 0 1~4 43.0 154 S 43.1 155 43,1 155 S 25 43,'~' 155 S ~5 43.0 154 45.1 154 4~.0 155 S 25 4~.~ 15~ S 25 45,S I 55 S 25 42.¢ 155 S 25 42,9 1 ~4 S 26 45.$ 154 42. ¢ 1~4~ S 4~' ,9 155 S 25 4~,0 154 S 26 43,3 154 4=_:..0 1=4, .S 26 ~_ 4~,0 154 S 26 43,1 155 S 25 43.1 155 S 2.~ ._ 43.0 1 ': ~ 4~.! 155 4Z.t 154 45.1 154 4= 2 I 54 S 2 43 2 1=4 S ~3.2 154 S ~6 4~.3 t~4 S 26 ~3.2 155 S 25 43 ~ 154 S c3. S 1 54 S 26 M~R~TMON OIL CO. STEELHEAD M-2 MC~RTHUR RIVER KEN~I 08t2~/B7 ~L~SK~ ~=PTM WL **XORM~TION DIP** ANG AZ BEARING GRACE OA CAZ~ ~$~RING 2662.0 266~.0 26~8.0 2672.0 2674.0 2676.0 267~.0 2682.0 2684.0 2656.0 2688.0 2692.0 269&.0 2696.0 2698.0 2700.0 270~.0 2708.~ 2712.0 2718.0 272G.0 2722.G 27~4.0 273e. C 2738.0 27~0.0 27~2.G ~7~4.0 2746.0 2748.~ ~'75G.u 2752.0 275~.G 275~.0 ~764.0 2766.0 2768.0 8.C.C 8.0C 8.06 8.00 8.00 8.0C 8,00 8.0C 8. OC 8.0C 8.00 8.00 8.00 8.00 8.0C 8.0C 8.00 8.00 8,00 8.00 8.00 8.0C 8. OC 8,0C 8.0C 8,00 8,00 8.0C 8.00 8, ~C 15.2 77 N ?7 E 82 11,2 B2 N 82 E :92 12.4 7~ N '~8~ F--. t00 C,9 12 N 12 E 130 ~=.7 50 N 5C 3.4 88 N 88 E 100 :~ I 79 N 79 E 18~ - I · 1~,5 158 C:.6 147 S 33 E 100 13,3 137 S ~3 E 66 1C· 2 153 S 27 10,0 153 S 27 E 1 10.3 163 S 1~.4. 136 S 4~ E 1~uC. 6 6 199 S 19 W 1~0 1~. 6~ 12m 10,0 124 S 56 E 71 7 3 144 S ~ = 1nq 1 8.6 244 S 1 7 20o S ~.3 226 S 46 w 92 20 9 237 .S ~ W 56 6.6 189 S 9 ~ 100 7.0 193 S 13 w 1C0 ~.2 t~. ~.~ 162 $ 1~ ~ 29 10,1 139 ~ 8 1On S ~'~ ..... ~u E 73 14.7 271 N ~9 N 77 3.3 270 N 90 W 100 3.1 231 S 51 N 1C0 .5.0 165 S 15 ~ 54 x 4 !21 ~ 59 ~ 1~.~ 12.0 2'~4 N a6 W 68 11.1 305 N 55 W 5t 18.0 278 N 17,4 2~1 N ~.8 ~3~ S 52 W 1C,0 249 S ~9 N 1C0 14.! 246 S 43.3 154 S 26 E 4~ 3 155 S 43,3 I 55 S 25 4~ 3 154 S 43 ~ 1 ~4 ~ P5 E 43,4 154 43.3 I ~5 S 25 ~3.2 155 S 25 43.3 154 S 26 43.3 154 S 26 4~ 3 1~4 S ~' 43.3 15'~ S 26 43.3 I 54 S 26 E 43.3 I 5~ S 26 4~ 4 1~4 S 26 43.4 1 5~ S Z 43.4 15~ S 25 43.5 154 S 25 E 43.5 I 54 43 · 5 154 S 43.5 !54 S 26 43.4 154 S 2~ 43. ~ 1 54 S 26 E 43.4 154 S 26 E 43.3 1 54 S 25 43.2 155 4~.3~ 1=4, S ~3.2 15~ 43.2 1~4¢ S 26 ¢._ 43.2 1 54 S 26 &3.'2 154 S 4~ 3 154 ~ ~6 E 43.3 154 4~ ~ 154 S 4~.3 154 S 26 43.5 1 ~4 S 2C a3,5 154 43.5 154 MARATHON STEELHEAD u~RTHUR KEN~I 08124/87 OiL CO. ;4-2 ~,IVER ALASKA ~EPTH WL ** FORNA'TION DIP** ANG A=~. ,:CARING~,. GRADE 2772.0 2774.0 277~.0 2778.0 2780.0 2782.0 2784.0 2786.0 2788.0 2790.0 2792.0 2798.0 2~0~.0 2802.0 2804.0 2806.0 2808.0 2810.0 281~.0 2818.0 2820.0 2822.0 2824.0 2528.0 2828.0 2.830.0 ~832.0 2534,0 283~,0 2838,0 2840,0 2842,0 2844,0 2846,0 28~.0 2850.0 2852.0 2854.0 2856.0 8.00 8.0C 8.0C 8.0C 8.0C $.00 8.0C 8, .ce 8.00 8.0C 8.00 8.00 .8.0C 8.0C 8.00 8.00 8.00 8,0C 8.00 8.0C 8.00 8.00 8.00 8.00 8.00 8.06 :* O0 8.06 8.aP 8.00 2~.9 253 S 73 W 71 8 I 37 N ,:~. 7 8.~ N I 2:3 ~'9 N 5.1 117 $ ~3 E 7o 21.6 57 N 67 E t00 4.,~ 72 N 72 E 4.6 11n S 7 ,., ..., E I d 0 2.1 147 ~-.5 141 S 39 ~ 63 5 -~ 111 S 69 E 9 ' I 7.2 26 N 2,5 E 100 1.9 34,5 N 12 10.9 345 N 17 W 100 4.3 261 S 11.4~ 176 S 4 E 61 11.3 150 S 30 E 23.9 54 N 54 E 1 7.8 35 N ~5 F- l~m~ 1~.0 42 N 42 E 100 4.1 22 N 22 E 100 4.5 151 S 29 E 10,3 3./~ 151 S 29 E 100 5:2 ld2 S 1 9.5 125 S 9.6 202 S 22 W 62 9.6 157 S 23 E 100 9.8 168 S 12 E 4.9 193 S 13 ~ 10'0 8.0 176 S 4 E 64 7.2 16'0 S 20 5.6 168 S 12 E 1C0 11 7 t2~ S ':::5 r-. ~'Z tl./4 140 S 40 E 20 14.1 22a S 16.7 2x7.~ S 57 w 7*.%, 5.4 219 S ]9 W 100 4.9 177 S 3 E iC0 11,5 149 $ $1 ~ 10 1.1 136 S 44 E 42 4~ ^ 1=4 S 26 43.6 I 54. $ 26 ~3.6 154 S 2,~ 43.6 154 S 26 E 43.6 1~4 S 26 4~ 7 I ~4 S 26 4= 7 154 S ~ ~1 43.7 1 54 S 26 ~ '~ 154 ~ 2.5 ~' I ~. ~ 4~,8 I 54 S 2~ 43,6 154 S 26 E ~3,8 153 S ~7 43,8 153 S 27 43,8 153 S 27 43.8 1 5~ S 2~ 43.7 153 S 27 4~.7 154 S 2~ 43.7 154 S 26 43.6 153 S 27 43.8 t53 S 27 E ~3.~, 15= S ;7 ~3.,5 153 S 27 43.S 153 S 27 4~, 9 153 S 27 43,9 153 S 27 43,9 153 S 27 4~,9 1 53 S 27 43,~ 155 S 27 43.~ 153 .S 27 E 4~ 9 15~ ~ 27 43,9 153 S 27 4~ , 9 15~ S ~7~ 4.3,m 153 S 27 E 43.9 153 S 27 43.9 1 53 S 27 4z.'9 1 5~ S ~7 , -, .~. ~ 43. ;' 153 S 27 4~.~_. 153 S ~7 _ ~-.9 153 S 27 E 4~ 7 15~ S 2~ MARATHON OIL STEELHE.~D M-2 MCARTHUR RIVER KENAI 08124/87 ALASKA DEPTH WL **:ORM&~ON, . ~, DIP**. AZ BE~RtN'~'u GRACE ****80RE~CLE***** DA OAZ BEARING 2864.0 2866.0 ~ 868: · 0 287(2.0 2872 ¢' 2874.0 28?6,0 2880,0 1882.0 2884,0 Z886.0 2~88,0 2890.0 2892,0 2~c~4 0 2896.0 2898.0 2900,0 2902.0 2906.0 2910.0 2912.0 2914.0 2916.0 2918.0 2920.0 2922.0 29,°z, 0 &.... 2926.0 2928.0 2942.0 2944.0 2~46.0 2948,0 2950.0 2952.0 2954.0 295~ 0 ~ m 2960.0 8,00 ' 8.00 8,00 8,0C 8. OO 8. 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M-2 RIVER AL~&SKA ~=PTH WL **FORMATZON DZP** ***'3Cp,~.,.~CL ~ ~.A C~Z ~EARING 2962.0 8.00 2964.0 8.00 2966. O 8.0O Z968.0 8.0C 2970,0 8.00 2972.0 8.00 2'974, C 2976,0 8,00 2978.0 8,0C 2980.0 8.0C ~9~? 0 8 0C 2984.0 2986,0 8.00 2988.0 8.00 2990,0 2992.0 2994.0 8,00 2996,0 8,FjC 2998,0 8.CC 3000.0 8,0C 3004,0 8.0,0 3006,0 8,00 3008,0 8,00 301C.0 8.0C 3012,0 3014,0 8,0C 3016,0 8,00 301 8,0 8 · OC 3022.0 8.00 ..... ~,0 r~ Or 3026,0 8,00 3028,0 8,00 3030,0. 8,00 3032,0 3034,0 8,CC 303~,© 3038,0 3040,0 $,OC 3042,0 8,00 3044.0 8,0C 4.1 152 S 2;,,,~ E 100 5.3 145 S 35 E 100 4.9 162 S 1~$ E 100 4..$ t7x~ .. .~ 7 ~= 1CC t.1 180 S 9 2,1 22~ S 4~ W 100 2.9 242 S 62 w 100 ~ ~ 235 S 55 4.1 232 S 13.2 262 S 82 W 60 t2.5 260 S EO w 64 :5 ~ 100 ~ 3 2~ S t.5 210 S 30 W 100 5,7 0 N 0 E 61 lg',0 76 N 78 E 55 15,3 71 N 71 ~ 72 5.1 102 S 78 e 160 11.9 81 N 81 E 1'33 1',~.9 344 N 16 W 59 2.6 321 N 4.0 319 N 41 W 97 1.1 292 N 68 W 100 7,5 319 N 41 W 100 7.2 306 N 54 W 100 11.9 119 S 61 E 51 9,4 121 S 59 E 100 7.6 87 N ~m = 6.~ _z3.6 ~ ~1 2 N 4 4.9 317 N 6.3 199 S 19 W 17 3.2 S4 N 84 E 1 CO 7,~ 139 S 41 E 100 7,7 146 S :4 E 100 9.6 142 S ]8 E 61 lC.7 10~ S 78 E 64 1~,8 76 N 7~ E 1'~¢ ~,8 1~8 S ]2 E 100 8,2 18¢ $,~ t53 S 27 ~ 100 4q ~ 1~3 S 2 43,9 153 S 27 E 43.9 153 S 27 E 43.9 153 S 27 4~.9 153 S 27 43, ~ 1 53 S ~7 4Z,,O 153 S 27 ~ 15~ 44,0 !53 S 27 E 44,1 153 S 27 44,1 153 S 27 E ~4,2 152 S 2e E 44,2 152 S Cc, Z 1 5~ S 28 44,2 15~ 44,2 153 S 2 44 ~ 1~ 44.3 1 53 S 27 Z ~4.3 153 S 27 44,3 153 S 27 44,4 153 S 27 44.4 153 S 27 44,4 153 S ~4.4 153 S 27 ~4.5 153 S 27 E 44.4 153 S 27 E ~4.5 153 S 27 44.5 153 S 27 44.5 153 S 27 E 44.6 152 S 44.6 152 44.~ 152 S 28 44.~ 152 S 44,8 ! 55 S 27 4~.8 152 S 44.8 155 S 27 44.8 152 S 2F ~4,S 152 S 44,9 152 S 44.9 152 S P~GE 1 ~ MARATHON OIL CO. qT~F-LHEA~ MCARTHU~ RIVER KENAI ALASKA DEPTH WL **mORMATZON DIP** ANG AZ ~E~RING GRADE ****BOREHCLE***** DA ~AZ 9EARING 3052.0 3056.0 3050.0 3002.0 Z066.0 30,58.0 3070.0 3072.0 3074.0 3076.0 3078,0 $080.0 3082.0 3086.O 3088.0 3094.3 3096.0 3098.0 3100.0 3102.0 3104.0 3106,0 3t12,0 3114.0 3116.0 31!8.0 3122.0 3124.0 3t26.0 3128.0 3t30.0 3132,0 3134 ~ 8.00 8.00 8.00 8.0g 8.00 8.0C 8.00 8.00 8,00 8.00 8.00 8.00 8.0C 8.00 8,0C 8.0C 8.0C ,8.0C 8.00 $.00 8.00 8.0C 8.0C 8.00 8.0C 8.0C 8.00 8,00 8.00 8.0C 8,0C 8.00 $,06 8.00 8.6 194 S 14 W 42 5.0 153 S 27 E 100 5.1 1:5,5 S 24 E t00 In I I° 8.5 114 S d6 E 100 8.8 77 N 77 5 77 ~.5 19 N 19 E 13... 8,1 52 N 52 E 19.5 23 N 23 E 2C,3 345 N 15 W 4.0 94 S ~5 ~ 100 24.9 76 N 76 ~ 54 ~.0 25~ S 79 W 100 27.0 307 N 53 W t00 11.7 19~ S 16 ~ 51 1C,0 188 S 17 4 273 N 11.2 208 S 28 w 70 10,~ 208 S 28 ~' 94 2,3 229 S 49 W 100 3.7 22& S 44 W 100 ~,3 164 S 1x~, E t0o 10.2 192 S 12 W 16,6 313 N 47 W 17.0 31 3 N 47 S, 4 308 N 6,8 228 S 48 W 100 ~,7 190 S 10 W 100 5 P 25~2 S 72 w :~'.m 2,9 179 S I E 1 5 1C,3 152 S 28 E 100 9 0 16~ S 15 E 100 ~.~. 16'~,~ S ,.:*.0 157 S 13 2t,2 2~3. a,8 192 S 12 w 100 7,1 170 S ~ 1 52 N 82 ~ 1On 44.C~ 152 .$ 28 E 44 9 I=P S 2;~ E 45.0 152 S 28 E 44.~ 15~ S 7;~ ~ 44. ~ 1 52 S 28 E 4~.0 1~2 ~ 28 E 45.¢~ 15P S P~ ~ 45.0 152 S 2g E 4~..0 152~ ~ 2,,,~ =,_ 45.1 152 S 28 E ..,.u 153 5 27 ~ 45.0 152 S 28 = ~5.0 152 S 28 E 45.0 152 S 2~ ~ 45.0 152 S 2~.~ ~_ 4~.1 152 S 28 E 45.0 153 S 27 ~ 45.0 1~3 S 27 ,_= 45.1 1 52 S 2~ ~ 45.0 152 S ~8 E 4~ .0 1 ~ S 28 ~ 45.0 153 S 17 '~ 45.1 151 S 2,S E 4= 1 153 S ~7 = 4= ~ 152 S 2,~ ~ 45.2 152 S 2~ ¢ 45.2 1 53 S 17 E ~ P 152 S 2~ = 45 ~ I 5~ S 2* = 45 ~ 152 S ~8 = 45.4 152 S 2S E 45.4 152 5 2R,.¢ c_ 45 4 152 S 2~ ~ a5.4 152 S 28 f 4= 5 152 ~ 2~ ~ ~5,5 152 S 2c~ ~ 45,,~ l~m q 22 E 45. ~ I 52 S 2 8 E ~ .7 152 S 28 = o ,; G E 14 MARATHON OIL STEELMEAD MCARTHUR RIVER ALASKA DEPT~ WL **FORMATION DIP** ~NG AZ BEaRiNG GRAD= ****=CR~MCLa*****~ . 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C 1 59 S 21 ~3.9 ! 59 S 21 43.9 159 S 21 MARATHON OIL CO. STEELHEA~ M-2 MC~RTHUR RIVER KENAi 0~/24/87 DEPTH WL **FORMATION DI~** ~NG AZ B, EA~:iNG GRADE ****EOREHCLE***** C~ CAZ BEARING 3336.0 3338.0 3340.0 3342.0 3344.0 3346,0 3348.0 335~ 0 3352.0 3354.0 335:6,0 3358.0 3360,0 3362,0 3366,0 3368,0 3370.0 3Z72.0 3376 ~ 3378,0 3~80.n 3382.0 3384,0 3336.0 3388.0 3390,0 3392.0 3394,0 3396.0 3398.0 3400.0 3404,0 3406.0 3408.0 3412.0 3418.0 3420.0 3422.0 3424.0 8.00 8.00 8.0¢.. 8.00 8.00 8.06 8.0C 8.00 8.00 * 00 8. 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STEELHEA3 M-2 MC$.RTHUR RIVER KENAI 08124/87 ALASKA DEPTH WL ~*FORMATION DZP*~ ANG AZ 8EARZNG GRADE DA EAT 3430.0 3432,0 3434.0 34~8 3440.0 3442.0 3444.0 3~6.0 .344~,0 3456.0 ~458. 3460.0 3452,0 3664,0 346~ ,0 .3472, 3474.0 3~76,0 3~78,0 3480,0 3482.0 3488.0 3490.0 3496,0 3498.0 3500.0 3~02 3504,0 3506.0 3510.0 3512.0 351 4 .O 3516.0 351~.0 3520 3522,0 3524.0 3526.0 8.00 8.00 8.00 8,00 8.06 8.00 8,OC 8.00 8.00 8,00 8,0C 8.00 8,06 8.0C 8.0C 8,06 8.00 8.06 8.00 $.06 8.OC 8.06 8.00 8.00 8.00 8.0C 8.0C 8.00 8.00 8.00 8.00 8.00 8.00 11,4 51 N 51 E 7,3 23 N 23 E t00 17.9 2~ N 26 3.7 65 N ~S E 1 0C 2.3 344 N I 6 W 75 5.2 233 S 53 v~ 100 5.8 168 S 12 E 1~ 6.8 101 S 79 6.1 131 S 49 E 100 lC.~ ln~ S 7~ ~ 100 1~. 9 101 S 7~- 1~ 4 97 S 8~ = 100 7.6 124 S 5~ E 100 ~. 5 1 21 S 59 7,5 t35 S 45 E 100 10,7 140 S 40 E 56 ~,1 !55 S Z5 E 95 7.8 209 S 15.3 24~ S da W 1~0 19.~ 283 N 77 W 87 7.8 276 N 84 W 100 17.1 241 S 81 W ~7 g.O 204 S 24 W 41 7.2 1 72 S 5 ~ 7~ 7.2 176 S 4 :~ 53 1~,4 82 N ~2 E 100 11.3 49 N 49 E 87 16.8 34 N 34 E 56 18. 0 86 N 86. ~ I 143 S I 18.1 118 S ~2 E 100 9 7 9~ Sp= . ~. .~, E 100 3.5 98 S 8:2 E 1~.3 7.2 1 8~ S 4 w 1 O0 8.9 155 S 25 E 100 ~ 4 185 ~ S W 5~ ~.t 156 S 24 E 1G'3 ~ 6 171 S 9 ~ 9& 5.5 164 S 1~ E 10~ ~.0 171 S 44 5 t6: S 15 44.5 1~5 S 15 44.6 165 S 15 E 44.8 166 S 14 E 44.8 166 S 14 E 44.7 16~ S 14 44.6 166 S 14 44,5 166 S 14 44.6 166 S 14 44.~ 168 S 44..5 168 S 12 E 44.8 16~, S 12 44.~ 1~9 $ 11 44,9 169 S 11 44.9 .169 S 11 E 44.9 169 S 1! 44.9 !7',?.,'S 10 E 44.9 170 S 10 44.~ 170 S 10 E 44.9 170 S 1"'~. =_ 44.9 170 S 10 44.9 170 S 10 4~.~ 170 S 10 44.9 170 S 10 l 44.8 171 S ~ E 44.9 ! 71 S 9 E 44. g t 71 S 45.C; 171 S .,9 :_ 44.9 171 S 9 44.9 171 S 9 45,.'.3 171 S 9 4~.0 171 45.1 !71 ,S 45.1 171 S 45,1 171 S ~ E 4~ I 171 S ~.5.1 17t S 9 4':; I 171 45.1 1 71 S 9 45.1 171 S 9 MARATHON O[L CO. ~T~ELHcAC M-2 MCARTHUR RIVER KEN.~I 08/24t87 ALASKA DEPTH NL **FORMATZON DIP** ~NG AZ ~EARiNG GRADE DA CAZ 8EARING 3528.0 8.00 3530.0 3540.0 8.00 3542.0 8.00 3544.0 8.0C 3546.0 8,00 3548.0 8.00 3550 ~ .u 8.06 3552.0 8.00 3554,0 8,00 3556.0 8,0C 3558,0 8,00 3560.0 8,00 3562.0 8,00 3564.0 8,00 3566.0 8.00 3~68 O 8 3570 ~ .u 8.uC 3572.0 3576.0 8.0C 3578,3 8,00 3580,0 8,00 3582.0 8.0C 3586.0 8,CC 3588.0 8.08 3590.0 8,00 3592.0 8,0C 3594.0 8,00 3596.0 8,00 3600,0 8,00 3604.0 8.08 3808,0 8,00 3612,0 8,00 3514,0 8,00 3516,0 8,00 3618.0 8.00 3622,0 362~.0 8.0C 3.628.0 8.00 3630.0 ~,0..., 154 S _m6 ~ 51 9,5 71 N 71 E 14,2 66 N 13.9 102 S 78 E 97 6.1 13'3 $ 47 E 100 7,8 t36 .S 44 E 100 8.5 137 $ 43 E 100 9,3 136 S 44 E 100 I I .~ 1t3 N 10 E 100 23.1 252 S 72 ~ 100 3.5 282 N 78 W 100 12.5 252 S 72 W 59 2~ 9 70 N 70 7.5 62 N 62 ~ 100 2 ~ 23 N ~ E 8.3 18.0 251 S 81 W 100 19.~ 268 S aO W 86 19.3 a6Z S ~2 W 12.0 26;5 S 88 4 4 238 S 20.7 93 S a 7 E 71 7.7 5 N 5 27.1 62 N e2 E 87 12,3 115 S 65 E 51 9.8 97 S ~3 E tl.6 tZ5 $ 55 E 100 34.0 ¢4 12,2 156 S 24 ~ 130 13.6 15o S 24 E 78. 8.3 50 N 50 E t C0 7,! 2~ N 28 ~ 100 12,8 82 N ~2 ~ 100 5.2 130 S 50 ~ 100 2,4 13~ S 41 E 100 7.8 131 S 4~ E 100 4.2 44 N 44 ~ lC0 ~ 5 ~15 N ~7 ~ 100 11.7 ~57 S 77 W 100 g.4 19P 5 19 W 100 ~ 8 1~4 S 4 W I'~' ,,~ 45.1 171 S 9 45.1 171 S 9 45.2 171 S 9 E 45.3 171 S o E 4~.3 171 S 9 E 45 ~ 171 S . _,' 45.3 171 S 0 45.3 171 S 9 4~ 2 171 S o 45._2 171 S 9 E 45.2 171 S ; -" 45,? 171 $ 45. ~ 171 S 9 45.2 171 5 45.2 171 45.2 171 S 45.2 171 45.2 171 5 9 45.2 171 S 9 z, 5.Z 171 5 9 ~5,1 171 45.1 171 $ 4;.1 171 S 9 E 45.! 171 45.1 17~ S 10 4~, · 1 171 S 9 _ 45.l~ 171 ~5.0 1~1 44,3 170 S 19 44 8 173 S 1 44 3 170 S 1 44.7 171 44.7 171 S 9 E 44.7 171 S 44. ~ I 71 S 44.7 171 S 44.7 171 S 9' E 44.7 171 S 9 44.7 171 S 9 ~GE lC M.'&RATHON OiL CO. MCARTHUR RTVER K ~L~SKA DEPTH WL *'*FORMATION DIP** ANG AZ BSARING GRADE 3632,0 8,00 ~6 36,0 3638,0 3640,0 8,00 3642.0 8.00 3646.0 8.00 3648.0 3650,0 8.0C 3652,0 8,00 3~54.0 8.00 3656.0 8.00 3658.0 8.00 3660.0 8.00 3662,0 8.00 3670.0 8.00 '3672.0 3676.0 8.00 3678.0 &.OC 3680,0 8.06 3682,0 8,00: 36:~4,0 8.,00 3586,0 8,00 3688,0 8.00 3694.0 8.00 ¢'~/"~ 7 ,.., ,,.; 0 8 · .. ,, "-~ ~ ~702.0 8.0,3 3?04,0 8, OC 3706.0 8.00 3708.0 8. CC 3710,0 371 2 · 0 37!4.0 8.00 3716.0 8.00 3718.0 8.00 3722.0 8.00 3724.0 8. OC 3726.0 8.0C 3728 0 8 I 3730,0 8.00 3732,3 8,00 7.3 204 S 24 ~: 10,¢ 7.5 117 S 83 E 67 12.6 142 S 3~ ~. 100 15 ? 4~ N 17.6 3~; N 38 E 15 3 7 N 7 E 1~ 3 I~ .. 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STEELHEAD M-2 MCaRTHUR RIVER KENAI 08124187 .aLASKA DEPTH ~L **FORMATION Di~** ~NG AZ 8EA~iNG.. ~.*RAB~ Ca SAZ eEa~ING 3734.0 8,00 3736.0 8.00 5738,0 8,00 374C,0 8,00 3742,0 8,00 3744,0 8,OC 3746,0 374~ 0 8, 3752, 0 8 3754,0 8.0C 3756,0 8 3758.0 8,00 37~C.0 8.0C 3762,0 8,00 3764,0 8,00 37~6.0 8,0C 3768,0 8,00 3776,0 8,00 3772,0 8,0C 3774.0 8.00 3776.0 8,00 3778,0 8.00 ~, . 5780,0 3782.0 8,00 3784,0 3788.0 8,0C 3790,0 8,0C 3792.0 8,00 3794,0 37?6.0 3800,0 8,0C 3802,0 8,0C 3804,0 8,00 3806,0 5808,0 8,00 38!0,0 8,00 3814.0 3816,0 8.00 3818,0 8,00 3826.0 8.0C 8,5 110 S 70 E t00 7,2 106 S 74 E 100 (:.6 110 S 78 E 100 5.2 1t5 $ 8~ E 7~. d.4 118 S d2 _= 109 2.7 112 S ~.S E 1CC t,7 82 N 82 E 100 3C.6 6a 1C.6 150 S 24 E 67 ~.9 106 S 74 E 100 1~.8 79 N 79 E 65 1~.7 292 N 14,b 29~ N 66 W 57 7,0 245 S 65 W 100 ~.4 237 S 57 ~.6 222 S 42 ~ 100 8,0 230 0,5 1~= ~ 47 ~ 100 8,2 129 S 5t E 88 4,9 t75 S 5 E 100 0.8 22~ .S 44 '~ 1CO 1,4 174 S 6 E 100 29,3 268 S 88 W 1CO 10.6 236 S 5~. W 16.9 24~ S (6 ~ 100 ~.0 111 S 69 E 100 5 4 109 S 71 E 7.3 97 S 19.3 86 N 86 E 105 14.5 100 S 8C E 100 d.5 110 S 70 E 100 8.0 98 S ~ = 100 6.7 102 S 78 E tC9 8,9 238 S 5 11.7 241 S ~1 N 73 ~.~ ~30 S 50 W 100 11.8 265 S 5.6 153 S 27 E 2.3 4.8 157 S 13 E 7.8 177 S 44,& 170 S 1C E 44 ~, 170 S 10 ~ 44,7 170 S 1.3 F. 44,~ 170 S 1"',.,=,_ 44.6 170 S 10 5 44,6 171 S g E 44.6 17C S 1C E 44,6 170 S 10 =_ 44.6 17'3 S 10 E 44,5 170 S 10 l 44,5 170 $ 1C E 44.5 171 $ 9 E 44.5 171 $ o E 44.5 I 71 S 9 E 44,5 171 S 9 ~ ~4,5 !71 5 ~ E ~4,5 171 3 9 E ~4,4 171 S ';' 5 ~4, ~ 1 71 S 9 E ~4,4 171 S 9 E 44.4 171 S 9 = ~4,4 171 S 9 E 44.4 171 S ~ ~ 44.4 171 S ~ E ~4.4 1 71 S 9 = 44.~,~ 170 S 10 ~ 44.6 171 S 9 E 44.6 17t S ~ E ~4.5 171 S 9 E 44,5 171 S 9 ~ 44,5 171 S 9 E 44.5 1'7~ ~ 1'~ ~ ~ ~ 170 S 1C E ~4,4 171 S ~ E 44,4 171 S 9 E 44.3 170 S 10 ~ 44.2 1 71 S ~ E 44.2 171 S 9 E 44.3 171 S ~ E 44. I 171 S ~ E P .aSE a I M4RATHON CIL CO. STEELHEAD M-2 MCARTHUR RIVER RENAi 08124187 ALASKA DEPTH WL **FOR!~TION DIP** ~NG AZ BEARING GR.&OE DA C~Z ~EARZNG 3830.0 3834,0 3836,0 3838,0 3842.0 3844,0 3846,0 3848.0 3852,0 3854.0 385~,.0 3858,0 3S62,0 3864,0 3866,0 3870.0 3872.0 3874,0 3880,0 3884,0 3888..0 3890.0 3'~94,~ · 0 3.S96.0 3898.0 3902,0 3904.0 3~. 06,0 3908.0 3910,0 3912.0 3914.0 3E16.0 3918.0 3920.0 3922.0 3924.0 392~,0 3928,0 8.CC 8,..00 8.00 8. CC 8,0C 8,OC 8.00 8.00 8.00 8.00 8.00 8,0C 8.0C: 8.00 8.uC 8.06;, 8.00 8.06 8 , 0C 8,0C 8.00 8.00 8,00 8.0r 8 · 0 C 8;. OC 8.0C 8,0C 8.00 8.00 8,0C 8.00 8.00 1~ ~ 105 S 15,1 16S S !5 E 42 27.0 274 N 85 30, 4 265, S ~: W ~7 ~ 1 266 S S6 W 1~ 9.2 26-3 S 83 ~ 100 16.2 260 S 80 w 100 14.2 259 S 79 W !00 lC.8 7 N ? 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STEELHEAD M-2 ~CARTHUR RIVER KENAI 08t24t$? ALASKA OEPTH WL **=ORF!AT!ON DIP** ANG AZ 8=.&RZNG GRADE ****~CRmHCL¢*****~ .. . CAZ eE&RiNG 3930,0 3934,0 3938,0 3940,0 3944.0 3946,0 3948.0 395C.0 3952.0 3954.0 3956,0 3958,0 3960.0 3970.0 3972,0 3974,0 3976,0 3978,0 3980.0 39~2,0 39~4,0 3988.0 3990.0 3994.0 3996,0 3998.0 ~000.0 4002.0 4004.0 4006.0 4012.0 ~014.0 4016.0 4018.0 4024,0 4026.0 4028.0 ~032.0 ~03~.0 · 8 · OC 8.00 8.00 8.0C $.00 8. OC 8.00 8.00 8.00 8.0C 8.00 ,8.0¢,, 8,06 8.00 8.0.,3 8.00 8.0C 8.CC 8.00 8,00 8.00 8.00 8.0C ~.OC 8.CC 8,0C 8,00 8.CC 8.00 8,00 8,00 8.0C 8.00 8,0C 17.1 320 N 40 W 13.9 91 S 89 E 8.3 5.1 3/+ N 34 E 1~ 11.8 131 S 49 E 57 12.~+ 267 S ~7 W 90 17.6 285 N 75 ~ ~2 18.1 286 N 74 ~i 61 ~.5 297 N 63 W 100 4.4 225 S 45 W 100 a. ! 246 S 66 W 1 11.7 282 N 78 ~ 29 t5,5 93 S 87 E 56 18,2 129 .S 51 18:.2 40 N 40 E 4~, 20.4 309 N 51 W I 11.7 231 S 51 W 100 ~.1 232 S 52 W 100 5.0 1t6 S 64 E 100 4.6 52 N 52 E !5 9.2 115 S ~5 E 50 10 2 10~ S 7~ E I 8. 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S 65 t4.0 244 S 84 W 64 24.1 24.~ S 66 11.1 240 S ~C N t~¢ '~'~ 5 170 S 1 ~3.3 170 S 10 ~,~.~_, 170 S 10 4'~ ~ 170 ~ 10 F-. ~ 3 170 S 1 4~ ~ 170 43.2 170 S 10 43.2 170 S 10 E 4=,2_, 170 S _,.~ 170 S 43.2 173 S 10 E 43.2 171 43.1 1~1 S ~ E ~,.u 171 S 9 E ~3.0 171 S 42.9 171 4Z.9 171 ~ ¢ E 42.9 171 S ~ E 42.~ 171 S 43.¢ 171 ~2 · 9 1 71 4Z.9 170 S 10 E 47.~ 170 S 10 E 4~.~ 171 ~2.9 171 42.9 1Y1 S 9 E 4Z.¢ 171 S ~2.'~ I 71 S 9 E 4= n 171 4~~. 0 t71 S ;~ I 171 S 9 43.1 171 S 9 E 43.1 171 S 9 4~ 1 171 S 0 z 4~ 1 !~1 S 43.1 171 S ~ E 43.1 170 S 10 4~ C 170 S 1 ~2.9 170 S 13 MARATHON STEELME~D MCARTHUR KENAI 38/24/87 OIL CO, ~-2 RIVER ALASKA DEPTH WL **FORMaTiON DIP'** SNG aZ BEARING GRAOE OA 2~Z E=~RING 4O 4O 4O 4O 4O 4O 4O 40 4O 4O 4O 4O 40 4O 4O 4O 4O 4O 4O 4O 4O 4O 40 4O 4O 41 41 41 41 41 41 41 41 41 41 41 41 41 41 36.0 38.0 40.0 42.0 44.0 50.0 52.0 54.0 50,0 58,0 62.0 64,0 66.0 72.0 74.0 76,0 ?8.0 82.0 84.,0 86.0 88,0 90,0 92,0 94.0 96,0 CO.O 02.0 04.0 06.0 8.0 !0,0 12,~ 14.0 16.0 18.0 20.0 22.0 24,0 26.0 8'OCr 8'00 8'0C 8'00 8'00 8'00 8'00 8'00 8.00 8.0C 8.00 8.0C 8.00 8.00 8.00 8,00 8.00 8.00 8.00 8,0C 8.0C 8.0C 8.00 8.0C 8.00 8.00 8 · 0 'C 8.00 8,00 8,0C 8.00 8,00 8, OC 8,00 8.0C 8.00 I ~· 6 I 23 S .~7 ~'. 85. 10,8 120 -S 60 9.0 247 $ 67 W 100 4.7 212 S 32 w 100 8.3 2.47 S 6,7 w 7;5 8,3 1:59 S 21 5.9 145 S 35 E 100 4,4 150 S 3C E 1C0 4,2 153 S 27 E 100 5,1 298 N OZ W 35 1~,1 302 N 58 W 9C 8 9 250 ., 5.6 ~6 N 46 E 100 ~ 6 338 N 22 W 100 2t,0 316 N 44 W 100 19,1 322 N 3,4 345 N 15 W 73 13,0 128 S 5Z E 53 7,~ 213 S ~3 W 100 6,6 I 76 S ~ E 100 1~.0 250 S 19,7 262 S 19,4 252 S 72 W 100 2t,0 120 S CO E 59 22,3 1t8 S ~2 E ~7 ~,m 1tl S 69 E 51 12.5 92 S E8 E 10C 1C.7 128 S 52 E 1C0 1~.0 Z56 S 76 W lOC 1 ~ 8 ~61 S 21 w Imm 19.0 239 S 59 ~,~ 100 20.8 62 N ~2 ~ 94 24.~ 57 N 57 22.6 57 N 57 E 102, 2C.0 57 N 57 E 100 25,0. 25:S S 8.0 192 S 12 N 69 8.4 203 S 23 e,4 205 S 25 W 1-30 19,3 230 S 50 w' 73 4P $ 170 S 1;'" 42,8 173 S 10 42, .~ t 70 S 1 4P, .~ 1 7'~ S 1 42.~ 170 S 10 ~2,6 170 S 42.6 17'0 S I~:. 42.6 170 S 13 ~ S 1~ F_ 42.~ 17.., 4~,5 170 S 42,5 170 42.~ 170 42,4 169 S 11 ~2,4 169 S 11 42,4 169 S 11 C2,C 1~9 S 11 42,3 169 42 ~ 16~ S 11 42.3 170 42.3 170 S 42.3 170 42.3 17~ S 10 4i.3 170 S 10 42.3 17C S 42,2 17C S 42,2 !70 S 10 ~2.2 170 42.2 170 S 42,2 17C S 42,2 170 S 42.2 1~1 S 9 ~2.2 170 ~2 ~ 1~n 42.2 171 S 42,2 171 S 9 42 · 2 1 71 S 9 42.2 171 42.2 171 S 9 42.2 171 42,2 171 S MARATHON OIL CO. .STEELHEAD MC&RTHUR RIVER KENAZ 08/24/87 ALASKA DEPTH WL **FORMATION DIP** 4t 28,O 8,0C 4130.0 4132,0 8.00 4135,0 8,0'3 4.138,0 8.0C 4140.0 8,00 4144,0 8,00 41 46 ~ 8 4148.0 8,06 41 52.0 8, 4154.0 8,00 41~8,0 8.00 4164.0 8,00 4168,0 8.00 4170,0 8,00 4172,0 8.00 4t74.0 8.00 4175,0 8,00 4178,0 8.00 4180,0 8,0C 4182,0 8,00 ~184.0 4186,0 8,00 4188,0 8.00 4190,0 41 ~2 ¢' , ,u 8.00 4194,0 8,00 4196.0 8.00 41'~8,0 8,0C 4200,0 8.00 4202,0 8,0C 4204,0 4208,0 4208.0 8.00 4210,0 8.00 4214,0 4216.0 8,00 42t8,0 ~.,0C 14.3 219 S 39 7.:~ 20:9 .S 29 W '76 6.,=~ 317 N 4] W 9,3 19.6 258 S 78 W lu~ 22.4 262 S 82 w 91 11.3 357 N 3 W 100 13,0 120 S 12.3 147 S ~3 E 3~ 16.7 228 .S 14.6 278 N aZ W 76 20.1 76 N 78 E 10C 1 t 3 ,84 N 20.2 7~ N 75 E 100 I~ 4 76 N 7a ¢ 10~ 11.7 62 N ~2 E 100 9.5 60 N 60 E 72 25,8 2~3 S 83 w 14,1 283 N 77 W 53 1C.4 315 N ~=,, W 100 10,7 3t5 N 45 W 89 11.0 319 N 41 W 72 2~.4 275 N 85 W 79 17,3 306 N 54 W 97 12,4 28 N 28 ~ 74 9,$- I~' N 1 14,5 274 N E6 W 73 25.4 28~ N 74 W 4.6 306 N 54 W 12,0 105 S 75 E Ir 8 111 S 8,1 177 S 3 E 63 lC.0 Z04 S 24 w 32 ~, 3 229 S 4~ ~ 97 12.5 13~ S 44 5 42 4 7 12~ 10,5 31 N 31 E 10:3 10,1 20 N 20 1C,4 14 N t4 E 100 2t 6 ~ N 75 13,8 241 S 51 ~ 100 42.3 171 z~2. ;' 171 S /+2,3 170 $ 10 E 4.2,2 !71 S 9 42,2 171 S ¢ E 4.2.3 171 S 9 z, 2,3 171 S 9 /,2.3 171 S ~ E z~2.3 171 S '~2.$ 171 S z, 2.3 171 S ~ E 42,4. I 71 S 4.2,3 171 S 42.4. 171 S /+ 2, z, 171 S 9 4.2, ~+ 171 S 9 4.2.4 171 S 9 E 42.4 171 S ~ E ~42,4. 171 S 9 42,,4 171 S 9 42.4 171 S 42.; 171 S 42.4 171 S 42.4 171 S 42.4 171 S .~ E 42.4 171 S 4.2,3 171 S 9 42.3 172 S 42.3 172 S z, 2.3 172 S 4.2,3 t 72 S 42.3 172 $ 42,2 17Z S 3 42.2 172 4.2.2 172 S 42,2 172 S 3 42.2 172 S 42.2 172 S z, 2.~_ 172 S S -4-2,2 172 S .~. E MARATHON OIL STEELHEA~ M-2 N!CARTHUR RIVER K~NAi 08/24/87 ~.LAS~A DEPTM WL **FORMATION DiD** ~NG AZ 5=ARING GR.&DE OA CAZ BEARING 422C,0 8.00 4222,0 8,0C 4224,0 8,0C 4226,0 8,0C 4250.0 4232.0 4234.0 8,0C 4236,0 8,0C 4238.0 8.00 4240.0 8,0C 4242.0 4244,0 8,00 ~250,0 8.0C 4252,0 4254,0 8,00 4256.0 8,00 4258.0 8,00 4258,5 8.00 42.60,0 8,00 4260.5 8.00 ~262,0 8.0C 4266.5 8,06 4268.5 8,0C 4270.5 8.0C 4272.0 8.00 4272.5 8 4274.5 8,0C 4278,0 4280,0 8.00 4282,0 4284.0 8,0C 4284 5 428~.0 8,06 4288.5 4290,5 8.00 4292.5 8.30 4294,5. 8.00 4296.5 8,00 4298,5 8,00 4300.5 8,00 19.5 246 S 66 W 100 1¢: z, 264 ~ ~4 W 100 9 2 32 N ~2 ~' lOC. 5.4 26 N 26 E 100 16.0 !~2 S 78 E 51 14.6 1C, 6 S 74 ~ 53 3.6 19~ S 19 w !00 27.4 26,5 S 85 W 1C.~ 2~.2 278 N 82 W 100 2~.1 301 N 59 ~2 5 3~ N _ . v5 55 w 10,~ 1 4,4 337 N 15.~ 212 S 32 21 5 P14 S =4 W ~7 7. 2 146. S ~=4 ¢ 72 1~.0 310 N 50 W 100 1i. 2 324 N 2~.6 ~13 N 47 W I~'~ I 3.8 299 N 61 11.4 306 N 54 W 100 23.3 252 S 72 W 12.2 2~5 7,0 178 S 2 ~ 65 5. ~ 250 S 70 2C.9 305 N 55 W 32 3.4 280 N t0.1 271 N ~9 W 63 11.4 256 S 76 W 66 t6.6 25~ S 76 W 100 17.0 273 N 87 26. 6 66 N., 66 4.3 131 S 4~ E lOC 15.9 22 N 22 E 70 I 7 346 N 14 N 10¢' 3 · 8 277 N 6.9 263 .S 83 1~.4 257 S 77 N 100 3.8 240 S 60 I 5.7 262 S I 2 ~ P50 S 7 ..... ~ ~ 74 ,~2.1 173 S 7 42.1 173 S 7 42:. 0 I 73 S 7 42.0 173 S 7 E 42. C 1 73 S 7 42.0 I 73 S 7 E 41.9 174 S 6 41 ~ 1 75 S 7 41.7 1 73 S 7 41.9' 173 S 7 41.6 173 S 7 41 · 6 I 73 S 7 4!.4 172 S 41.3 I 72 S 41.4 173 S 7 41.4 173 S 7 E 41.4 17~ S 8 E 4t.3 173 S 7 4t. 4 I 7~ S 4!.$ 173 S 7 E 41.3 172 S 41.2 171 S 9 41.2 171 S 4!.2 171 S 41.1 170 S 10 4 ,~ · ~ 1 73 S 7 E 41.2 172 S 3 E 41.1 169 S 11 41.1 169 S tl 41.1 168 S 12 E 41 I 1.~ S 12 41.P 172 40.9 168 S 12 41.1 172 S 41.2 I 72 S ~ E 4t.2 172 S 8 E 41.2 172 S 4!.2 171 S 9 4! ~ 171 S 9 4!.c 171 S P~.GE 2¢· ~ARATHON OIL CO. STEELHEA~ M-2 MCARTHUR RIVER KENAi 03124187 DEPTH WL **FORMATZON O!P*~ ~NG AZ :BEARING ****~CREHCLE***** CA CAZ ~EARING 4302.5 4304.5 8.00 4306.5 8.0C: 4308.5 8.00 431,~,. ~' 5 8.. 4312.5 8.00 4314.~ 8.0C 4316.5 4318.5 8.0C 4320.5 8.0C 43Z4.5 8.00 432~.5 8.00 4328.5 8.00 4334.5 4336.5 810C 4338,5 8.0C ~340.5 8.00 4346.5 8..0C · ~2 5 8.0C 4354.5 8.00 4356.5 8.0C 4358.5 8.0'"~-, 4362.5 8.00 4364.5 8.0C 436.6.5 8. OC 4370.5 8.00 4372.5 8.00 4374.5 8.00 4376.5 8.0C 4378,5 4380.5 8.00 4382.5 8.00 4354.5 8.06 4386 5 8 4388.5 8.0C 4390.5 8.00 43,92.5 8.00 4394,5 .~,. 4396.5 8.00 439'8.5 8.0C 22..0 67 N 67 E 100 15.3 9~6 $ 82 E 100 6.8 175 S 5 E 65 6 ~ 128 ~, ~ E 130 7.5 106 S 74 E 7.~ 106 S 74 8 !00 4.8 147 S ~3 ~ 6.2 ~x S 84 = 1**' 12.4 119 S dl E 4.7 151 S 29 E 75 4,5 182 S 2 w 82 2.7 225 S 45 W 1C0 12 5 225 S 45 W 13.1 14 N 14 E t0C 8,5 1 2 N I 2 E ~ 1 11.1 27 N 27 E 34 1~.8 1~' S ~7 - 6 ~., 16 6 120 ~ e~ = 10~, ~.7 3'] N ~O E 10n 22.6 49 N 49 E 50 16.7 107 S 73 E 15.2 72 N 72 E 48 ~.9~ 125 ~ ~.~5 E 14.6 161 S 19 E 100 12.3 1~2 S 18 E 1GO 13.5 142 S 38 E 1,~ 13.3 143 S $7 E 73 7.3 137 S 43 E 100 7.5 132 S 4~:,~ =. 100 4.2 16~,~ ~ 12 _: 1C, 0 1~ 3 ~7 S 83 = 9~ 17.4 98 S e2 E 1~ 14.5 103 S 77 E 12.4 42 N 42 e 1C0 11.0 25 N. ,~ E 1Cn I~~. 0 C N 0 :E 100 $.7 20 N 2'~ =_ t~0 1~.~ 224 N 7~.~, ~ 10~: 13.9 284 N 76 ~ lOC 41.8 171 S 4!.7 171 S 9 E 41. ~ I 71 42. C t 72 S 8 E 42.3 1 72 S /.2.5 172 S 42.5 172 S 8 E ~2.7 172 S 8 E 42.~ 173 S ~ E 4~.u 175 S 7 E 43.1 174 S 6 4~ 0 174 S 6 43.0 174 S ~ E 47.~ 173 S 7 E ¢2.~ 173 S 7 42 ~ 17~ S 7 42.:~ 173 S 7 42.4 I 73 S 7 42.~ 172 S 42.2 17~ S 42.-~ 173 S 7 42.t 172 S S E 42.1 173 S 7 42.1 1 73 S 42.1 !72 S 4~. ,S 1 72 S 42.0 172 S 42.3 172 S 42 r~ 172 42. P ,~ 1~2 S 8 42.0 1 72 S ~1 ~ I 7P S Cl, c 1 72 S ~t. 9 172 S 4t ~ 1 ~2 S ~2' ~ 172 ~1.~ 172 S 41.~' 172 S 42.,3 173 S 7 MaRfiT~-ON OIL CO, ST~-ELHEAD M-2 MCARTHUR RIVER KENAI C8t24/87 ALAS ~'=mTH WL **FORMATION O!P** ~NG AZ BE.&R lNG GR~DE ****BCREHCL~***** gA [AZ ~EARiNG 4400.5 4402.5 4404.5 ~406.5 4~08.5 4412.5 44!4.5 4416,5 4420,5 ~422.5 4426,5 4~25.5 4430.5 4~44.5 4446.5 4448.5 4450.5 4456.5 4458.5 4460.5 4462.5 4464. 4468.5 44?0°5 4472.5 4474.5 4476.5 4478.5 4482.5 4484.5 4486, 4490.5 4492.5 4494.5 4498.5 4502.5 8,00 8.,00 8,00 8,0C 8,60 8,00 8,0C 8,0C 8. OC 8,0 C 8,00 8,00 8.00 8,00 8.00 8.00 8,00 8.00 8.00 8.00 8.0C 8,00 8 · nC I 8.0C 3.OF] 5.0 C 8.04 8,0C: 8.00 8.0C 8.00 8.06 8 · C C 8.06 8,00 8.,~0,,.., E.6 144 S 36 E 10,0 16,4 143 S 37 E 97 ~: 4 ~ N 2~ ~: 100 6,3 $5 N $5 E 100 7.5 355 N 5 W t00 Pi 0 2~2 N 7m W 17 22,7 297 ~.; a3 w 45 c.5 233 S 5~ N 47 17,2 242 S 62 W 1S,2 233 S 5S W 58 4,9 200 S 20 14,8 247 S 67 W 100 15,9 249 S ~9 W 100 ~.5~ 2~t. S 7.1 225 S 2.0 255 I~ 0 17a S 4 ~ 1~ ~,.2 163 9.9 1 ~4 S Z6 ~ 93 14,9 !5 N 15 E 100 11,7 359 N 1 W 100 t7,6 337 N 23 W 95 21,4 1 N I E 100 22.3 4 N 4 ?.3 338 N 22 W 100 ~.9 1=2 S 12 7 149 ~ =t ~ 10'* 11.6 142 S 38 .5 1C0 13,3 98 .S 82 E 79 14,6 140 S 40 E 30 7.7 10r, S ~ E 10~ 14,1 230 S 5~: W 52 12,6 242 S d2 W 105 7 3 21t S I C, 7 250 $ 70 W 9.4 73 N 7 8.9 75 N 7S E 92 1~.2 315 N 45 W t 2~_,.4 330, N ~,S W 99 24.6 ~'3 N a3 E 4$,u~ 172 S 41 · ¢ 1 72 S S :_= 41 , '9 172 S 8 41,9 173 S 7 42.0 173 S 7 _ 41.9 173 S 7 4 t · 9 1 73 S 7 41. :5 1 73 S 7 E 41.7 I 72 4!,7 172 S 41,5 17~ S 10 41.6 170 S 1C 41.6 170 S 10 4t,? 17C S !0 E 41.6 170 S 10 41,6 170 .S 10 E 41.7 17'3 S 41,7 169 S 11 E 41.7 170 S 10 E ~1,? 170 S 1 41.-¢:~ 170 S 10 _ 41,8 169 S 11 E 41.9 169 S 11 41.$ 159 S 11 E 41.8 109' S 11 41 .9 169 S I 1 E 41,0 leg S 11 41.9 lo9 S 1! 41.9 169 S 11 E 41.:~ 16g S 1! E 41,8 16~ S 11 ~1.8 16g S !1 41.7 1~9 S 11 4!.7 169 S 11 E 4!,7 16'~ S 11 41~ ,6 IC9 S 11 41,6 169 S 11 E 41,6 159 S 11 E 41.~ 169 S 11 41,4 169 S 11 PAGE MARATHON OIL CO. 3TEELHEAC M-2 MC~RTHUR RIVER KENAI 0~/24/87 DEPTH WL **=OR'M.~TiON DIP** ~NG AZ~,~A~iNGc ~ ***~OREHCLE***** DA ~AZ BEARING, 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 ~5 45 45 45 45 06.5 n8 5 16,5 18.5 20,5 22.5 24.5 26.5 ~~-8.5 34.5 36,5 40.5 44.5 48.5 54.5 60.5 62.5 ~4 ,C 64.5 56.0 66.5 68.0 ~8.5 7C.0 72 ,O ?2,5 74.0 74.5 76.5 78,0 78.5 80.5 82.0 82,5 84.0 84.5 ~ O0 8,0C 8.0C 8,0C 8.0C 8,00 8,00 8,00 8.00 8 . ~'"~ ~"~ 8,00 8,00 8.00 8.0C 8.00 8,00 .8. OC 8.0¢ 8.0C 8.00 ~ uC 8,0C 8.~0.~ 8,0C 8,00 8.00 8,OC 8. OC 8,00 8.00 8,00 8.00 c,~ "' !1.6 91 S 89 5 100 9.'~,.. 94 S 86 ~= 100 13.7 109 S 71 E t00 6,8 101 S 4.5 175 S 5 E 100 ~ 9 178 S ~ ; 9;:', 1~ 4 Z~ ~. ~7 ~ 27 w 100 16.6 239 S 59 W 100 7,9 331 N 29 W ~3 12.1 8 N ~ ~ 10'~ 12,3 7 N 7 4.1 27 N 27 E 97 8,0 340 N 20 W 73 9,4 53 N ~==¢ E 100 6,4 350 N 10 W 100 9.6 354 N 6 ~,~ 94 1C.5 349 N 11 W 59 19,9 69 N 17.0 8.3 N 83 E 64 16,2 72 N 72 7.1 135 S 45 E 100 6 4 150 S 3 ~,9 1.39 S 4! E 100 ~,8 135 S 45 ~ 100 5,7 152 S 28 E !00 5,9 125 S 55 E 100 4. 3 177 S ~ == 100 14,5 214 S 34 W 70 11,5 215 S 3~ W 1C0 3,3 16 N 16 E 100 4,4 27 N 27 ~ 100 11,5 33 N 33 E 10C ~ I 35 N t2,6 39 N 39 E 77 12.8 214 S ]4 W 9~ 1~,2~ ~16. S .~6. ~ 100 1~ 4 218 14.5 222 S 42 ~ 9'9 21,~ 254. S 74 25.5 253 S 73 ~ 1CC 41,4 169 :S 11 E 41.3 170 S 10 41,3 170 S 10 41,3 170 S 18 E 41.3 170 S 10 E 41,2 170 S 10 E 41.2 170 S 1.0 E 41.2 170 S 10 41.;' 17C S 10 41.1 170 S 1',~ _ 41.1 1~9 S 11 al .C 169 S 11 ~!.0 1~8 41.C' 168 .u I~, S 12 ~C,~ 168 S 1 2 40.¢ 1~8 40.~ 1~9 S 11 4C,9 169 4C,8 159 40,9 1¢9 40.9 16o 40,9 169 S 11 ~0,9 169 S 1 1 E 4~. 9 1-~9 S 1 1 40.9 169 S 11 40,9 169 S 11 E 41,0 169 S 11 ~0,9 169 S 11 ~1,0 1~9 S 11 41,0 !69 S 11 ~1.0 169 S 11 41.0 169 S 11 ¢1.0 169 S 11 4!.0 170 S lC ~I. 0 t 70 S 1 C 41.t 17~ S 1 41,0 170 S !0 ~t.0 1~9 S 11 41,0 169 S 1! ~GE 2~ MARATHON OIL CO. STEELHE~D M-2 MC~RTHUR RIVER KENAZ C$/24187 ALASKA OEPTH WL **~ORMATION DIP** SNG AZ EEARING GRAOE ****BCREHCLE***** BA £.A~ ~_:=&RING 4586.0 8.go 4588.0 8.00 4590.0 c590.5 4592.0 4592,5 8.0C 4594 .C 8.00 4594.5 8,00 4596,5 4598.0 4598.5 8.00 4600.0 8. OC 4604,0 8.00 4606.0 8,00 4608.0 8.0C 4610.0 8.00 A,.A12 0 8 0" 4614.0 8.0C 4616.0 8.00 4618.0 8.00 4620 · 0 8 · 4622.0 8.00 4624,0 8.00 4626.0 8.00 4628.0 4632.0 8,00 4534.0 8 · 0O 46~6 0 $ O0 4638.0 ,8.00 4.. 640.0. . 8. "'C,..., 46'~2.0 8.00 46&4 · .~, 8.00 4646.0 8.0C 4648,0 8 4650.0 8.00 ~652.0 4654.0 8.0C 4656.0 8.00 4666.0 4668.0 24.~_ 236 ..¢. 5x~. W 100 13,4 224 S 44 W 55 13.5 22'~ S 46 W 72 6.0 231 S 51 ~ 100 5.8 334. 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STEELHEAD ~-2 ~rARTHUR RZi!V~R KENAi 08124/87 ~L~SKA DEPTH WL **FORMATZON m' ~NG AZ BEARING GRADE ****5C, REHCL E ,.~A CAZ 4.670.0 4672.0 4.674.0 4.676.0 4.678.0 4680.0 4.682.0 4684.0 468.6 · 4688.0 4690.0 4694.0 469 ~,, 4702.0 4704.0 4706.0 4708.0 4710.0 4712.0 4714.0 4716.0 4720.0 4722.0 4726.0 4730.0 4732 .G 4734,0 4736 4738.0 474~.0 4742.0 4744.0 4746.0 4748, 4750.0 475~ .0 4754.0 4756.0 4758.0 476C,0 8,00 8.0C 8,00 8,0C 8.0C 8,00 8,0C 8.0C 8,CC 8.00 8,0C 8.00 8 8.06 8,0C 8,00 8.00 8,0C 8,00 8.0C 8.0C 8,06 8,0C 8,00 8.0C 8.0C 8,00 8,00 8.00 :~ OC 8,0C. 8.00 8.00 8 8.0C: 8.02 12.3 195 S t5 W 100 2.3 258 S 78 24,7 5 N 5 E 100 13.9 32~ N 36 w 1'00 13 4 2¢ . ,~,3 N 77 W 1CC ?,4 292 N 68 w 180 7,1 285 N 75 ~ 100 t0,8 1 86 S 6 ~ 100 11,2 t85 S 5 W 100 ~.4 2i8 S 48 ~ 100 5.~,~ 233 S 5~ w 100 3.3 21t $ 31 ~ 100 12,7 175 S 5 E 100 4.6 137 S 43 5 100 18.3 350 3.9 358 N 2 C.9 12 N 12 E 100 1C.6 344 N 16 W tC~ 6.8 21 N 9.5 17 N 17 E 100 11.4 244 S ~4 W 100 9.0 249 S 69 ~' ~¢1 1C.1 253 9.4 170 S 1G ~.3 127 ~ 53 ~ 100 3.1 125 S 55 E 100 14.5 356 N 4 ~ 100 ?.6 '* ~ = 100 11.9 45 25.9 48 N 48 E ~8.6 3~ N 39 E 87 17.9 78 N 7~ 4.1 55 N 55 ~ 75 7,8 74 N 74 E 100 1C.O 140 8.t 134 S 46 E 95 1C.9 108 ....q 7P '= I~'uu 11.2 'gP S E8 E 67 13.~. 113 S 6 11.~~ 101 39.~ 39.7 39.7 39,7 39,7 3~.7 3~ .7 39.5 39.6 39.6 39.6 3~ .6 39.~6 3~,5 3~.5 39.4 3.c,. 5 39.5 39.5 39.5 3c.5 3~.5 39.5 39,~ 39.5 39.5 39,4 39.4 39.4 39,4 39,4 39,4 39.5 39.4 39.~ 39.1 3~ .1 34,1 39 .Z 39.2 17C S 10 E 170 S 1C 169 S 11 E I 6 ~. S I 1 159 .S 11 170 1'39 S 11 169 S 11 E 159 S 11 E 170 S 12~ E 170 S 1C 170 S 13 E 170 S 13 E 170 S 10 E 170 S 17C S 170 S 10 E 17~ S 10 170 170 S 1C E 170 170 170 171 171 S 171 S 9 E 171 S 171 S 171 171 S 9 E 171 17Z 173 S 7 172 17Z S 8 E 173 173 173 S 7 173 S 7 173 S 7 MARATHON STEELHSAD MCARTMUR KENAI C8/24t87 O,rL ,-,, .,~ ',., ~ . R?VER ALASKA DEPTH WL **FORMATION DIP** ANG AZ BEARING GRADE OA C,~Z ~EA~ING 4762.~u 4766.0 4768.0 4770 · O 4772.0 4776.0 4778.0 4780.0 4782,0 4784.0 4786.0 4790.0 4792.0 4796,0 4802 .O 4804.0 4806.0 4808.0 4810.0 4812,0 48t4.0 4816.0 4818.0 4822.0 4826.0 4828.0 4850.0 4832.0 4834.0 4842.0 4544.0 4846.0 4848,-~ 4850.0 4852.0 4858.0 8.CC 8.0C 8.0C 8.0C 8.0C 8.0C 8.00 8.06 8.00 :,,,~,,~ 8.00 8.00 8.00 8.CC 8.GO * OC 8.0C 8.00 8.00 8.00 8.00 8,00 8.0C 8.00 8.00 8.00 8.0C 8.00 8.00 8.00 8.00 8.00 8.00 8.00 8.00 t0.3 9~ S 85 ~ 34 8.6 95 S 85 E 1,3,3 8.6 274 N a6 W !03 11.4 252 S 82 W 9:3 11,6 263 S ~3 W 69 22,7 293 N ~7 7,9 161 S 19 E 1CC' ~,9 17~ S 10 E 100 9,5 213 $ 33 W 72 19,8 321 N 39 W 92 23,0 272 N ~8 W ~3 21,5 277 N ~3 31,9 265 S 27,9 291 N 69 W t~ 3,9 3~2 N 58 W 100 3.6 226 S 46 W 5,3 245 $ 55 W 100 17,2 248 S a8 N 55 10,0 191 S 11 W 100 10.0 191 S 11 W 100 9,9 172 S 8. E t00 7,9 188 S ~ N 1~0 7,8 201 S 21 w 10~ 14,7 2159 $ 79 W 100 5.9 264 S 84 W 100 13.3 312 N 48 W 100 t3,3 311 N 49 W 100 2.8 303 N 57 4,9 294 N ~6 W 100 ~ 6 267 $ 87 W 10~ c~,.6 t94 S 14 W 4.7 219 S 1~.5 286 N 74 W 1,30 1].5 204 S ~4 N 100 5.7 242 S 62 W 100 13~.5 283 N 77 w 100 4.5 266 S 88 W 100 ~2.2 312 N 48 22.3 354 N 5 W 100 20.7 t35 S 45 E 63 39,1 174 S 6 E 39,1 174 S 6 39.1 t75 S 5 E 39,1 175 $ 5 39,0 175 S 5 39,C 175 $ 5 E 38,9 1 75 S 5 ~.~ 9 175 3~ ~ 1~5 S 5 38.8 175 S 3 a , 3 I 75 S 5 3~,7 174 S 3E.6 174 S 6 38.3 174 S 6 37,~-e~ 174 S ~.x ~_ 37.7 174 S 6 37.6 175 S 5 ~7.=~ 175 S ~ : 37,4 1 74 S 37,3 174 S 37,1 174 S 6 35,9 174 S 6 36,~ 17~ S 6 36.7 174 S 33 = 17~ S 5 3e,~ 174 S 6 E 36.2 1 74 S 3d.t 175 36.1 174 S 6 3~.9 174 35 , ~:7 174 S 6 E 35.5 175 S 5 E 35,5 174 S 6 E 35,4 17~ S 35,3 175 S 5 35.2 175 S 5 E 35,2 174 S 6 35,2 174 S 6 35,1 174 S 6 34.8 175 S 5 E MARATHON OIL CO. STEELHEAD M-2 MCARTHUR RIVER KENAI 08124187 ALASKA DEPTH WL **~ORMATiON C. IP** ANG AZ 8E.ARiNG GRADE ****BCREHCL:***** DA OAZ BEARING 4860.0 4862.0 ~64 0 4866.0 4868.0 ~870.0 4872,0 4874,0 48?6,0 ¢878,0 ¢88C,~u 4882,0 4886.0 ~890,0 4894,0 ~896,0 490~.0 ¢902.0 4908.0 4912.0 4914,0 4922.0 49~6,0 ¢928.0 493~.0 ~93~.0 4936,0 4~38.0 494C.0 4944.0 494e.0 4948.0 49,50.~ 8.0C 8.OC 8 · L,C 8.0C 8,CC 8.00' 8.0C 8 8.0C 8. OC 8. CC 8.00 8.00 8 · OO 8.0C 8.00 8,00 8.0C 8.03 8,00 ~. OC 8. OC 8.CC .,~ OC 8.06 8. OC 8· 0C .., ~,J. U 8. '0r~ 8.0C 8.0C . 8,00 8.00 8 mr' ~ : 1~ ~ 16TM ~ 17 = ;50 13.5 258 S 78 w 130 17.6 254 S 74 w 73 1C,9 107 S 73 E 59 14.6 100 S 8C E 52 7,3 177 S 3 S 10C 16.5 238 S 58 ~ 77 13.1 22~ S 4~ W 79 15.6 356 N 4 W 100 lC.3 28.8 N 72 W 100 7,4 3.26 N ]4 w 100 3.7 298 N 62 w 100 3,7 8 N 8 E 74 4.8 323 N 37 W 1 31 2 2~8 N 62 ~ 7~ 18,5 355 ~',; 5 ~' 27 18,3 346 N 17,6 344 N 11,3 333 N 27 W 57 12,7 273 N e7 w 1C0 !3.0 281 ",] 79 W ICC 1~.~ 122 4 3 ~ N 53 9.9 90 N ~0 8 74 19,¢. · ~ 37 N. I 7 2;4 N 4.6 343 N 17 ~ 100 4.7 3.36 N ~4 W lC0 t].2 28~ N 22,4 260 .S 8C w 5t 29,4 289 N 71 N 76 37.6 303 N 57 w 38 21.7 ~89 N 71 W 73 24.4 291 N ~g ~ 63 15.1 272 N 88 ~ 55 Zt.6 303 N 57 W 7Z 19,3 27~ N e6 ~ Z2 34 7 17 34.6 1 74 34.4 17,; 34.2 I 74 34,2 174 34.1 34 · 0 1 74 ~= ~ 17 3= ,~: 1 73 33.6 17~ ~3.~ 173 3= 5 173 ~.: 17 3~ : 17z 33,2 1 73 5.~,0 175 32, ~ 1 73 3P ,~ ! 7 32,e t72 ~2 5 172 $2.~ 17~ 32,6 173 32,0 174 3~ ~ ~ ~ 173 ~1.c 174 32,3 175 _~c.$ 175 ~2 ,¢ t 7 3~ .~ I 75 32.3 175 3~,~ 17 32.3 175 32,2 175 3~.2 174 ~ ~ 175 32,4 175 32.4 175 32,3 174 3P.3 t7~ MARATHON OiL CO. STEELHE.~C M-2 MCARTMUR RIVER KENAI DEPTH WL **FORMATION DIP** ~NG AZ BEARING GRADE ****BOREHCLE***** 4~, 52.'~ 4954.0 4256.0 4958.0 4962.0 4964.0 4966.0 4968.0 4970.0 4972.0 4974.0 4976.0 4978.0 4982.0 4984.0 4986- .0 4~88.0 4990.0 4~92.0 ~9~4.0 4998.0 5000.0 5002.0 5004.0 5006.0 500r~ 0 , ,~ m 50t0.0 5012.0 ~014.0 ~0!6 0 ~018.0 5020.0 5022.0 5024 .C 5026,0 5028,0 5030,0 5032.0 8,00 8,0C 8.00 8. OC 8,00 8,00 8.00 8.00 8,00 8,00 8,00 8.00 8,00 8.00 8,06 8,00 8,0C: 8,0C 8.0C 8,00 8.0C 8,00 8.00 8,00 8 .CC 8,00 8.00 8,0C 8.00 8.00 CC 8.0C 8, O0 8,0¢ 8.00 8,00 17.1 27~ N ~1 W 70 22.9 239 S 59 W 72 13.7 230 S 50 W 67 1=.,.1 220 S &O. W 1C0 13.3 221 S 4! W 74 1~ 9 218 ~- '~ ~ 100 1~.9 22,B S 4S ~ 55 15.5 161 t~,6 242 S ~2 ~ 85 ~ 6 190 $ 8,4 20t S 21 k 100 · 8 PI* S ~6 W 100 .: _ ~ - . 15,6 134 S 46 E 59 9,7 143 S 37 E 100 10.9 89 N 8g E 100 6 9 21~ S ~6 W 100 0.9 1 79 S 1 16.~ 11~ 13.5 127 S 53 E 61 5.1 181 S 1 ~ 100 5.5 t47 S 1~ E 90 5,0 141 S ~.9 ~. 1~ '*,3 8,3 116 5 ~4 E 100 2.4 58 N 58 E 100 !. ,8 349 N 11 ~ 1 O0 2,8 332 N 3.1 320 N 40 w 100 4.0 S24 N ]6 W 100 5.3 42 N 42 E 100 5.~ 56 N 56 E 100 4.9 a4 N d4 E 100 19.6 303 N 57 ~ 1~0 ~.2 33 N 33 E 1~0 ~.2 111 S 69 E 1~C 1!.9 115 S ~5 E 100 11,9 1t3 S 67 E 99 t5,5 111 S ~9 E 100 11,2 193 S 1~ W 100 17.6 149 S 31 E 76 32.2 174 S 6 E 32,1 174 S 6 E 32,1 174 S 5 ~ 32.0 174 S ~ ~ 31.9 1 7~. S 6 E 31.~ 174 S 6 E 31,6 1 74 S 6 ~ 31.~ 174 S ~ ~ 31 .~ 174 ~ ~ = 31.3 174 S 6 E '31.2 174 S 6 = 3!. 2 1 74 S 6 E 3!,1 174 S ~ E 31.3 !75 S 5 ~ 30.8 175 S 5 E 3C, ,~ I 74 S 6 E 30.7 1'74 S ~ ~ 3C. 7 1 74 S 6 E 3 'C · 7 1 74 S 6 'E 3C. 6 1 74 S 6 E 30.7 I 74 S ~ E 3C.7 174 S 5 ~ 3~.7 174 S 6 E 30.~ 174 S 6 E 30 ~ 174 ~ 6 E ~.~.~ 17~ S 6 ~,= 30.4 17~ S 5 E 30.4 17~ S 6 E 30.3 174 S 6 5 30.~ 17~ S 5 ~ ~0.2 174 S ~ = 30.1 1 74 S ~ ~: 30.0 I 74 S 6 E 2°.9 174 S 6 5 2~.c 174 S ,6 ~ 29..~ 1 74 S 6 ~ 29.7 174 .S 5 E ~' ,~. ~'v.6 !74 S 6 = 29.6 1 74 S 6 E MARATHON OiL CO. STEELHEAO M-2 MCARTHUR RIVER K~NA! ©8/24/97 AL~,SKA DEPTH WL *'* F-ORM~TI ON ~N$ ~Z :~ARiNG GRACE ****5nRmmCLE*****,~ . 5q3~.0,., 5036.0 5040,0 8.0C 50.~2,0 5044.0 8,OC 5046.0 8.0C 50~8.0 8.06 5050.0 8.0C 5052.0 8,00 5054.0 5056.0 8,CC 5058.0 5060.0 8,00 5062.0 8,00 506~.0 8,00 5068.0 8.00 50'70.0 8.00 5072 .C 8.0C 5074.0 8.0C 5076.0 8,00 5078.0 8.00 5080.0 8.00 5082.0 8.00 5084. ¢ ~ OC 5086.0 8.00 50:B8. O 8.00 5092.0 8.00 5094.0 8.00 5100.0 8.00 5102.0 8.00 5104.0 8,00 5106.0 8.00 5108.0 8.00 5110,0' 5114,~ :~ OC 5110.0 8.00 5118.0 8,06, 512C.~:~ 5122.0 8,00 5124.0 8.00 17,3 149 S 31 ~ 60 5.7 12'3 S 57 E 100 6.7 15~ S 27 7.0 151 S 29 ~ 100 ~.9 134 S 46 E 100 1 4 · I 91 S 89 E 94 13.4 99 S 81 E !00 1.0 15-8 S 22 E 100 14.5 1=7.~ S 23 5 10~. 1~.1 148 5 32 E 59 ~ 8 215 S ~ W I~ I~ ~ 107 S 73 E 100 15.9 97 S ~'3 E 100 15. 8 9~ S ~6 .~ 70 '~0.3 55 N 55 ~ 24 13.1 117 S 63 E 4.7 1535 S 5 W 10C 9.0 128 S 52 E 1~0 11.1 9n~, N 90 E 10 9.2 95 S ~'~. ~.~, ~ 1~7~, S 4 19.5 278 N 8Z W 8-8 23,2 310 N 5C N 100 32,1 290 N 70 W 77 2~.7 359 N 1 W 52 20,6 273 N 87 6.7 196 S 16 W 65 9.3 t73 S 7 E 40 22.0 122 S 58 E 35 14.2 134 S 7~ E 100 10.2 113 S 67 16,8 1t3 S ~7 E ~,5 105 S 77 5 100 1 ~ 1 )4~ S ~ 5 ~ ;7 12,4 277 N 83 12.6 241 S ~1 w lu~ 17.8 317 N 2~ 7 ~30 N 15 5 103 S 78 = 10,4 1~ S 46 E 70 29.5 174 S 'C ~ 2'9,4 !74 S 6 E 29.3 174 S e. _= 29,2 17z~ S 0 E 2 .c,'. I 174 S 6 E 2g.C 174 S 6 E 2E~.9 174 S 5 E 28.~ 174 S 6 E 28. ~ ! 74 S 6 E 28.7 1 74 S 6 E 2,5.6 174 S ~ E 28.5 174 S 6 E 2~.3 17~ S 6 E 2~ ~ I 74 q A ~ 2~, 2 174 S ~ ~ 27.9 1 74 S 6 E 27,9 174 S 6 E 27.8 173 S 7 E 27 . ,~, 1 73 S 7 E 27.7 173 S 7 ~ 27.~.~ 174 .c ~¢ E 27,6 175 S 5 ~ 2Z.e 174 S ~ ~ 27.~ 17~ S 5 ~ 27.6 1 75 S ~ E 27,5 175 S 5 ~ 27,5 175 S ~ E 27.5 175 S 5 e 27,5 175 S 5 E 27.4 t 75 S 5 [ 17.4 175 S 5 E 27,4 174 S 6 ~ 27.4 1 74 S 6 E 27.4 174 S C E 27,5 1 7~ S 6 e 27.3 1 74 S 6 [ 27,1 !74 S 6 ~ i7,0 t73 S 7 ~ ZT,C 173 S 7 ~ P~: ~ ~74 ~ ~ $ M6R6THON STEELHEA:C MC~RTHUR KENAI OIL CO. M-2 RIVER ~ L ,~ S K A DEPTH WL **$ORMATiON BEARING GRADE 5t26.0 5128.0 5130.0 $132.u 5134.0 513~.0 5142.0 514~.0 5146.0 515C.0 51 52.0 5158.0 5t6G.0 51~4.0 51~ 0 5170.0 51~2.0 5t 74.0 5176.0 5178.0 5180.0 51 8~ .0 518~.0 5186.0 51 ~1~0.0 ~t92.C 5196.9 5198.0 ~20C.0 5Z02 .C ~Z04.0 5206.0 5208.0 521C.0 521~.0 8.0C 8,0C 8.00 8.,0C 8,00 8,00 8.0C 8.OC 8.00 8.00 $.0C 8.00 8.00 8,00 8.0C 8: · 0 C 8,CC 8,0C 8,CC 8.0C 8.0C $.00 8.0C 8.0C 8.00 8.00 8 · 0C 8.CC' 8,CC 8.CC 8.0C 8,0C 8,0C 8 ,CC 14,1 217 S 37 W 67 22,9 291 N 69 N 100 25,6 291 N 6~ W 1C0 4.6 67 N 2C,6 27 N ;'7 ~ 8'~:,. !6.0 30 N =C, E 10~ 2!.3 b2 N 2~.6 68 N 68 E 25 I ~7 N ~7 2~, 5 51 N el ~ 79 2~,9 322 N ~8 N 58 7,8 282 N 78 w' 100 7.~,,. 279. N 24.6 275 N 85 W 1CC 22,5 283 N 77 W 10C 28.9 ~'~ .Y~ N $7 W 93 16.0 338 N 22 15,4 6 N 6 E 72 14.7 351 N 9 ~ I 0C 4.8 27 N 27 ~ 100 15.3 37 N 37 E 64 11.4 32 N 32 E ~ 5 34~- N 14 W 100 22,0 342 N 18 ~ 69 15,6 ~52 N ] W 100 8,4 557 N 3 W 1 C0 9,8 34~ N 1~ ~ l~u 17,1 60 N 6~ 14,7 60 N d0 ~ 100 5.0 20 N . lC.8 19~ S 8.7 148 S 32 8,6 176 S 4 E 100 8,~ 195 S 15 w 100 1~. 3 l&~ S 3,0 1~I S t4,5 115 S ?,6 75 N 75 ~ 66 27 ,C I 74 S 6 26.0 174 S 6 E 26.8 174 S 6 _: ~ r. 174 S 6 26.7 174 S 6 26,6. 1 75 S 5 26,5 1 74 S 6 26,4 17~ S 6 2 26,~ 174 S 6 26,4 174 S 6 26,4 175 S 26,& 175 S 2~, 4 17~ S 5 26.4 175 S 5 26.3 1~ S 5 26.3 175 S 26.3 175 S 5 26. ¢= 1 75 S 5 26.3 t74 S 6 26.3 174 S 26 · 1 1 74 S 6 26.2 174 S 6 26.1 174 S 6 26.2 !74 S 6 E 2~.~ 174 S 6 26.~ t74 25.9 1~3 S 7 25.9 1 73 S 7 2*. ~ 1 7P 2~ S 171 S 9 25,7 171 S 25.8 17S S 7 2.~,7 17S S 7 ~5.6 17S S 7 2 ~ · 5 1 74 S ,6 25,6 174 S 6 ~5,5 175 S 5 ~5,5 174 S ~ARATHON OZL CO. STEEL~EAO M-2 MCARTHUR RIVER KENAI 08/24t87 ALASKA DEPTH WL **FORMATION DIP** ANG .AZ bEARING GRADE DA B.AZ BEARING 52 52 52 52 52 52 52 52 52 S2 52 552 .53 53 18.0 20,0 22.0 2C,C 26,0 28,0 32.0 34,0 36.,0 ~0,0 44.0 46.0 48.0 50,0 552,0 5z,,O 56,0 60.0 62.~,~ 64,0 66.0 68.0 70,0 72.0 74,0 76,0 78.0 80,n 82.0 ~ ,0 ~6,0 92,0 96.0 9~ 0 00.0 02,0 04,0 36.n O 8 · 0 8,0C 8,00 8,0C 8,00 8,00 8,00 8. OO 8,0C 8,00 8,00 8.00 8,00 8,00 8,OC 8.00 8,0C 8.00 8. uC 8.00 8,00 8.0O 8. CC 8,00 8,00 8,00 8,06 8.00 ~,0m 8,0C .S,OC 8,00 8 Or` 8,0C 8,CC g .0~ $, 0 C: 8,8 80 N 10,4 4Sl N 81 ; 1CC 2.8 119 S 61 E 7'9 2,9 2~+1 S al w 100 4,3 190 S !0 W 100 4.2 268 S 8~ W 100 7.1 246 S 4.7 240 S 63 ~ 100 5,5 248 S 5-* W lu~ 1,9 258 S 78 w 100 8 t 258 ~ 78 W luO i ~ · , 7.0 26 C S '~ 0 256 S 76 9.3 196 S !6 W 10C ~.5 114 S 6~ ~ 92 1~.3 1n ~. ~.3 S 77 E 100 1= 0 110 S 70 E 100 32.7 3~8 N 2 w 76 33,2 359 N 1 '1~,5 298 N 62 W 100 23,9 66 N 8~ E 100 12.0 141 S 39 E 100 9,7 117 S a3 ~ 100 14,~ 40 N ~C E 1C0 ,u N 4 E 1 16.6 46 N 46 E 98 2C, 0 24 N 24 ~ 99 19,0 26 N 26 ~ 100 4.7 22~ S 44 N 1C0 19.3 291 N a9 W 51 1.S,2 265 '~.~ ~- ~ W 100 14.1 108 S 17 3 148 S 1a.6 166 S 17,~' 154 S 26 ~ 74 ~3,2 143 S 37 E 100 17 ~ 155 S !1,8 202 S 2~ W 130 11,2 197 $ 17 W 10C: 12,7 201 S 21 ;.J 109 25,5 175 25,6 175 25,5 17.5. 25,? 175 ~ 7 175 25.7 175 255.6 174 2~ 6 174 25.~ 17~ 25.6 17~ 25.5 174 25.5 1 74 2~ ~ t75 25.4 1 25.4 174 25.4 25.~ t74 25.3 lye 25.2 17~ 25.2 174 25.2 17& 25.2 t7~ 25.2 174 25,1 174 25.1 !'74 85.~ 17~ 25,1 174 25.1 174 25,! 174 2~ 1 174 25.! !74 25,1 174 ~5,1 174 25.1 17~ 2~ 1 1 74 ~5,1 174 2~$.1 !74 25.1 174 25,1 ;~,1 r~ ~ ,$ E 37 M~RATHON .STEELHE~D MCARTHUR KENAI 8S/24/87 CZL CO. 'AL ASK.a DSPTH WL ** F-OR.. ~.~"AT .TON F',T.. $.. $.Z 5E~RING GRADE 53 53 5'3 53 53 53 53 53 53 53 53 53 53 53 53 5~ 53 53 53 53 53 53 53 53 53 53 53 53 10..0 1 2.0 14.0 16.0 18.0 22,0 30 .C 32,S 3~,0 36.0 ~O. 0 44.0 46.0 48.0 50.0 54.0 5~ ,C 60.0 62,0 66.0 ~ ,0 70.0 72.0 '74.0 7 6 - 78.0 80.0 '6.0 88.0 90,0 92 ,O 94.0 96.0 8.OC 8.0C 8.0C S · OC 8.OC 8,00 8 .CO 8.0C 8.0C 8.00 8.00 8,OC 8.00 8,0C 8.CC 8.00 8,00 8,0C 8,0C 8.0C 8 · OC 8.0C 8.00 8.OC 8.00 8.00 8.0C 8.00 8 · OC 8.00 ,8. OC 8.CC 8.00 8.00 8.0C 21,3 72 N 72 E 100 1~ 5 111 $ 69 "' ~'"' lC,9 192 S 12 W 100 11,2 209 S ZO W 84 12.9 190 S 10 ~ aS 2,9 209 S 29 W 100 11,6 171 S 9 E 22.2 168 S 12 5 , 3 08 N ~8 12.3 138 S 42 E 66 C· 2 115 2.7 227 S 47 ~ 100 15.0 212 S $2 W 75 11.2 204 S 24 ~ 7~ 11.3 $0~ ~ 4 2~~ 5,~ W InuO 12 5 1~2 5.6 2~ N 2;~ ~ 10r~ 24,3 355 N 4 ~ 1C9 21,~ 3~5 N 15 W 100 11,9 173 S 7 ~ 10C 13.8 199 S lg W 88 7.6 1S~ S 5 N 100 ~.6 182 S 2 N 10C C.2 200 S 2C ~' 7S S.8 16d S 2U E I~ g.3 198 S 18 3,0 191 S 11 W 100 ~ 6 ~04 S s4 W 1CC 8,5 227 S 10.1 235 S 55 N 100 1C,8 202 S ~.,.~7 o 284 N 7 Zd,7 285 N 75 N t00 tl,7 162 S la ~ 7~ 7,2 2o5 s 25 w 72 7.5 201 s 2t w 10o 7.3 I 39 S 41 E 81 25.1 174 25.1 174 25.1 174 P5.1.. 174 25.1 174. 25,1 1 74 Z5.1 173 25.1 174 P~ I I 7~ ~5 n 1 7~ 25,~ 175 25,0 1 75 2~ C 175 25.0 17~ Z$,C 175 25.3 17~ P5 '~ 1 75 25 n 17~ ~5 '~ 175 25.C 175 P= ~' 176 25,0 175 u t7~ 25 ,C 1 75 2~,0 176 25 . G 1 7 5 25.0 170 25.0 175 25.0 175 25.0 175 ~ ~ 176 ~ ~ i ~ , 2~,0 176 ~f.O 1 7e ~5,0 1 76 2~.C 1 76 24, ~ 176 24.9 176 24.9 176 24.9 1 76 MARATHON OIL CO, STEELHEAD M-2 MCARTHUR. R'"VER~. C8124187 DEPTH WL 5398.0 5400.0 8.00 5 ~, 02,0 5404,0 8,0C 5406 . ,.~ 8. OO 5408.0 8.0C 5410, 0 5~,12,0 5414.0 8,00 5416.0 5~18,0 8,00 5420,0 8.00 5422.0 8.CC 54!4.0 8 5426,0 5428,0 543C.0 8,0C 5432.0 8.00 543z,.0 8.00 5436,0 8.CC 5438.0 8.00 5440,0 8.CC 5444,0 8.06 · 544~., 0 5~'50,0 8,0C 5452.0 8.00 ~4=4 0 5456 O 8,0¢ 5458.0 8,00 5450,0 8. O0 5462.0 ,.'~. OC 54.§4.0 8,0C 5466,0 8.00 5468.0 8,0C: 547(3,0 8.0C' 5472,0 8.0C 5474.0 8.00 5476.0 547 n ,~ 8 · 0 C 5480.0 8,00 ALASKA / **FORMATZON 3iP** .aNG AZ BE.AR lNG GRACE 1:~.,7 215 S 35 ~ ~,6 186 S 6 W 11,~ 153 S ~7 E lC,7 157 S 23 E lC.3 154 S i6 E 9,3 15~ S 22 ~- 9.2 174 S 6 E 16,5 172 S 8 E 11,8 172 S .8 E 9.6 154 S 1~ E 12,5 196 S 16 W 1~,2 201 S 21 N 13.4 211 S 31 ~ 1~,2 2~5 S ~5 ~ 18,9 226 S ~6 ~ 19,6 227 S 47 W 11,~ 257 S 7T N 15,6 20~ S ~6 ~4 11.0 15.5 S 22 E 1~,6 254 S 84 W 14,0 272 N E8 W la,& 227 S 47 ~ 5,C 159 S 21 E 2 7 15~ c - . ~. ~4 E 12,~ 228 S 48 W 15,1 21~ S $~ N 12,2 21! S ~1 W 13,8 1~9 S 19 N I 1 · 0 205 S 2 ~ 10,0 205 S 25 W 10,4 ~0~ S 29 W 11,5 2t~. S ¢=~ W t 1.1 2~t S 41 W 1t,5 192 S 12 W lC.7 2c. N 26 E 17,1 56 N 56 E 15.e. t16 S 84 ~ I~,3 61 N 61 E 19,6 6~ N a] E !5 t00 1C0 100 100 98 t00 ~ 4 lO0 100 1tO ! 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S 46. E .~,84 .8.1 295 N ~5 W 10:0 12,5 323 N 37 W 1CC 4.4 288 N 7 ~,u 350 N 10 W 100 39,6 327 N 33 W 65 2~, 5 302 N 58 W 19.7 276 N ~4 w leo 9,7 138 s 42 E 94 9.0 10~ S 74 E 100 9,0 110 S 70 [ I0~ ~,5 103 S. 77 E 100 15.4 29~. N 4,0 309 N 51 W 100 12,3 ~6_. S 1~.p.~ _ 288 N 7~ ~ 5 ~64 ~ ~4 W ~ 0C 22.2 84 N 84 E 60 75,3 77 N 77 E 6~ 10 '~ 3a N 30 8.4 27 N 27 E I O0 ~:, 9 342 N 1 12,5 355 N 22.4 356 N 4 20,5 ~0 N 19,7 347 N 13 W 74 2~,1 32~ N 34 W !CO 18.0 22 N ~2 E 1 ~ 11,1 O N 0 E t00 12,7 28 N 2;~, E 65 13.7 297 N ~3 W 65 22.0 22 .C 22.0 22.0 22,0 21,; 22.0 2! ,9 21.9 21.8 21 ,8 2t .7 2! .7 2t ,? 21 .? 21 ,~ 21 ,e 21 , = 2t ,7 21.8. 21.8 21,7 2! .7 21 .7 2t .7 21 .7 21 .7 21,6 21,6 2t ,~ 21,5 21,4 2! .5 21 .4 21 .2 2! ,1 21,1 21 .C' 175 175 175 175 176 17~ 17,5 175 176 176 176 176 177 177 177 176 17~ 176 177 177 177 177 177 177 177 177 177 177 177 177 177 177 177 177 177 177 t76 175 17~ 177 MARATHON ~T~LHE~~ MCARTHUR KENA! O8/24/87 OTL M - 2 RIVER AL.&SK.& DEPTH WL **~CR~ATiON DIP** ANG AZ BEA~'ING GRACE 585O,0 8.CC 58~2,0 ~ O0 5~8~ n .~ CC 58~S6.0 8,oe 5890.0 8.0~ 5892.0 8.CO 5~9& 0 ~ nC ~898 ,O 8,0C 5 900. C 8. OC 5902,0 8.0C 5904 .g 8,0C 5908.0 5~1C.0 8,00 5912.g 591~,0 592C,0 8.0C 5924,g 8,0C 5926,0 5928.0 5932.0 8,0C ~934.0 5936.0 8.00 ~938.0 $942.0 ~9C4.0 59~,C 8,0C 595~ u. 0 8,0C 5952.0 8.00 3954,0 8,00 5956,0 8.00 5~38.0 59~C,0 8,0C 5~62 0 8 5964,0 ~966.0 8.0C ~968,0 8,0C 5974,0 8,00 ~976,0 8,0C 59~8,0 8,00 14,6 27F'. N 82 25,t 244 S 64 ~, 100 24,2 2/,3 S 63 w 67 21, L6 2/,t S 61 17.9 237 S 57 w 43 11 4 196 S 16 1C,5 106 S 74 E ~5 4,1 1~S. S ~=5 ~ 1CO 4,8 179 6. 4 18~,.~ S 8 ~ 100 2~,5 126 S 54 E ~1 1~,5 173 S 7 E 1C~ 8.8 143 S 37 E 100 25,8 261 S 81 w 53 ~.8 342 N 18 ~' 100 5.2 336 N 24 W 100 13,0 319 N 41 N 100 12,3 291 N ~'~ N 100 .~: 0 ~ N 5 E 100 ~.! 102 S 78 E 100 ~, 6 150 2 169 ~ 11 E 1C0 ~,0 150 S 7,2 165 S 17 E t0C 1~,7 201 S 21 w t00 16,5 286 N 74 ~ 83 1!,~ 32~... 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STESLMEAC MC~RTHUR RIVER KENAI :~$/24/87 O~PTH WL **FORMaTiON O!m** A.NG AZ BEARING GRAOE 5980,0 5982,0 5988,0 59';C.0 5992.0 5994,0 5996.0 5998.,0 6000.0 6C04.0 6006.0 6008.0 5010.0 6014.0 6016.0 §018.C' 6020.0 .6022.0 602~.0 a026.0 6028.0 0030. 6032,0 6034,9 6036.0 6038.0 60~8,0 6052,0 6054.0 6056.0 .u58,0 6060.0 6062,0 6064,0 6066,0 6068.0 6C70.0 6072,0 6074.0 8.0C 8.OC 8.00 8.0C 8.0C 8,00 8.0C 8,0C 8.OC 8.gO 8.0C 8.0C 8.0C .,8. OC ~.OC $.0C 8 ,CC 8.00 8.00 B.OC 8.00 8.00 8.00 8,0C 8,00 8.0C 8.0C 8.00 8.00 8.0'~,~ 8.00 8,00 .8. 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C.5 179 ~C.5 179 S 1 20.4 179 S 1 ~C.3 179 S 1 2C.3 179 S 1 2C · 3. 1 79 S 1 2C.$ 17~ S t 2C.1 17~ S 2 20.1 17~ S 2 2C.0 17~ S 2 1;.9 178 S 2 1~.9 !73 S 2 lg.~ 178 S 2 19.8 178 19.8 178 S 2 19.9 178 19.~ 17~ S 2 1 9 . :3 I 78 S t9.9 177 S 3 19.8 177 S 3 19.~ 177 S 3 19.7 17~5 S 2 E 19.~ 178 S 19.8 17:~ S 2 19.;~ 17,~ S 19.8 173 S 2 E 19.7 178 S 2 19.8 178 S 2 19.7 178 S 2 19.7 17n c 19.T 178 S 19,7 178 S 19,7 17~ S 1 ~, ~ 1 73 S MARATHON OIL CO. ST[ELHE.AD iqC4RTHUR RIVER KEN~I u 8 / 2418 7 ALASKA DEPTH WL **FORMATION ANG aZ EEARING GRADE ****BCREHCLE***** 6076.0 8.00 6078.0 6082.C 6084. 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S 17~ S 1 I ~:.6 179 S 1 I~ 5 170 S 1 1;S.S 179 S 1 18,5 17~ S 1 MARATHON OIL CO, STEELHEAO M-2 MCARTMUR RIVER 08124187 ALASKA DEPTH WL **FORMATION OlP** ~NG AZ BEARING GRA3E ****$CREHCL:***** 6162.0 5164.0 8.00 6160.0 8.00 5168.0 8.00 6170.0 8.00 6172.0 8.00 6174.0 8.00 6175.0 8.00 5t78.0 8.00 S180 0 '~ OC .,5182.0 8.00 61 84.0 8.00 6186.0 8.00 ~138.0 8.00 6192,0 8.00 6194.0 8.0C 6196.0 8.00 6198.0 8.00 6206.0 8.C0 6202.0 8 .CC 6204.0 8.00 6206.0 8,00 6216;.0 8,00 621~,0 8.00 6214.0 8,00 6216.0 8,00 6218.0 8.00 6220,0 8 ,CC 6222,0 8,00 6224,0 8,CC 6226.0 8.00 6228.0 8.0C 6230,0 8.00 6232,C 8,00 ~234,0 8.00, 623~.0 8.0C 6238.0 8.0C 52~,C.0 8.0C 6242,0 8.00 6244.0 8.00 .~.1 156 S 24 E 100 5.8 193 S 13 W 100 14.1 3/,,4 N 16 W 100 15.7 322 N 3~ ~ 01 14.3 307 N 53 W 8.5 6.9 320 N 40 W 1CC 8.6 4n~ N 4~- ;_ 100 13.2 42 N 42 11.9 227 S 47 W 100 5.8 190 S 10 W 10n 5.4 244 S ~4 W 100 28.2 262 S E2 w 52 2.7 332 N 2 15,9 220 S 4:3 W 87 4,7 219 S 39 W 100 9,5 333 N 27 W 100 2 9 8~ N 1t,2 62 N a2 E t00 7 ~ 138 S 8 8 130 S ~O ~ 10~ 1!.5 136 S 44 E 100 9.0 270 N 9.~ 238 S 15.0 242 S ~2 W 52 4.2 247 S d7 W 100 8.6 194 S 14 W 100 ~.2 180 S C E 100 8.2 193 S !3 ~ 25 lC.3 212 S 32 W 93 9.5 186 S 5 w 100 9.6 17~ S 1 E 10~ 1!.~ 187 S 7 W 93 13,1 186 S 6 W 1CC 8 8 19q S 13 w 100 13,~ 263 S a3 w 100 11.0 2.~8, S 6~ w 100 12.2 277 N 83 W 108 2~.7 290 N 70 w 100 1G,3 180 .S O E 100 1!,~ 173 S 7 E 7.~ 18.5 179 S 1 t8.5 179 S 1 18.5 179 S 1 18.5 179 S I E 1~. 5 179 S 1 F 1~ ~ 17'9 S I ;:,~ . ,,,,' 1~ 5 179 S 1 18.4 179 S 1 18.4 179 1~.4 179 S 1 1:~ 4 179 S 1 18.4 1~9 S 1 E I ~..4 179 S 1 1 ,~, .4 1 79 S 1 E 1&.3 179 S 1 18.2 179 S 1 1~ 1 1~9 1~.2 179 S 1 E I~ 2 1~3 18.2 179 S 1 18.2 179 S 1 18.2 179 S 1 1 ~. 1 1 80 S C 1~.1 18,9 S n..~ I~ O 1 o~ S C 18.0 180 S 0 1 8 C 1 .:u 18.0 1 sj; 0 S 0 18,0 180 1.~.1 180 S C 1-~.1 150 S 0 18.0 1;~0 S '~'~ ~. 18.1 1~;0 S u : t8.1 180 S 0 18.0 1:~1 S I W 18.0 la, C S C 18.! 1~1 S 1 1' 1 1 1~.0 1,~0 S C E la,0 180 S~ =_ MARATHON OIL CO. STEELHEAC M-2 MC/~RTHUR RIVER KENA! C8/24/87 ALASKA DEPTH WL **FORMATION DIP** ;NG AZ BEARING GRADE ****80REHCLE***** 6246.0 6248.0 6252.0 6254.C 6256.0 6~58.0 626C.0 626,2.0 6264.0 62,56 .O 6268.0 6270,0 6272.0 6274,0 6276.0 62'78,0 6282,0 6288,0 6290.0 6292.0 6294,0 629b .C ,530C. 0 0302. O 6306.0 6308.0 6310.0 631 2.O 6314.0 6316.0 6318,0 6320.0 6322.0 6326.0 6328.0 633G.0 633Z.0 8.CO 8.CC 8.0C 8.00 8.0C 8.0C 8.00 8.00 8 .CC 8.0C 8 .OC 8.0C ~ .OC 8.0C 8.00 8.(30 8.0C 8.00 8.0C 8.0C 8- · ¢ C 8.0C 8.0C 8.00 8.00 $.00 8.06 8.0¢ ,, 8.OC 8.0C 8.0C 8.00 8.00 8.0C 8.0 C 8 .ne: 6.8 186 S 6 W 1~C.3 128 S 52 E 10,3 13.1 163 S 17 E 61 1 ?. 5 158 S 22 E 75 11.7 171 S 9 E 1CO 5,$ 182 S 2 W 100 11.6 171 S 9 E 10'0 9,1 169 $ 11 E 1C 14.5 211 .S 31 W 1C0 2,2 197 S 17 W 100 I · 8 224 S 44 7. 6 211 S - 13,9 186 S 6 W 100 14.3 182 S 2 W 100 11.5 141 S 39 ~ 100 ¢ ~ 10~ 15 2 160 S 14 , 0 1 79 S 1 E 64 6,2 145 S 35 E t00 1C',9 175 S 5 E 100 19,2 123 S 57 E 60 14,5 138 S 42 E 100 1~ 8 13~ S 5¢ ~ 100 16,0 130 S 50 E 1C'0 16.7 12.8 S 52 E 81 11.4 121 S 59 E 74 4.4 1~ S 34 E 100 ~, 5 1 45 S c.~ 160 S 2 7.4 211 S 31 W 100 7.4. 211 S ~1 W t00 7,2 204 S 24 W 10C 22,1 247 S 67 W 55 7,1 283 N 77 W 1 2,1 309 N 51 W 1C0 4, 2 158 S 2~ ~.3 10! S 7~ ~ 100 1C 4 ~5 16,~ 11~ S C4 ~ 100 8.9 253 S 73 W 100 6.5 249 S e9 W I0C 18 n l~n S 0 13.0 180 S 0 E 1,~ 0 !~1 17.9 18.0 S 0 E 17,9 180 S O 17 c I~ , .. ~, 1 S 1 !?,8 181 S I W 1 7,8: I .~ 1 17,8. 181 S 1 t7,~ 1':1 S 1 I 7, .8 1 ~ 1 S t W 17,8 151 S 1 w 17 ~ 181 * 1 W 17.8 lgl S 1 W 17,8- 1;~;1 S 1 W 17,~ 181 S 1 W 17,7 182 S 17,8 181 S 1 W 17,7 181 S t 17,7 181 S 1 17,7 181 S 1 w I 7,7 I 81 S 1 17.7 1~;1 S 1 w 1'?.6 1~1 S I w 17.7 181 S 1 17.6 1~1 S 1 w t7 : 1~3 S 0 17· -~' 18C S 17.6 1,5'3 S ~ : 17,5 130 S C 17.5 150 S C E 17.~ 180 S C 17, 5 150 S 17,/., 17~ 17.~ 179 S 1 t7.z. 179 S 1 -: 17.~_, 179 S 1 17.3 179 S 1 17.3 179 S 1 E 17.3 179 S 1 qAR~THON OZL CO. ~TE:LHEAm MCARTHUR RIVER KENAI ALASKA DEPTM WL **FORMATION CIP** ANG AZ BEARING GRADE DA CAZ BEARING 6334.0 8 .5338,0 8,0C 634G,0 8.00 634t.0 6344.0 8,0C 6346 0 8- . · 6348,0 8,00 6350.0 6352.0 8,00 6354.0 8,00 6356,0 6358 ~ ..~ 6360.0 8,0C 636~.0 8,0C 6366.0 8,00 ~368,0 8,0C 6370,0 8,0C 6372,0 8,00 6374.0 8,00 6376.0 8,OC 6378,0 8,00 6380.0 8.0C 6382,0 8,0C 6384,0 8,00 6386.0 63'?0,0 8.00 6394.G 6396,0 8,00 6398,0 8,0C 6400 0 8 6404,0 6406,0 8,0C 6408,0 8.0C ~10,0 6412,0 ~41~,0 6416.0 8.0C 6418.0 6420.0 64~2.0 8.0C 14,4 .~-~9 N .~;9 ~.= 72 18,5 92 S 88 18,1 92 S ~8 E 100 1~.4 86 N E6 E 100 7,~ 28 N 2~ ~ 1CC 14.6 t8~. 14 9 1~7 S 7 ~ 10'm 14.5 187 S 7 W 10~ 1 ~. 8 t 87 S 7 W 1 30 12.8 158 S 8 W 10~ 9.1 264 S E4 ~ 100 ~ 7 2.5A S 76 W I~ 5.4 315 ~ 45 ~ 1C0 6.5 303 N 57 W 51 ~. ~. 303 N 57 6.4 93 2C.0 ~5 N 85 ~ 100 10.5 16 N 16 E 100 1~.8 ~9 N 4~ E 85 13.6 44 N 44 E 100 4.1 35~ N 6 W 100 ~.9 59 N 5~ E 100 ~.6 ~7n,~ N 90 W 100 17 5 22O S 4~ ' 3.2 1~2 S 2 w 100 5,9 1~9 S 51 ~ 100 18,3 124 S 56 E 53 14.8 126 S 54 E 72 9.9 173 S 7 E 75 1G,8 217 S 37 W 100 ~.5 207 S E7 W 10C ~,5 ~03 S 23 W 100 9 3 1~3 S 57 a.O 1~2, S 3~ .: 1C0 7.1 101 S 79 ~ 4.4 122 11.0 145 S 35 E 74 11.7 183 S 3 w 99 12.1 179 S I E 100 i~, 3 198 t7 ~ 179 1 ?. 3 179 17.3 17g 17.3 179 t7.2 t~0 17.3 180 17.3 1;,50 t7,4 180 17.3 1~,n 17,Z 179 17,4 179 17,4 179 17,3 178 17,4 179 17,~ 179 17,3 17~ 17,3 179 17,3 179 17,3 179 !7,3 179 17,3 17S 17,3 17~ 17,3 179 17,3 178 17,3 178 17,3 179 17,3 178 1?,3 178 17,3 179 17,3 179 17,2 179 17.7 183' 17 3 1'~ . ,~u 17,Z 1.51 1 7.3 1 ~: 0 17,3 t80 17,2 180 17,2 leo 17,~ I~:~ MAR~THrjN CZL CO, STEELHE~O M-2 MCARTHUR RIVER KEN4I ~8t24/87 2L4SKA DEPTH WL **FOR~4TION DIP** ANG AZ B~ARING GRADE ~***ROREHCL~***** 3AZ ~E~RiNG 5424,0 6426,0 8,00 6428,0 6430,0 ~32.0 8.0C 5434.0 6436.0 8.00 6440.0 8.00 6442.0 8,00 6444 O 8 6450,0 8,0C 6452.0 8.00 5454.0 8,00 6456.0 8,0C 6458,0 8,00 6460.0 $.06 6462,0 8,00 6464,0 8.00 6466.0 8,00 ,5468,0 8,OC 6470,0 8,00 6472,0 8,00 6474,0 8,00 6476,0 8.0C 6~78,0 8,00 5480,0 .8,0e ~482.0 8.!30 b484,0 8.0C 6486.0 8,OC 5488,0 6492.0 8,0~ 5494,0 64~6.0 8,00 6498.0 ~500.0 6502.0 8,0C 6504,0 8,00 6506.0 8.0C 6508.0 13,! 189 S 9 W 100 6,5 170 12,5 156 S 24 E 100 13,.3 165 S 15 E 52 13.3 131 S 4~ E 1~C 13.4 135 S 45 E 73 14,3 145 S 35 E 100 ~ 0 151 S 29 6,3 157 S 9.4 157 S 23 ~ 100 13.1 137 ~ 43 E 100 11,1 141 S ~9 E 1C0 8,6 190 ~.6 2Ol S 2-'~ N 5~, 9.0 209 S 2~ w 97 1C,4 132 S 4~ E t00 7,0 1S8 S 22 E 100 ~,2 154 S 25 E 100 2.5 58 N 5~, 4,5 115 S 67 E 100 9,4 149 S ~1 E 100 10,4 t54 S 26 E 10C 7,~ 17~ S 7 ~ 100 5,2 165 S 6,1 156 S 24 E 100 I, 9 1 95 S I S = 0 1~ S 42 ~ 100 1.3 t17 S 63 E 1C0 C.8 87 N 87 E 1C0 5,~ 84 N 84 E 100 4,7 344 N 16 W 100 24,C: 340 N 2C W 100 12 ~ 337 N 2 1~.~,o,. 166. ~.~14 E 100 9,1 t77 S ~ E 100 22.9 170 S 9.5 18t S 1 w 100 2~,, 4 56 N 17.1 43 N 43 E 100 ~,5 P5 S 85 E 100 17.3 180 S 0 -- 17,2 1.~0 S '~ = 17.7 150 S C E 17.2 180 S 17,2 1~0 S C 17,2 181 S 1 W 17 2 150 S 17.~ 1~0 S 17.2 I~0 S 3 17,2 t80 S 0 1~,1 t 80 17,1 180 S 17.0 !8-,.'n ~ O E 16.9 183 S 0 E 16.9 160 S 0 1~,8 180 S O 1~.~ 180 S O 15,8 18~ S O 16.8 180 S 1~,7 1~0 S 0 1~.7 180 S 16.7 150 S le.7 180 S 0 E 16.7 180 S O 16,7 1 ~¢' 1~,0 1~0 S 1' 7 lo~- S 1~.~ t80 S 1~,6 t50 S 18.5 180 S 0 t6 ~ 180 S C la,~ 13n S 0 16, S 1 ;51 .S 1 W 16.S 183 S 1 6.6 I ~: 0 S la,5 181 S I W 18,5 1~0 S O 16 : 1~0 MARATHON STEELHEAB MCARTHUR KENAZ ~8/24/$7 OiL CO. RIVER ALASKA DEPTH WL **FORMATION~'~'IP**, ANG AZ B~A~ING GRAOE BEARING 6510.0 6512.0 5514.0 6516.0 6520.0 6522.0 6524.0 ,5526.0 5528.0 6532.5 6534.0 653~ O .~¢4C 0 6~44.0 6546.0 654~.C 6552.0 6~54.0 6556.0 6558.0 65~0.0 6~2,0 65~4.0 65~8.0 657~.0 6572.0 6574.0 6~7~ 0 6578.0 ~5~4.0 6588.0 6596. '3 6598.0 8.00 8.CC 8.0,0 8.0C 8.0C 8.00 $ .0C 8.00 8.00 8.0O 8.0C 8 uu 8. OC 8.OC 8.0C 8.06 8,00 8.00 8. OO 8,0C 8.00 8.0C 8,00 8.00 8,00 8.00 8.00 8.06 8,00 8,0C 4,3 123 S 57 E 10C 5,2 131 S 49 ~ 100 5.1 139 4.9 133 10.3 97. S 5.3 158 S 12.1 10t S 79 - 100 9.7 165 S I 5 E 70 ~.5 221 S 41 W 100 18.-~ 323 N 37 13.4 27 N 27 E 130 5.4 21 N 21 :E 100 16.7 296 N 64 ~ 100 3.5 164 S 16 E 100 5,9 170 S 1C b 100 11.5 179 S 1 ?. 5 I 72 .S 8 E I CO 7.8 151 S 29 E 10'c~ 7.1 140 :~ I 127 S 5x = 100 2.6 12~ S 56 5 10C, 4.0 13.8 S 42 E 100 7.6 65 N,, ~5 = ~ 10C 6.a 72 N 72 E 100 7.6 ~8 N ~8; E 1CC !.7 335 N 25 ~' 100 2,8 287 N 73 7,3 1t6 S 54 E 100 5 3 lX4 S 4x = lOr~ 7,6 21S S 3~ w 1CO 1 2, ~ 17,~ 1~. . 7 1~2~ S 4L lb.2 1Z1 2 59 E 100 4,7 137 S 43 E 100 1 5 2~5 S 7,1 219 S 39 W 100 9 , 5 248 S 9.2 241 S 6t W 100 13.9 115 S 65 E 90 16,5 180 ld,5 180 16,5 180 1' = 180 1~ A 1,~ ld.b I 8,3 !6.6 18,0 lc.6 18.1 16.6 180 1 6.6 1 16.4 1E:1 1 0.4 1 81 I 6.5 1~1 16.5 1~1 16.5 18.1 1~. ~ 151 15.4 181 16.4 1~;1 16.5 1&1 ld.5 !,51 1~ 4 181 15.C 18,0 15.4 1S1 1~.3 151 1~.5 18.1 1~.~ 181 16.2 1~,1 18.2 180 1~.1 1~,1 16.1 150 1~.1 181 16.1 181 15.1 180 1~.t 181 1~ I 1~1 I 5.1 16.1 181 15.! 181 15.1 1:~! t ~.C 1~1 PASE 51 HARATHON STEELHEAO MCARTHUR KENAZ 08/2~/87 OTL Cn RIVER ALASKA DEPTH WL **FORMAT ION Di ANG AZ BEARING GRAD5 CAZ BEA~ING 6600.0 6602.0 6604.0 6608.0 6610.0 6612.0 5614.0 6616.0 6618.0 5620.0 6~22,0 66.24,0 6626,0 6628,0 6630,0 6632.0 6634,0 6636,0 6635.0 ~640'.0 6~2,0 6644.0 66~6.0 6648.0 ~652,0 66~6.0 6658,0 6662.0 6664.0 6666,0 6668.0 6670,0 6672.0 6674.0 6676.0 6678.0 6680,0 6682.0 6684.0 $.00 8.0C 8.00 8.0C 8.0C 8.0C 8.0C 8.0C 8.0C 8.00 8,0C 8.00 8.00 8.0C 8,00 8.06 8. O0 8.00 8,00 8 Or: 8.00 8.00 8,00 8. OC 8.00 ,. r'~ f-, 8 8.00 8.00 8.00 8.0C 8.0C 8.00 8.00 8.00 8.00 8.00 8.00 8.00 ~,6 161 S 19 ? 5 ~63 S 22,8 302 N 53 21, 2 3~, N 19,3 121 S 5¢ E 14,3 121 S 59 E 9,5 142 S 38 E u 178 S 2 11,7 208 S 28 W 4,3 131 S 49 E ~,3 1t5 S 63 E 14,8 146 S 34 E 13,9 154 .S 46 E 6,2 121 S 59 E 10,~ 1~0 S 5,2 126 S 54 : I 114 q 6~~ E 1,2 201 S 21 7 I 149 '~ =1 E 7,~ 14~ S 11,1 157 S 23 8,1 11~ S ~2 E 9 .3 114 S lC,3 111 ~ ~9 E 1'~.0 96 S 84 E 17.4 98 1~,6 101 S 79 E 1~.6 85 N .~5 E ¢ ,~ 1 35 S 45 E 1C 4 1=5 24,0 13~,. ~ 42 E 12,~ 123 S 57 15,2 142 S 3~ E t2,4 124 S 56 12,0 123 S ~7 E ~.'7 145 S 35 E 3,7 159 S 21 E 3,9 1~9 S 21 20,3 267 S 87 11,5 27 N 27 100 6n 100 lO0 100 100 100 1C0 lO0 SS lO0 100 t C-O 100 100 lOu 10,3 1 100 ?6 100 100 100 100 10,.,'"' 81 t0C 100 100 t00 1 00 16,1 151 S 1 W 1~.1 151 S 1 '~ 1 6. ! I ;? 1 S 1 W 1.~ t 1~-2 S 2 W t~,1 181 S 1 W 16.1 1~2 S ~ ~, 16,1 182 S 2 ~ ld.O 182 S 2 W la.O 182 S 2 N lC,O 182 S 2 w 16,O 132 S 2 ~ 1~,0 182 S 2 W 1 5. ~ 1 ~ 2 S 2 W 15.9 182 S 2 W 15,~ 1.52 S 2 w 15,~ tE2 S 2 W 1~ :~ 18= S 3 W 15.9 183 S 3 N ~ ~ 1~3 ¢ 3 W Ic 8 1:~: S ~ ~ 15,:~ t83 S 3 ~ 15.-3 13"3 S 3 W 15,.~ li~,3 S 3 W 15,~ 183 S 3 'N 15.~ 1~4 S 4 W 15.7 1~4 .S 4 W 15.7 183 S 3 w 15,7 1~3 S 3 ~ 15.7 183 S 3 W 15,7 1~'~ q 3 w 15.C 1~-~ S 2 W 15,6 182 S 2 W 1 ~. 6 1 82 S 2 w 15,7 1~.3 S 3 ~N 15,7 183 S 3 W 15.7 183 S 3 w 15.7 18~ S 4 W 1~,8 183 S ~ ~ 15,7 !8S S ~ W MARATHON OiL CO. STEELHEAO M-2 MCARTHUR RIVER KEN&Z 08/24187 ALASKA OEPTH ~L **~ORM,ATZON OZP** ANS .AZ E, EARZNG GRADE ~ " _ ~NG u~ S~Z E~AR~ 6686,0 8,00 6688,0 8,06 6690.0 8,00 6692,0 8,00 6694.0 8,00 6698,0 8,00 670C,0 6702.0 8 6704.0 8.gE 0706.0 8,00 6708.0 8,00 6710.0 8.00 6712,0 8.00 6714.0 8.00 6716,0 8.00 5718,0 8,00 6720,0 8,0e 6722.0 8,00 6726,0 8.00 6728,0 8,00 6750.0 8.0C 67x2 O 8.0~ 6756.0 8.0C 6738.0 8,0C 6740,0 8.00 6742,0 6744,0 8,00 6746,0 8,00: 6748,0 8,00 6750 0 · · 6752,0 8.0C 6754,0 8,00 ~756.0 8,00 6758.0 8.00 6760.0 8,00 6762.0 8,00 67~4,0 8.0C 6766 ,O 8.CC 6768,0 8,0C' 6770,0 8,0C 11.5 15 N t5 e 100 ~ 9 2~ ...... u N 20 E 1CL. 21 .8 I 02 S 78 E 1 24. $ 78 N 78 F-~. 1 ,..""'0 2~., ./., 96 S 15 9 18~ . . u S 16, O 186 S 21,4 15,9 S 21 E !00 20,0 164 S 16 E 100 1':; 5 14,4 S 36 E ~,~.... 153 S 27 E 100 12.9' t54 S 26 5 .87 1C, 6 1 86 S ?; W 82 1.8 51 N 51 ~ 100 19,5 3~'~ 18.0 358 N 22 ~ 100 1,.73 -.:. , , ~,,6 N 14 W 100 ~1.;5 275 N ~5 w 56 !9,t 271 N 89 W~ 100 4.7 12o S .,=~.. c lOu 7.3 146 S 34 E 100 8.6 t02 S 78 E !00 1~ m 178 S 2 E 100 22.4 232 S 52 W 100 2C.6 228- S 48 w 100 8.2 214 S 34 m 100 6.3 !71 S g E 100 8.3 18~ S 5 ~ 10c a.2 142 S 3~ E 100 t7.3 112 S ~¢~:~, .~ 98 17.4 113 S 67 E 84 ;~ 9 '~'~ S 81 E 10~~ 16.6 109 S 71 E 1 7.8 8! N 81 5 t00 2.6 93 S 87 E 108 1.7 314 N 4~ W 100 5.. 8 241 S 7.0 184 S 4 w 100 17 2 243 S 17.2 246 S 66 N 100 15.7 18'4 15.5 183 15.5 183 15.5 183 1 = - ~,.) 183 15,7 153 15,7 184 I 5 . 7 I 83 15.7 134 1S.6 183 15.6 184 15.5 164 15.5 1.83 15.6 15.5 1~2 15.4 1,51 15.2 17,8 15.2 179 15.1 178 15.2 179 15.2 179 15.3 t79 15.2 179 15.2 179 1~.3 179 15.3 !79 15.3 179 15.3 1;53 15.3 179 1~ ~ 17~ I 5.3 1 15,2 180 15,3 la. 1 1 5 ,~ 130 Ic~ . 4 1,S1 15,Z t $:0 15.3 180 15.3 180 15.~ 180 15,2 MARATHuN~' OIL ~"O, STEELHEaD MCARTHUR KENAI C8/24/87 ~LASK.A DEPTH NL **'~ORMATZON DIP AZ BEARING GR~DE **** 50~ 5HCL-'***** ~7 67 ,57 67 67 67 67 67 67 67 67 67 67 68 68 68 68 68 68 68 68 68 68 68 68 68 6~ 68 6~ 6~ 68 6~ 72.0 74.0 76.0 78.0 80.0 S2.0 84.0 86.O 88.0 90.0 92.0 94.0 96.0 98.0 0C.0 02.0 04.0 08.0 10.0 12.0 14.0 16.0 18.0 20.0 22.0 24.0 26.0 28.0 3C.0 32.0 34.0 36.0 38.0 40.0 42,0 44.0 4~:.0 4~ .,3 52 .C 8.00 8.0O 8.00 8.0,3 8 $ .00 8.0C., 8.00 8.0C 8.0C 8.00 8.00 8.00 8,00 8.0C 8.00 8.0C 8.00 · 8,00 8,0C 8,0C :8.00 8.00 8.00 8.0C 8.00 S.OC 8,0C 8.00 8.0C ~ O0 a,.OC ~ m 8.CC 8.00 8.00 2~ 7 268 S 18,8 321 N I 1 8 118 S 62 7.0. 124 S .~6 E 1CC ~..4 1¢2~ S 2~ ~* 100 ~. 2 171 S 6.7 1~0 S 20 E t00 16 7 154 S 16 ~ 10r~ 7.4 224 S 44 W 1 8.1 155 S 25 E 1CC ~.~. ,.¢ 141 S ~'9 E 1CO 9.5 148 S 32 E 100 12.5 !68 S 12 E 100 7.1 112 S 68 E 100 5.2 165 S 15 8.5 151 S 29 E 100 3.2 196 S 16 N 10:3 1~,4 132 S 43 ~ 100 17,7 128 S 52 E 100 3.1 255 S 75 W 86 ~.~ 32~ N 15.5 26S S ~3 w 100 3,8 204 S 24 N 100 7.3 155 S 25 E 100 d.8 16.2 S 18 9.~ 1~8 S 12 E 100 8.4 176 S 4 E lOC. 9.7 153 S 27 E 1CC 1~ ~ 156 c 24 E 94 1C,3 154 tl.0 160 S 2C 14.7 16F S 13 ~ 100 7.t 190 Slr w 1~ 7 2 1: ~ S 12 W' t00 7.9 73 N 73 7.1 24 N 24 = lu~O 14.8 251 S 71 .' 100 13.9 245 S C5 w 1CC 15,2 180 S 3 15,3 17'~ S 1 E 1~ 3 1'~ ~L:: S ~' · 15.3 179 S 1 15,3 1 ~"C ~ 0 = 15.Z !80 S C 15.~ 179 S 1 15 = 17~ S 1 15.5 180 S C 1~.5 179 .S 15.5 180 S C 15.3 179 S 15.4 179 1~.4 150 S 0 15.4 1~0 S ~ _ 15.4 180 S 0 I~ 4 1~0 S t~ 4 1~0 S O 15,4 180 S 15,4 180 S 0 15,4 180 S 15.5 1S0 S 0 E 15.4 180 S S 15.5 179 S 1 15.~ 179 S 1 15..5 1SC S C I~ 5 17~ S 1 t5,5 17~ 15,~ 179 S 1 1 5,5 179 S 1 E 15.4 179 S 1 15.5 179 S 1 ' ~ 179 S 1 I~ ~ 179 S 15.5 179 S 1 t5 ~ 179 S 1 15.4 1,8'~,~ S 15 3 1;~0 S " : P,~GE 54 MARATHON OiL CO. STEELHEAD MCARTHUR RIVER KENAI 08/24/87 ALASKA DEPTH WL **~ORMATZON DIP** ~NG AZ BEARING GRADE 6854.0 5856.0 6858.0 6860,0 6862.0 6866.0 5868.0 6870,0 8872 .C 6S74,0 6876.0 6880.0 6882.0 6884,r' 6886,0 6888.0 689n 0 6892,0 6894.0 6898.0 6900. C: 6904,0 6906.0 6908.0 5910.0 6912.0 6914 .O 6916.0 6918,0 5920.0 6922 .O 692~.0 6926.0 6928.0 6932,0 6934.0 6916.g 6940.0 6942.0 694A~, 0 8,00 8,0C 8.00 8,0C 8,OC 8,0C 8,00 8.00 8,06 8.00 8,00 8.00 8,00 8.00 8,00 8,hr~ 8.06 8.00 8.00 8,CC 8,00 8.0C 8,00 8,00 8.0C ~ O,~ ,~ . . "~,.j 8,00 8.0C 8.00 8,00 8 8.0C 8 . n ¢ 8.00 8,00 8.00 1~.5 253 $ 7S W 100 5.8 P43 S 17.4 153 S 27 ~ 10C 14 3 14~' . v S 4n ~ 77 13,8 142 S ~8 E 94 25.6 83 N a3 E 100 20.9 93 S 87 ~ 100 18.2 96 S 84 E 100 la. 3 94 S 86 E 10 g I 107 S 7~ ~ 100 · I 13.2 ~4 N 84 E 1 12.~ 5~ N 5~. ' 100 3.7 89 N 89 E 100 ~. 2 93 ¢ 87 ¢ 10n 13.7 121 S 59 E 5 ~ 272 N 12.1 257 S 87 W 1~,3 15.9 253 S 7 16,3 260 S 80 W 94 4.7 195 S t5 W 92 t7.5 2~7 S 67 W 10~2 25.2 224 S 4~ N 64 14.8 11~ S d3 E 1C0 t3.3 126 S 54 E 100 13.5 125 S 55 E 1C0 1;,8. 127 S ~=~ E 1CO t~.3 t27 S 53 ~_ 100 14.1 121 S 59 E 100 1~.8 225 S 45 W 100 7.2 t6~ S 12 E 100 14.6 186 S 6 W 78 4,1 144 S 17.4 224 S 44 W 53 16.8 225 S 45 W 56 11.4 172 S 8 E 89 19.7 157 S 23 5 73 1~.. 2 229 1E.1 172 S 3 ~ luu 1~ 3 18~u I~.. . 3 130 153 13" 15,3 18.1 15,~ 180 11,$ 188 1~,~ 180 15,2 180 1: 2 l&O 15.~ 1~ 1 ~. 2 I 8; O 1~.= 150 15.3 180 15.3 151 15.3 180 I~ ~ 1~1 15.2 1 a 1 15.2 1~0 15.~~ 1~0 15.2 180 15.2 180 1~,2 1.~1 15.1 181 1~,1 181 1~.1 181 15.1 181 15.0 151 1 ~.O 1.[~1 15. C 181 14.9 lA0 14.9 181 14.9 182 14.8 182 14. ~ I 81 1~.9 162 1 4.~, 181 14.S 18~ 14.E 1~ MARATHON OIL CO. STEELHEAD M-~ HCARTHUR RIVER KENA== 0~/2~/87 AL.~SKA DEPTH WL **FORMATION ANn_ A?_ S;ARtNG DA D~Z eEARING 6946.0 8.0C 6~48.0 8.0C 695C.0 8.00 6952.0 8.00 6954,0 6960.0 8.OC 6962,0 6964.0 6966,0 8.0~ 6970.0 8 .OC 697~ .0 8.Og 6974.0 8.OC 6976.0 8.0~ 6978.0 6980.0 698~., O 6~8~,0 8.0~ 6988.0 8.0C 6990.0 8.CO 6992.0 8,00 6996,C 8,0u 6998.0 8.00 7002,0 8.0C 7004.0 8.00 7006.0 8.oe 7008.0 8,0C 7010.0 8.06 7014.0 8.00 7016.0 8.06 7020 .O 8.0C 7022.0 8.00 70~8.0 8.00 70~2.C 8.0C 7034,0 8,OC 7036.0 8.00 7038.0 8.00 7040.0 8.0C 7042.0 8.00 7044.0 8.3C 7046,0 8.00 4,1 9-~ S ~5 E 130 16.8 153 S 27 E 100 I'~., , 4 64 N ~4 ,.= 10',.3 14,3 106 S 74 5 100 3.7 t20 S 60 12.0 85 N 85 E I,~''''' 14.8 9:0 N 90 E 100 13.7 97 S 83 E 100 15.8 50 N 50 E !OO 5. 8 105 S 75 4.1 26 N 26 E 87 21.1 333 N 27 W 59 ~ ~ 5 ~,'5 ~$ 1Cu ~ 6 3 N 3 F- luO 1.8 271 N 89 W !00 3.7 231 S 51 w 65 11.3 191 S 1t W 10C 11.9 1,87 S 7 ~' 100 !9.6 350 N 1C ~,~ 67 19.3 336 N 2A~ W 1'00 18.5 356 N 4 W 100 8.7 303 N 57 N 180 9.9 298 N 62 W 10C' 4.5 ~_34 S 54 N 1CC 1C.3 244 S 64 w 10 5.1 250 S 70 W 1 CO 4.8 184 S 4 W 100 1C,$ 2!8 S 38 W 6.9 11,2 158 S 22 1C.4 1,53 S 17 E 15.~, 155, S 15.~, 117 S 6:3 £ 63 1 2.4 61 N ~ 1 E 1 CO 16.0 131 S 49 ~ 53 22.7 17'9 S I E 77 8.4 120 S 60 E 1CL'''~ 4,4 129 S 51 ~ 100 17.1 309 N 51 W 100 14,5 347 N 13 W t00 14,7 183 S 3 W 14.7 182 S 2 14.7 182 S 2 W 14,7 162 S 2 W 14.7 182 S 2 w !4.7 17,2 S 2 14.7 183 S 3 14.7 183 S 3 W 14.6 183 S 3 1~.7 1 83 S 3 14.6 1~3 S 3 14.6 t,~3 S 3 W 14.6 183 S 3 W 14.6 183 S 3 w 14.~ 1;~3 S 3 W I 4.6 I ~; ~ S m W 14.6. 183 S 3 W 14.5 183 S 3 w 14.e 182 S 2 W t4,~ 153 S 3 w 14 ~ 18~ S 3 W 1 4._~ 1 ~:~ ~ ~ ~ W 14.5 18~ S & W 14.3 183 S 7 W 14.4 1,~2 S 2 W 1~.3 164 S 4 W 14.3 184 S 4 W 14.3 184 S 4 W 14. ~ ~ 1~3 ~ 3 W 14.3 !~ S 4 14.3 183 S 3 14.2 1~,4 S 4 W 14.2 1..,, 5 S 14.2 1~4 S 4 W 1&.2 185 S ~ W 14.2 184 S ~ W 14.~ 184 S 4 14.2 l~q S 4 14.2 1~4 S 4 W 14.1 1~ S MARATHON OIL CO. STEELHEAD M-2 MCARTHUR RIVER KENAI 08,/24/87 ALASKA DEPTH WL **=ORMATiON DIP** $~NG AZ ~EA~ING GRADE ****SCREMCLE***** 7050.0 7052.0 7056,0 7058.0 7060.0 7062.0 7064.0 7068.,.'"" 7072.0 7074 n 7076.0 7n78 0 ,.,.., . 7080.0 7n82 ~ 7084 .O 7086,0 7088.0 7092,0 7094 .O 7096,0 7100 n 7102.0 7t04.0 7106.0 7108,0 7110,0 7112.0 7114,0 7t16,0 71!8.0 71 20.0 7122.0 7124.0 7126.0 7128.0 7130.0 7132.0 7134.0 7136.0 7138.0 8.00 8.00 8.0.6 8.00 ~ CC Nc I 8.00 8.0C 8.0C 8,00 8.00 8.0C 8.00 8 8.00 8.00 8 · nC ~.~, 8.0C 8.0C 8. OC 8.00 00 8 · "'" 0 8.00 8.00 8.0C 8,00 8.0C 8.00. 8.00 8.06 8.00 8.0C 8.00 8.00 8.0C 4.0 346 N 12 ~, 51 3.9 348 N 1 2 W 59 4.2 36 N 38 E 100 12.2 48 N 48 E 67 21.6 I N 1 E 100 22,2 1 N 1 E 100 11.7 42 N 42 E 74 11.5 SO N 80 E 1'30 6,1 8t N 81 E 100 5 ~ 125 S =5 = 100 5 3 172 S = ~ 100 6.7 1 86 S 6 ~' 100 15.4 1:~..~ S 4P E 95 I C · 0 159 S 21 19.0 16~ .S 13 E 68 3.6 60 N 60 E !CC 24.3 30 N 30 E 72 2 4 t3 N 13 4.0 I 2 N I 9 75 N 10.6 62 N 6 14.9 33 N 33 E 10~ I~ 6 ~, N ,'~ E 100 5 I ~1 ~ 6 252 S 72 w 100 18,9 245 S 65 W 6~ 18.7 22 N 2~ E !03 1~.2 22 N 22 E 73 23.1 63 N 63 E 52 13.U 229 S 49 W 1~0 18.0 239 S 59 W 1C0 13.6 176 S 4 E 13.5 149 S 31 E 6o 14. 0 137- S 4 4.2 205 S 25 ~ 88 5.5 133 S 4.~. 157 S 23 E lm3u ~.1 t86 ~ ~ w 1~a 12 5 175 S ~ ~- 1n~' 9.6 165 S 15 E 100 14.1 1F¢4 S 4 x 14.1 I ~4 S 4 w 14 "'" 1~,3 S ~ i~ 14.0 15~, s 4 W 14.0 1 84 S 4 W 14.0 184 S 4 W 1= ~ 184 S 4 W' 13.7 185 S S W 15,9 1&4 S 4 W 13.9 185 S 5 ~ 13.9 1,~5 S 5 w 13.9 185 S 5 w 13.~' 1~5 S 5 w 1~ R 1~6 S 6 w 13.6 18,7 S 7 W 13.7 ! 87 S 7 W 13.6 187 S 7 W 13.6 18.8 S 8 ,~ 13.6 188 S S W 1~.7. 1~~,~ S ,~ W 13.6 187 S ~ w 1].5 1F¢7 S 7 W 1TM 8 , ~,.~ I 8 q 8 W 13.5 1~7 .S 7 W I~, c 1~7 S 7 W 13.4 187 S 7 W 1~.4 !87 S 7 W 13.3 1~7 S 7 W 13 4 1¢7 S 7 W 1~ . 4 1~7~ S 7 W 13.5 186 S 6 W 13 c 1~ S ~ w 1~ . & 1~,6~ S 6 W 13.4 187 S 7 W 13.4 1~-7 S 7 W 13.5 187 S 7 ;-~ 13.4 13~ S 6 W 13.4 186 S ,5 W 1~..~ 187 ~_ 7 '~4 1~_,, . 4 185 S 5 W P~GE 57 MARATHON OIL C STEELH~AD MCARTHUR RIVER K~NAi ©8174187 ALASKA OEOTH WL **~ORMATION DIP** ANG AZ BEARING GRADE 71,40.0 7142.0 7144,. 0 7146.0 7148.0 7152.0 7154.0 7156.0 7158.0 7162.0 7164.0 7166.0 7168,0 7170.0 7172.0 7174.0 7178.0 7180.0 7182.0 71:86. O 7188.0 7194.r',. ~- 71~6,0 7198.0 7 20C.,,0 7202,0 7204.0 7206.0 7208.9 7210,0 7212,0 7214,0 7216,0 7218.,0 722C.0 7222,0 7224.0 7226.0 7230.0 723Z .0 e~ 8.00 8.00 8.00 8.00 8,CC 8.0C 8.0 8.0C 8.00 ~ OC 8.00 8 8. O0 8.06 8, .OO 8.00 8.00 8.0C 8.00 8.00 8.0C ~: O0 8,00 8.00 8.00 8.00 8.00 8.0C 8.0C 8 .Or' 8.OC 8.00 13.3 1~6 S 24 E 1~. . 1 16:9 12.6 154 S 26 E 1.~ 17 6 147 ~ 313 $ t'* 11.0 97 S 83 E 100 6.7 65 N 65 E t00 18 · 1 183 S 3 W 62 2.7 170 S 10 E 100 3.8 1~1 S 39 E 1 5.2 114 S 66 E t00 ~.2 123 S 57 E 100 ~.8 126 ~ 54 :_= I~uO 1C.5 38 N ~8- ~: lnO~ · 5,9 29 N 2~ a !00 1C,1 170 S 10 E 100 11.2 157 S 23 : 100 22,5 1 73 S 7 6,3 155 S 25 E 65 t6,4 1~0 S 20 E 100 5,1 78 N 78 5,4 81 N 9,9 352 N 8 W 103 2~,6 333 N 27 W 71 18,7 321 N ]9 w 100 24,8 333 N 27 W 10'8 1C:.2 300 N 60 ~ lOC. 5,4 17° S 1 ~ 1~ 6.2 164 S 1~ ~ 100 6.8 165 S 15 E 1CC 3.5 61 N 61 Z 100 ~ ~ 50 N ~C ~ 10~ 15.5 1~4 S ~5 E 100 1 4.1 225 13.8 243 S 63 w 69 16,4 244 S 15.5 241 S 61 W 100 1~,9 2~9 S 59 W 1CC. 14.6 2!S S 12,5 167 S 1S ~ 100 25,S 186 S 6 W 79 1= 4 1&5 ~ 5 1'~ 4 1~ $ 6 W 1~.~ 1~'~ ~ 6 W 13 4 I~ S 6 W i '~' ' 13.~ 1 R5 S ~ W 13.3 185 S 5 W 13.3 186 S 6 W 13.3 185 S 5 ~: 13.2 185 S 5 W 13.1 186 S 6 W 1~.~ 186 S 6 W t3.1 1~'~5 S 5 W 1= 1 186 S 6 W 1 3 . 1 1 S 6 S 6 W 13,1 186 S 6 w 13.0 186 S 6 W 13.0 18~ S 6 W 1].0 186 S 6 w I= n 186 S 6 w 13.0 1~S7 S 7 w I],E 186 S 6 w 12.9 1~6 S 6 W 12.g 186 S 6 W 12.9 1157 S 7 W 12,8 18a, S 6 N 12.8 1 ~7 S 7 W 12,g 18~ S 7 N ..~ 1~7 ~ 7 w 1~.0 167 S 7 W ~.~ 187 S 7 w 13.1 188 S ~, w 13.C 187 S 7 w 13.0 18~ S 7 '~ 13.0 t ~;7 S 7 w 13.0 188 S ~ w 1~ . C 187 S 7 W I~ ~ 1~5~: ~ ~ '~ M'.~RATHON OIL CO. STEELHEAO M-2 MCARTHUR RIVER KENAI O8124t87 ALASKA D~PTH WL ~NG A* ~=~RZNG GR~D~ ****BCR:MCLE****~ £AZ E~ARING 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 72 73 73 73 73 73 73 73 73 36.0 38.0 40,0 42,0 44.0 46,0 48,0 50,0 52,0 54,0 58,0 60.0 66.0 70.0 72,0 74.0 76,0 78,0 80.0 ~ 2 · 0 84,0 86.0 90.0 92.0 94.0 g6.0 98.0 riO.n 02.0 04.0 06.G 08 · 10,0 12,0 14.0 t8.0 8.0C 8.0C 8. OC 8.00 8.06 8.00 8.00 8.00 8.00 8.00 8.00 8.0C 8.00 8.00 8,00 8.00 8.00 8.00 8..00 8.OC 8.00 8.OC 8.0C 8.0"' 8.0C 8.00 8.0C 8.00 8.00 8,00 8.00 8.00 8.00 8.0C 8.0C ~ OC ,,,,," i 8. OC 14 ~ 196 ..~ ~ ~ luO .~,u 197 S 17 N 10''~ 18.6 193 S 13 W !00 15.7 208 S 16,0 195 S 16 W 1CC 5.9 230 S 50 w 1C0 8.0 219 S ]9 w t0C 20.6 162 S 18 8 59 1C.1 154 S 26 8.7 265 S 85 >J 100 1~ ~ 19~ S 6.8 161 :S 1:9 E 100 7.8 t88 21.4 159 S 21 13.6 185 S 8 ~. 100 19.3 222 S 42 W 96 10.2 23~. S 8.9 229 S 49 W 1 7.5 193 S 13 W 1C0 8.3. 155 S 25 E !00 4.7 207 S 27 ~ t00 2.] 196 S 16 W 100 1.0 207 S 27 W 100 4.9 45 N 45 E 100 6.~ 89 N :89 E 10C I= ¢ 1'~ ~,~4 S ~6 ~ 9~ 12.6 171 S 9 ~ 83 11.5 207 S -'7 N 100 6.5 244 S 12.2 ~1 N Cl ~ 100 3.7 352 N ~ w 85 5.6 131 S 49 E 100 1~ 6 13~ . u S 5u E 8.8 97 S ~3 E 9~ 21,6 9~ S 82 5 83 4,6 349 N 11 ~ 100 24,0 41 N 41 E 68 13,2 2'9~ N ~5 ;~ 72 26.9 339 N 21 13.2 189 $ 9 w 13.0 189 S 9 w 15.1 156 S 8 w 13.0 18,S S 8 w 13,0 18,;3 S 8 w 1~,0 1~3 S ~ w 13.0 188 S ~ w 12.9 188 S 8 w 12,9 1~9 S 9 w 12,9 123 S 8 w 12,9 188 S ~ w !2.9 188 S 8 ~ 12.9 !88 S 8 w 12.9 18~ S 8 N 12.g 188 S ,$ N 12.9 13,~ S ~ w ,,,.9 1,~. 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MC~RTHUR RIVER KENAI 08/2Z,/87 ALASKA DEPTH WL **FORMATION Dim** ANG AZ BE.bRING GR,.DE C& C~7 8=ARING 73 73 73 73 73 73 73 73 73 73 73 73 73 73 73 73 73 73 73 73 73 ,73 73 73 73 73 73 73 74 74 74 74 74 74 74 20.0 22.0 26.0 28.0 3C.0 32 .C 38.0 54.0 56.0 58.0 ~2.0 64.0 6~ n 7C.0 72.0 80.0 84. u 86.0 88.0 90.0 92.0 94.0 96.0 98.0 OC .C 02.0 0~.0 06.0 08.0 12.0 1~.0 16.0 8.OC 8,00 8.0C 6.00 8 8.00 8.0O 8,00 8.00 8,00 8.uC 8.0C 8.0C 8.0C 8.00 8,00 8.00 8,00 8.00 8.00 8.CC 8.0S 8.06 8.00 8.0C 8.0C 8.0C 8.0C 8.00 3.6 223 S 43 W 2.6 197 S 1 2!.0 105 S 75 ~ 7 141 13.5 204 S 2.8. 89 N ~.6 2 N 2 E 5.8 38 N 38 E ~ 5 41 N 41 t;.1 550 N 10 W 5.6 ~0 N 7,5 126 0,1 t38 S 42 E 12,~ 167 11,5 184 S 4 W 10.5 88 N 88 E 8.9 337 N 23 22.8 324 N 25.1 340 N 20 W 24,8 341 N I 7,6 109 4 0 12~ S 17.1 151 S 17.1 157 S 23 10,1 1~9 S 41 E 1!,0 154 S 26 12.6 135 S 45 E 13.8 146 S 21,0 99 S 21,4 97 S 83 E 25.6 151 S 2g E ~.2 211 S 12,9 196 S t6 W 5.9 177 S 3 E 8,5 2O3 S ~ W C. 7 249 S 69 W 1C.7 302 N 58 W 18 0 350 N I . ~ W 22.~ 265 $ ~ w I 00 100' 100 100 100 103 100 I O !'3 $ t 10C 100 99 9g 67 79 100 10O 1~0 1~0 1C~ 75 7t 10C 10C uO 1 -8,3 100 100 72 12.~ 188 S ~ w 12.7 1 ~9 'S 9 w 1 2.7 189 S ~ 'w t2.8 18,9 S ,~ w 12.~ 188 S .~ ~' 12.~ 159 S ~ w 1~ 7 190 S 1¢ w 12.7 190 S 10 w 12.0 190 S 10 w 12.5 190 S 10 w 12.~ 1~0 S 1C N 12.6 19'0 S 10 N 12.6 190 S 10 ~ 12.7 190 S 10 W 12.5 190 S 1m ~- W 12.4 t93 S 10 ~ 12.5 190 S 10 W 12.6 190 S 10 ~ 12.7 190 S 10 w 12.6 191 S 11 w t2.¢ 191 S 11 W 12..8 191 S 11 ~ 12.~ 1~1 S 11 w 12.7 192 S 12 w 12.6 191 S 11 W 12.5 190 S 10 k 12.7 192 S 12 ~ 12.5 1;1 S 11 ~ t2.~ 192 S 12 W 12.6 192 S 12 W 12.5 !91 S 11 W 12.5 t91 S 11 w 12.5 I~1 S 11 W 12.6 192 S 12 ~ 12.5 I~2 S 12 ~4 12.3 191 S 11 ~ 12.4 192 S 12 W 12.4 192 S 12 ~ 12.4 t92 S 12 W MARATHON .qTEELH;A KENAI 08124187 OIL CO, M-2 RIVER ~LASKA DEPTH NL **~ORM&T~' . . ~vN DTp** AT_ ~=EARTNc. .~ GR~CE ****BC~E~CL£***** CA CAZ BEARING 74t8,0 7420,0 7422,0 7424.0 7426,0 7428.0 7430,0 7432,0 7434.0 7436.0 7438.0 7440.0 7442.0 7444.0 7446.0 7448.0 7450,0 7452.0 7~54.0 7456,0 7~58,0 7460,0 7~62,0 ?~64.0 7466.0 7468.0 7470,0 7472,0 7474,0 7475,0 7478,0 8.0£ 8,00 8,00 8,00 8.06 ,8. 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OC 8,00 8,0C 8.00 8,00 8,0C 8,00 8, OC.' 8.00 17 ~' ~63 S _ ~, W 100 ld.8 250 S 70 W 100 14.5 259 S 79 11,6 227 S 47 W !00 12.0 212 S 32 k 1C0 1~ 4 200 S 2,~ W 1,jO 10,8 186 .S 6 W 100 5.1 172 S 8. 1~,9 t65 S 15 E 100 5.1 18.5 S 5 k 10:3 a,3 186 S 6 k 100 12,3 !76 S ~ :E 100 5,1 171 S 9 E 100 2,0 145 S ~ E 100 4.1 152 S 2e ~ leo 8,5 152 S 28 11.1 ~01 S 21 W 100 11.9 233 S 55 W 57 12.2 218 S 3,8 W 100 7.1 225 5 45 W 103 ~.6 178 S 2 E !00 7.3 191 S 11 ~ 100 2.! 132 S 4cq E 100 4.6 1 5~ S 4 2 19~ ~ 16 W 10~ 6.~ 203 S 23 w 100 1C. 2 212 S 14,5 !4 N 14 E 100 1.5 323 N 37 W 1CO ~5.0 70 N 7C E 100 12.2 lg~1 12.2 192 12.3 192 12,3 191 12,4 192 12.4 192 12,3 192 12,1 192 12,2 192 I 2.2 192 12,2 191 12,3 192 12,3 191 12,3 192 12.3 192 12,4 192 12,3 1-~2 12.1 192 1£.0 1~3 12.0 193 1! .9 173 11.9 193 1! .~ 193 11 .~ 193 1! .~, 1:~3 11 .,~. t93 tl .7 193 11.7 1~3 11 .7 1:93 11,7 193 tl ,~ 1~ S 11 W S 12 W S 12 W S ti w S 12 W S 12 W S 12 W S 12 W S 12 W S 12 w S 11 W S 12 w S 11 W SlP_ W S 12 '~ S 17 w S 12 W S t2 w S 13 '~ S 13 w S 13 W S 13 W S 13 ~ S 1~ '~ S 1~ w S 13 W S 13 w S 13 w S 13 w S 13 w S 13 W '* REEL HEADER *~ REEL NAME': DATE : ORIGIN : FSYS SERVICE NAME: BITL!S REEL CONTINUATION NUMBER: 01 PREVIOUS REEL N~E : COMMENTS: DRESSER ATLAS LiS CUSTOMER TAPE --- CRE~TEr~ EY SCS =~.OG2~M R 2.C LENGTH..:. 132 BYTES ~* T/tOE HEADER ** TAPE N.4ME : DATE : ORIGIN : FSYS SERVICE NAME: M~iN TAPE CONTINU~T.ION NUMBER: 01 PREVIOUS TAPE Nh,NE : COMMENTS: LENGTH: 132 ~'YTES ** FiLE HEADER # 1 ** FILE NAME: MaIN .GO1 SERVICE NAM;' V:RSION ~ : 1 D~TE: 55111/2C MAX RECO~D LENGTh: 102~ BYTES FILE TYPE: LO PREVIOUS FILE NAPE: . ** INFCRMATiCN RECORDS MNEM CONTENTS ~DIN : 5073320389 '~ CN : MARATHON OIL COMPANY WN : STEELHEAD PLATFORM M-2 FN : MC ARTHUR RIVER COUN : KENAi STAT : ALASK~ LCD : 150.00 ** FORMAT ** UNITS ENTRY BLOCKS TYP$ ENTRY GESCRIPTiON mmmI 8 g, 11 C 1 DEPTHS DECREASE 6C.0 FRAME SPACING .lIN FRAME SPACING UNITS 12 M~XIMUM FRAMES/RECORD TERMZNATOR -0.500 LEVEL SPACING D~TUM SPECIFICATION BLOCKS CURVE NAME C4LD REPR CODE SIZE SAMmLE ~NITS 68 4 1 IN CURVE N~ME CON REPR CC3E SIZE SAMPLE UNITS lmmI Immm ii----! 6.8 4 1 , ~N .... 68 4 I % CORR 65 4 1 G/C3 OEN 68 4 I G/C3 GRO 6~ 4 I ~I PORO 68 4 I % LSN 68 4 I CmS SSN 68 4 1 CPS GR 58 4 1 ~PI RDC 68 ~ 1 RS 68 4 I C~MM RD 68 ~ I OHMM RT 68 4 I CHMM sp 68 4 I Mv DZ 68 4 1 RMLL 68 4 I CHMM CAL 68 4 1 IN RSC 68 4 I FORMAT ** ENTRY BLOCKS TYPE ENTRY D=.SCRIDTION 4 I C~PTHS 8 60,0 FR r~E SP.~CING 9 ,lin FRAME SmACZNG UNITS 11 12 MAXIMUM FRAM=_S/RECORg 0 TERMINATOR -0,500 LEVEL SPACING gATUM SPECI.=ICATICN 8LOCKS CURVE REPR CURVE REPR NAME CODE SIZ] S~MPL5 UNITS NAME COCE SIZE mm--I ii.! ii.-- .III C~LD 65 4 I IN CON 6~ 4 CN 68 ~ I % CO~q ~8 ~ 3EN 68 4 1 G/C3 GRD 63 4 PORO 68 4 I % LSN 6a 4 SSN 68 4 I CPS G~ ~8 4 ~DC 85 ~ 1 RS 6B 4 RD 68 4 1 C~MM RT c8 4 Sm 68 4 I MV O! 68 4 RMLL 68 4 I OHMM CAL 68 4 RSC 68 4 1 DEPTH 7485.000 FT 2281.433C M CALD 11,518 CON 12,410 CN BEN 2.5C0 GRD 57,723 PORD SSN 209,979 GR -9999.000 RDC RD -9999,CC0 RT -9999,0eC SP RMLL -~999,C00 CAL -999'~.C00 RSC BEPTH 7400.CC0 F-'T 2255.525C M i ! I I i i I I i i i m ! I ! i ! CALD 16,954 CON 32,713 CN DEN 2,156 GRO 9C,575 PORO SSN 132,173 GR 78,418 ROC RD 91646 RT I 3,974 .SP RMLL 3,004 CAL 15,545 RSC DEPTH 7300.CC0 FT 2225.044C M CALD 21 ,735 CON 181,942 CN DEN 1 ,514 GRD 31,967 PORD SSN 1~4,744 GR 66,121 RDC RD 8,452 RT 12,54.8 SP RMLL 3,359 CAL 17,233 RSC 15,000 9.078 -9999.0CC -9999.0CC -9999.0CC 38,93C 29,935 10,54~ -37,677 6.744 1C1.494 68.823 9,458 -38.2~2 6,1E5 UNITS 1 1 G/C3 I APl 1 C~5 1 ~Di I C HMM 1 C ~ ~'! M CORR 0.£27 LSN 35,481 RS 5.635 OI 37,690 CORR 0,055 LSN 20.460 RS 4,922 Ol 41,926 DEPTH 7200.C00 FT 2194.5640 M CALD 14,608 CCN 35 DEN 2.207 GRD 63 SSN 119.623 GR 94 RD 8.188 RT 10 RMLL 1,751 CAL 14 DEPTH 7100.C00 FT 2164.084C 1'4 CALD 14.C85 CCN 41 DEN 2.263 GRD 61 SSN " 122.143 GR 79 RD 13.844 RT t8 RMLL 1,160 CXL 13 DEPTH 7000.CC0 VT 2133.604C M CALD 15.038 CCH 20 DEN 2.455 GR3 56 SSN 179.529 GR 87 RD 13.439 RT 18 RML,L 2,C66 C~L DEPTH 6900.CCC FT 2103.1240 t,.; I ! i I i I ! I I i I I I I ! ! C~.LD 15,367 CCN 34 DEN 2,412 GRO 96 SSN 154.435 GR 57 RD 26 ~2 RT 3~ RMLL 0.5~2 C6L 15 DF-PTH 6800.C00 FT 2072.644C M CALD 12.51:4 CCN 25 DEN 2.237 GRD 54 SSN 162.143 GR 48 RD 9.532 RT 14 RMLL 4.419 C~L 12 DEPTH 6700. CC'O FT 2042.16~0 CALD 12.670 CCN 26 DEN 2.400 GRD 64 SSN 140.711 GR 85 RD 10.~20 RT 16 RMLL 4 242 CAL 1 . OEPTH 6600.0G0 FT 2Cl1.6~C M CALD 12.875 CCN 28 DEN 2,407 GRD 87 SSN 175,160 GR 44 RD 11.314 RT 15 RMLL 3.862 C~L 12 OF--'PTH 6500.0C0 FT 1981.2040 M CALD 13.131 CCN 30 OEN 2.402 GRD 89 SSN 125.434 GR 80 RO 8.797 RT 12 RMLL 3,934 C~L 13 DePTH 64C0.CC0 FT 1950.7240 M .309 ,472 .882 .992 .850 ,926 .221 .115 .542 .177 .561 .219 .17,7 .7.~ 2 .352 .3~ .87.5 . 3~ L.¢ 1 . ~, ,,.,, .2~,~, .....~ ,247 .C75 ~74 .761 .500 .100 .488 .113 .427 ,$92 .731 .721 .495 .913 .7r~3 .245 .0/-,. 5 .067 CN PORD RDC SP RSC CN PORD RDC SP RSC CN RDC SP RSC CN PORD ~DC S~ RSC ~,N PORO RCC S~ RSC CN PORD ROC SP ~SC CN PORD RDC SP RSC CN PORD SP RSC 40.939 2d.83C 9.114 -33.053 7.318 47.4~7 23.47¢ 15.06¢ -2¢.399 10.626 24.942 11.702 14'.4~3 -20.406 10.22c 40.172 1~.435 29.377 -L.333 19.C~C 2,9 25 1C.22o 4.13~ 3C.~.05 15,136 11.783 11.876 7.172 33.447 14.735 12.168 17.440 8.641 35.585 15.015 G.396 -0.806 ~,~2= CORR LSN RS DI CORR LSN RS Ci CORR LSN qS £i CORR LSN RS CORR LSN CI CORR LSN RS BI CORR LSN RS Dl CORR LSN RS Ci 0.146 26.255 5.905 22.29'~ C .022 3C.011 8.920 23.1~2 O,IE1 57.50~ 8.7c0 25.60~ G,044 15.142 21 .149 C.014 5C.C$7 5.566 54.308 0.194 41 .~63 6.039 47.510 O. 50.676 7. 33.483 C.224 30.213 =.666 42.753 CALD 14.363 CCN 41.404 DEN 2.177 GRO 77.876 SSN 149.605 GR 85.707 RD 5.307 7.O52 RMLL 0.802 DEPTH 6300.00 0 FT 1920.2440 M CALO 13.040 CCN 24.089 DEN 2.298 GRD 42.623 SSN 202.692 GR 50.873 RD 7.925 RT 10.678 RMLL -- 4.150 C~L 13.037 DEPTH 6200. CCO FT 1889.764C M CALD 13.832 CCN 35.427 DEN 2.405 GRD 82.806 SSN 203.634 GR 88.049 RO 7.715 RT 8.94! RMLL 1.231 CAL 13.765 DEPTH 6100.CCO FT 1~59.2~C H C~LD 12.375 CCN 15.~4~ DEN 2.221 SR~ 3~.2~7 SSN 177.022 GR 85.225 RD 10.227 RT 14.496 RMLL 1.647 CAL 13.647 DEPTH._ 6000.C~0~ FT 1828.804C M C~LO 14.727 CCN 35.489 OEN 2.221 G~D ~2.118 SSN 130.409 GR 49.229 RD 25.378 RT 34.765 RMLL C.829 C~L 1~.533 DEPTH 5900.CC0 FT 1795.3240 M C~LO 1 5.34& CCN 39.648 DEN 2.307 GRD 51.149 SSN 151.171 GR ~0.048 RD 10.605 RT 1'4.789 RMLL 0.751 CAL 14.653 DEPTH 5800.C00 FT 1767.8440 M I --i CALD 12.750 CCN 10.738 DEN 2.432 GRO 41 SSN 178.667 GR ~7.370 PO 10.341 RT 14.258 RMLL I .267 CAL 14.469 DEPTH 5700. Cg 0 FT 1737.3640 M CALD 16.643 CCN 41.423 DEN 2.180 GRO 54.384 SSN 139.536 GR 31.950 RD 304.668 RT 379.153 RMLL 0.457 CAL 20.752 DEPTH 5600.C0 0 FT 1706.8540 M CALO DEN 13 2 CN PORD RDC SP RSC CN PORO RDC SP RSC CN ~C SP 23C CN FOR3 RDC SP RSC CN POR3 S~ RSC CN PORD RDC SP RSC CN PORD RDC SP RSC CN PORO ROC SP RSC .052 CCN 1~.691 CN .151 GRD 39.384 PORO 47.054 28.694 5.675 1.057 4.178 28.429 21.358 8.620 16.8C7 6.633 · -- 11.10~ 1';.11E 2~ .0£1 11.1C6 29.10c, 7.085 41 .1~9 ~_6.013 27.3~1 88.0~5 14.55~ 45.569 2:3.806 11.692 7.285 13.55Z 13.228 11.0~2 90.760 7.0.~5 47.722 28.5C4 299.893 141.766 22.~18 18.131 30.257 LSN CCRR L SN RS Ol CCRR LSN RS CI COR~ LSN LSN RS Ol CORR LSN RS DI COR~ LSN RS DI CORR LSN RS CZ CORR LSN 0.077 39.320 · z 6,~0 24.253 0.042 68.~6.6 37.704 C.170 11.146 C.120 68.769 5.919 29.?09 ~.275 33 11 .578 24.610 0.21C 36.951 6.010 25.140 0.105 69.354 6.127 27.355 C.064 31.918 17.793 28.152 0.057 66.584 SSN : 171.902 GR 60 RD 8.71 4 RT 1 2 RMLL 1 .182 C/~L 13 .133 .423 .898 DEPTH 5500.C00 FT 1676.4030 M CALD 17.941 CCN 70 DEN I .586 GRD 2,5 SSN 92.827 GR 42 RD 23.627 RT 31 RMLL 1 .653 C~L 14 .008 .100 .816 .041 .047 D=PTH "5400.CC0 FT 1645.9230 M SALD 12.565 CCN 26 ~EN 2 251 GRO 4~ SSN 166.498 GR 53 RD 3.788 RT ~ RMLL 4,669 CAL 12 .989 .731 .029 .5~5~ Or-PT~ 5300,CC0 FT 1615.4430 M CALO 13.119 CCN 1~ DEN 2.237 GRD C8 SSN 191.902 GR 53 RD 5.~34 RT 6 RMLL 4.077 C~L 12 .;14 .225 .A~7 .960 .84~ DEPTH 5~O0.CCC FT 1584.~63C ¢4 CALD 21.C24 CCN 136 DEN 1.374 GRD 19 SSN 90.659 GR 81 RD 8.627 RT 11 RMLL 1.572 CAL 13 .872 .221 .71 ..'-~ .4,~9 .$41 DEPTH 5100,000 FT 15~4,4836 N CALD 16.535 CCN 32 SEN 2.319 GRD 66 SSN 145.68] GR 69 RD 14,C01 RT 20 RMLL 1.368 CAL 14 .701 .474 .261 .843 DEPTH 5000.COO FT 1524.003C N CALD 13.743 CCN 28 DEN 2.339 GRD 73 SSN 113.446 GR 58 RD 11.429 RT 16 RMLL 4.476 CAL 13 ,800 .963 .803 .272 DEPTH 4900.600 FT 1493.523~ M I IIIlI llllill III! III! I CALD 19.271 CCN 97 DEN I .479 G~O 21 SSN 116.727 GR 39 RD 26.487 RT 35 RMLL 0,570 C~L 20 .446 ,~20 .267 .512 .122 DEPTH 4800,600 FT 1463.0430 M CALD 15.4~4 CCN DEN 2.350 GRD $SN 156.889 GR RD 14.029 RT 25.932 72.594 81.465 20.641 RDC SP RSC CN PORD RDC S~ RSC CN RDC S~ RSC CN ~DC SP R$C CN PO~C' S? RSC CN S~ CN PORO ROC SP RSC CN POR~ ROC SP RSC CN PORD RDC SP ~.522 146.522 5.915 74.86~ 64.487 25.619 150.771 1~.42~ 31.267 2&.183 159.257 3.477 20.63~ 25.01~ 6.0C$ 128.68E 5.1=1 127.379 77.376 9.317 146.009 7.042 3~.797 20.036 15.43~ 139.375 8.574 33.834 18.826 12.3~ 13~.028 7.653 97.979 70.964 29.142 142.754 16.481 31.338 18.2C0 15.571 163.294 DI CORR LSN RS CI CORR LSN RS CORR LSN RS LSN CCR~. LSN RS CCRR LSN RS 3I CORR LSN RS DI CORR LSN RS DI 4.958 28,834 14,.$19 1~,11~ 21 ,195 C .031 47.217 2.957 C . ,'~ ,-',, (,- C,022 ~7,277 4.428 C.O07 17.165 6.009 24.169 C.C$5 z9.657 7.031 29.368 0,055 26.15~ 6.515 4.6.6~ 0.009 27.405 13.110 22,606 0.156 4.~.233 7.599 33.2~4 RML.L 2.790 CAL 1 5 OEPTH 4700,000 FT t432,563C M CALD 19,849 CCN 32 BEN 2,432 GRD 87 SSN 134,859 GR 86 RD 13,4~8 RT 19 RMLL 0,551 CAL 20 DEPTH 4600,CCC FT 1402,083C M CALD " 16.905 CCN 29 DEN 2.354 GRD 68 SSN 143.614 GR 61 RD 10,7~3 RT 16 RMLL 1,579 CAL 16 C-EPTH 4'500,600 FT 1371,603C M CALD 16,553 CCN 16 OEN 2,315 GRD 46 S SN 1 89,4 53 Gr< 50 RD 12.701 RT 18 RMLL 1 .659 C~L !6 DEPTH 4400,CC0 FT 1341,123C M lImI--i--IIlIImIIl. II/--lI' CALD 13,5~9 CCN 17 DEN 2,326 GR~ 43 ~SN 20~. 511 GR ~ RD 25,387 RT 36 RMLL 2,21~ C&L !4 D~PTH 43~0,~ FT 1310,643C M ~'~LO~ ml_ ,5'7.S CCN 1*O- DEN 1,354 GRO 19 SSN 87,83~ GR 53 RO 1'3,305 RT I ~ RMLL 1,116 C'~L 18 DEPTH 42C0.CC0 FT 1280.163C M C4LD 14,490 CCN 21 DEN 2,251 GRD 47 SSN 214,249 GR 50 RO 9,044 RT 13 RMLL 3,801 C.4L 14 DEPTH 41GO,CCO FT 1249,633G N C~LD 13.809 CCN 22 DEN 2.190 GRD 53 SSN 236,620 GR 49 RD 14,849 RT 21 RMLL 2,189 CAL 13 DEPTH 4000.CC0 FT 1219.202C M C~LD 15.525 CCN 183 DEN 1,579 GRD 35 SSN 100,531 GR 59 RD 13.217. RT 20 RMLL 3,622 CAL 14 .899 ,074 .C38 .74~ ,513 .59C ,077 .C9'~,, .716 . .J .6~-~ .C25 ,313 ,C7~ ,849 ,203 .3C9 .9~3 ,191 ,659 .270 ,915 ,311 ,981 ,250 ,734 ,486 ,326 ,96~ ,!28 ,C39 ,442 ,622 ,486 ,739 RSC CN PORD RDC S~ RSC CN RDC $? RSC CN PORD ROC S~ RSC CN PCRC RDC Se RSC CN PORD RDC SP RSC CN PORD RDC SP RSC CN PO~D RDC RSC CN PORO RDC SP RSC 9.4~c 39,489 13,192 15,014 178,5~9 7,672 35,805 17,92C 12,036 135,61~ 6,731 2'?.6zC EC.321 14,1CC 1~2.874 8.1a~ 21.3C8 19.~31 27.346 163,01~ 1~.C4z 143.127 7E,554 14.871 1C3,869 13.7EC 26.71C 24.17~ 1C.03C 113.84(] 27,1C3 27,874 16,Q19 123,5CC 9,562 lC2,464 64,9C7 14.587 127,175 7,643 CORR LSN RS DI COR~ LSN RS SZ CORR LSN RS Si CC~R LSN RS CORR LSN RS CCRR LSN RS OI CORR LSN RS BI CORR LSN RS DI C.147 31.988 6.108 25.802 C ,147 35,946 5.413 C.135 6 C · 9 ,$ C 6. C;29 ~1 C.C21 73.~27 11.7~3 3'-j.564 -C.028 13.057 E.575 22.~83 0.066 83.270 5.439 C.06~ 98,501 8,138 3C.~3~ C,C14 17 ,c. 46 6,286 4~,549 DEPT'H 3900,C00 FT 1188,7220 M CALD 14,234 CCN OEN 2,221 GRO SSN 175,454 GR RD 17,727 RT RMLL 3,800 C~L 24,199 49,061 48.556 27,451 14,25~ DEPTH 3800.000 FT 1158.2420 M C,~LD 17,163 CCN 28.320 D=N,. 2.25'~., GeD 62. SSN '~ 185,330 GR 29,525 RD 3Z,432 RT 43,282 RMLL .0,789 C~L 1~,480 DEPTH 3700,CC0 FT 1127,762£ -- C~LD 14,711 CCN 27,345 DEN 2,251 GRD ~0.C85 SS~ 211,06~ GR ~D 11,7~0 RT 17,637 RMLL 3,761 C~L t~,225 ~EFTH 36£0,000 FT 1097,28ZC M ---- CALD 14,778 CCN 2~,204 CEN 2,217 GRD 49.~1 5 SSN 185,693 GR 72,927 RD 10,1~1 RT 13,5~3 RMLL I ,499 C~L 15,73~ OE~TH ~500.CC0 FT 1066.802C r. CALD 15,983 CCN DEN 2,249 GRD SSN 154,642 GR RO 12,225 RT RMLL I ,837 C~L DE.mTN 3400.C~0 25,929 68,108 64 18,076 16,234 FT 1036,3220 M C~LD 16,584 CCN DEN 2,270 GRO SSN 113,758 GR RD 11,215 RT RMLL 1,&85 C~L 35,745 72,~12 87,927 16,441 16,449 DEPTH 3300.0C0 FT 1005.842C CALD 17.015 CCN DEN 2.243 SSN 122,124 GR RD 6,720 RT RMLL 1,933 C~L M 3! .824 58,794 51 ,434 10,171 16,309 DEPTH 3200,0C0 FT 975,3621 CALO 14,439 CCN DEN 2,599 GRO SSN 168,231 GR RO 24,761 RT RMLL 2,638 C~L 10.698 ~4 7~1 46,251 14,C'15 BEPTH 3100.600 FT CN POR3 RDC RSC CN FORD RDC SP RSC c,~ P'ORE RDC SP RSC C N POI;: D S~ RSC CN PORD RDC SP RSC CN FORD RDC SP RSC CN PORC RDC SP RSC CN PORD RDC sP RSC 29,124 26,003 19.46C 135,156 g,b4~ 34.364 2~ 92~ ~c 592 157,319 21,295 32.~33 24.1cC 148.;47 7,907 24,904 26,233 11,0C~ 158.8~d 8,25C =1 ,47C 2/.,3C3 13,68C 119,7z, 2 8,078 41,957 23,041 12,552 137,247 7,564 3E.02C 24,654 7,474 119,6~2 4,358 14.070 3.088 26.481 134.419 13.12C CORR LSN RS OI CORR LSN RS OI CORR LSN RS COqR LSN RS 3I CORR LSN RS El CORR LSN RS DI CORR LSN RS DI CORR LSN RS OI 0.009 56.143 7.801 43.738 C.03C 49.771 16.92] 22.289 C.C12 66.~71 6,355 41 ,086 C. OJ'~, 6C.C56 23,5 ~c~. 0.117 ~7 50~ 6.436 31.010 0,063 25,232 ~.31 29,343 C.264 3.511 40.691 C.104 53,924 11.21~ 33,047 CALO CON DEN 2.242 GRD 68.447 SSN 136.637 GR 57,367 R'3 18.G18 RT 24.650 RMLL 0.727 C~L 16.285 DEPTH 30GO.CO0 FT 914.4019 M CALD 17.354 CCN 29.532 DEN 2.359 GRD 62.004 S SN I 44.2 99 GR 81 · 476 RD 10.824 RT 15.621 RMLL " 1.608 CAL 16.775 DEPTH 2900.000 FT 883.921~; M C~LD 14.734 CCN DEN 2.277 GRO SSN 173.616 GR RD 14.467 RT RHLL I .619 CAL 25.72~- 50.2z, 2 15.3"'~ DEPTH 2800.CC0 FT 853.4417 CALD 16,176 CCN SEN 1,703 GRO SSN 95,319 GR 22 9,514 RT RMLL 2.122 C~L 65.163 33.~24 61.23~ 14,153 15,761 BEPTH 2700.000 FT 822.9517 M CALD 15.514 CCN CEN 2.22~ GR2 SSN 148.22C GR RO 17.9~4 RT RMLL 4,354 CAL 33.65~ 54.279 47.C~0 27.d37 15.3~6 0 r-'pTH 2600.CC0 FT 792.4,517 C~,"LD 16.249 CCN DEN 2.204 GR3 SSN 186.~68 GR RD 7.877 RT RMLL 2.257 CAL 23,405 63,128 57.774 11.106 16.57~ OEPTH 2500.000 FT 762.0015 M CALD 16.784 CCN DEN 2,233 SSN 119,711 GR RD 25.286 RT RMLL 1.760 CAL ~ 472 62.965 23,793 34.526 17.402 DEPTH 2400.600 FT 731.5215 CALD 17.886 CCN BEN 2.274 GRO SSN 132.~05 GR RD 7.271 RT RMLL 1.757 CAL 42.313 64,344 62.161 10.421 17.275 DEPTH 2300.000 FT 701.C415 M CALD 15.659 DEN 2.180 CC N GRD 24.262 60.044 CN PORD RDC S.~ RSC CN PORD RDC SP RSC CN POR3 RDC SO RS~ CN RDC S~ RSC CN se CN F'ORD ROC SP RSC CN PO~D RDC SP RSr CN PORD RDC Sp RSC CN POR3 24.748 19.76a 132.910 11.341 ~5.705 17.637 11.2~1 152.573 7.187 3c.904 22.613 ld.OC.q 1~c.14c 1t'.074 7,..17= 57.39~ 10 ~'~7 120.152 6.429 3~.~§7 19.9cl 12~.514 10.633 28.827 27.009 8.790 132,337 6.303 51.7d9 25.24~ 2E.131 143.152 26.028 48.734 22.818 ~.094 135.982 5.494 29.580 2~.456 CORR LSN RS DI CCRR LSN RS DI LSk ~S Ci CCRR LSN Cl CCR~ LSN RS DI CCRR LSN RS Di CORP LSN RS Dl CORR LSN RS DI CORR LSN C.133 30.025 9.400 2~.177 C. 20'1 35 3C ,345 9.057' 2c.5~6 8.303 lC.~05 5.255 C.022 35.~,17 41 0.001 56.~70 5,035 3' C.103 £5.066 22.3~6 29.768 4.401 37.269 SN · 140.096 GR 0 11 .257 RT MLL 2.928 CAI O~PTH 2200.CC0 FT 670.561~ 55.182 17.344 15.378 RDC SP RSC 12.525 14C.041 6.763 RS OI 5.481 Z, 2.53b CALD 13,628 CCN DEN 2.225 GRD SSN 169.403 GR RD 4.841 RT RMLL 3.1 85 CAL 27.246 43.868 49.814 7.975 13.824 CN PORS RDC SP RSC 32.123 25.744 5.243 13t.2-66 3.542 CORR LSN RS DI 0.035 50.169 2.g59' 100.470 DEPTH '2100.000 F'"¢ 640.0813 C ',1 LO 13.593 CCN 2 C'EN 2.218 GRO 4 SSN I 73.54,5 GR 4 RD 5.8C9 RT RMLL 2.892 CAL 1 M 9.984 .5.344 7.143 8.985 3.584 CN POreD RDC S~ RSC 34.997 26.151 a.2a~ 132.37E 3.$51 C OR R LSN RS DI C.01¢ 3.236 6d.q17 DEPTH 2000 r- :? Oo .~c'O 6 601 ~ H CALD 16.728 CCN DEN 2.123 SSN 116.141 GR R3 7.063 RT RMLL 1.4~4 CAL 47 ~80 m ~ ~0.595 75.890 10.460 15.~39 ~N SP RSC 53.52,~ 31.91~ 7.770 134.5]C 4.497 LSN ~S OI 25.713 3.~5 35.¢.e2 OF-'PTH 1CO0.COC FT 5'79.1211 M CALD 12.639 CCN SEN 1.778 G~D SSN 104.7~7 GR RD 6.708 RT RMLL 2.601 C~L 57.43.9 34.134 57.651 7.230 13.499 CN PORS RDC SP RSC 61.854 52.~57 7.230 137.938 28.773 CORR LSN RS -3.922 23.985 EEPTH I 80 O. C 0 ¢__.., FT 548.6411 CALD 12.588 CCN 12 DEN 0.972 GRO 1 SSN 85.654 GR -999 RD -9999.C00 RT -999 RMLL -9999.C-00 C.&L 1 3.247 5 4~1 9.CCO 9.000 2.=88 CN RDC SP RSC 119.155 101.675 -9999.000 -9999.0CC -999g.006 CORR LSN RS Dl -1.34~ 11.&26 -9;99.000 -999~.000 DEPTH 1700.000 FT .518.1611 M C~LD 12.562 CCN 25.227 DEN 1 .322 GRD 25.452 SSN 114 160 GR -~ga OhO RO -~9o9 000 RT -9999 C~n . . · . · ~U RMLL -9999 CO0 CAL -9.999 uuO CN FORD RDC S~ RSC 29.393 -999~.00C -9999.00C -9999.000 CORR LSN RS 0i -1 .785 35.40~ -9009.000 -999c .OOO OEPTM 1600.CC0 FT 487.6809 M CALD 12.567 CCN 35.757 DEN 1.809 GRD 29.051 SSN 119.822 GR -9999.CC0 RD -9999.000 RT -9999.000 RMLL -9999.C09 C~L -9999.000 CN POR~ ROC SP RSC 40.401 5C.995 -9,99';.000 -9999.000 -9909.00C CORm LSN RS Ol -1.062 28.$26 -9999.000 -9999.000 DEPTH 1500.600 FT 457.2009 M CALD 12.558 CCN 87.273 DEN 1.620 GRO 33.03~ SSN 103.1 01 GR -999'~. 000 RD -9999.C~0 RT -9999.000 CN FORD ROC SP ED.O4C d2.39~ -9999.0CC -999~.000 . . CORR LSN RS OI -0.993 18.246 -9999.000 -9999.00C RMLL -9999.000 CAL -gggg.CO0 RSC -9999.0C0 DEPTH 1400.000 FT 426.720g M CALD 1 2.496 CCN 204.888 CN DEN 1 .630 GRD 15.120 FORD SSN 90.319 GR -9999.CC0 ROD RD -9999.000 RT -90"~9. 000 SP RMLL -9999.CCg C,~L -~)999.000 RSC DEPTH 1~57_., .EOm,.., F'r, 4.13.766~. M CALD -- 12.497 CCN 29.147 CN B=N,_ 1 . 4'~2.~ GRD 28 . ..~22 FORD SSN 84..992 GR -9999.Cos ROD RD -0999.C00 RT -9999.CC0 SP RMLL -9909.C00 CAL -9999.C00 RSC ST4RTING DEPTH = 74'85.000 FT · 22;B1.4330 ~4 ENDING DEPTH = 1357.500 ~-T 413.766S M ** FILE TRAILER FiLE NAME: M$iN .001 SERVICE NAME: VERSICN ~ : 1 DATE: 85/11/ MAXIMUM L=NGTH:~ 1 FILE TY~E: LC N;XT FILE NAME: 170.793 98.179 -9999.0CC -9999.000 -9990.00C 33.505 73.819 -990;.OCC -9999.0CC CORR LSN RS CORR LSN RS Di -1.~15 15.022 -9099.000 -999G.000 -1.1c;,. -9999.000 10 ** FiLE HE,DER ¢ 2 ** FILE N~ME: CNREPT.O02 SERVICE NAME: VERSION # : 1 DATE: 85/11/20 MAX RECORD LENGTH: 1~24 6YTES FiLE TYPE: LO PREVIOUS FILE N~ME: . .., ** INFORMATION RECORDS ** MNEM CONTENTS APIN : 5073320389 CN : M~R~THON OIL COMPANY WN : STEELHE~ PLATFORM M-2 FN : MC ~RTH~R RIVER COUN : KEN~ STAT : ALASLA LCD : 150.00 UNITS ** FORMAT ** TYPE 8 9 11 0 ENTRY ~LOCKS ENTRY EESCRIPTION 1 DEPTHS CECREASE 6C.g FRAME SPACING .liN FRANE SPACING UNITS 16 MAXIMUM FRaMES/RECORD TERMINATOR '-0.500 LEVEL SPACING 04TUM SPECIFICATION BLOCKS CURVE REPR NAME CODE SIZE S~MPLE UNITS iiIt iIml SSD 68 4 1 CPS CAL 68 4 1 IN LSN 68 4 I C~S TEMP 68 4 1 DEGF SPD 68 4 1 F/MN CORR 68 4 I G/C3 PORD 68 4 1 % ** FORMAT ** CURVE REPR NAME CCCE SiZE S~MPLE iIII ilii LSC 68 4 1 SSN 68 4 1 GR 6~ 4 I TTEN 68 4 1 DEN 68 4 1 CN 68 4 1 CCN 6a 4 1 UNITS CPS CPS LEF G/C3 % 11 ENTRY BLOCKS TYPE ENTRY DESCRIPTION 4 I DEPTHS O EC RE,~.S= 8 6C.0 F~AME S~CZNG 9 ,lIN FR~ SP~CiNG UNITS 11 16 ~Xt~UM FR2MES/RECCRD 0 T E RMZN~TO R -0. 500 LEVEL SPAC~N D~,TUM SPEC!FIC~.TION 8LOCKS CURVE REDR NAME CODE SiZE S~M=LE UNITS ImmI III-- II--I-- SSD 68 4 1 CPS CAL 68 4 1 IN LSN 68 4 1 C~S TEMP 68 4 I CEGF SP2 68 4 I F/MN CORR 68 4 I G/C3 PORO 68 4 1 % ** DATA ** DEPTH 7483.C00 FT 2280.823C M SSD 370.963 LSD LSN 83.992 GR SPD 0 C~'~ . ~, DEN PORD 9.1~0 CCN 304.970 61.643 2.~C0 12.151 D:PTH; 7400.CC0 FT 2255.525c. M SSD 433.740 LSD LSN 34.376 GR SmD 29.202 DEN PORD 31.474 CCN 298.375 94 ~1 2.131 33.304 OEPTH 7300.C00 FT 2225,0440 M SSD 570.545 LSD LSN 29.526 GR SPD 27.967 DEN PORD 71.619 CCN 544.472 39.581 1 .468 85.715 CAL TEMP CORR CAL T~M? CO~R CAL TEMP CORR CURVE REPR NSM: CC£E SIZE S$~PLE IiII --Il-- --II--II LSD d.~ 4 1 SSN 65 4 1 G~ 68 4 1 TTEN ~$ 4 1 DEN 6~ 4 1 CN- 68 4 1 CCN 6~ 4 1 12.37C SSN 8~6.1~4 TTEN C .OCt CN 16.0C4 SSN 9~0.635 TTEN 0.133 CN 20.267 SSN 10a¢.45C TTEN C.038 CN UNITS C$S CmS LBF G/C3 209.979 4037.797 15.C30 128.866 4049.114 3~.271 142. r',04 4049.431 56.561 DEPTH 7200.C60 FT 2194.564C M SSD 481.806 LSD LSN 26.681 GR SPD 29.587 DEN PORD 27.721 CCN 410,332 64,129 Z,193 40,314 CAL TEMP CORR DEPTH 7100.600 FT 2164.084C M SSD 4Q8,373 LSN 25,673 SPO 29,548 PORD 26,710 DEPTH 7051,500 FT LSD GR DEN CCN 395,551 65,812 ~3,998 2149,302C N CAL TEMP CORR SSD 654,935 LSD LSN 27,997 GR SPD 28,9Q7 DEN PORD 43,548 CCN 79~,~21 CAL 3O.ZDZ TEND 1.931 CO~R 68.373 STARTING., DEPTH : 7483.000 ~=T, 2~:~0~.,, .8230 M ENDING DEPTH = 7051.500 FT 214~.3C20 N ** FILE TR&ILER ** FiLE NAME: CNREPT.O02 SERVICE NAME: VERSION # : 1 DATE: 85/11/ M~XIMUM LENGTH: 1024 F~LE TY~ ~ .: LC NEXT FILE NAME: ** FILE HE~DER # 3 ** mILE NAME: DL-RE~.O03 SERVICE NAME: VERSION # : 1 DATE: 85/11/20 M&~ RECORD LENGTP: 102~ FiLE TYPE: LO PREVIOUS FILE NA~E: ** INFORMATIO~ RECORDS ** BYTES MNEM CONTENTS APIN : 50733203~9 CN : MARATHON OIL COMPANY WN : STEELMEAD PLATFORM N-2 FN : MC ~RTMUR RiVeR COUN : KENAI STAT : ALASKA LCC : 150,00 FORMAT ** UNITS TYPE 9 ENTRY BLOCKS ENTRY 1 60.0 ,1IN DESCRIPTION DEPTHS DECREASE FRAME SPACING FRAME SPACING UNITS 14,303 919,071 C,202 14,15C 1011,309 C.11C I ~ '~CC 1047.3~ C,232 SSN TTr-N CN SSN TTSN CN SSN TTE~ CN 124,20~ 4036,441 45,942 11~.74~' 3~38.Z!8 /-,,',~. 578 153,9~.5 3~$9,001 12 11 - 18 0 -C.ECO DATUM SPECIF MAXIMUM FRAMES/RECORD 'TERMINATOR LEVEL SPACING ICATION BLOCKS CURVE REPR NAME CODE SIZE SAMPLE UNITS CAL 68 4 I iN IS 68 4 I A ZD 68 4 1 ~ SP 68 4 I Mv TTEN 68 4 1 LBF RMLL 68 4 I OH~M RS 68 4 1 OHN~ ** FCRMAT ** CUqVE R;PR N~ME COCE SIZE SAMPLE ES ~8- 4 1 ED 68 4 1 GR 68 4 1 CHT 68 4 1 SPO 65 4 1 RS 68 4 I UNITS MV MV LBF :/MN OHNM 13 =NTRY :LOCKS TYPE ENTRY CESCRIPTION I II I 4 I ~EPTHS ~ECRE~SE 8 60.0 :RAME SPACING 9 .lin FRAME SPACING UNITS 11 !8 M~XiMUM FRAMES/RECCRC 0 TERMINATOR u~ L~V.L SmA ING CATUM SPECI=!CATION BLOCKS CURVE REPR NAME CODE SIZE SAMPLE LNITS CAL 68 4 I IN iS 68 4 1 iD 68 4 1 ~ 68 4 I MV TTEN 68 4 I L~F RMLL 68 4 I OHMM RO 68 4 I OHMM ** DATA ** DEPTH 7515.000 FT 2290.5776 M CAL 7.2~5 ES ID 325.468 GR TTEN 1744.426 SPD RD 10.786 215.728 O.CCO DEPTH 7500.000 FT 2286.005C M CAL 18.161 ES ID 325.468 GR TTEN 3674.223 SPO RD 10.786 215.728 40.536 22.174 DEPTH 7400.000 FT 2255.5256 M CAL 13.562 ES iD 167.220 GR TTEN 3777.767 SPD RD 10.786 95.590 89.CC2 24.962 CURVE REPR NAME CCDE SiZE ES ~8 4 ED 68 4 GR 68 4 CHT ~8 4 SPD 6~ 4 RS 58 4 IS SP RMLL IS SP RMLL IS SP RMLL 534.447 -2.074 C.72~ 534.447 -2.074 C.635 504.395 -28.6C7 2.455 1 1 1 1 1 1 CHT RS EB CbT RS ED CHT RS UNITS MV MV LBF F/MN OHMM 236. C'3c 344.216 15.115 236.039 1125,745 15.115 121.271 1165.494 7.097 OEPTH 7300.CCC FT 2225.0440 M CAL 18.357 ES 122.695 IO 13.015 GR 34.703 TTEN 3678.451 SPD 25.130 RD 158.688 IS SP RMLL CEPTH 7200.000 FT 21 94.5640 M CaL 14.541 ES iD 224.748 GR TTEN -' 3615.097 SmD 7.984 89.243 69.139 25.665 IS SP RMLL DEPTH CAL ID TTEN RD 7100.000 VT 2t64.0840 M 13.776 ES 236.t92 GR 3476.652 SPD 9.083 65.6c7 25.997 IS S~' R~LL DEPTH 705!.500 ~T 2149.3~20 M CAL 13.776 ES ID 235.~14 GR TTEN 3~76.652 SPD RO 9.C03 98.~0~ ~ IS 66.810 S° 25.997 RMLL STARTING DEPTH = 7515.000 FT ENDING DEPTH = 7051.500 FT 2290.5770 M 2149.3020 M 153.21~ -1 5.598 C.895 541.375 -17 1.029 718.937 -'2a .'71 7 C.53~ . ;. 717.928 -2.905 O.53a ED CbT RS ED CHT ~D CHT 2S ED CbT 138.636 1093.307 29.987 12,3.~60 1251.188 6.173 14~. 25,3 12a5.762 5.147 144.23C 1245.762 5.153 14 ** FILE TRAILER ** FILE NAME: DL-REP.O03 SERVICE N~ME: VERSION # : 1 DATE: 85/11/ MAXIMUM LENGTH: 1024 FILE TYPE: LO ~XT FILE NAME: ** TAPE TRAILER ** TAPE NAME: SERVICE NAME: OL-REP DATE: ...... ORIGIN OF DATA: FSYS TAPE CONTINUATION # NEXT TAPE NAME: COMMENTS: : 01 ** REEL. TRAILER ** REEL NAME: SERVICE N~ME: e, ITLIS DATE : ORIGIN O~ DATA: FSYS REEL CONTINUATION NEXT REEL N~NE: COMMENTS: DRESSER REEL HEA~ER - TAPE HEACER - FiLE HEACER - INFORMATION - FORMAT - : 01 ATLAS 1 1 3 3 6 LIS CUSTOMER T~PE --- CRE~TEC BY SDS PROGRAM R 2.0 TABLE DUMP - 3 FILE TRAILER - 3 TAPE TRAILER - 1 REEL TRAILER - I TOTAL R~CORDS: 1150