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Home My WebLink About190-138Wallace, Chris D (CED) From: Holly Tipton <hotipton@hilcorp.com> Sent: Friday, May 8, 2020 9:03 AM To: Wallace, Chris D (CED) Cc: Dan Marlowe Subject: M-27 Possible Tbg x IA Communication Attachments: M-27 90 Day TIO -May 2020.xlsx; M-27 Schematic 2012-06-29.doc Good morning Chris, We shut in Steelhead M-27 yesterday morning due to possible tubing x IA communication. Hilcorp requests 60 days to conduct well diagnostics. During that time we would bring this well back online as needed to conduct temperature surveys, wellhead test, etc. Attached are the well's schematic and 90 day TIO plot. Please let me know if you have any further questions. Holly Tipton Regulatory Tech - CIO Asset Team Hilcorp Alaska, LLC o: (907) 777-8330 1 m: (281) 543-8964 e: hotipton@hilcorp.com M • • Wallace, Chris D (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Monday, February 22, 2016 10:16 AM To: Wallace, Chris D (DOA) Cc: Trudi Hallett Subject: FW: Possible Csg Communication - Steelhead M-27 (PTD # 1901380) Attachments: M-27 Schematic 2012-06-29.doc; M-27 csg pressure testing.xlsx Hi Chris Wanted to give you an update and request a return to injection for the M-27 Steelhead injector. The well has been shut-in since you were last notified and our annulus pressure testing has been completed (see attached pressure testing record). The annular communication (OOA x 000A)we suspected was confirmed, although very minor in nature, as was the integrity of the tbg x IA, IA x OA and OA x OOA. As we still have tbg x IA and IA x OA integrity, we request to be allowed to return this well to injection with the existing downhole containment barriers. We will continue to monitor all wellhead pressures and would be glad to add this well to the AA well monitoring report so a monthly report would be sent to the state on its mechanical integrity. Please call me to discuss at your convenience. Larry SCANNED MAY 1 9 2016 777-8322 From: Trudi Hallett Sent: Thursday, February 04, 2016 3:21 PM To: Chris Wallace (Chris.Wallace@alaska.gov) Cc: Larry Greenstein Subject: Possible Csg Communication - Steelhead M-27 (PTD # 190-138) API No. 50-733-20423-00 Hi Chris— We(Hilcorp)would like to notify you that we may have a possible OA—OOA casing communication with the Steelhead Platform waterflood injector, M-27( PTD#190-138).The pressure increased—200 psi over a couple of days(ranging from 240 psi—535 psi). We did shut in the well to do some diagnostics and will keep you in the loop as we proceed. I have attached the pressure plot and wellbore schematic for your convenience. Please feel free to give Larry or myself a call if you have any questions or concerns. Thank you, Tru-o4. Trudi Hallett Operations Engineer Cook Inlet Offshore Asset Team Hilcorp Alaska,LLC 1 • • Wallace, Chris D (DOA) From: Trudi Hallett <thallett@hilcorp.com> Sent: Thursday, February 04, 2016 3:21 PM To: Wallace, Chris D (DOA) Cc: Larry Greenstein Subject: Possible Csg Communication - Steelhead M-27 (PTD# 190-138)API No. 50-733-20423-00 Attachments: M-27 Pressure Plot.xlsx; M-27 Schematic 2012-06-29.doc Hi Chris— We (Hilcorp)would like to notify you that we may have a possible OA—OOA casing communication with the Steelhead Platform waterflood injector, M-27( PTD#190-138).The pressure increased—200 psi over a couple of days(ranging from 240 psi—535 psi). We did shut in the well to do some diagnostics and will keep you in the loop as we proceed. I have attached the pressure plot and wellbore schematic for your convenience. Please feel free to give Larry or myself a call if you have any questions or concerns. Thank you, Trwoli. Trudi Hallett l Operations Engineer Cook Inlet Offshore Asset Team Hilcorp Alaska, LLC Hilcorp SCOW MAY 1 2Q16 A Company Built on Energy thallettAhilcorp.com 0: 907.777.8323 C: 907.301.6657 1 • .• 0 0 0 O 0 0 0 O 0 0 0 g 0 0 0 0 0 .-. 0 0 r-J 0 •• 1 1 - .-4 0 I, •-.4 .II 0 .1 --.1 — -b- ._. P IVIP . r 1 i t , .rx ..... a._ . . ..... ...... . - 0 o 7, ^I o ill c, c, Ir/ v...._.................... . ..... ..._ •—. rs. f.4 0 C) E ,D = M Uli j5:211 .-. 0 I- 1 ...". '....."1. ammigomm....- Y •••••.- 8 I AININ , 11.=..m.. . . .*-- .11•• ......-. 1'1— .- . .......... . .. -..........smom IS,.... .. .... ... ... .... . .,.................... .e. sm...-- L.."..." '"-`1•••••- ci. ln 0 -._ ' GO 0 o 0 0 0 0 0 0 O 0 0 0 0 0 O in 0 Lr, CD WI in ...I .-.. •-• .-4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ': E Z�q„'z&,� DATE: Tuesday, January 28, 2020 P.I. Supervisor �l q SUBJECT: Mechanical Integrity Tests Hilcorp Alaska LLC M-27 FROM: Austin McLeod TRADING BAY UNIT M-27 Petroleum Inspector Ste: Inspector Reviewed By:�n P.I. Supry NON -CONFIDENTIAL Comm Well Name TRADING BAY UNIT M-27 API Well Number 50-733-20423-00-00 Inspector Name: Austin McLeod Permit Number: 190-138-0 Inspection Date: 1/242020 Insp Num: mitSAM200128072446 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Inj Tubing M-27 Tyo503 03- 1503 PTD 1901380 Type Test I sPT Test psi 2239 - IA 213 2420 2415 - 241s - BBL Pumped: s.l 'BBL Returned: 49 OA 235 240. 240 - 240- Interval OTHER P/F Notes: MIT -IA. Soon after completing this test the operator discovered M-30 was due instead of M-27. Tuesday, January 28, 2020 Page 1 of 1 STATE OF ALASKA A•KA OIL AND GAS CONSERVATION COMMI•N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well Li Plug Perforations U Perforate U Other kJ R &R tubing / reoerforate Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 190 -138 - 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic ❑ Service 0 6. API Number: Anchorage, AK 99503 50 -733- 20423 -00 - "00 7. Property Designation (Lease Number): 8. Well Name and Number: Steelhead Platform / ADL0018730 - Trading Bay Unit / M -27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): t N/A McArthur River Field / Hemlock Oil, West Foreland Oil & Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 15,380 feet Plugs measured 14,240 feet true vertical 10,855 feet Junk measured N/A feet Effective Depth measured 14,240 feet Packer measured 12,555 & 14,250 feet true vertical 10,060 feet true vertical 9,013 & 10,067 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 1,332' 16" 1,412' 1,409' 2,630 psi 1,020 psi Surface 4,106' 13 -3/8" 4,185' 3,764' 3,090 psi 1,540 psi Intermediate 410' 10 -3/4" 487' 486' 5,860 psi 3,220 psi Production 13,156' 9 -5/8" 13,643' 6,870' 6,870 psi 4,760 psi Liner 1,928' 7" 15,379' 10,854' 8,160 psi RECEIVED Liner Perforation depth Measured depth See Attached Schematic feet JUL 0 6 20 12 True Vertical depth See Attached Schematic feet AO G C C Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6 # / L -80 12,552' (MD) 9,011' (TVD) 12,555'(M D) /9,013'(TVD) Packers and SSSV (type, measured and true vertical depth) Baker SB - Packer x 2 14,250'(MD)/10,067'(TVD) N/A N/A 12. Stimulation or cement squeeze summary: ��``�� JUL 2 } t' U Intervals treated (measured): > �J�lr' J 2 4 G iL N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 4,800 0 2,790 14. Attachments: 15. Well Class after work: „ Copies of Logs and Surveys Run Exploratory ❑ Development Service El Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ -g WINJ El WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -159 Contact Ted E. Kramer Printed Name Ted E. Kramer ,if,, Title Operations Engineer Signature �� v v Phone 907- 777 -8420 Date 7/6/2012 i 7/ RBDNIS JUL Oi 2012 fE 3--/ 1 7 / J Z Form 10 -404 Revised 11/2011 Submit Original Only • • McArthur River Field /TBU SCHEMATIC Steelhead Platform Hilcorp Alaska, IAA: Well No. M -27 Last Completed 6/6/2012 CASING DETAIL RKB to TBG Hanger = 74.35' Size WT GRADE CONN TOP BOTTOM L 16" 75 K -55 BTC 80' 1,412' 1 3 3/8" 61 K 55 BTC 79' 2,958' L 1 13 -3/8" 68 K -55 BTC 2,958' 4,185' 10 -3/4" 51 N -80 BTC 77' 487' 9 -5/8" 47 N -80 BTC 487' 6,909' 9 -5/8" 53.5 N -80 BTC 6,909' 13,643' 7" 29 N -80 TKC 13,468' 15,379' L TUBING DETAIL 4 -1/2" 12.6 L -80/ 13CR VAM -TOP 76.4' 12,551.7' JEWELRY DETAIL NO. Depth Item 1 504' Baker X -Lock w/ flow coupling above and below (3.750" ID) 2 2 12,462' Baker p Production Packer Model 194 47, s 3, 5-1/2" VAM top 3 3 12,531' BXN Nipple 4 12,552' Mule Shoe 7 :1 5 12,678' – I 12,698' HOWCO Casing Patch (8.225" ID) 5 6 14,250' Baker SB -3 Packer n 7 14,260' Pengo bridge plug w/ 20' cement dumped on top I 8 14,284' Halliburton type "0" bridge plug G Zone 9 14,293' Baker "F" nipple (2.750" ID) ri 10 14,329' Baker "R" nipple (2.690" ID) I 11 14,332' WLREG — .. H Zone TOC 14,240' ►M 6 0.7,24 7 MINI ► =1 8 PERFORATIONS ARE LISTED ON THE NEXT PAGE 9 10 V11 n ri ER }WFZone A PBTD = 15,280' TD = 15,380' MAX HOLE ANGLE = 53.9 REVISED: 7/6/12 by TDF • • . Iii McArthur River Field /TBU SCHEMATIC Steelhead Platform Well No. M -27 Hilcorp Alaska, LLC Last Completed 6/6/2012 PERFORATION DATA ZONE TOP(MD) BTM(MD TOP(TVD) BTM(TVD) SPF DATE COMMENTS 12,688' 12,690' 9,093' 9,094' 2/4/1991 Sqz Perfs 12,758' 12,788' 9,135' 9,153' 6/4/2012 TCP G -1 12,770' 12,790' 9,142' 9,154' 4 2/13/1991 TCP 12,833' 12,873' 9,180' 9,204' 6/4/2012 TCP 12,840' 12,875' 9,184' 9,205' 4 2/13/1991 TCP G -2 12,903' 12,928' 9,222' 9,237' 6/4/2012 TCP 12,910' 12,935' 9,226' 9,241' 4 2/13/1991 TCP 12,943' 12,983' 9,246' 9,271' 6/4/2012 TCP G -3 12,950' 12,990' 9,250' 9,275' 4 2/13/1991 TCP 13,018' 13,108' 9,292' 9,347' 6/4/2012 TCP G -4 13,030' 13,100' 9,299' 9,342' 4 2/13/1991 TCP 13,208' • 13,283' 9,409' 9,456' 6/4/2012 TCP G -5 13,215' 13,295' 9,413' 9,463' 4 2/13/1991 TCP HB -1 13,563' 13,613' 9,634' 9,666' 6/4/2012 TCP 13,673' 13,693' 9,705' 9,718' 6/4/2012 TCP HB-2 13,771' 13,785' 9,767' 9,776' 6/4/2012 TCP HB -3 13,818' 13,853' 9,796' 9,818' 6/4/2012 TCP 13,936' 13,966' 9,869' 9,887' 6/4/2012 TCP HB -4 13,986' 14,013' 9,900' 9,916' 6/4/2012 TCP 14,058' 14,088' 9,944' 9,963' 6/4/2012 TCP 14,143' 14,153' 9,998' 10,004' 6/4/2012 TCP HB-5 14,159' 14,171' 10,008' 10,016' 6/4/2012 TCP HB -6 14,178' 14,203' 10,020' 10,037' 6/4/2012 TCP WF -2 14,524' 14,606' 10,252' 10,309' 4 2/12/1991 TCP /Isolated WF -3 14,636' 14,666' 10,330' 10,350' 4 2/12/1991 TCP /Isolated WF -4 14,734' 14,776' 10,397' 10,427' 4 2/12/1991 TCP /Isolated WF -5 14,810' 14,989' 10,450' 10,575' 4 2/12/1991 TCP /Isolated WF -6 15,014' 15,066' 10,592' 10,628' 4 2/12/1991 TCP /Isolated WF -7 15,110' 15,142' 10,659' 10,682' 4 2/12/1991 TCP /Isolated REVISED: 7/6/12 by TDF • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date N1-27A 507332042300 1901380 4/26/12 6/7/12 Daily Qperattons 05/13/12 - Sunday Grease choke manifold. Replace hopper discharge valves in pits. Work on TD Grabber dies (stripped threads). Inventory pressure gauges and discard damaged ones. General cleaning of rig floor area. Stage equip for BOP test. Work on Rig inspection list. 05/14/12 - Monday Continue to clean and organize work areas. AOGCC & Vetco Gray Reps. arrived on Platform @ 08:30. Make up Safety Valve to IBOP & Pump -in sub. Pull BPV & install TWC. Make up 5" Test stand to CS- Hydril XO and screw into Tubing Hanger. Make up Safety Valves & flood BOP to purge air. Test BOPs and related equipment to 250 psi low /3,500 psi high. Hold pressure for 5 min each test and chart record same. Production tested LEL and H2S Gas alarms successfully. #3 Kill Line valve failed initial test, Service and retest. Tighten DSA on Choke Manifold Super Choke. Tighten Flange between Annular and Double Gate. Replace gauge on test manifold and check against chart. Attempt to test Lower Pipe Rams (failed). Pull test stand and found mark on tool joint indicating Ram contact. Open Sgl Gate doors to inspect Rams. Make up Test stand and adjust w /Pup. Test Lower Pipe Rams, IBOP and 4 1/2" TIW valve. Pull Test stand and rack back in Derrick. Test Blind Rams and CMVs #1 - #14. Test Choke HCR and Manual valves. (CMVs #1, #2, #3 failed). Suspend testing operations. Rig up Weatherford Tubing tongs and lines. Make up 4 1/2" IBT test stand and XO to CS- Hydril. Continue testing operations. Pressure test Upper Top Drive valve, Lower TD valve, Upper 4 1/2" Rams & Annular. 05/15/12 - Tuesday Continue BOP testing operations w/ AOGCC inspector John Crisp (chasing & repairing leaks). Remove TDS pipe handler & chg /out upper IBOP. Reinstall TDS pipe handler. Open upper ram doors, remove rams & patterson Rep. Chg out Mud seal on both Ram cylinders. Reinstall 4 -1/2" rams in upper rams. RU & test Upper IBOP & upper rams 250 psi low & 3,500 psi high on chart. RD test equipment. Remove test jt. Remove BPV & B.O.L.D.S. Install landing jt. 05/16/12 - Wednesday Continue BOP testing operations w/ AOGCC inspector John Crisp (chasing & repairing leaks). Remove TDS pipe handler & chg /out upper IBOP. Reinstall TDS pipe handler. Open upper ram doors, remove rams & patterson Rep. Chg out Mud seal on both Ram cylinders. Reinstall 4 -1/2" rams in upper rams. RU & test Upper IBOP & upper rams 250 psi low & 3,500 psi high on chart. RD test equipment. Remove test jt. Remove BPV & B.O.L.D.S. Install landing jt. • • 05/17/12 - Thursday Pull hanger loose & place 4 -1/2" tbg in tension w/ 15k over monitor well on trip tank while RU E -line (20 bph loss rate). RIH w/ 2.5" radial torch Tie in to Packer & nipples, place cutter on depth & sever tbg @ 12525' RKB (9' dn from collar & 1.5' below tbg punch holes). Work cutter free, Pooh, inspect tools & R /dn e-line. Tbg not free; work tbg to 80% with no movement. R /up & pump dn tbg while working pipe. Gained pipe movement (appears to be in fill). Pump 906 bbls FIW dn tbg @ 7 bph @ 500 psi w/ returns to production (to clear well bore of corrosion inhibitor). Sample & monitor returns. Remove lines from production & open well & monitor well with minimal losses. Pull hanger to rig floor w/ traveling up wt @ 195k. Remover hanger. Pooh & laydown & inspect tbg 82 jt out w/ no anomalies noted & 10 -15. BPH loss rate @ report time. 05/18/12 - Friday Continue Pooh laydown and inspect 4 -1/2" tbg completion (10 -15 bph losses). Continue Pooh laydown and inspect 4 -1/2" tbg completion (10 -15 bph losses). Found 1/8" hole in Jt #14 +/- 496'. No NORM found above back ground. Pipe in good shape both ID & OD. Recovered total 399 jts + hanger + (1) XO + (3) pups + (2) baker flow couplings + cut off (est TOF @ 12,525' RKB ; = 22.5' cut off + 5.75' pup + .98' Baker E -22 anchor locator seal assy. RD tubing handling equipment. Chg top rams t/ 5" and install test plug & test jt / test same 250 psi & 3500 psi on chart. 05/19/12 - Saturday Continue test top 5" rams t/ 250 -3500 psi on chart (good test ). L /dn test plug. R /dn test equipment. Install wear ring fill hole 1st w/ 28 bbls 2 fill 23 bbls. P /up wash over Bha #1 = 8 -1/4" muled shoed wash over shoe. RIH slow / Brk /circ & chk parameters @ 3000', 6000', 9000' & 12000' Reverse circ @ 12002' @ 5.5 bpm @ 310 psi. Btm up very dirty water w/ minimal solids in returns. Continue RIH F/ 12002' wash over fish & tag packer @12555'. Up wt 350k dn wt 225k rot wt 270k @ 15000 ft /lbs. Reverse circ @ report time. Brought on completion tbg & back loaded most of pulled tbg & lost tide. Present well loss Rate = 8 -10 BPH. 05/20/12 - Sunday Continue reversing until clean F/ 12540' w/ Dirty water and very little solids in returns @ 5.6 bpm @ 300 psi. Pooh. L /dn & inspect Bha #1 (signs of fish inside & marks of running on packer). P /up fishing assy Bha #2 w/ bowen series 150 basket grapple & control. RIH service rig perform static hole loss (9 BPH). Continue RIH w/ fishing Bha #2 T/ 12500' P /up single establish parameters up wt = 349k Dn wt = 230k Rot wt = 270k TQ 12k engage fish @ 12525' & set grapple ok. Attempt to work rounds of RH rotation dn hole to anchor w/ rig max out on torque @ 30k @ 24 turns free but unable to relatch anchor to comfirm. Monitor hole & adjust brakes. Pooh to chk tools. Present well loss Rate = 9 BPH. 05/21/12 - Monday Continue pooh chk tools. No recovery, breakdown O/S (grapple dull & rounded). Mointor static hole losses @ 9.5 bph loss rate. P /up fishing assy Bha #3 w/ bowen series 150 basket grapple & control. RIH t/ 11203' & laydown test stand. Continue RIH P /up pups for space out, establish parameters, up wt 349k dn wt = 230k rot wt= 270k TO @ 40 rpm = 13.5k. Engage fish @ 12525' & work tubing t/ 12534' set grapple. Attempt fire jars & pulled free. Work tubing t/ 12537' set grapple & fire jar @ 50k over & free tools, unable to re- engage fish. Pooh to chk tools. Present well loss Rate = 9.5 BPH. 05/22/12 - Tuesday Continue pooh Chk tools. Work Bha & laydown fish. Fish in hole +/- 1.00' est TOF 1.00' inside packer @ 12556.5'. Monitor well static loss rate = 12 BPH. P /up fishing bha #4 concave mill. (BHA can enter packer bore 10.1'). RIH t/ 12500' Kelly up. Establish parameters up wt = 350k dn wt = 230k rot wt 270k TQ 13.5k @ 40 rpm 750 psi @ 6 bpm. Find top of packer @ 12555.5'. Engage fish @ 1256.5'. Jar dn w/ little head way attempt mill on fish (excessive torque ) go back to jarring dn / force fish thru packer bore into mill out extension t/ 12566' chk packer bore for clear from 12555' to 12566'. Pooh to chk tools. II • • 05/23/12- Wednesday Finish POOH working BHA. Inspect 4.7' mill & stinger. L /dn mill & stinger assy. M /up test jts, pull wear ring and set test plug. Test BOP to 250 psi low /3,500 psi high, as per AGOCC regulations and sundry. Pull test plug and set wear ring. P /up BHA packer plucker assy BHA #5 with 3- 11/16" bull nose mill. RIH & set dn @ 11,600'. Fire jar (3) times to free pipe Kelly up work thru tight spot. Took 45k dn wt to pop thru & 45k over to come back thru. Continue RIH t/ 12,540' Kelly up. 05/24/12 - Thursday Engage packer stab prt thru bore t/ 12,560.5'. Mill packer f/ 12,555.5' t/12,558.5'. POOH working packer. 05/25/12 - Friday Continue POOH working packer thru Csg w/ 20 -50k overpull all the way to 10 -3/4" @ 497'. L /dn BHA #5 & fish to complete recovery. Can see seal section fish & most of collett up in end of mill out ext & also recovered other piece of collett stuck in "R" nipple. Cut & slip DrIg line. P /up BHA #6 with 7 -7/8" fishing magnet. RIH (did not see tight spot @ 11,600' w/ string mill) Kelly up @ 12,550'. Reciprocate & rotate full Std f/ 12,550' t/ 12,638'. Begin POOH. 05/26/12 - Saturday Continue to POOH. L /dn BHA clean & inspect mangets & junk bsk. P /up BHA #7 with 8.25" reverse basket. RIH t/ 12,630' Kelly up & establish parameters. Drop ball & circ dn to on seat & put basket in reverse mode. Reverse dn f/ 12,630' t/ 12,708' (10' past btm of patch). Did not see top of patch w/ basket & placed 8 -3/8" string mill @ 12,678' (est top of patch & did not set dn). POOH chk tools & recovery. 05/27/12 - Sunday Continue POOH w/ BHA #7 t/ 2,040'. POOH w /BHA and chk BHA. RIH w/ (9) 6 -1/2" Dc & POOH. L /dn same. P /up Rabbit & strap C /out BHA #8 with 6" open mill tooth RR bit. RIH and set dn @ 12,708'. Wash & ream f/ 12,708' t/ 12,711' & fall thru. Continue RIH t/ 13,395'. Wash & ream into liner t/ 13,500'. 05/28/12 - Monday Wash & ream f/ 13,500' t/14,239'. POOH t/ 13,437' & drop 2.875" drift w/ 100' S/L wire dn pipe. POOH t/ BHA recover drift. L /dn BHA #8. 24hr Notification given to AOGCC of weekly BOP Test. 05/29/12 - Tuesday Continue L /dn BHA #8. Clean String mag & all 5 junk bsk. R /up E -line. RIH w/ Usit log w/ B -sub for 6.2" and set dn @ 12,720'. Chg out tool for 9 -5/8" log. RIH w/ Usit log w/ C -sub for 8.6" t/ 12,650'. Tie in & log f/ 12,650' t/ 500' @ 6000 fph. Found 8 spots of intrest. Make high resolution passes across each @ 11,200 fph; 12,644' - 12,087'; 11,646' - 11,411'; 9,913' - 9,687'; 8,968'- 8,777'; 8,262' - 7,439'; 7,056' - 6,844'; 5,460' - 5,331' & 4,691' - 4,234'. Worst spot @ 4,276'. Top of cmt @ 4,180'. POOH. RIH w/ Usit log w/ B -sub for 6.2" set dn @ 12,720' wlm. This spot correlates w/ DPM of 12,708' - 12,711' that had to be rotated thru (right below patch). POOH & R /dn E -line. Chg out super choke, attempted to test choke manifold well on trip tank. Set test plug & test stand. R /up & test BOP to 250 psi low /3,500 psi high, per AOGCC regulations. John Crisp & Jeff Jones both called & waived witness of BOP test. • • • 05/30/12 - Wednesday Rig up test lines and fill Stack with water. Test BOP and related equipment to 250 psi low /3,500 psi high. AOGCC representative John Crisp waived witness. Hold test pressures f/5 min and chart record same. Test Accumulator pre - charge. Rig down test equipment and install Wear Bushing. Make Up RTTS and TIH with 5" HWDP. Continue to RIH on 5" Dp to 4,129'. Set RTTS @ 4,129' w /20k. Close Rams and circulate from Kill to Choke to purge all air from system. Pressure test casing to 2,500 psi in 500 psi intervals while monitoring 9 -5/8 x 13 -3/8 annulus. 2.8 bbls to achieve 2,500 psi. (good test). Trip in hole w/ 9 -5/8" RTTS from 4,129' to 11,498'. Set RTTS w/ 20k. Pressure test casing to 2,500 psi in 500 psi intervals w /monitoring 9 -5/8 ann. 05/31/12 - Thursday Test 9 -5/8" casing @ 11,508 to 2,500 psi. Stage up pressure in 500 psi increments w/ monitoring Annulus pressures. (good test). TIH and set RTTS @ 11,690. Repeat test procedure to 2,500 psi ( :ood test). TIH from 11,690 to 12,605'. Set RTTS @12,605'. Set RTTS @ 12,650. Step test casing to 2,500 psi and hold for 30 min. (0 psi bleed in 30 min) Bleed pressure and rig down test equipment. Flow check well. POOH from 12,650 slowly. No overpulls witnessed through any of the USIT anomalies. Drain stack and visually inspect Well Head. Call for Slickline crew and Super Magnets. Tools became stuck across new perfs w /RIH . RIH w/ 3 -3/4" Super Magnet slow to 12,708' and tag obstruction. POOH. Retrieve partial fish. RIH with 3 -3/4" Magnet assy on Slick Line and fish for tools. 06/01/12 - Friday RIH 5 times with 3.75" magnet on tool string to 12,964'. Retrieved multiple fish. Appear to be pushing obstruction down hole. Continue working tool string and moving down hole f/12,964 t/13,451'. Enter top of Liner @ 13,451' and continue to push obstruction to 14,161'. Unable to push to PBTD of 14,239' due to limited amount of Wire on Unit. POOH from 14,161'. Recovered more fish. Discuss options with Project Engineer and agreed to Run LIB. Change out Slick Line units to unit with more wire on spool. Make up 1 -3/4" Tool String with RS, WT bars, KJ, Oil Jar, Spang & 5 -1/2" LIB = 22.5' RIH w/ 5 -1/2" LIB. Enter TOL w/o tag. Tag obstruction @ 14,161' and push to 14,166'. Pull to TOL and witness wt drop when entering 9 -5/8. Slick Line measurements are 17' shallower than DPM. RIH and tag @ 14,166' (14,183' adj. depth). Spang down x 5 with no progress. POOH and witness TOL @ same depth. Continue t /POOH. Pulled tight @ 12,718' LIB depth. (300# over). Unable to pass Casing Patch @ 12,678'- 12,698'. POOH. Build 2nd 1 -3/4" centralized Tool String with solid body 4 -/2" centralizer on bottom RIH to 12,775' to verify Tools had dropped away from Patch. (confirmed) POOH. Make up 2 -1/2" JDC retrieving tool to 1 -3/4" Tool String. RIH to fish string #1. Latched Fish @ 14,156', (gained 150# wt) POOH from 14,179' slow. Strap and prep BHA and 3 1/2" DP for clean out run. 06/02/12 - Saturday RIH with (7) stands of 5" HWDP from Derrick. Pass through casing Patch @ 12,678 - 12,698 w/o tag. Continue TIH from TOL @ 13,451 to 14,204' (tag obstruction) Pick up single and space out to reverse circulate with full stand. Clean out obstruction in 7" casing by reverse circulating from 14,204' to PBTD of 14,239'. Recovered 1/2 bbl of scale and debris. Continue to reverse circulate for pipe complete well vol. Work e and tag solid PBTD 14 239. POOH (slow) pp g @ ( ) with Clean Out assembly from 14,239' to 3 -1/2" BHA @ 909'. No additional drag or tight spots encountered on trip out of hole. Recovered more fish. Stage TCP tools and lay out guns in preparation for TCP run. • • 06/03/12 - Sunday RIH with 1,445' ft of Schlumberger 4.5" Omega, 5 spf Guns and Blanks. Total perf intervals = 553 ft. SLM to confirm distance from Top Shot to PIP Tag. Continue Trip in hole from 1,558 ft to PBTD. Tag TD @ 14,236'. Work pipe & measure 5.7 feet of pipe travel from DN to UP wt. Park pipe in tension 5.38' below calculated perf interval. R/U E -Line equip & make up 1- 11/16" tool string. RIH with GR /CCL & correlate formation to RA Tag. Found RA Tag @ 12,552' (14' high). Pull second pass with same results. RD E -Line sheave. Tag bottom and pick up to UP wt to place guns @ max depth. Bottom Nose @ 14,229' Dp measurements. Rig up E -Line. RIH and correlate guns to formation. 06/04/12 - Monday POOH with GR /CCL correlation assembly. Rig down E -line equipment and prep for Perforating. Fired guns. Begin pulling pipe slowly. Pull and rack back (9) stands of Dp to place Bull Nose above TOL @ 13,451'. POOH with Spent TCP Gun assembly from 13,451'. Rig up Weatherford hydraulic tongs and stage TCP handling equipment. POOH and lay down spent TCP guns. Inspect each gun and verify all shots had fired. Lay down TCP tools and equipment. Pull Wear Bushing & Install Test Plug. Circ through choke manifold to purge air. Test Upper Pipe Rams to 250 psi low /3,500 psi high. (good test) Rig down testing equipment and pull Test Plug. 06/05/12 - Tuesday RU Weatherford tubing running equipment. Make up XO to Floor Safety Valve. P/U and RIH with 4.5 ", 12.6 #, L -80, 13 -Cr, VAM TOP Tbg. Utilize Weatherford's Torq -Turn system to make up connections to 4,400 ft /lb. Drift each joint with 3.833" Drift. Make up Mule Shoe, Pup jts, XN- Nipple, XOs, and Baker Model 194 -47, S -3, 9 -5/8" Packer. Continue RIH with 4 -1/2" VAM TOP 13 -Cr Injection Completion from 6,188'. Drift and Torq -Turn each joint. 06/06/12 - Wednesday P/U and RIH with 4 -1/2 ", 12.6 #, L -80, 13 -Cr tubing from 9,450' to 12,553'. Install X- Nipple and flow couplings @ 509'. Drift and Torq turn all connections. M/U Pup, XO Pup and hanger. Pick up XO Pup and Landing Joints. Land Hanger and RILDS, 299 joints of 4 -1/2" 13 -Cr tbg run. Rig up circulating lines from Rig floor to Annulus. Reverse circulate 700 bbls of clean Sea Water w /1% CRW -132 corrosion inhibitor @ 3 bpm. While circulating Packer fluid: Install New BOP Lift Cradle. RD circulating lines. Drop Packer Setting Ball /Rod. Wait 30 min, then chase setting ball to Seat in XN- Nipple @ 12,530' with 46 bbls @ 2.5 bpm. Set Baker S -3 Packer: Pressure to 1,000 psi and wait 2 min. Pressure to 2,500 psi w/ Rig Pump then shut in Stand Pipe to isolate relief valves. Increase Tubing pressure with Test Pump to 4,000 psi. Hold pressure for 10 min to complete hydraulic set of Packer. Bleed pressure. Pressure test 9 5/8" Casing and Packer to 2,500 psi for 30 min. & chart record same. 0 psi bleed in 30 min. Rig up Slick Line Lubricator and Tool String. RIH and retrieve Setting Ball /Rod and RHC Plug. RD Slick line. Set BPV to secure well. ND BOP: Disconnect Choke, Kill and Accumulator lines. Pull Master Bushings, remove Flow Nipple and Upper Air Boot Flange. Break Flange bolts between Single Gate and DSA. Stump back BOP and secure same. Remove Mid -Riser Clamp and lay down upper section of Riser. 06/07/12 - Thursday Continue with ND operations. Break and lay down lower section of 16 -3/4" Riser. NU 16 -3/4, 5M x 4 -1/16 5M Double Master and Swab Injection Tree. Torque all studs to spec.(3,000 ft /lb). Pressure test Tubing Hanger void to 250/5000 psi for 30 min each test. Pull BPV, install TWC. Pressure test Tree to 250/5000 psi f /30 min. Pull TWC. Remove Blind Flanges and install Production Flowline. RTP. Release Rig from M -27. • • Ferguson, Victoria L (DOA) From: Ted Kramer [tkramer ©hilcorp.com] Sent: Thursday, July 12, 2012 9:42 AM To: Ferguson, Victoria L (DOA); Larry Greenstein Cc: Schwartz, Guy L (DOA) Subject: RE: TBU M -27 Victoria, The MIT was conducted yesterday. I have not seen the results yet but I did talk to the platform and was told that it looked very good. I asked the platform to send me the results and will forward as soon as I get them. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907 - 777 -8420 C 985 - 867 -0665 From: Ferguson, Victoria L (DOA) [ mailto :victoria.ferguson©alaska.govj Sent: Thursday, July 12, 2012 9:08 AM To: Larry Greenstein; Ted Kramer Cc: Schwartz, Guy L (DOA) Subject: TBU M -27 Larry, Ted, What is the status of the MIT on this well after stabilized injection? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(o�alaska.gov 1 Prt) lg013 Regg, James B (DOA) From: Regg, James B (DOA) � Sent: Friday, June 08, 2012 10:41 AM '`f? 6 r To: Larry Greenstein Cc: Trudi Hallett; George Ivie; Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: MIT_M-27_MIT_06-05-12 Good test; ok to put M -27 on injection. We would like to witness MIT when out for BOPE test on M -29. I waived witness of initial BOP test on M -29 (today), so we will be looking to witness BOPE (M -29) and MIT (M -27) in 2 weeks or so. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 �.aa ..iU , 1 3 2 Original Message From: Larry Greenstein [mailto:lgreenstein @ hilcorp.com] Sent: Friday, June 08, 2012 10:33 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: Trudi Hallett; George Ivie Subject: MIT_M- 27_MIT_06 -05 -12 Hi Jim, Attached for your review is the WO MIT for the Steelhead M -27 water injection well. ,- With your permission we would like to begin injection in this well and, after the temperatures stabilize, call for an inspector to witness the initial MIT. Thank you Larry 1 f . r f ''SE, ,,/ 2aaa �._.. .___. t ' ° / 1 �� -- F , / [mil` �� 1 • `� / v\ ,6 ,E / , i ,'*:-‘ . e ' , ' z - "'''' ' . - ' - '''.. -- ,Z,, ' , :; \ ' \ „ \\ f cis O j r 14-..i ' y, ` ` ma y Z� � .°.J "N + - � A to a ° a 1 � a " � ? V' � . fir. i ° i f� (\\ \..i7k9 \-- \ \ -:' ' . - -.' .._ / ' L. t.t.0 .c‘ — " ‘ ..o 01 III \\...... ' !, / / i d "V1f�HV�� d .. f z ' - '-' q ) , o, ,s; ' \ ,,,, N ....„, ..)--. ,, 0 ,. ,e' . , / \/ i i , Nj i i ` �( / . r r t / � r f J __ c :- ,, /' ' "" a 4 „``, _ _ i . aav , r - wr . • 110 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reo0(rDalaska cloy; doa .aocicc.prudhoe.bay(5alaska.00vi. phoebe brookse✓talaska.aov OPERATOR: Hilcorp Alaska, LLC/G/ t1 ui 1 v FIELD / UNIT / PAD: McArthur River/Trading Bay /Steelhead Platform DATE: 06/05/12 OPERATOR REP: Mike Leslie AOGCC REP: N/A Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well M -27 ' Type Inj W - TVD 8,956' " Tubing 0 0 0 0 0 0 Interval 0 P.T.D. 1901380' Type test P Test psi 2239 ' Casing 0 2,500 ' 2,500 2,500 2,500 2,500 - P/F P Notes: WO MIT performed after running the completion . OA 546 546 546 546 546 546 Wet Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P T D. Type test Test psi Casing P /F_ Notes: OA Well Type lnj TVD Tubing Interval P.T.D. Type test_ Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Work Over MIT done while the rig was on the well OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Vanance N = Not Injecting A = Temperature Anomaly Survey 0 = Other (describe in notes) W = Water D = Differential Temperature Test Form 10-426 (Revised 02/2012) MIT_Steelhead_06 - 05 - 12 • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number. Start Date End Date M -27A 507332042300 1901380 4/26/12 Daily Operations: 05/23/12 - Wednesday Finish POOH working BHA. Inspect 4.7' mill & stinger. L /dn mill & stinger assy. M /up test jts, pull wear ring and set test plug. Test BOP to 250 psi low /3,500 psi high, as per AGOCC regulations and sundry. Pull test plug and set wear ring. P /up BHA packer plucker assy BHA #5 with 3- 11/16" bull nose mill. RIH & set dn @ 11,600'. Fire jar (3) times to free pipe Kelly up work thru tight spot. Took 45k dn wt to pop thru & 45k over to come back thru. Continue RIH t/ 12,540' Kelly up. 05/24/12 - Thursday Engage packer stab prt thru bore t/ 12,560.5'. Mill packer f/ 12,555.5' t/12,558.5'. POOH working packer. 05/25/12 - Friday Continue POOH working packer thru Csg w/ 20 -50k overpull all the way to 10 -3/4" @ 497'. L /dn BHA #5 & fish to complete recovery. Can see seal section fish & most of collett up in end of mill out ext & also recovered other piece of collett stuck in "R" nipple. Cut & slip Drlg line. P /up BHA #6 with 7 -7/8" fishing magnet. RIH (did not see tight spot @ 11,600' w/ string mill) Kelly up @ 12,550'. Reciprocate & rotate full Std f/ 12,550' t/ 12,638'. Begin POOH. 05/26/12 - Saturday Continue to POOH. L /dn BHA clean & inspect mangets & junk bsk. P /up BHA #7 with 8.25" reverse basket. RIH t/ 12,630' Kelly up & establish parameters. Drop ball & circ dn to on seat & put basket in reverse mode. Reverse dn f/ 12,630' t/ 12,708' (10' past btm of patch). Did not see top of patch w/ basket & placed 8 -3/8" string mill @ 12,678' (est top of patch & did not set dn). POOH chk tools & recovery. 05/27/12 - Sunday Continue POOH w/ BHA #7 t/ 2,040'. POOH w /BHA and chk BHA. RIH w/ (9) 6 -1/2" Dc & POOH. L /dn same. P /up Rabbit & strap C /out BHA #8 with 6" open mill tooth RR bit. RIH and set dn @ 12,708'. Wash & ream f/ 12,708' t/ 12,711' & fall thru. Continue RIH t/ 13,395'. Wash & ream into liner t/ 13,500'. 05/28/12 - Monday Wash & ream f/ 13,500' t/14,239'. POOH t/ 13,437' & drop 2.875" drift w/ 100' S/L wire dn pipe. POOH t/ BHA recover drift. L /dn BHA #8. 24hr Notification given to AOGCC of weekly BOP Test. .vidoiNED JUL Z1114 4 • 05 /29 /12- Tuesday Continue L /dn BHA #8. Clean String mag & all 5 junk bsk. R /up E -line. RIH w/ Usit log w/ B -sub for 6.2" and set dn @ 12,720'. Chg out tool for 9 -5/8" log. RIH w/ Usit log w/ C -sub for 8.6" t/ 12,650'. Tie in & log f/ 12,650' t/ 500' @ 6000 fph. Found 8 spots of intrest. Make high resolution passes across each @ 11,200 fph; 12,644' - 12,087'; 11,646' - 11,411'; 9,913' - 9,687'; 8,968'- 8,777'; 8,262' - 7,439'; 7,056' - 6,844'; 5,460' - 5,331' & 4,691' - 4,234'. Worst spot @ 4,276'. Top of cmt @ 4,180'. POOH. RIH w/ Usit log w/ B -sub for 6.2" set dn @ 12,720' wlm. This spot correlates w/ DPM of 12,708' - 12,711' that had to be rotated thru (right below patch). POOH & R /dn E -line. Chg out super choke, attempted to test choke manifold well on trip tank. Set test plug & test stand. R /up & test BOP to 250 psi low /3,500 psi high, per AOGCC regulations. John Crisp & Jeff Jones both called & waived witness of BOP test. • • 11 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date M -27A 507332042300 190 -138 4/26/12 6/7/12 Daily Operations: 06/06/12 - Wednesday P/U and RIH with 4 -1/2 ", 12.6 4t, L -80, 13 -Cr tubing from 9,450' to 12,553'. Install X- Nipple and flow couplings @ 509'. Drift and Torq turn all connections. M/U Pup, XO Pup and hanger. Pick up XO Pup and Landing Joints. Land Hanger and RILDS, 299 joints of 4 -1/2" 13 -Cr tbg run. Rig up circulating lines from Rig floor to Annulus. Reverse circulate 700 bbls of clean Sea Water w /1% CRW -132 corrosion inhibitor @ 3 bpm. While circulating Packer fluid: Install New BOP Lift Cradle. RD circulating lines. Drop Packer Setting Ball /Rod. Wait 30 min, then chase setting ball to Seat in XN- Nipple @ 12,530' with 46 bbls @ 2.5 bpm. Set Baker S -3 Packer: Pressure to 1,000 psi and wait 2 min. Pressure to 2,500 psi w/ Rig Pump then shut in Stand Pipe to isolate relief valves. Increase Tubing pressure with Test Pump to 4,000 psi. Hold pressure for 10 min to complete hydraulic set of Packer. Bleed pressure. Pressure test 9 5/8" Casing and Packer to 2,500 psi for 30 min. & chart record same. 0 psi bleed in 30 min. Rig up Slick Line Lubricator and Tool String. RIH and retrieve Setting Ball /Rod and RHC Plug. RD Slick line. Set BPV to secure well. ND BOP: Disconnect Choke, Kill and Accumulator lines. Pull Master Bushings, remove Flow Nipple and Upper Air Boot Flange. Break Flange bolts between Single Gate and DSA. Stump back BOP and secure same. Remove Mid -Riser Clamp and lay down upper section of Riser. 06/07/12 - Thursday Continue with ND operations. Break and lay down lower section of 16 -3/4" Riser. NU 16 -3/4, 5M x 4 -1/16 5M Double Master and Swab Injection Tree. Torque all studs to spec.(3,000 ft/lb). Pressure test Tubing Hanger void to 250/5000 psi for 30 min each test. Pull BPV, install TWC. Pressure test Tree to 250/5000 psi f /30 min. Pull TWC. Remove Blind Flanges and install Production Flowline. RTP. Release Rig from M -27. 06/08/12 - Friday No operations to report. 06/09/12 - Saturday No operations to report. 06/10/12 - Sunday No operations to report. 06/11/12 - Monday No operations to report. 06/12/12 - Tuesday No operations to report. TBU M -27 (PTD 1901380) 1 1 2012 BOPE Test Charts JUN Rig 51 (Steelhead) Operated by Kuukpik Drilling • • BOPE Test Charts; Steelhead Rig 51; TBU M -27 (PTD 1901380) 5/12/2012 Page 1 of 5� �� • • 'n> • BOPE Test Charts; Steelhead Rig 51; TBU M -27 (PTD 1901380) 5/12/2012 Page2of5 • '+al • • fit r S . • BOPE Test Charts; Steelhead Rig 51; TBU M -27 (PTD 1901380) 5/12/2012 Page 3 of 5 • • BOPE Test Charts; Steelhead Rig 51; TBU M -27 (PTD 1901380) 5/12/2012 Page 4 of 5 • • BOPE Test Charts; Steelhead Rig 51; TBU M -27 (PTD 1901380) 5/12/2012 Page 5 of 5 0 . _ 0 0 A r 7, ,, , , , L n • , [1 r i jj L u pi.1 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION O ANCHORAGE, ALASKA 99501-3539 PHNE (907) 279-1433 FAX (907) 276-7542 Ted E. Kramer Senior Operations Engineer C / Hilcorp Alaska, LLC 10 — I 3 3800 Centerpoint Drive, Suite 100 .,---..- Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G Oil Pool, M-27 Sundry Number: 312-159 5001NEE) APR 2 7 2 .° 12 . Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. d el rely r 1 o r . n om ■1 :*oner DATED this 0(cay of April, 2012. Encl. e! ,• • 0 RECEIVED STATE OF ALASKA Arr'. 1 8 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Q • Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: R&R tubing / reperforate El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 190 -138 • 3. Address: Stratigraphic ❑ Service 0 • 6. API Number. 3800 Centerpoint Drive, STE 100, Anchorage, AK 99503 50- 733 - 20423 -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 cianges: Spacing Exception Required? Yes ❑ No El . M -27 • 9. Property Designation (Lease Number): 10. Field /Pool(s): Steelhead Platform ADL 18730 • McArthur River Field / Middle Kenai G Oil Pool' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15,380' . 10,855' , 14,240' 10,060' 14,240' 13,543' Casing Length Size MD TVD Burst Collapse Structural Conductor 1,332' 16' 1,412' 1,409' 2,630 psi 1,020 psi Surface 4,106' 13 -3/8" 4,185' 3,764' 3,090 psi 1,540 psi Intermediate 410' 10 -3/4" 487' 486' 5,860 psi 3,220 psi Production 13,156' 9 -5/8" 13,643' 6,870' 6,870 psi 4,760 psi Liner 1,928' 7" 15,379' 10,854' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12,688' - 13,295' 9,093' - 9,463' 4 -1/2" 12.6 # / L -80 12,260' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker SB -3 Packer / Baker SB -3 Packer 12,555' (MD)/9,013' (TVD) & 14,250' (MD)/10,067' (TVD) 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/1/2012 Oil ❑ Gas ❑ WDSPL El Suspended ❑ 16. Verbal Approval: Date: N/A WINJ El GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted E. Kramer Printed Name Ted E. Kramer Title Sr. Operations Engineer Signature Phone (907) 777 -8420 Date 4/17/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 51 2` Plug Integrity ❑ BOP Test 'L1 2 Mechanical Integrity Test Lid Location Clearance ❑ Other: �f re 5 f 130 /" / 3571 1 05 G - N V J ,h5 t e' fzl a 5 iiri fiea - fc) / . Y fi J ` r 0 v r � r / / / 7 & Fey Subsequent Form Required: 0 ," APPROVED BY �` Approved by: O r/ OM ISSIONER THE COMMISSION Date: �• Z,) �/ 76 �3RBDMS APR 26 6 101 1 - r�Ss, �Z i v - Form 10 -403 Revised 1/2010 ‹,. ` 17 t ( Submit in Duplicate y'�• fr • M -27 Water In'J ector • McArthur River Field WO Procedure April 17, 2012 Hilcorp Alaska, LLC WELL: M -27 JOB SEQUENCE: No. 1 of 4 (First job in Leg B -1) OBJECTIVE: • Water Injection Workover — Retrieve / Replace current completion with 13- Chrome tubing. Add Hemlock Bench 3- 6 perforations and reperforate G -Zone. BACKGROUND: . M -27 is a shut -in G -zone water injector with a single deviated completion perf d through the G -Zone (G -1 thru G- 5). It is completed with a 7" liner from TD to base of G -Zone @ 13451' and 4 -1/2" IPC tbg running in 9 -5/8" from 12620' to surface. Well was completed 2/20/91 originally injecting into the G -Zone and West Foreland. The West Foreland was isolated 10/6/1994, where 20' of cement sets on bridge plug @ 14260'. The well was last injecting about 1500 bwpd but was initially capable of taking about 4000 bwpd in just the G -Zone. Tbg to csg communication along with a temp survey cooling anomaly just at the packer @ 12,555' caused the well to be shut -in on 3/08/2012 A well clean out to the cement .1u. re • Iacin • to • • i . a re • erforation of the - on din. n. with ddiJlq rforations to the Hemlock zone should increase iniection rates to over 10.000 b w o d. There is a 20' casing patch @ 12,678. Last tag was with 2.25" GR to 13,303' (mid G -Zone perfs). • CURRENT STATUS: Current BHP: 4349 psi © 13,000' MD and 9,280' TVD — based on a Pressure/ Temperature Survey on 7/2/2010 Max Downhole Pressure: 4600 psi @ 14,000' MD and 9,908' TVD (New perfs being added) MASP, worst case: 2300 psi Leg: B -1 (NW Corner, Outer ring) RKB to MSL: 160.3' BHT: 180 °F Max Deviation / Max Dogleg: 54.0° at 10,700' MD / 2.19 °/100 ft. at 15,276' Maximum TD with DP: 14,220' HIGH LEVEL PROCEDURE SUMMARY: Notify AOGCC at least 48 hours in advance of well operations to witness test of BOPE and to inspect equipment. 1. RU wireline unit and RIH w/ 3.5" GR to WLEG @ 12,620'. 2. RIH with tbg punch and shoot holes above packer for well kill using filtered inlet water — water flood. Circulate wellbore taking inhibited returns to production. 3. Pre Rig for well work — remove hatches, stage equipment, skid rig, test equipment and make necessary repairs, and build brine and LCM pills �,✓� f a-►t 55 �l5 4. Mobe Steelhead Rig. 5. Install BOPE on top of tree. Test BOPs per standard procedure. Record _pressures. Notify AOGCC (if not present) of successful test. 35corsc i3c.P 6. RU Eline and RIH with 4'/2" tbg radial torch and cut tbg above pkr. RD Eline. CBU. Monitor losses. 7. LD tbg hngr. POOH. LD completion string. Txt 8. RIH with overshot on DP. Latch tbg stub. Rotate anchor out of pkr. 9. MU clean out assy. RIH and cleanout to TOC. ciU psi ✓ �� 10. RU TCP and RIH to re- perforate G -Zone and perforate Hemlock. 5 C has 30 0 11. PUMU pkr and assy on 4 -1/2" 13 -Cr completion string. RIH to set depth. 12. Circulated /annulus with pkr fluid. Space -out stab /latch into pkr. Pressure test csg. Land tbg hngr. 13. ND BOPE. NU tree. Pressure test same. 14. Demobe from M -27. Release rig to M -29. Pi M -27 Integrity WO Page 1 of 4 y T Hallett 1: nn m 11111 II III M -27 Water Injector McArthur River Field WO Procedure April 17, 2012 Hilcorp Alaska, LLC Schematic (As Built) RKB to TBG Hanger = 74.35' CASLNG AND TLTBLNG DETAIL J L SIZE WT GRADE CONN TOP BOTTOM 16" 75 K -55 BTC 80' 1412' 13 -3/8" 61,68 K -55 BTC 79' 4185' 1 10-3/4" 51 N -SO BTC 77' 487' ; ,i ; P 9 -5/8" 47,535 N -SO BTC 487' 13643' _.; EK-99. 7"1.= 29 N -SO MC 13451' 15379' LI Tubing: 4 -1 12.6 L -80 CSCB 74.35' 12620' JEWELRY DETAIL NO. Depth Item 1 521' Baker "F' nipple wr' flow coupling above -1-4, below (3.750" ID) 2 12554' Baker anchorlocator seal amy 2 3 12555' BakerSB-3 Packer lo" 7 ... 1 3 4 12576' Baker "F' nipple (3.680" ID) 4 5 12610' Baker "R" nipple (3.625" ID) 6 12620' WLREG 5 7 12678' -698' HOWCO Ca sing Patch(8225 "ID) II= 8 14250' BakerSB -3 Packer 6 ' 9 14260' P.saaga bridge 20' cern ent dum P ed on >� P lu g 1 ILGGe I 14604 top 7 10 14284' Hallibueton type "D" bridge plug I-1 11 14293' Baker "F' nipple (2.750" ID) 12 14329' Baker "R" nipple (2.690" ID) 13 14332' WLREG �Fish/Fill Information: A A. 1 2 0 -'0 6: Taggedbal7edfdl at 13543'. . B. 10 6'94: Top ofdunpbadedcem ent estimatedat14240'. PERFORATION DATA TOP BT1I ZONE SPF DATE COMMENTS 12688' 12690' 2/4/91 ,au pats B I'{ Z Div = A-724 8 12770' 12790' G -1 4 2/13191 TCP rya 9 12840' 12875' G -2 4 2.'13/91 TCP 10 12910' 12935' G -2 4 213191 TCP 12950' 12990' G -3 4 2/13191 TCP MI 11 13030' 13100' G-4 4 2/13191 TCP 12 13215' 13295' 0-5 4 2'13/91 TCP al OF 13 14524' 14606' WF -2 4 2'1291 TCP/Isolated I 14636' 14666' WE-3 4 2/1291 TCPzlsolated H 14734' 14776' WT-4 4 2'12/91 TCP/Isolated Ii 14810' 14989' WE -5 4 212/91 TCP/I solated 1 15014' 15066' WF-6 4 2'12/91 TCP A 15110' 15142' WF -7 4 2/12/91 TCP/Isolated PBTD = 4.Q',JD = 15380' MAX HOLE ANGLE = 53.9° REVISED: 4;17.2012 DRAWN BY: TDF M -27 Integrity WO Page 2 of 4 T Hallett 11/1 !Y) ')nl') II • M -27 Water Injector • McArthur River Field WO Procedure April 17, 2012 Hilcorp Alaska, LLC PROPOSED M -27 Schematic I RIO to TBG Hanger = 74.35' CASING AND TCBLN G DETAIL SIZE WT GRADE CONK TOP BOTTOM J i 16" 75 K -55 1 BTC 80' 1412' 1 13 -3/8" 61, 68 K -55 BTC 79' 4185' c (10-3/4" 51 N -80 BTC 77' 48T 9-5/8" 4743,5 N -80 BTC 487' 13643' 7" J,n 29 N -80 TKC 13451' 15379' u Tom: A i 3 3 4 4 -1/2" 12.6 L -80 CSCB 7435' 12620' JEWELRY DETAIL NO. Depth Item 1 521' Baker "X' nipple w flow coupling above 4below (3.750" ID) 12555' BakerSB -3 Packer MM M=1 - S 12610' Baker "B.7 1" nipple (3.81" ID) 6 12620' WLREG 12678' — 698' HOWCO Casing Patch (8.225 ID) € 14250' Baker SB -3 Packer 9 14260' Peng9 bridge plug w/ 20' cement dumped ontop L,_______ 6 10 14284' Halliburtontvpe "D " bridge plug 11 14293' Baker' nipple (2.750' ID) - sedGZ�weBeP�sjs: I 1. 14329' Baker"R nipple (2.690" ID) 2 S:- 12795' 30ft ,$UQ,- 12880' 40ft I 1 13 14332' WLREG 12910,- 12935' 25ft .a 12990' 40ft , Q : - 13115' 9011 1„}; , „ - 13290' 75ff i> 1 5 /g ,, a 1 J e/Fish/Fill Information: / ailed-£s11 -a t -13 -513'. Fc.0 r34 B. 10/6/94. Top of dump bailed cement estimated at 14240'. Proposed liK Berfs: HB-� - 13860' 35ft PERFORATION DATA HB- 4„J3943'- 13973' 30ft 4 TOP BTII ZONE SPF DATE CO EVENTS HB 13993' 14020' 27ft .., , B 12688' 12690' 2/4/91 SIR Perfs 1-1134.14320:-14095' 30ft 8 11B J. Q;, 14160' 1011 1313- 1,14. - 14178' 12f I ' 12770' 12790' G -1 4 2/13`91 TCP 1.1B- - 14210' 25ft 12840' 12875' G -2 4 2/1391 TCP 11 12910' 12935' G -2 4 2/13'91 TCP 12950' 12990' G -3 4 2/13'91 TCP 12 13030' 13100' G-4 4 2/13 :91 TCP 13 13215' 13295' G -5 4 2/13/91 TCP I I 14524' 14606' WF -2 4 2/12/91 TCP Isolated *PLEASE NOTE: All 14636' 14666' WF -3 4 2/12/91 TCP Isolated above prop oseclp 14734' 14776' WF-4 4 2/12/91 TCP/Isolated are approximations 14810' 14989' WF -5 4 2/12/91 TCP /Isolated A a 15014' 15066' WF-6 4 2/12/91 TCP /Isolated 15110' 15142' WF 7 4 2/12 91 TCPrlsolated PBTD = .1. Mr TI) = 15380' MAX HOLE ANGLE =53.9° REVISED: 44742 DRAWN BY: TRH M -27 Integrity WO Page 3 of 4 T Hallett nn 10 'nt) M -27 Water Injector McArthur River Field WO Procedure April 17, 2012 llilcarp Alaska, LLC Steelhead Platform 16 -3/4 5M BOP (Oil Leg) g or e 25' ,88. tlnp pen 11 8 22" pipe for air boot Flanges /� /� / /�J 9 J // yf)(' x822' A (L^ � 4_/ I //`Y"�J 1 I Moon pool Oeck / lV(4- m ng noor ST III 111111111111 5.10' Hydril ill it! Ii, 111,11 111 111 111 111 t 11 5.46' Moon ,,,fl wellbee0 roam goor�55.95' II! '1 11 '.1 .. 111 Top o. 960' l0eck 9 W' 111 111 111 111 111 IOII :AI '71:1 : II {: 110 3.00' +. 11wmgaii 111 3.58' 1f. 'i1 111 if, If, OSA16%10MX16a /.5M 1 66' 11 'I i I ,il 10s enge ebave rp cuba2tinp Rig sub 91811.3 Riser, 16 % 5M API hub X 16 3/4 10M FE Upper WellbeeO Room 10 Rig Sub Gregng x3 9T T 53C Chmp above floor Upper we1111ee0 mom floor 1 Riser, 16 % 5M FE X 16 % 5M API hub wmbe.e noor.o upperweune.e .n 11 Room x3 BS' • e : . "1 111 IMg /,!'.. . : ' T 1111,,1111,,.i. 'i. irt1 +k!r ^ .: � �j 'I RN 1 ill M -27 Integrity WO Page 4 of 4 T Hallett on m 11111 • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Wednesday, December 14, 2011 5:45 AM To: Maunder, Thomas E (DOA) • • Cc: Martin, J. Hal; Brandenburg, Tim C; Regg, James B (DOA) Subject: RE: 2011 November's Waivered Injection Well Report Agreed, Tom...we have not and will not inject into this well until our diagnostics are done and we've gone over them with you to get your agreement, either way. Hal Martin will be back next week and can follow up with you on this well. I don't believe any wireline /well work has been done since September. Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, December 13, 2011 10:08 AM To: Greenstein, Larry P jw@ ; Cc: Martin, J. Hal; Lambert, Steve A; Hallett, Trudi R.; Regg, James B (DOA) Subject: RE: 2011 November's Waivered Injection Well Report Larry, et al, 1 '' %SO— Keep us informed on M -27 diagnostics. Was there any well work done since September? It appears that the pressures are moving "out" and shallower with the 16" pressure now equal to the 13 -3/8" and the 20" climbing. The well should not be operated. Call or message with any questions. Tom Maunder, PE AOGCC From: Greenstein, Larry P [mailto :Greensteinlp @chevron.com] Sent: Monday, December 12, 2011 7:35 AM \ To: Maunder, Thomas E (DOA); Regg, James B (DOA) `��- "� V-5AC .�: <.;,' U J� � �., � U`■V Cc: Martin, J. Hal; Lambert, Steve A; Hallett, Trudi R. ` Subject: 2011 November's Waivered Injection Well Report t 0C'� 5 ``�`� �\�� i`�� 5 Hi Tom &Jim, Here is November's monthly report for all the active monitored injection wells. We're looking into the climb in the 16" & 20" up towards the pressure of the 13 3/8" on M -27. The well is shut -in and the pressures are within calculated upper limits for the strings. Tree servicing and other diagnostic work results will be passed on to the state as we receive them here. The Grayling had some upsets in their waterflood which clearly show up on the plots, but is running smooth now. The active injection wells are responding as expected to ups and downs in injection volumes without any apparent pressure or rate anomalies observed. The inactive wells are remaining stable or responding as expected to being shut -in. Bottom line, I don't see any indication that any of these wells are losing control of the injected fluids downhole. Larry 12/16/2011 • • Plot Pressure & Rate vs Time - Well M -27 600 - 200 180 500 160 •••■9 5/8" 13 3/8" 16" ,,,�, -20" 140 400 26' / - Tu bing • - Vol 120 I' N m 300 10 a 1 a 80 200 40 100. 20 0 11 0 CO _ _ _ _ _ _ M M 0M N N N N .f) CO r N O 0 0 0 0 0 0 Date 13 3/8" 16" 20" 26" , , TIO Report 11/29/11 505 500 420 190 • - 11/28/11 505 500 410 180 Data Sheet 11/27/11 500 500 400 180 11/26/11 505 500 400 180 11/25/11 510 500 400 180 M -27 11/24/11 510 500 380 180 11/23/11 510 500 380 180 11/22/11 510 505 380 179 INJECTION 11/21/11 515 510 380 180 11/20/11 510 510 370 180 11/19/11 515 510 360 180 Permit # 1901380 11/18/11 520 515 360 175 11/17/11 510 505 350 170 11/16/11 520 520 340 180 API # 50- 733- 20423 -00 11/15/11 520 520 340 180 11/14/11 525 430 330 180 11/13/11 530 421 330 180 05/31/2011 to 11/30/2011 11/12/11 530 385 320 180 11/11/11 530 380 320 180 11/10/11 530 380 320 180 11/09/11 530 380 310 180 11/08/11 530 379 310 180 11/07/11 530 380 310 180 11/06/11 530 375 310 180 11/05/11 530 370 310 180 11/04/11 520 370 310 180 11/03/11 520 370 310 180 11/02/11 520 370 310 185 11/01/11 520 360 300 180 10/31/11 520 360 300 180 10/30/11 520 360 300 180 10/29/11 520 360 300 190 10/28/11 520 325 300 180 10/27/11 520 350 300 180 10/26/11 520 350 300 180 10/25/11 520 345 300 180 12/12/2011 8:32 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 11 30.xls M -27 2UlO June's WoivcredI�cot�z\�cD �� Page 1 of 1 Injection �� Maunder, Thomas E (DOA) From: Greenebein, Larry P [Greensteinlp@chevron.com] Sent: Monday, July 12, 2010 1:20 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Co: KXartin, J. Hal; Lnmbert, Steve A Subject: 2010 June's Waivered Injection Well Report Attachments: Master Well List TIO Report 2010 06 30.xls Hi Tom & Jim, Here is June's monthly report for all the active monitored injection wells. M-27 is SI again. It was brought back on to re-establish a temperature profile after the downhole plug was finally retrieved and to have a temperature survey run to a deeper depth than was completed previously. This has been accomplished and the analysis of both temp surveys has begun. The G-11 well is SI waiting on a replacement choke to be installed. Nothing out of the ordinary appeared in the rates or pressures of the other wells this last month. Bottom line, | don't see any indication that any of these wells are losing control of the injected fluids downhole. Larry «Master Well List TIO Report 2010 0030x|o>> 12/13/2011 • • Plot Pressure & Rate vs Time - Well M -27 2000 i 3000 _ �� 1800 1600 2500 •"'''9 5/8" 1400 13 3/8" 2000 16" 20" 1200 26" f \ A y Tubing 3 ''Vol M -27 11 i N 1000 m d 1500 - -_. -- - - -- -- -_.. _ _- - ........ _ - -- __ -_. _. - -- -__ -- _..___. - - - -__ ....__._. - m �S 800 1000 - li 600 400 500 - 1 200 O 0 0) 0 0 0 0 0 0 o 7 -7 r 7 7 0) N N N N N N CO CV O O O O O O Date 13 3/8" 16" 20" 26" Tubi" TIO Report 06/30/10 600 600 560 340 12 06/29/10 605 600 560 340 1208 890 Data Sheet 06/28/10 605 600 560 325 1377. 880 06/27/10 600 595 550 340 1496 760 06/26/10 605 600 560 350 1427 780 M-27 06/25/10 600 595 560 350 1292 730 06/24/10 590 580 559 340 1510 760 06/23/10 580 580 560 350 1048 930 INJECTION 06/22/10 580 580 558 350 1052 940 06/21/10 580 570 550 340 1084 940 06/20/10 580 580 560 320 1077 950 Permit # 1901380 06/19/10 580 575 550 350 1105 950 06/18/10 580 575 550 350 1086', 950 06/17/10 580 575 550 345 1109 960 API # 50- 733- 20423 -00 06/16/10 580 580 550 350 1203 970 06/15/10 585 580 550 350 1203' 980 06/14/10 580 578 540 340 1241 980 12/29/2009 to 06/30/2010 06/13/10 580 578 540 340 1223 980 06/12/10 585 580 550 350 1237 980 06/11/10 585 580 540 350 1259 1000 06/10/10 590 580 540 320 1309 1020 06/09/10 600 580 545 350 1373 1040 06/08/10 600 580 540 340 1475 1120 06/07/10 580 560 530 340 1776 1060 06/06/10 550 550 520 330 0 0 06/05/10 550 550 520 330 0 0 06/04/10 550 550 520 330 0 0 06/03/10 560 560 520 340 0 0 06/02/10 560 560 520 340 0 06/01/10 560 560 520 340 0 05/31/10 560 560 520 340 05/30/10 560 555 525 320 05/29/10 565 560 525 340 05/28/10 565 560 520 340 05/27/10 560 555 525 320 05/26/10 560 555 520 320 12/13/2011 10:17 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2010 06 30 (8).xls M -27 2010 April's Waivered Injection Well Rep. • Page 1 of 2 Maunder, Thomas E (DOA) From: Martin, J. Hal [Hal.Martin @chevron.com] Sent: Saturday, May 15, 2010 10:11 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Greenstein, Larry P Subject: RE: 2010 April's Waivered Injection Well Report Tom, To add to what Larry mentioned below, if you recall, we made the first slickline attempt below during rig operations when there was a brief window of opportunity to get on the well with slickline. We didn't have enough time to continue working the issue when the plug didn't come right away. We are ready to make a second slickline attempt now that the rig is off location. However, the slickline lubricator is undergoing its annual inspection as we speak which is putting the work on hold a couple of weeks or so. This attempt will use a different pulling tool to hopefully release the plug. Thanx, Hal From: Greenstein, Larry P Sent: Friday, May 14, 2010 8:18 AM To: Maunder, Thomas E (DOA) Cc: Martin, J. Hal; Regg, James B (DOA); Lambert, Steve A Subject: RE: 2010 April's Waivered Injection Well Report Tom, In mid -March we tried pulling that plug, that kept us from getting across the packer with the temp survey, using some specialized high angle well pulling tools. Latched on with some difficulty, jarred up for 1 1/2 hrs, but couldn't get the plug to release. Jarred down to get off the plug and had trouble getting free to POOH. Caused us to pause to consider other options and not having much luck (without WO). Hoping to figure something out to get a more complete temp survey. The high angle really complicates the issues. Wish I had better news. Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, May 14, 2010 7:50 AM To: Greenstein, Larry P; Lambert, Steve A Cc: Martin, J. Hal; Regg, James B (DOA) Subject: RE: 2010 April's Waivered Injection Well Report Hi Larry, What is the status of the wireline work on M -27? Thanks, Tom 12/13/2011 2010 April's Waivered Injection Well Rep, • Page 2 of 2 From: Greenstein, Larry P [mailto:Greensteinlp @chevron.com] Sent: Friday, May 14, 2010 7:15 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, Steve A Subject: 2010 April's Waivered Injection Well Report Hi Tom & Jim, Here is April's monthly report for all the active monitored injection wells. The M -27 remains shut -in pending further wireline work to allow a more complete survey. The G -11 well is still showing a localized response to the volcano shutdown, RTP of D -47 and loss of G -22 & G -40 injection with a slow increase in the amount of water being injected at a fairly stable pressure. Nothing out of the ordinary appeared in the rates or pressures of the other wells this last month. Bottom line, I don't see any indication that any of these wells are losing control of the injected fluids downhole. Larry «Master Well List TIO Report 2010 04 30.xls» 12/13/2011 2OlO March's WoiveredInicot��l��l �� 9o�elmfl Injection �� Page E (DOA) From: Gnoanatein, Larry P [Greensteinlp@chevron.com] Sent: Tuesday, April 06, 2010 2:06 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Co: W1artin, J. Hal; Lambert, Steve A Subject: 2010 Marchs Waivered Injection Well Report Attachments: Master Well List TIO Report 2010 0401x|m Hi Tom & Jim, Here is March's monthly report for all the active monitored injection wells. The M-27 survey done last month indicated a temperature anomaly right around the packer that we couldn't explain, so the well has remained shut-in for now. We will be trying to pull a plug out of the well to allow us better coverage across this area of the welibore to further investigate Nothing out of the ordinary appeared in the rates or pressures of the other wells this last month. Bottom line, I don't see any indication that any of these wells are losing control of the injected fluids downhole. Larry <<&iauterVVe|| List TIO Report 2010 04 01.x|m>> 12/13/2011 2010 February's Waivered Injection Well *port Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Friday, March 05, 2010 3:05 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Martin, J. Hal; Lambert, Steve A; Kramer, Ted E. Subject: 2010 February's Waivered Injection Well Report Attachments: Master Well List TIO Report 2010 03 01.xls Hi Tom & Jim, Here is February's monthly report for all the active monitored injection wells. I've added the M -27 well to this report as it is now showing tbg /csg communication. A temp survey is scheduled for this weekend and we'll be getting the analysis completed early next week. I just heard that the high winds have delayed the first attempt at rigging up for the temp survey, we'll try again tomorrow. The D -41 & D -29 13 3/8" annulus pressures are stable and looking good. Nothing out of the ordinary appeared in the rates or pressures of the other wells this last month. Bottom line, I don't see any indication that any of these wells are losing control of the injected fluids downhole. Larry «Master Well List TIO Report 2010 03 01.xis» 12/13/2011 • • Plot Pressure & Rate vs Time - Well M -27 3500 3000 liti l'IL."...7 2000 2500 ^ 1 500 9 5/8" 2000 --- 13 3/8" —_— — m 16" a 20" a` 26" I 1500 Tubing - — 1000 Vol 1000 500 500 o 0 0 0 0 0 0 0 7 M N N N N N CV CO O o O O Date 13 3/8" 16" 20" 26" _ Tubin Voi TIO Report 02/28/10 620 610 565 295 17 980 02/27/10 620 610 560 295 1666 950 Data Sheet 02/26/10 620 610 560 295 1703 960 02/25/10 620 610 560 295 1751 960 02/24/10 625 610 560 294 1817 950 M-27 02/23/10 625 610 560 295 1788 980 02/22/10 625 615 560 300 1755 950 02/21/10 625 610 560 300 1870 940 INJECTION 02/20/10 625 610 560 295 1745 920 02/19/10 620 600 555 295 1555 1300 02/18/10 620 600 550 290 3033 1450 Permit # 1901380 02/17/10 605 585 550 290 3096 1690 02/16/10 600 595 555 290 3084', 1710 02/15/10 600 580 550 280 3089 1720 API # 50- 733 - 20423 -00 02/14/10 600 580 550 280 3089 1720 02/13/10 600 580 550 280 3080' 1720 02/12/10 600 580 560 280 3078 1730 08/30/2009 to 03/01/2010 02/11/10 600 580 560 280 3084 1690 02/10/10 600 580 550 280 3095 1690 02/09/10 600 580 550 280 3096 1700 02/08/10 600 580 550 280 3096 1700 • 02/07/10 590 580 560 280 3097 1710 02/06/10 600 580 560 280 3100 1710 02/05/10 600 580 550 280 3098 1710 02/04/10 600 580 550 280 3100 1720 02/03/10 600 580 550 280 3103 1730 02/02/10 600 590 560 280 3105 1740 02/01/10 600 590 560 280 3109 1720 01/31/10 600 580 560 280 3111 1710 01/30/10 600 580 560 280 3127. 1670 01/29/10 600 580 560 280 3124 1680 01/28/10 600 590 555 280 3122 1690 01/27/10 600 590 555 280 3128 1690 01/26/10 600 590 555 280 3125 169 01/25/10 600 590 555 280 3122 1 01/24/10 605 590 555 280 3122 16 12/13/2011 10:18 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2010 03 01 (6).xls M -27 • • Chevron John Zager Union Oil Company of California General Manager, Alaska 3800 Centerpoint Drive, Suite 100 MidContinent/Alaska SBU Anchorage, AK 99503 Tel 907 263 7815 - 3 S ( Mobile 907 223 0128 Fax 907 263 7897 Email jzager @chevron.com ,J—A,SZ�)- `t0 -0 C. --oS2) rL t b - OW - S RECENE � November 16, 2011 a� �n� a , ®® _ \y \ NOV Xi 7 ? IM VA0 -- ‘ a Oil & G as cons. C �� UIC Manager — 0 LQ� i 0 ( t t° asSi I➢ Thor Cutler, OCE -082 U.S. Environmental Protection Agency, Region 10 1200 Sixth Ave., Suite 900 , Seattle, WA 98101 Re: Amended Request for Permit Transfer: Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC Dear UIC Manager: Please replace my letter dated November 15, 2011 requesting permit transfer of Underground Injection Control (UIC) Permit No. AK- 1I006 -A by Union Oil Company of California ( "Union ") to Hilcorp Alaska, LLC. Union Oil Company of California ( "Union ") has entered into an Asset Sale and Purchase Agreement dated July 1, 2011 to sell its interests in the Cook Inlet Area to Hilcorp Alaska, LLC, ( "Hilcorp ") with an anticipated closing scheduled on or about December 15, 2011, assuming certain regulatory approvals are received by December 1, and all other Closing conditions are met. The actual closing date may vary depending on how quickly certain regulatory approvals are processed. The transfer of Union's interest to Hilcorp is conditioned on the completion of the transaction ( "Closing ") pursuant to the Asset Sale and Purchase Agreement by and between Union and Hilcorp. Union and Hilcorp will advise you upon Closing that the transfer has become effective, and Hilcorp has taken over Union's interest and operations, including the above referenced UIC Permit No. AK- 1I006 -A. Should the Closing for any reason not occur, Union will advise you that it has retained its interest. Environmental Protection Agency (EPA) Form 7520 -7, Application to Transfer Permit, is enclosed. Eight wells are permitted as candidate wells for Class I operation under this permit. These eight wells are: Dolly Varden Platform wells D -9RD and D- 15RD2, Grayling Platform wells G -5RD and G -16, King Salmon wells K -11 and K- 24RD2, and Steelhead Platform wells M -27 and M -30. Currently, only D -9RD has received written authori7atinn from EPA Region 10 to commence Class I injection. An agreement memorializing the transfer of UIC Permit No. AK- 1I006 -A from Union to Hilcorp is also enclosed. 1 of 2 • • UIC Manager US Environmental Protection Agency November 16, 2011 Page 2 We appreciate your attention to this request and apologize for the inconvenience. Should you have any questions, please do not hesitate to contact Faye Sullivan at FayeSullivanchevron.com or 263 -7685. Regards 7 (./ John ager r Enclosures: US EPA Form 7520 -7 Agreement to Transfer UIC Permit No. AK- 1I006 -A cc: John A. Barnes, Hilcorp Alaska, LLC Marc Bentley, ADEC Cathy Foerster, AOGCC 2 of 2 • • OMB No. 2040 -0042 Approval Expires 12/3112011 United States Environmental Protection Agency ` 1% C Washington, DC 20460 /+� Application To Transfer Permit Name and Address of Existing Pennittee Name and Address of Surface Owner Union Oil Company of California; P.O. Box 196247 State of Alaska, Department of Natural Resources Anchorage, AK 99519-6247 550 West 7th Avenue, Ste. 800; Anchorage, AK 99501 State County Permit Number Locate Well and Outline Unit on Alaska NA -State waters offshore AK- 11006 -A Section Plat • 640 Acres N Surface Location Description I I —1—T--1—, , se 114 of tie 114 of SW 1/4 of SW 1/4 of Section ,C__ Township 811 Range 13w -4---- I -i- - ` 4 - . i Locate Well In two directions from nearest lines of quarter section and drilling unit I 7 f 7 7-'I -7 Surface -4-1--4- _ -� -- I--- 4 T f Location 754 ft. frm (NIS) S Line of quarter section I I I I I I 1 and 113$1. from (WIN) w Line of quarter section. W l ii i 1 1 i I Weil Activity Well Status Type of Permit -4--I-4- -4 - I 4 ! N Class I operating Individual I I I I I I Class -- 7 - i - 7 - - - - I I - - it _. Modification/Conversion —K--- Area I % 1 I _ Brine Disposal K Proposed Number of Wells - - - - - I Enhanced Recovery i I I I I I 1 Hydrocarbon Storage . t S Class HI Other Lease Number See Attached Well Number See Attached Name(s) and Addresses) of New Owners) Name and Address of New Operator Hilcorp Alaska, LLC; 3800 Centerpoint Drive Suite 100; Hilcorp Alaska, LLC; 3800 Centerpoint Drive, Suite 100; Anchorage, AK 99503 -5826 Anchorage, AK 99503 Attach to this application a written agreement between the existing and new permittee containing a specific date for transfer of permit responsibility, coverage, and liability between them. The new permittee must show evidence of financial responsibility by the submission of a surety bond, or other adequate assurance, such as financial statements or other materials acceptable to the Director. Certification I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals Immediately responsible for obtaining the information, i believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. (Ref. 40 CFR 144.32) Name and Official Title (Please type or print) Signature Date Signed John "Lager, General Manager 11/15/2011 ,d ile EPA Form 7620 -7 (Rev, 12 -08) ' • • • Attachment to Form 7520 -7, Application to Transfer Permit One well is fully authorized for operation as a Class I well. An additional 7 wells are proposed candidate wells, but are not fully authorized for operation as Class I wells. The location map and surface well location shown on the front page of EPA Form 7520 -7 illustrates the location of the 1 authorized and operating Class I well. Well information for each of the 8 permitted wells is included on this page. Well API No. Lease Feet from Section Seward Meridian Line (Surface location) Sec Twp Range Authorized Well D -9RD I 50- 733 - 20131 -01 -00 ADL 018729 756 FSL/ 1138 FWL 6 8N 13W Permitted wells M -27 50- 733 - 20423 -00 -00 ADL 018730 974 FNL/ 531 FWL 33 9N 13W M -30 50 -733- 20430 -00 -00 ADL 017594 967 FNL/ 520 FWL 33 9N 13W G -5RD 50- 733 - 20162 -01 -00 ADL 018730 1.838 FNL/ 1487 FEL 29 9N 13W G -16 50- 733 - 20060 -00 -00 ADL 017594 1879 FSL/ 1381 FEL 29 9N 13W K -11 50- 733 - 20148 -00 -00 ADL 017594 617 FSL/ 131 FEL 17 9N 13W K -24 RD2 50- 733 - 20330 -01 -00 ADL 018730 733 FSL/ 131 FEL 17 9N 13W 0-15 RD2 50- 733 - 20159 -02 -00 ADL 018729 754 FSL/ 1130 FWL 6 8N 13W FSL = Feet from south line of quarter section (feet south section line) FNL= Feet from north line of quarter section FWL= Feet from west line of quarter section FEL= Feet from east line of quarter section • • Agreement to Transfer UIC Permit No. AK- 1I006 -A This Agreement to Transfer UIC Permit No. AK- 1I006 -A ( "Agreement ") is made the 15 day of November, 2011 between Union Oil Company of California, a California corporation ( "Union "), and Hilcorp Alaska, LLC., a Delaware limited liability company ( "Hilcorp "), collectively referred to as the "Parties," or individually as a "Party." RECITALS WHEREAS, Union and Hilcorp have executed an Asset Sale and Purchase Agreement dated effective as of July 1, 2011, ( "ASPA ") whereby Union agreed to sell its therein described interests in the Cook Inlet Area to Hilcorp; and WHEREAS, Union's interests in the Cook Inlet Area include UIC Permit No. AK- 11006 -A; and WHEREAS, Union wishes to effect the transfer of that permit to Hilcorp as authorized by regulation promulgated by the Environmental Protection Agency ( "EPA ") at 40 CFR § 144.38(b); and WHEREAS, the EPA requires a written agreement between Union and Hilcorp containing the specific date for transfer of permit responsibility, coverage and liability between them. Agreement to Transfer UIC Permit No. AK -I I006 -A • • AGREEMENT NOW, THEREFORE, in consideration of each Party's intent to consummate the closing of the ASPA, and for such other consideration the receipt and sufficiency of which is hereby acknowledged, the Parties agree as follows: 1. In the absence of notification to the Parties by the Director of EPA of the Director's intent to modify or revoke and reissue the permit, then effective as of the date of closing of the transaction contemplated by the aforementioned ASPA (the "Closing "), which Closing is projected to occur on or about December 15, 2011, subject to certain regulatory approvals being received by December 1, 2011 and all other Closing conditions being met, Union transfers and assigns to Hilcorp, and Hilcorp agrees to accept and assume, all of Union's rights, responsibilities, and liabilities under UIC Permit No. AK- 1I006 -A. The specific date for transfer of permit responsibility from Union to Hilcorp for this permit will be on the actual Closing date, which is anticipated on December 15, 2011, but may be later depending on when Closing actually occurs. 2. Should the Closing not occur for whatever reason, the Parties agree that Union shall retain all of its rights, responsibilities, and liabilities under UIC Permit No. AK- 11006 -A, and Hilcorp shall have no rights, responsibilities, or liabilities under the permit. 3. In the event that the Director of EPA notifies the Parties of the Director's intent to modify or revoke and reissue the permit, then, assuming the Closing will nevertheless occur, Union shall undertake commercially reasonable efforts to cooperate with Hilcorp should it 2 Agreement to Transfer UIC Permit No. AK- 1I006 -A 0 choose to engage with EPA while the Director works to modify or revoke and reissue the permit. 4. Notices shall be made as follows: Union: Steve Wright Asset Development Manager 3800 Centerpoint, Dr., Suite 100 Anchorage, AK 99503 (907) 263-7865 sswr@chevron.corn Hi !carp: John Barnes Senior Vice President Exploration and Production - Alaska 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 (907) 263-7739 5. This Agreement may only be amended by written agreement signed by a duly authorized representative of each Party. 6. Except as set forth herein, this Agreement shall be binding only upon, and inure only to the benefit of, the Parties and their respective successors and assigns. No Party shall assign its rights or benefits under this Agreement without the prior written consent of the other Party. 7. This Agreement shall be governed by the laws of the state of Texas. 3 Agreement to Transfer U1C Permit No. AK-1 1006-A • 8. The Parties have jointly drafted this Agreement, and this Agreement shall not be interpreted against or in favor of either of the Parties on the ground that any Party participated in drafting this Agreement. 9. This Agreement constitutes the entire agreement and understanding of the Parties with respect to the matters addressed herein. 10. In the event that there is any conflict between terms and conditions of this Agreement and the ASPA, the terms and conditions of the ASPA shall prevail. 11. No Party or representative, agent, or attorney for a Party has made any representation or warranty to influence the execution of this Agreement that is not expressly contained in this Agreement. 12. This Agreement may be executed in counterparts, all of which • together shall constitute one and the same instrument. 13. By execution of this Agreement, each of the Parties hereto represents and warrants that they have the corporate power and authority to execute and deliver this Agreement and that each of the Parties has the power and authority to make and carry out its obligations hereunder. WHEREFORE, this Agreement shall become fully enforceable and effective in all respects on the latter of the two dates appearing below. 4 Agreement to Transfer UIC Permit No. AK- 1I006 -A • Union Oil Company of California, Hilcorp Alaska, LLC, a a California corporation Delaware limited liability company By -.+., .t B y: Name: Vilit 1 Name: --ia l-■ 4 Its: Its: k 1 Date: ,4.1 Date: /tio.f Zo 11 5 Agreement to Transfer MC Permit No. AK- 11006 -A MEM®RANDLTM • To: Jim Regg ~ 3j2?(G`~ P.I. Supervisor ~P~~ rRONI: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Cox~sexvation Commission DATE: Tuesday, March 17, 2009 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 1tf-27 TRADING BAI UNIT M-27 Src: hxspector l~rnN-('ONFiDENTIAL Reviewed By:!~-7 P.I. Suprv ~~=~`~ Comm Well Name: TRADING BAY UNIT M-27 Insp Num: mitRCN090307102550 Rel Insp Num: API Well Number: 50-733-20423-00-00 Permit Number: 190-138-0 Inspector Name• Bob Noble Inspection Date: 3/6,2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well M-27 Type Inj. ~~ TVD 9012 ~ ~ 1600 2260 2260 2260 ;i P.T. 1901380 TypeTest SPT TCSf p51 2'60 ~ OA 540 5-1(1 540 540 Interval 4YRTST P/F P ~ TUbing 3^_00 3200 3200 3200 NOteS: Good test ;"``.yy ~y ~^iU Tuesday, March 17, 2009 Page 1 of 1 RE: M-27 In house MIT Steelhead • Regg, James B (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com] ~,UD~ Sent: Wednesday, March 04, 2009 10:32 AM ~~ ~ 3l~ ~ To: Re , James B DOA 99 ( ) Subject: RE: M-27 In house MIT Steelhead Attachments: MIT SHP M-27 2-13-09.x1s Here you go Jim. I`ll get the witnessed form off to everyone as soon as we get it done. Larry From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, March 04, 2009 9:08 AM To: Greenstein, Larry P Subject: RE: M-27 In house MIT Steelhead Pleae put info on the attached form; thank you. Jim Regg AOGCC ~~" '' ~~`~ ~~~ ~' t~` ~J~e ors-dam' ~.~..j " 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Wednesday, March 04, 2009 8:08 AM To: Regg, James B (DOA) Cc: Martin, J. Hal; Bartolowits, Paul D; Holt, Chester; Chivers, Mike W Subject: RE: M-27 In house MIT Steelhead Hi Jim, Here is a copy of the pre-test we performed on M-27 the 13th of 1=ebruary. Page 1 of 2 P~ Igo - ~3g f'll get everyone copied on the witnessed MIT whenever Noble can get with the platform to complete it. Thanks for the workaround, Jim. Larry «M-27 In-house MIT 2/13/09» 3/4/2009 RE: M-27 In house MIT Steelhead Page 2 of 2 From: Chivers, Mike W Sent: Tuesday, March 03, 2009 6:15 PM To: Greenstein, Larry P Cc: Martin, J. Hal; Bartolowits, Paul D; Holt, Chester Subject: M-27 In house MIT Steelhead Larry After talking with Hal Martin about the MIT test on M-27 he brought to my attention we were due for our MIT on 2- 28-2009. We knew this and had been in contact with Mr. Bob Noble about setting a date. Although I had been in contact with Bob Noble with the AOGCC about rescheduling the test day so he can return from the Slope, I failed to ask permition from Jim Regg at the AOGCC to extend our deadline. Hal requested that I contact Mr. Regg and explain it was an over site on our part and ask him to advise us on either shutting the well in until Mr. Noble gets here or leave it running. I then contacted Mr. Regg and explained to him our dilemma and the fact that we did do an in house test at this time and it held good. He felt this was not a problem because they typically give some grace period and that since we did an in-house test he felt this would be sufficient for this period of time until Mr. Noble arrives to do a witnessed test. He did say not to shut the well in, but he would like for us to send him a copy of the in-house MIT test. Could you please sent him our in house MIT test? Thanks Mike Chivers 3/4/2009 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: Union Oil Company of Afaska McArthur River Field / TBU / Steelhead Platform 02/13/09 Chris Johnson in-house pre-test, not witnessed Packer Depth Pretest Initial 5 Min. 30 Min. Well M-27 Type Inj. W TVD 9,012' Tubing 3,150 3,150 3,150 3,150 Interval O P.T.D. 1901380 Type test P Test psi 2253 Casing 100 2,260 2,260 2,260 P/F P Notes: In-house test prior to calling for state inspector to OA 510 510 510 510 witness official test Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test i INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 2009-0213_MIT_TBU_M-27.x1s 1. Operations Abandon Performed~. ¿Alter Casing D.f Pull Tubing 0 Chw.:ye A'l>proved Program)) Operat. Shutdown 0 2. Operator Union Oil Company of California Name: RT OF SUNDRY WELL OPERATIONS Pâ.-S'ltwlt.b;;-ð ì ~-S Stimulate Waiver 0 Time Extension Re-enter Suspended Well 0 5. Permit to Drill Number: 190-138 6. API Number: 50-733-20423 9. Well Name and Number: M-27 . 10. Field/Pool(s): McArthur River Field / G Zone Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development 0 Stratigraphic 0 4_""....' V l::U JUN 2 9 2006 AIBska ail & Gas C C '. ons. ommìSSI 1, n orage nable to / Perforate ^f *\øP I STATE OF ALASKA e ALAS Oil AND GAS CONSERVATION COMMISSION , /..... 3. Address: PO Box 196247, Anchorage, AK 99519 Exploratory 0 Service 0 7. KB Elevation (ft): 74.35' RKB to tbg hanger 8. Property Designation: Steelhead Platform ;It> L.. 1$ 7"5ð ,J)s".t!I.O(, 11. Present Well Condition Summary: Total Depth measured 15,380' feet true vertical 10,855' feet Effective Depth measured 14,240' feet true vertical 10,060' feet Casing Length Size Structural Conductor 1332 16" Surface 4106 13-3/8" Intermediate 410 10-3/4" Production 13156 9-5/8" Liner 1928 7" Plugs (measured) 14,240' Junk (measured) 13,543' (fill) MD TVD Burst Collapse 1 ,412' 4,185' 487' 13,643' 15,379' 1 ,409' 3,764' 486' 9,685' 10,854' 2,630 psi 3,090 psi 5,860 psi 6,870 psi 8,160 psi 1,020 psi 1,540 psi 3,220 psi 4,760 psi 7,020 psi Perforation depth: Measured depth: 12,770' - 13,295' ',' ~\j(>jL'~' 3\,;'~ ~~ '~; '1tj,k.., ..j, True Vertical depth: 9,141' - 9463' Tubing: (size, grade, and measured depth) 4-1/2" L-80 12,620' Packers and SSSV (type and measured depth) Baker SB-3 Packer 12,555' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 13. N/A Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 15. Well Class after proposed work: Exploratory D Development D 16. Well Status after proposed work: OilD Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 0 x GINJ D WINJ 0 WDSPL D Sundry Number or N/A if C.O. Exempt: 305-335 Contact Chantal Walsh (263-7627) Printed Name Timothy C. Brandenburg Title Drilling Manager Signature IG'¡r'PLf .. ¡\p\ Date (p /0.29/~ "ì Submit Original Only ( ~ Ai> ¡,¿ff.t;t. ~/tb M-27 Primary Job Type Perforating Jobs Primary Job Type Perforating Daily Operations 1/19/200600:00 -1/20/2006 00:00 Operations Summary Mob equipment to platform. Shut down water flood. Have PJSM. Bleed down well. 1/20/2006 00:00 - 1/21/2006 00:00 Operations Summary Continue to bleed down well. PJSM. Rig up slickline. RIH with 2.5" gauge ring. Tagged at 12,782' RKB POOH. RIH with swedge. Tagged at 13,540 RKB. POOH RIH with 2.25" bailer. Tagged with bailer at 13,543' RKB. POOH with bailer full of fill. RIH with bailer and tagged fill at 13,543' RKB. POOH with bailer filled with fill. This depth is not to the depth of the requested re perf interval. RD sliickline and stopped job. ~ -. RKB to TBG Hanger = 74.35' 3 4 5 16" 75 K-55 BTC 80' 1412' 13-3/8" 61,68 K-55 BTC 79' 4185' 10-3/4" 51 N-80 BTC 77' 487' 9-5/8" 47,53.5 N-80 BTC 487' 13643 ' 7" Lnr 29 N-80 TKC 13451 ' 15379' 4-1/2" 12.6 L-80 CSCB 74.35' 12620' 521 ' 2 3 4 5 6 7 8 9 10 11 12 13 12554' 12555' 12576' 12610' 12620 ' 12698' 718' 14250' 14260' 14284' 14293' 14329' 14332' JEWELRY Baker "F" nipple w/ flow couplìng above and below (3.750" ID) Baker "E-22" anchor locator seal assy Baker SB-3 Packer Baker "F" nipple (3.680" ID) Baker "R" nipple (3.625" ID) WLREG HOWCO Casing Patch (8.225"ID) Baker FB-l Packer Pen go bridge plug w/ 20' cement dumped on top Halliburton type "D" bridge plug Baker "F" nipple (2.750" ID) Baker "R" nipple (2.690" ID) WLREG Slickline/Fish/Fm A. 10/6/94: Top of dump bailed cement estimated at 14240'. B. 1/20/06: Tagged fill at 13,543' RKB ,/ A 12688' 12690' 8 12770' 12790' G-1 4 2/13/91 TCP 12840' 12875' G-2 4 2/13/91 TCP 12910' 12935' 0-2 4 2/13/91 12950' 12990' G-3 4 2/13/91 TCP 13030' 13100' G-4 4 2/13/91 TCP 13215' 13295' G-5 4 2/13/91 TCP 14524' 14606' WF-2 4 2/12/91 TCP/Isolated 14636' 14666' WF-3 4 2/12/9 1 TCP/Isolated 14734' 14776' WF-4 4 2/12/91 TCP /Iso lated A 14810' 14989' WF-5 4 2/12/91 TCP /Iso 1ated 15014 ' 15066 ' WF-6 4 2/12/91 TCP/Isolated 15110' 15142' WF-7 4 2/12/91 TCP/lsolated PBTD = 14240' TD = 15380' O:\DRILLI~®~l¡¡'~Ié\-~ Pr~fs\2006 Steelhead\M-27\M-27 Add HK Perfs AFE 164730\Schematics\M- 27 _Schem]eb91.doc REVISED: 7/I4/05 DRA WNBY: JHM l'r:'[, '.' "",Ii,",,",~~\, ,'~ I' r,f6' " ~ I ! l'l' ! I! ; If,' .: ¡, ~; 1;: \~ ! I ! if il i,~." ¡ :\.: iU \) U lob ) if ~...J :1 ~:::::J :1 :1 U ) / / .I / FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AM) GAS CONSERVATION COMMISSION 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 'co -l3CZ Re: McArthur River M-27 Sundry Number: 305-335 5CAWNED NOV ij 2,2005 Dear Mr. Brandenburg: 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 fonn. Please provide at least twenty-four (24) hours 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 fùe with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Su perior Court unless rehearing has been requested. Sincerely, DATED thiS~ay of October, 2005 Enc!. 1. Type of Request: Cf4; O~¿,7 ·-0S- STATE OF ALASKA ALA } OIL AND GAS CONSERVATION COMM, ÀON APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: U Suspend U Repair well 0 Pull Tubing 0 Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 74.35' RKB to tbg hanger 8. Property Designation Steelhead Platform 11. Total Depth MD (ft): 15,380' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 12,688'to 15,142' Packers and SSSV Type: Development Stratigraphic Perforate ~ w~~t(~, \r:~~ Gem:nï1;~~tJ Stimulate 0 Time Extension 1j' ,", Re-enter Suspended Well 0 5. Permit to Drill ~umber: ,.,./ Exploratory 0 190-138 \.," [] 6. API Number: ./ 50-733-20423-00 o o Service 9. Well Name and Number: M-27 10. Field/Pools( s): McArthur River Field/G-Zone PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 10,855' Effective Depth MD (ft): 14,240' Effective Depth TVD (ft): 10,060' MD TVD Plugs (measured): cement plug @ 14,240' Burst Length Size 1 ,332' 16" 4,106' 13-3/8" 410' . 10-3/4" 13,156' 9-5/8" 1,928' 7" Perforation Depth TVD (ft): 9,093' to 10,682' 1 ,412' 4,185' 487' 13,643' 15,379' Tubing Size: 4-1/2" Baker SB-3 Packer; Baker FB-1 Paker 1 ,409' 3,764' 486' 9,685' 10,854' Tubing Grade: L-80 Packers and SSSV MD (ft): ' E'VED~íì OCT 2 6 ZOOS ~~ Junk (measured): Collapse 2,630 psi 1,020 psi 3,090 psi 1,540 psi 5,860 psi 3,220 psi 6,870 psi 4,760 psi 8,160 psi 7,020 psi Tubing MD (ft): 12,620' 12,555'; 14,250' 12. Attachments: Description Summary of Proposal Detailed Operations Program [] BOP Sketch 14. Estimated Date for Commencing Operations: U 13. Well Class after proposed work: o Exploratory 0 Development 0 1.2./' /O.s- 15. Well Status after proposed work: 11f3/2005 Oil 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 16. Verbal Approval: Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title Drilling Manager Signature 907-276-7600 Date ;m]~z y~hOne COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Contact Service D Abandoned o o WDSPL Steve Tyler 263-7649 /04-'C6 -oS- Sundry Number: ,:5('" 5- 3-3'S- Location Clearance 0 Other: \I\..X \ \ L~\ t"C \ e...C;," \ ~\\>~,,-\- ~\' d.D~~,CdS-,d-~{ Approv . RBDMS BFL 0 CT 3 J 2005 APPROVED BY CÕMRrGR N AT: COMMISSION Date: ,of! or Submit in Duplicate ) ) M-27 Work Summary Perforate Hemlock sands · MIRV Slickline. Tag fill. RIH wi dummy gun. RD Slickline. · MIRV Eline. RIH wi 2-l/2"guns (HSD, 6spf, 60ophasing). · Perf Hemlock sands as follows (GR log will determine DIL depth for perf): HB-5 14185'md to 14210'md HB-5 14150'md to 14160'md HB-4 14065'md to 14095'md HB-4 13993'md to 14020'md HB-4 13943'md to 13973'md HB-3 13825'md to 13860'md HB-l 13595'md to 13618'md (contingent) (\"\~E:C \G.~\ · RD Eline. · Turn well over to production. RKB to TBG Hanger 74.35' 1412' 4185' 487' 13643' 15379' 80' 79' 77' 487' 13451 ' BTC BTC BTC BTC TKC 16" 75 K-55 13-3/8" 61,68 K-55 10-3/4" 51 N-80 9-5/8" 47,53.5 N-80 7" Lm 29 N-80 1 Tubing: 4-1/2" 12.6 L-80 12620' 74.35' CSCB Baker "F" nipple w/ flow coupling above and below (3.750" ill) Baker "E-22" anchor locator seal assy Baker SB-3 Packer Baker "F" nipple (3.680" ill) Baker "R" nipple (3.625" ill) WLREG HOWCO Casing Patch (8.225" ill) Baker FB-l Packer Pengo bridge plug w/20' cement dumped on top Halliburton type "D" bridge plug Baker "F" nipple (2.750" ill) Baker "R" nipple (2.690" ill) WLREG 521' 12554' 12555' 12576' 12610' 12620' 12698' -718' 14250' 14260' 14284' 14293' 14329' 14332' 2 3 4 5 6 7 8 9 10 11 12 13 3 4 5 A. 10/6/94: Top of dump bailed cement estimated at 14240'. A 12688' 12690 ' 2/4/91 Sqz Perfs 8 12770' 12790' G-1 4 2/13/91 TCP 12840' 12875' G-2 4 2/13/91 TCP 12910' 12935' G-2 4 2/13/91 TCP 12950' 12990' G-3 4 2/13/91 TCP 13030' 13100' G-4 4 2/13/91 TCP 13215' 13295' G-5 4 2/13/91 TCP 14524' 14606' WF-2 4 2/12/91 TCP /Isolated 14636' 14666' WF-3 4 2/12/91 TCP/Iso1ated 14734' 14776' WF-4 4 2/12/91 TCP/Iso1ated A 14810' 14989' WF-5 4 2/12/91 TCP/lso1ated 15014' 15066' WF-6 4 2/12/91 TCP /Iso1ated 15110' 15142' WF-7 4 2/12/91 TCP/Iso1ated PBTD = 14240' TD = 15380' O:\DRlLL~M;IF~l~ I'~~ts\2005 Stee1head\M-27 Add HK Perfs\P1an Package\M-27 _ Schem ]eb91.doc REVISED: 7/14/05 DRAWN BY: JHM MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg-;:) .1 {- P.I. Supervisor f\etn3, 4 ~i7 DATE: Monday, February 28,2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA M-27 TRADING BAY UNIT M-27 LO 0 -- 13<0 FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .:Jþ£-- Comm Well Name: TRADING BAY UNIT M-27 Insp Num: mitLG050226215833 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50.733-20423-00-00 Permit Number: 190-138-0 Inspector Name: Lou Grimaldi Inspection Date: 2/25/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well M-27 Type Inj. S TVD 8993 IA 200 2330 2320 2320 I P.T. 1901380 TypeTest SPT Test psi 2248.25 OA 580 590 600 600 Interval 4YRTST P/F P Tubing 3300 3250 3270 3270 Notes: IA checked for fluid to surface. ;",("');¡'Ai~,Cl''''\~ \\11 r\R 1 ': 2.DD5 ~~,hß~~~'-'" mM ..'""~. Monday, February 28,2005 Page 1 of 1 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P E E L E W A T E R IA L U N D E TH IS M ARK ER R STATE OF ALASKA ALASKA O~b AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging X Perforate Pull tubing After casing Repair well Pull tubing Other 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 - 6247 5. Type of Well: Development ~x Exploratory __ Stratigraphic Service ~ Location of well at surface Leg B1, Cond. #4, Steelhead Platform 974' FNL, 531' FWL, Sec. 33, T9N, R13W, SM At top of productive interval 4,158'FSL, 1,507'[FWL, Sec. 27, TgN, R13W, SM 0~IGINAL At effective depth At total depth 160' FSL, 2,912' FWL, Sec. 22, T9N, R13W, SM 6. Datum elevation (DF or KB) 160' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number M-27 9. Permit number 90-138~94-224 10. APl number 50-733-20473-00 11. Field/Pool G Zone/McArthur River Field 12. Present well condition summary Total depth: measured true vertical 15,380 feet Plugs (measured) 14,240' - 14,285' 10,852 feet Effective depth: measured 14,240 feet Junk (measured) true vertical 10,069 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1,332' 16" 2,200 sx 1,412' 1,409' Surface 4,106' 13-3/8" 2,650 sx 4,185' 3,765' Intermediate 410' 10-3/4" 3,130 sx 487' 487' Production 13,156' 9-5/8" 3,130 sx 13,643' 9,685' Liner 1,928' 7" 500 sx 15,379' 10,852' Perforation depth: measured See Attached true vertical See Attached i "~::'. ii' "';i ~... ,.', ! i..-_", i! '~ .: Tubing (size, grade, and measured depth) 4-1/2", 12,75#, L-80, Hydril CS-CB Tbg IPC w/TK-99 to 12,620' Packers and SSSV (type and measured depth) Baker 'SB-3' Pkr @ 12,554'; Baker 'FB-1 Pkr @ 14,250' 13. Stimulation or cement squeeze summary Intervals treated (measured) 14. Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation 2974 1670 Subsequent to operation 3341 3590 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil Gas Suspended Service X 17. I hereby certify that the for.;ego~ng.,is true an& correct to the'best of my knowledge· Signed G. Russell Schmidt Form 10-404 Rev 06/15/88 ' SUBMIT IN DU~LI'CATE ATTACHMENT #1 WELL M-27 Perforations MD TVD G-Zone (Open) 12,770 12,790 9,142 9,153 12,840 12,875 9,183 9,204 12,910 12,935 9,226 9,241 12,950 12,990 9,250 9,274 13,030 13,100 9,299 9,342 13,215 13,295 9,413 9,463 West Foreland (Isolated by Pluo) 14,524 14,606 10,251 10,308 14,636 14,666 10,328 10,349 14,734 14,776 10,396 10,425 14,810 14,914 10,449 10,521 14,914 14,989 10,521 10,573 15,014 15,066 10,591 10,627 15,110 15,142 10,658 10,681 Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 995'19-6247 Telephone (907) 276-7600 UNOCAL March 4, 1996 Mr. David Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Commissioner Johnston' Re' Steelhead Platform - Well M-27 APl Number 50-733-20423-00 Between September 29, 1994 & October 6, 1994, a plug was set at 14,240'-14,285' to isolate West Foreland perforation. This was done to prevent communication with a known West Foreland thief zone, and improve injection into the G-Zone Very truly yours, ..... /-"-,-;' :' ' --' '.:"i G. Russell Schmidt Drilling Manager Attachment 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 casin"~- Repair wel--~' Plugging X -- Time extension Stimulat"~' Change approved program Pull Tubing Variance Perforate Other 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Achorage, AK 5. Type of Well: Development Exploratory Stratig rap hic Service 4. Location of well at surface 974' FNL, 531' FWL, Sec. 33 9N-13W-SM At top of productive interval 4,158' FSL, 1,507' FWL, Sec. 27 9N-13W-SM At effective depth Leg B1, Cond. #.4, Steelhead Platform At total depth 160' FSL, 2,912' FWL, Sec. 22-13W-SM ORIGINAL 6. Datum elevation (DF or KB) 160' KB above MSL feet 7. Unit or Property name Trading Bay Unit j8. Well number M-27 9. Permit number/approval number 90-138 10. APl number 50- 733-20473 11. Field/Pool McAurthur River Field G-Zone, West Foreland 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 1 5,380' feet 10,852' feet 15,21 5' feet 10,680' feet Length Size Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 1,332' 16" 2,200 sx 1,412' 1,409' 4,106' 13-3/8" 2,650 sx 4,185' 3,765' 410' 10-3/4" 3,130 sx 487' 487' 13,156' 9-5/8" 3,130 sx 13,643' 9,685' 1,928' 7" 500 sx 15,379' 10,852' 13. See Attachment #1 Tubing (size, grade, and measured depth) 4-1/2", 12.75#, L-80, Hydril CS-CB Tbg IPC w/TK-99 to 12,620' Packers and SSSV (type and measured depth) Baker 'SB-3' Pkr @ 12,554'; Baker 'FB-I' Pkr @ 14,250' Attachments Description summary of proposal X RECEIVED AUG '1 7 1994 Alaska Oil & Gas Cons. Commission Anchorao~ Detailed operations program BOP sketch X Estimated date of commencing operation August 18,1994 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended Service Water Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢...~ ~/-'. ~' Title FOR COMMI'~SION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test__ Location clearance Mechanical Integrity Test __ Subsequent form required 1-~- Approved by order of the Commision Original Signed By David W. Johnston Approved Copy Returned Commissioner IApprova, NO.¢ ¢--¢P,~ ¢ Date ~/Z ?///~v ~ SUBMIT IN TRI~LICATE~ Form 10-403 Rev 06/15/88 MD 12,770' - 12 840' - 12,910' - 12,950' - 13,030' - 13,215' - 14,524' - 14,636' - 14,734' - 14,810' - 14,914' - 15,014' - 15,110' - Attachment #1 Well M-27 Perforations G-Zone 12,790' 12 875' 12,935' 12,990' 13,100' 13,295' 'I'VD 9,142' - 9,183' - 9,226' - 9,250' - 9,299' - 9,413' - West Foreland 14,606' 14,666' 14,776' 14,914' 14,989' 15,066' 15,142' 10,251' 10,328' 10,396' 10,449' 10,521' 10,591' 10,658' 9,153' 9,204' 9,241' 9,274' 9,342' 9,463' 10,308' 10,349' 10,425' 10,521' 10,573' 10,627' 10,681' RECEIVED AUG ] 7 1994 Oii & Gas Cons. Commission Anchor~,:j~; [DATABASE.XLW]Perf Database STEELHEAD WELL M-27 PROPOSED WEST FORELAND PLUGGING PROCEDURE CURRENT STATUS: OBJECTIVE: Commingled G-Zone and West Foreland water injection well. Plugback the West Foreland. Continue G-Zone injection. PROCEDURE: i · · SI injection. RU slickline. PT lubricator and BOP's to 2500 psi. RIH with 20' of 2-1/8" stem to 12,800' to ensure clearance through damaged casing patch at 12,678'. POOH and RD slickline. RU coiled tubing and pumping equipment. PT lubricator, BOP's and pumping lines to 4000 psi. · RIH with 2-1/8" inflatable cement retainer (6000 psi differential ressure rating). Set retainer at 14,320' (inside tail pipe of solation packer). 5. Mix and pump 13 sacks Class "G" cement and lay a continuous plug from retainer at 14,320' to 14,200'. 6. POOH to 12,600'. CBU with FIW. POOH and RD coiled tubing. 7. WOC for 24 hours. 8. Return well to G-Zone injection. RECEIVED AUG 1 ? 1994 Alaska. Oil & Gas Cons. Commission Anchora,g~ MARATHON OIL . iPANY TRADING BAY UNIT WELL M-B7 RECEIVED AUG ] 7 1994 ~iaska Oil & Gas Cons, Commission Anch0ra~ Comole'ted 2/19191 ~/C~Po~D ~t~$T F0~z~,JD ~AJ~FCr,o~J AU measUreMents ~Pe RKO to Top oF equipMenl~. CQsinq Detoi[ 26' 16' 75~ K-55 80' 1,412' 13-3/8' 61~ K-55 79 2.958' 13-3/8' 68~ K-55 ~,958 4,185' 10-3/4' 51N N-80 77' 487' 9-5/8° 47~ N-80 487' 6.909' 9-5/8' 53.5f~ N-BO 6,909 ' 13.$43' 7' ' '~9t~ N-80 13.468 .... 15.379' Completion Strlno: 74' 5~1' 1~554' 1~555' 12559' 1~575' l~61D' 18617' 4-1/2" lP.75N, L-80, Hydr'~{ CS-CB Tbg. IPC w/ TK-99 FHC H~nger TC1AEN 4-1/~' CS B~ker 'F' nipple, 3.75' ProFile, CS-CB BxP w/ two ni~rile Chevron se~l units. ~R~r 'S~-3' p~cker, size [94-47 ~oker mlllout extension 7' LTC PxP B~ker 'F' nipple, 3.6B' ProFile, CS-C~ BxP ~ker '~' nipple, 3.GB' ProFile, 2.6~5" NoGo X-O 4-1/~' CS-C2 ~OX x Vom Pin AVA ~ez~CZ~bte ~tt se~t .A-CHD-RBS-450-O ]SOlm tion PooRer 14~50' BoNer 'FB-,' D~cker, slze 85-40. 14~53' B~ker miL~OU¢ extension, 5' LTC PxP 14~58' X-O 5' LTC Box x 3-1/~' Butt tbg pin ~4~9~' B~ker 'F' nipple, ~.75' profile, Butt BxP . ~ ~ II Max. ID reauceo P~FORAT[DNS I/ Intervol F__~ Sp.F Phn~p Dote ~9.zoo' G-ZONE q~ c¢_~¢ 4 60 8/13/91 ~o~ 1~,770' - 1~,790' ~0' 1~.840' - 1~,875' 35' 4 60 1~.910' - 1~.935' ~5' 4 60 _.~ ~e~.~- 1~.950' - 1~,990' 40' 4 60 2/13/9I ~ ~4.~o 13.030' 13.100' 70' 4 60 2/13/91 13,~15' - 13,~95' BO' 4 GO i = 14,.S-Zq WEST FORELAND I 14.524' - 14,606' 82' 4 60 2/1279) ~ 14,G36' - 14,666' 30' 4 60 2/1~/91 ! 14,734' - 14,776' '42' 4 60 2/1E/9I 14,810' - 14,914' 104' 4 60 2/IE/9! -¢'W~-Sm 14,914' - 14,989' 75' 4 60 2/12/91 -~f°/b~c~'jp 15,014" .- 15,066' 52' 4 60 2/11~/9I ~= 15,110" - 15,14a' 32' 4 60 2/12/91 I Revision Dote: 1216/91 PBTD ~ 15,E~BO' Revised By, PMO/evo TD ~ 15.380' Rec~on: Uo~l~te Previous Revision, 7/IE/91 STEZLHEAD PL ATFoRM Coiled Tubing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 psi WP -- HYDRAULIC RAMS '4 '1716'. 5000 CHISTMAS TREE mi Jilt POSITIVE CHOKE RECEIVED AUG 1 7 199~ Oil & Gas Cons. Commission 2' 5000 psi 2' 3000 psi. 13 3/8' CASING STATE OF ALASKA AkASK~k OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL ~ GAS ~ SUSPENDED ~ ABANDONED ~ 2. Name of Operator UNOCAL (Marathon Oil Co. Sub-operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 / Y~F~ ! I 7. Permit Number l~~ 18. APl Number ~;~ ~o~,~~,~T~ ~o- 733-20473 4. Location of well at surface Leg 51, Cond. steelhead PlatfOrm~.~:~'~,, 974' FNL, 531' FWL, Sec. 33 9N-13W-SM At Top Producing Interval 4,158' FSL, 1,507' FWL, Sec. 27 9N-13W-SM At Total Depth 160' FSL, 2,912' FWL, Sec, 22 9N-13W-SM ,5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 160' KB above MLLW '[ ADL 18730 12, Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. 11/5/90 J 1/26/91 . 3/22/91 17. Total E~ept'h (MD+TVD) J18.Plug Back Depth(MD+Tv'D) 19. Directional Survey 15380m & 10852'[ 15215' & 10680' YESi--]X NO[]]] 22, Type EI.ectric or Other Logs Ru.n ..... GR/PHASOR/SONIC/TCL/AMS/TDT/CET/CBT/CCL 9. Unit or Lease Name Trading Bay Unit 10. Well Number M-27 11. Field and Pool McArthur River Field "G" 0il Zone W/Fore]and 15. Water Depth, if offshore 116. No. of Completions 187 Ifeet MSL) 1 20. Depth where SSSV set 21. Thickness of Permafiost 521~e' MD N/A 23. CASING, LINER ANDCEMENTIN( RECORD CASING SIZE i6" 10-3/4" g-5/8" 7" WT. PER FT. 75# 29# GRADE K-55 K-55 'N-80 N-80 N-80 SETTING DEPTH MD TOP ] BOTTOM . 80~I i,4i2' 79' 4,185' ' 11' 481' 487' 13,643' 13,451' 15,3~9i HOLE SIZE ~2-'; 17.5" 12.25" 12.25" 8.5" 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) See Attached Sheet 25, CEMENTING RECORD 2200 sx Class 1150/1500 sx Class 12~0/1900 sx Class 1230/1900 sx Class 500 sx Class TUBING RECORD AMOUNT PULLED 39,000# 357,000# 357,000# SIZE 45II .5II 26. DEPTH SET (MD) 12,620' 14,250-14,332 PACKER SET (MD) 12,555' 14,250 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT'S'KIND OF MATERIAL USED 27. Date First Production Date of Test I Hours Tested 03/23/91! 24 Flow Tubin9 J Casin9 Pressure Press. 2281 / 400 PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) Water Injection TEST PERIOD ~ I-NA CALCULATED .~ J OIL-BBC 24-HOUR RATE "~1 NA IGAS-MCF N/A GAS-MCF N/A 28. CORE DATA WATER-BBL 5000 WATER-BBL 5000 ICHOKE SIZE GAS-OIL RATIO NA NA OIL GRAVITY-APl (corr) I NA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. AUG 081991 "'~ ~chorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 3O. 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. i O - Oil Coals 12,718' 9110' I G-Zone 12,765' 9138' I Hemlock 13,514' 9602I I West 14,484' 0,223' Foreland All measurnents to top (f zone , 31' LIST OF ATTACHMENTl~, Daily Operations Summary; 2. Wellbore Diagram; 3. Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 sh°w 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 10407 Attachment #1 Daily Wel 10perati ons Report Wel 1 M-27 11/4/90 Skidded rig over Well M-27. 11/5/90 Adjust top drive. N/U 30" riser and 29-1/2" annular. Build BHA. N/U 16" diverter valves and lines. Troubleshooting koomey electrical system. 11/6/90 Tested diverter system and casing to 500 psi. Drilled cement from 410' to 500'. CBU. Tested casing to 500 psi. Drilled cement to 560' washed and reamed to 970'. CBU. Tested casing to 500 psi. Displaced with spud mud. Drilled cement and float shoe to 995. Tripped for BHA. Drilled and surveyed from 995 to 1060'. 11/7/90 Drilled and surveyed with mud motor from 1060' to 1445' CBU. Survey. CBU. Tripped for underreamer, underreamed cement in casing f~om 410' to 665'. 11/8/90 Underreamed cement in casing to 988'. Underreamed to 22" from 988' to 1445'. CBU. Short tripped to shoe. Conditioned mud. POOH. Started running 16" casing. 11/9/90 Ran 16" casing to 450' Hit obstruction, unable to work deeper. POOH with 16" casing. Underream~d from 410' to 466' with 22" underreamer. Tripped for 20" underreamed from 410' to 1445'. CBU. POOH. 16" Casing FMC Hanger 31 Jts, 16", 75#, K-55 Float Collar, 16" i Jt, 16", 75#, K-55 Float Shoe 16" 80' to 83' 83' to 1361' 1361' to 1363' 1363' to 1410' 1410' to 1412' 11/10/90 RIH with 17-1/2" bit and tandem stabilizers. CBU. POOH. R/U and run 16" casing to 1412'. Circulated and reciprocated pipe. Cement 16" casing with 2200 sx cement. POOH with DP and stabin sub. R~~'~'V~D o 1991 Gas Cons..GQm chora.qe Daily Well Operatiol,o Report Wel 1 M-27 Page 3 11/11/90 Finished POOH w/stab in sub. Put 100 psi on backside of 16" and WOC. N/D diverter. N/U unihead and attempted to test same without success. N/D unihead and inspected seals. No visible damage. N/U unihead. 11/12/90 Attempted to test unihead w/o success. R/U and moved rotary table while waiting on new SBMS seals for unihead. N/U unihead and test same to 200 psi ok. N/U BOP's. 11/13/90 Test BOPE. Cleanout floats and cement to 1455'. L.O.T. to 14.0 PPG EMW. POOH L/D HWDP. Build mud motor BHA and P/U new HWDP. 11/14/90 Finish P/U HWDP. RIH and directionally drill 1455'-2883'. 11/15/90 Orient and drill 2883'-2937'. Short trip to 16" shoe. Orient and drill 2937'-3938'. 11/16/90 Orient and drill 3839'-4235'. CBU and POOH. RIH w/17-1/2" underreamer. UR 1415'-1680'. 11/17/90 Underream to 17-1/2" F/1680'-2519'. Short trip to shoe. Continue underreaming 2519'-2720'. 11/18/90 Underream hole to 17-1/2" from 2720'-3364'. Short trip. Underream 3364'-3374'. POOH due to low penetration rate. L/D underreamer. Picking up new underreamer. 11/19/90 M/U new underreamer & RIN. Underream F/3374'-4038'. 11/20/90 Underreamed 4031 '-4080'. Short trip. U/R to 4227'. Short trip to casing shoe. CBU and condition mud. POOH. Change rams and prepare to run casing. , 11/21/90 Run bowl protector. Made dry run w/hangar. R/U and run 13-3/8" casing. Daily Well Operatio~,~ Report Wel 1 M-27 Page 4 13-3/8" Casinq 72 Jts, 13-3/8" 61#, Butt, K-55 BTC 27 Jts, 13-3/8" 6~}#, Butt, K-55 BTC 1 Jr, 13-3/8" GV~ Float Collar 2 Jts, 13-3/8" 6~#, BTC K-55 BUTC 1 Jr, 13-3/8" GW Float Collar 78.60' to 2957.89' 2957.89' to 4094.31' 4094.31' to 4096.11' 4096.11' to 4182.89' 4182.89' to 4184.53' 26" 16" 75#, K-55 80' 1412' 1100 sx 13-3/8", 61#, K-5~, 79','2958, 1150 sx/ 1500 sx, 39,000# 13-3/8", 68#, K-55, 2958', 4~85', 1150 sx/ 1500 sx, 39,000# 10-3/4", 51#, N-80, 77', 487 , 1230 sx/ 1900 sx, 357,000# 9-5/8", 47#, N-80, 487', 6909', 1230 sx/ 1900 sx, 357,000# 9-5/8", 53.5#, N-80, 6909', 13643', 12.25, 1230 sx/ 1900 sx, 357,000# 7", 29#, N-80, 13,468', 15,379', 8.5", 500 sx 11/22/90 Finish running 13-3/8" casing. Circulated. Cemented w/1150sx lead TLW and 1500 sx tail "G". Could not land mandrel hangar. N/D and set emergency slips. Set and test packoff and reinstall TBG head. 11/23/90 Set RTTS at 508'. Released and skid rig to Well M-28 for electric line work for 15.5 hours. Accepted rig back to M-27 at 24:00 hours. 11/24/90 N/U 8OPE and change rams. Stackup test 10-3/4" casing hanger mandrel. Test 8OPE. Attempt to retrieve stom packer at 508'. Retrieved portion of tool. Fishing for remainder of packer and tailpipe. 11/25/90 Fishing for storm packer and tailpipe. 11/26/90 POOH w/full recovery of fish. BHA. RIH. Test casing to 2000 psi drill cement and floats + 10' formation to 4245'. CBU. Test CSG shoe to 14.0 ppg EMW. POOH. BHA. RIH w/drilling assembly. Wash to bottom. 11/27/90 Orient and drill 4245'-5393'. 11/28/90 Drilled 5393'-5483' Short trip to 13-3/8" shoe' Wash and ream 4440' to 5483'. Drilled 548~'-6016'. Daily Well Operatio,,~ Report Wel 1 M-27 Page 5 Drilled 6016'-6238'. Short trip to 13-3/8" shoe. Tight 5484'-4639'. Drilled 6238'-6517'. 11/30/90 Drilled 6517'-6649'. CBU. POOH. L/D motor. Test BOPE 250/3000 psi. M/U packed BHA. RIH. Drill 6649'-6660'. 12/01/90 Drilled w/packed BHA F/6660'-7196'. CBU prior to POOH F/BHA change. 12/02/90 POOH. Found bit with junk damage. RIH w/milltooth bit and junk baskets. Cleaned bottom of hole and drilled 3'. POOH recovered 6 pieces of junk iron. M/U packed BHA. RIH drilled 7199'-7266'. 12/03/90 Drilled from 7266'-7815'. 12/04/90 CBU. Made 10 stand short trip. Drilled from 7815' to 7835'. Lost platform power, circulated with emergency generator. Drilled from 7835' to 8062'. CBU. POOH. 12/05/90 RIH with new bit. Drilled from 8062' to 8349'. 12/06/90 Drilled and surveyed from 8349' to 8470'. Short tripped. Drilled and surveyed from 8470' to 8752'. 12/07/90 Drilled 8752' to 8835'. CBU. POOH. Tested BOP's. Started RIH. 12/08/90 Finished RIH. Drilled from 8835' to 9013'. CBU. POOH. 12/09/90 Finished RIH. Drilled from 9013' to 9315'. CBU. Started POOH. 12/10/90 Finished POOH. Changed BHA. RIH. Drilled from 9315' to 9611'. Daily Well Operatio,,J Report Wel 1 M-27 Page 6 12/11/90 Drilled from 9611'-9733'. 10 stand short trip to 8750'. Drilled from 9733'-9977'. 12/12/90 Drilled from 9977'-10,088' Motor stalling. C & C. POOH. Changed bits and MWD electronics. RIH. Drill from 10,088'-10,166'. 12/13/90 Drilled from 10,166'-10,410'. Short trip to 9495' O.K. Drilled from 10,410'-10,439'. 12/14/90 Drilled w/steerable mudmotor F/10,439'-10,807'. POOH F/BHA. 12/15/90 POOH. Test BOP's O.K. P/U new bit. RIH. Drill from 10,807'-10,985'. 12/16/90 Drilled w/mudmotor from 10,985'-11,158'. Short trip to 10,250'. OK. Drilled w/mudmotor from 11,158'-11,222'. 12/17/90 Drilled w/mudmotor from 11,222'-11,507'. 10 stand short trip. OK. Drilled w/mudmotor from 11,507' - 11,548' 12/18/90 Drilled from 11,548 to 11,593'. CBU. POOH. BHA. RIH. Reamed from 9315' to 10,504'. 12/19/90 Reamed from 10,504' to 11,593. Drilled from 11,593' to 11,816'. 12/20/90 Drilled from 11,816' to 11,914'. CBU. Made 10 stand trip. Drilled from 11,914 to 12,102'. 12/21/90 Drilled from 12,102' to 12,153'. CBU. POOH. Tested BOP's. 12/22/90 Finished testing BOP's. P/U mudmotor and BHA. RIH. Drilled from 12,153' to 12,320'. Daily Well Operation~ Report Well M-27 Page 7 12/23/90 Drilled from 12,320' to 12,455'. CBU. Made 10 stand short trip. Drilled from 12,455' to 12,563'. 12/24/90 Drilled from 12,563' to 12,695'. Circulated. Made 10 stand short trip. Drilled from 12,695' to 12,777'. 12/25/90 Drilled with motor to 12,793'. CBU. POOH for bit. RIH. Drilled to 12,826'. 12/26/90 Drilled from 12,826'-13,033'. Made 10 stand short trip. Drilled to 13,047'. 12/27/90 Drilled 13,047' to 13,333'. 12/28/90 C~rculate. Beg~n pulling.out of hole. Had to backream through three t~ght spots. Pulled into tight spot at 11,605' and pipe stuck. Work pipe free. Backreaming through tight spot and working pipe to 11,571'. 12/29/90 Backreamed out of hole 1~,571'-11 422'. Stuck pipe and worked same free. Backreamed out to 11,410 and pulied free. POOH. 12/30/90 POOH. BHA. Test BOPE 250/3000 annular 250/2500. BHA. RIH with hole opener. Washing, reaming and backreaming tight spots. 12/31/90 Wash and ream to bottom. CBU. POOH. Had to backream 11,286'-11,069'. POOH. BHA. RIH with drilling assembly. Finished RIH to 13,333. Drilled from 13,333' to 13,526'. 01/02/91 Drilled from 13,526' to 13,545'. Circulated. Short tripped. Drilled from 13,545' to 13,678'. Daily Well Operatio,,o Report Well M-27 Page 8 01/03/91 Drilled from 13,678' to 13,700' CBU. POOH. Pipe stuck at 5019'. Jar on stuck pipe. RIH with strin§sho~ and attempted backoff at 4789'. POOH with wireline. Shot did not fire. 01/04/91 Made backoff at top of jars. TOF 4789' RIH with 10" cut lip guide, to 4913'. Did not tag fish. Tripped for ~2-1/4" bit and stabilizers. Tagged up on fish at 4789'. POOH. Made up 12" OD crippled shoe and bumper sub. 01/05/91 RIH. Screwed into fish. Jarred same free. POOH. Had full recovery. RIH to 4100'. Changed out drilling line spool and strung up to 12 lines. RIH for conditioning trip. 01/06/91 RIH. Reamed from 12,778' to TD. Circulated and conditioned mud. POOH to shoe. Working through tight spots. RIH. 01/07/91 Finished RIH. Circulated and conditioned mud. POOH. Changed top set pipe rams to 9-5/8". POOH with test plug, left test plug bushing in wellhead. RIH and set 13-3/8" RTTS. N/D BOP's. 01/08/91 P/U stack and removed test plug bushing. N/U stack. Retrieved packer. Tested riser to 2500 psi. R/U and started running casing. 01/09/91 Run 9-5/8" x 10-3/4" casing string. At report time running last joint prior to picking up casing hanger and landing joints. Casing shoe at 13,535'. 01/10/91 Fin running casing with shoe at 13,643' C & C mud. Cement CSG with 1230 SXS of 13.2 PPG "TLW" with adds. FolloWed by 1900 SXS of 15.8 PPG Class "G" with adds. CIP at 1630 hrs 1-9-91. Set slips on 10-3/4" with 357, 000#. Restringing blocks to 10 lines. Daily Well Operatio,,o' Report Wel 1 M-27 Page 9 10-3/4" & 9-5/8" Casinq 1 Jt, 10-3/4", 51#, Butt, N-80 5 Jts, 10-3/4", 51#, Butt, N-80 5 Jts, 10-3/4", 55#, Butt, N-80 Crossover 10-3/4" x 9-5/8" 150 Jts, 9-5/8", 47#, Butt, N-80 157 Jts, 9-5/8", 53.5#, Butt, N-80 Float Collar 2 Jts, 9-5/8", 53.5#, Butt, N-80 Float Shoe 77.10' to 108.26 108.26' to 291.52 291.52' to 486.57 486.57' to 488.78 488.78' to 6908.95 6908.95' to 13,555.39 13,555.39' to 13,556.89 13,556.89' to 13,641.66 13,641.66' to 13,643.45 01/11/91 String blocks to 10 lines. Set 10-3/4" x 16" packoff. Test pull to 40,000# and test seals to 2800 psi. RIH with 8-1/2" bit and scraper cleanout cement F/13,064' -13,500'. 01/12/91 Drilled cement to 13,550' CBU (continuous gyro) log to ~3,515; report 'time. Test casing to 3000 psi. R/U and run GCT · Running CET (cement evaluation) log at 01/13/91 Run CBT CET log from 13,550'-3,700' with 1000 psi on casing. P/U mudmotor BHA and RIH. 01/14/91 Drill cement and 10' new formation F/13,550'-13,710'. Test shoe to 14.0 PPG EMW with no leakoff. Drill with mudmotor 13,710'-13,939'. Excessive torque. Circulate and POOH. 01/15/91 POOH. Change bit. RIH. Ream 13,805'-13,939'. Drill with mudmotor from 13,939'-14,042'. 01/16/91 Drilled 14,042'-14,164'. Tripped for bit. Wash/ream 13,932'-14,045'. 01/17/91 Reamed from 14,045' to 14,164'. Drilled from 14,164' to 14,501'. 01/18/91 Circulated. POOH. Tested BOP's. RIH. Daily Well Operatio,.o Report Well M-27 Page 10 Finished RIH to 13,800'. Reamed 13,800' to 14,501'. Drilled from 14,501' to 14,749'. 01/20/91 Drilled from 14,749' to 14,940'. Circulated. POOH. Changed bit and stab sleeves. RIH. Drilled from 14,940' to 15,184'. 01/22/91 Drilled from 15,184' to 15,205'. POOH. BHA. RIH. Drilled from 15,205' to 15,210'. 01/23/91 Drilled from 15,210' to 15,380'. CBU. Short tripped to shoe. Circulated and conditioned mud. Started POOH. 01/24/91 POOH to log. Log run #1GR/PHASOR/SONIC/TCL/AMS 13,643'-15,380'. Attempt log run #2 LDT/CNL/MLT/GR/TCL/AMS. Tools became stuck in9-5/8" casing shoe. Cut wireline and R/U to strip over wire with fishing tools. 01/25/91 Makeup fishing tools and strip over'E line. 01/26/91 Strip over and wash over wireline tools to 13,645'. Pulled tools into casing, pulled wireline out of hole and pulling out of hole with fish. 01/27/91 POOH with fish. Full recovery of logging tools. Test BOP's. RIH to 14,315'. Wash/ream to 15,380'. Pipe pulling tight. Circ and raise mud weight to 10.1 ppg. 01/28/91 Raise mud weight to 10.4 ppg. short trip to 9-5/8" shoe. C&C. POOH. Change top rams to 7" and test. R/U and running 7" 29# TKC liner on drill pipe. Run 7" liner to 15,380'. Circulate, reciprocate and rotate liner while mixing dual spacer prior to cementing in place. Daily Well Operatio,,s Report Wel 1 M-27 Page 11 7" Liner TIW Rotating Hanger w/ Tie Back Sleeve 42 Jts. 7", 29#, N-80, TKC TIW Landing Collar 1 Jt. 7", 29#, N-80, TKC TIW Float Collar 1 Jt. 7", 29#, N-80, TKC TIW Float Shoe 13,451 13,468 15,286 15,287 15,330 15,332 to 13,468 to 15,286 to 12,287 to 15,330 to 15,332 to 15,376 15,376 to 15,379 01/30/91 Mixed and pumped 36 bbls of dual spacer. Cemented liner with 500 SXS of 15.6 PPG class "G" with additives. Rotated and reciprocated liner through out job. Bumped plug to 3200 psi. Pulled 12 stands and reversed out. POOH. P/U 8.5" bit and scraper, cleanout to 13,447'. CBU. 01/31/91 Circulated. Tested 9-5/8" casing and 7" liner lap to 4000 psi for 30 min. POOH. Changed top pipe rams to 3-1/2". P/U 7" casing scraper and 4-3/4" and 3-1/2" DP. RIH. Worked through lap. RIH to 15,240'. 02/01/91 Washed and reamed from 15,240' to 15,280'. CBU. Tested liner to 1500 psi. POOH. R/U and RIH with TDT log. Logged from 15,250' to 5,980'. 02/02/91 Finished logging with TDT. RIH and logged 7" liner with cement bond log. POOH, adjusted tools. RIH and started logging with cement bond log over 9-5/8" casing. 02/03/91 Finished running cement bond log from 8000'-2800'. Attempted to run rate gyro, tool failed. RIH and set cement retainer at 12,750'. Circulated and conditioned mud. 02/04/91 Circulated. POOH. R/U wireline, RIH and perforated 12,688'-12,690'. RIH with retainer and set at 12,650'. Mixed pumped 200 sx cement, squeezed 100 sx into formation. Reversed out. Started POOH. 02/06/91 Finished drilled retainer and cement. Tested squeeze perf's. Drill second retainer. RIH. Drilled retainer junk on top of lap. CBU. POOH Changed top pipe rams to 3-1/2". RIH with 6" bit, 7" and 9-5/8" casing scrapers. Daily Well Operatio,,~ Report Wel 1 M-27 Page 12 02/07/91 RIH to 15,280'. CBU. POOH. R/U Schlumberger. Run CET/CBT/GR/CCL log from 13,430'-4000'. POOH for gyro. 02/08/91 POOH with cement bond logs. RIH with Schlumberger GCT gyro to 1000'. Could not calibrate tools. POOH. RIH with bit and tandem casing scrapers. Displacing mud from hole with seawater. 02/09/91 Displace hole with seawater. Roundtrip casing scrapers. Displace hole with filtered 34 KCL water. POOH to run GYRO. 02/10/91 POOH. Run GYRO surveys from 12,500'-15,290' WLM on 100' stations. Test BOPE 250/3000 psi. P/U TCP guns for run #1. 02/11/91 TIH with TCP guns filling DP for 1500 psi underbalance. Run GR/CCL to log RA tag, for gun placement. Space out, installed flow control head, and set packer at 14,500'. 02/12/91 Test surface lines to 2000 psi. Pressured annulus to 1750 psi. Perforated 417' of West Foreland zones with 1500 psi underbalance. Allowed well to flow to poorboy degasser with no fluid to surface. Reverse circulated to kill well. POOH. P/U stage #2 of TCP guns. 02/13/91 RIH with 4-1/2" TCP guns filling DP for 1500 psi underbalance. R/U RIH with GR/CCL for RA tracer survey. Space out guns across zones. Pressured annulus and fired guns. Perf 270' of "G" zones. Strong blow in bubble bucket. Reverse out to kill well. 02/14/91 Reversed out. Unseated packer, monitored well. POOH. RIH w/bit and scraper. Tagged fill at 15,254', washed to 15,278'. Circulated and filtered fluid. 02/15/91 Circulated and filtered fluid. POOH. M/U isolation packer and RIH. Set same at 14,250' DPM. POOH. 02/16/91 Finished POOH. L/D 3-1/2" DP and packer running tool. Changed top pipe rams to 5". Repaired top drive. M/U casing patch and RIH with same. R/U Daily Well Operatio,s Report Well M-27 Page 13 Schlumberger and made correlation run. Set casing patch 12,698'-12,718'. POOH, laying down drill pipe. 02/17/91 POOH laying down drill pipe. Changed top set of pipe rams to 4-1/2". R/U to run tubing. 02/18/91 Made up packer assembly. Started running 4-1/2" production tubing. Had 280 jts run at 0600. 02/19/91 Finished running production tubing. Reverse circulated and spotted inhibited fluid in annulus. Spaced out, landed hanger. Set packer at 12,555'. Tested tubing and annulus to 2500 psi. Set plug in "F" nipple at 500'.L/D landing joints and set BPV. 02/20/91 Replaced annular element and top set of pipe rams. N/D stack and riser. N/U tree and tested.same. Pulled BPV and plug. Injected 500 bbls of filtered KCL with 1~ bacteriacide. Started breaking down top drive for inspection. PERFORATIONS G-Zone 12,770 12,840 12,910 12,950 13,030 MD - 12,790 - 12,875 - 12,935 - 12,990 - 13,100 13,215 - 13,295 9,142 9,183 9,226 9,250 9,299 TVD - 9,153' - 9,204' - 9,241' - 9,274' - 9,342' 9,413 - 9,463' West Forel and 14,524 14,636 14,734 14,810 14,914 15,014 - 14,606 - 14,666 - 14,776 - 14,914 - 14,989 - 15,066 15,110 - 15,142 10,251 10,328 10,396 10,449 10,521 10,591 - 10,308' - 10,349' - 10,425' - 10,521' - 10,573' - 10,627' 10,658 - 10,681' All Perforations are 4 SPF, 60o Phased \docs\shp\m27. doc Attachment #2 MARATHON rlIL COMPANY TRADING BAY UNIT VELL M-27 Compte~ced 2/19/91 All measurements :re RKB to top o? equipment. C~s~n.q Deto;l 16' 75# K-55 80' L41P' 13-3/8' 61# K-55 79 8,958' 13-3/8' 68# K-55 2,958 4,185' 10-3/4' 51ff N-80 77' 487' 9-5/8' 4?# N-80 487' 6,909' 9-5/8' 53.5# N-BO 6,909 13,643' 7' 29# N-80 13,468' 15,379' Comol~lon Strlno. 0'-12,620 74' 521' 12554' 12555' 12559' 12575' 12617' 4-1/2' 12.75#, L-BO, Hydr~l CS-CB Tbg. IPC w/ TK-99 FMC H~nger TC1AEN 4-1/2' CS B~ker 'F' nipple, 3.75' ProFile, CS-CB BxP B~ker 'E-2P' onchor Iocotor seol mssembly, ~/ ~o nlt?lle Chevron se~ units. 3oker 'SB-3' p~cker, size 194-47 3raker MK~ou~ extension 7' LTC PxP ~ker 'F' nipple, 2.68' ProFile, CS-6B BxP Boker 'R' nipple, 3.68' Pro?Ke, 3.625' NoGo X-O 4-1/2' CS-CB Box x Vom Pin AVA petpmctobte boo se~ ~A-CHD-RBS-450-O AVA ~lneilne entry guide [solatlon Pocket 14250' 14253' 14258' 14292' 14329' B~ker 'FS-1° p:cker, size 85-40. B~kep miliout extension, 5' LTC PxP X-II 5' LTC Box x 3-1/2' Butt tbg p~n B~ker 'F' n~pple, 2.75' pro?fie, Butt BxP B:ker 'R' nipple, 2.75° pro~Ke, P.69' NoGo ~queeze PerPorotlons. 12678' - 12698' HOMCO C~slng perch set to cover Squeeze Pete. ~ 12688'-12690' M~x. ID reduced to 8.225' ~n~erval G-ZONE 12,770' - 12,790' 12,840' - lP~875' 12,910' - 12,935' 12,950' - 12,990' 13,030' - 13,100' 13,215' - 13,295' ;~EST FORELAND 14,524' - 14,606' 14,636' - 14,666' 14,734' - 14,776' 14,810' - 14,914' 14,914' - 14,989' 15,014' - 15,066' 15,110' - 15,142' PERFORATIONS FT SPF 20' 4 60 2113/91 35' 4 60 2/13/91 E~5' 4' 60 2/13/91 40' 4 60 ~/13/91 70' 4 60 2/13/9! 80' 4 60 2113191 82' 4 60 2112191 30' 4 60 2112191 42' 4 60 2/12/91 104' 4 60 E~/12/91 75' 4 60 2112191 52' 4 60 2/12/91 3~' 4 60 ~/12/91 PINTO @ 15,215' TI) E 15,380' " Rews~on D~'ce, , 7/IE/91 ' '.:. .... ' ........ '-- ''" '" .... Revised By~ ' "PH[]/evo ' ' -Re.sot, -' New Cc~i~e~mn'.:''~'-~''' · Pr'ev~ou$ Revls~Ofl: . None ' '. ~C ~ ;t~: .;:' 't ' A Gyrodata Directional for MARATHON OIL COMPANY TRADING BAY UNIT WELL NO. M-27 KENAI BOROUGH ALASKA Survey Date Run: 09-FEB-91 11:15:00 Job Number: AKO291G210 Surveyor: SURMAN Calculation Method: RADIUS OF CURVATURE Survey Latitude: 60.8250deg N Azimuths are Relative to TRUE NORTH Proposed Well Azimuth: 49.7000deg Vertical Section Calculated from Well. Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference RATHON OIL COMPANY ADING BAY UNIT WELL NO. M-27 NAI BOROUGH ALASKA b Number: AK0291G210 A Gyro dar a Directional Survey Page MEAS INCL AZIMUTH DEPTH ft deg deg 12400.0 50.62 48.96 1~,86.0 51 37 49 73 12586.0 52.72 49.61 12686.0 53.42 49.,50 12786.0 53.79 49.53 12886.0 52.61 49.43 12986.0 52.11 50.09 13086.0 52.24 49.95 13186.0 51.76 49.87 13286.0 5].]2 49.89 13386.0 50.91 49.66 13486.0 50.06 49.23 13586.0 49.96 49.44 13686.0 50.44 48.73 13786.0 51.54 48.24 13886.0 5].92 47.-55 13986.0 52.26 47.46 14086.0 50.99 47.21 14186.0 49.85 46.40 14286.0 48.47 46.56 DOG-LEG VERT VERT C L O S U R E SEVERITY ,DEPTH SECTION DISTANCE AZIMUTH deg/lO0' ft ft ft deg .00 8916.0 7805.3 7806.4 50.6 TIE-IN DATA FROM SCHLUMBERGER G.C.T. SURVEY MEASURED DEPTHS REFERENCED TO STEEL}lEAD R.K.B. ELEV. 160.0 F MEASURED DEPTHS CORRECTED -14 FT. FOR WIRELINE DEPTH ERROR 12500 - 13400 FT. GYRODATA MULTISHOT SURVEY RUN IN 9 5/8 CSG 13500 - 15290 FT. GYRODATA MULTISHOT SURVEY RUN IN 7" LINER 1.12 8970.2 7872.1 7873.2 50.6 1.35 9031.7 7950.9 7952.1 50.6 .70 9091.7 8030.9 8032.0 50.6 .37 9151.1 8111.4 8112.4 50.6 .1 .18 9211.0 8191.4 8192.5 50.6 .73 9272.1 8270.6 8271.7 50.6 .17 9333.4 8349.6 8350.7 50.6 .48 9395.0' 8428.4 8429.5 50.6 .64 9457.3 8506.6 8507.6 50.6 .27 9520.2 8584.3 8585.4 50.5 .92 9583.8 8661.5 8662.5 50.5 .19 9648.1 8738.1 8739.1 50.5 .73 9712.1 8814.9 8815.9 50.5 .17 9775.0 8892.6 8893.6 50.5 .66 9837.0 8971.1 8972.0 50.5 .35 9898.4 9049.9 9050.8 50.4 .29 9960.5 9128.3 9129.1 50.4 .30 10024.2 9205.2 9206.0 50.4 .38 10089.6 9280.8 9281.4 50.4 HORIZONTAL COORDINATES feet 4946.83 N 6038.94 E 4990.37 N 6089.64 E 5041.41 N 6149.75 E 5093.27 N 6210.58 E 5145.53 N 6271.79 E 5197.55 N 6332.66 E 5248.71 N 6393.10 E 5299.46 N 6453.63 E 5350.21 N 6513.91 E 5400.60 N 6573.71 E 5450.80 N 66133.06 5500.96 N 669].68 5550.88 N 6749.79 5601.20 N 6807.84 5652.70 N 6866 02 5705.35 N 6924.27 E 5755.65 N 6982.44 E 5811.78 N 7040.09 E 5864.53 N 7096.28 E 5916.62 N 7151.14 E RATHON OIL COMPANY ADING BAY UNIT WELL NO. M-27 NAI BOROUGH ALASKA b Number: AK0291G210 A Gyrodat a Directional Survey Page 2 MEAS INCL AZIMUTH DEPTH ft deg deg 14386.0 47.57 45.89 14486.0 46.42 45.92 14586.0 46.37 46.54 14686.0 45.99 45.92 14786.0 45.99 45.85 14886.0 46.11 45.28 14986.0 45.95 45.06 15086.0 45.24 44.76 15186.0 44.73 45.30 15276.0 42.90 46.34 DOG-LEG SEVERITY deg/lO0' 1.03 1.16 .45 .58 .05 .43 .20 .77 .64 2.18 VERT .DEPTH ft 10156.5 10224.7 10293.7 10362.9 104.32.4 10501.8 10571.2 10641.2 10711.9 10776.8 VERT C L O S U R E SECTION DISTANCE AZIMUTH ft ft deg 9355.0 9427.9 9500.2 9572.2 9644.0 9715.8 9787.5 9858.8 9929.2 9991.4 9355.6 50.3 9428.5 50.3 9500.7 50.3 9572.7 50.2 9644.4 50.2 9716.2 50.2 9787.9 50.1 9859.0 50.1 9929.4 50.0 9991.6 50.0 HORIZONTAL COORDINATES feet 5968.05 N 7204.81 E 6018.94 N 7257.33 E 6069.03 N 7309.62 E 6118.94 N 7361.72 E 6169.00 N 7413.35 E 6219.41 N 7464.76 E 6270.16 N 7515.81 E 6320.77 N 7566.26 E 6370.73 N 7616.27 E 6414.15 N 7660.96 E Final Station Closure: 9991.6 feet 50.0622 degrees ~.. ~:~: : ,~ ~ l~-~aNau~~---~S~m .... i .... 4=::: ~':' :.':~: ::':-,~/~~~::: I":' -~=L-rz-l'frf~'~z-l~--~f' ;'-gK~'zsi~z-i'~:::[::~::'.':'/:;::'.'-J~':.::: ~::. j.::-:L: .. ~ ..---' -' ~ .:::.~:.~.[ ~:!J:~dzl~,zpk~:r::-: :-~:.!-:~:F: :. : ::-.- I:: :.~ : : :!:: ..... :: :J~ :: .::: :::: I : ~ ~ , . ~-~-; . : ... ; :, _ : : . ~ . : ~ . . . . ~-~-t-~=:-~ :!.~-:-,~:.~l .... ~.:::1.:.:..: ========================= ==== ~ ..: .... ~':. ::.~ -~H~j":-L~-' ~-f:¢~t~:,~'.l; :~ ';: .... :~-.::1 .... ::-~ ~ -:.'- .... ~: ........... :: ~q-~'-~':~-7'7-,.-~" i ~1':',-~-7~ "; : : J .... 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I ................. :::: :::: :::: '::: ::: :::'': t::::' ' ::..: :::: ~"',--~ :~ ............ ~ .......... I '".- I- [ - ~ t .......... '. :f'l' ]-~'~' f: '.4 :::; -.-:--::l-:- ~-:::~:-":-: ...... ; ...... 1"~-:'--~ .... : ...... :'-I ............. ~7' :~"i-' '"~' ":- ~ 'f ............. / ..... ' ,, --/ · · i ........ i~:~:~:~: ~-;~ :::.~ ::::1:-:: ::" '.::,::, i :-: ::i--:l-::~.'. :~ '.-.:' '..: ':. -~ -~--~ : · i .... :! .:.[. .., ']--~-. i.: ~' ..,, ..... ~' .~ .... :~i-:ki'~-~Z ~ ~ : : I:: : 'i. I :: ' i ::: .:I:::. : !. : ..- ~ ": '1":' H-k~-! ~'i ~:~ ~f:~ .... I ....... t ..... 4' -i: I ....... :-.:..:': :: : ..::!..:~ -~-!-~ -i-j~f- ~if ~-. : .:::~::-~::-T~ ~-:?:: ..... ;-~7- :... 7: :~:'-~.. :~T :.:. ~- . ~.:i:.~, ~_~ '~;~:~-' .... '-: '~ ...... ,l: ...................... ~ .................... i ' · ~_,,~ ~ ~z: ::: .~:::: ::':i:-:: ::: J:' : ~.:: ~::: ::~i:~:~ :~::,::~: ::~: :':~.::::~:~r :.~-~. ~-~ --~- i~ ..... ~.:,: ... ' ........................................ ~?=:~:~:k~ ~?"~'~: ::':~": ..... ~ .... ~ .... ~ ...... , ......... · ...... :":::": :~''~- -~-~-~+~: ~? '~'~ ::::[:::: ::':: :: :~::':~:::: :::: :::: ::::l:::: ~::: ::" :::: :::: ::~. '.:.i:' ~-~ff't-H~-~- ~--~-~ ~..I- ~ .!:-../ ......... ~:.:- .:.~l .... :,. :,: ..... ,:-~- ,-~.~- '-~-~ ~-~ ' ' ~ -~ ~ ~ ~ .....I : .....I ' ' ~ ~ ' ' ' ' ' ' ' ~ ~l- - , ~ · ~, · ~ .-~ -. ,~ ~ ~ .... ,-,-.-,,,..:: ... :.,. ...... , ............... , ......... ............... ,,~..... ,.. ,'~-.~. ~-,:, .._ ......... ..~. ~.~.. ..... . .' ~ ....... ~ ",," -~ Energy Systems Technology MARATHON OIL ¢OIqFAH¥ 156~' Bro~dwag, Sutto 9~1 R. DRUM~ELLER - ANCHORAGE, ALASKA Denver, Colorado B~ZN2 (2~3) 861-2424 ~r w ES-LOG True Vmrtlcal Depth Resut~s w True Vertical Depth Data - Full Report * ~ermlnml Angle Method PROJECT NAME : TBU We~l Name FLD/~NIT County State kocatlon Country P,:A. RATHOIII OIL COMPANY M~Z7 MC ARTHUR RIVER F.IELD KEHAI PENItfSLfLA BOROUGH ALASKA STEEL~EAD PLATI'ORM, LEG B-) USA TgU GRC: CASED-HOLE GR FROM INTERMEDIATE RUN 1/13/51 GROH x GR OPE~-HOLE TD PROJ FR~M 15Z76 AT ~,~2 DEG PER FT INCL, AND ~.~12 D/FT AZ RECEIVED AFR 2 99i Alaska 0il & Gas Oor, s. Oorr~mission ,Anchorage 27-MAEigt t4:]B Project: TI)t{ Well~ M-Z7 Page; ~ Measured Drift i)rff% Depth %fcai Dog Leg P, ectangula Coordfnates Depth Ang Ie I) lre¢t Ion Interval Depth Sever ity [feet) (deg mmin) {deg mlm) (feet) (feet) (deg/l~g fi) (feet) 1~8'.I~ g 18 S 12 8 £ lgg.9~ 99.999 1,~ Z~,~E g 1~ S 9 Z W !~,~ 199.998 4~.~ ~ 3t S 32 7 E I~.gF~ 399.993 5~.~YE I 13 S 46 34 6 l~.~ ~99.97~ 1.~ 60~.~Z 1 47 S 6~ 36 E 1~.0~ 599,922 7~.~ Z 3 S B1 58 E 1~,8~ G99.858 8~.~8~ Z 7 H 82 45 E 1~.~ 799.79~ ~,~ 3 33 N 66 51 E 188,E~ 999,535 1.8~ llE,~,~ 5 9 ~ 63 Z3 E lg~,g~ 1~99.111 13~,~8 7 47 H 51 15 E 10~.~ff 1297.563 140~.~8 B 28 N 5~ 6 E iS~.ff~ I395,493 1.~ 1780,~ff 13 3a N 53 26 £ 100.~ff~ 169~,23~ 18R9.~ 15 15 N 5I 47 E lg~.~8~ 1786.7~8 2~8,~8Y lB 59 H 49 34 E I~B.~ 1978.772 Z2~.~B~ 22 18 N 58 37 E t~.~BB 2162.929 238~.08~ 23 53 ~ 52 1~ E lS~,~g 2254.365 1.~80 240~,~ 25 28 N 52 57 E 100.~B 2344,652 1,~ Z50~.~ 27 4 N 53 6 £ l~g.B~ 2433.698 ZSEE.~ 28 3~ N 5Z 51 E IE~,~0 2501.58~ 280~.~ 30 24 N 52 29 E 1~O.~ 2~94.~t~ 1.~ 29~8.B~0 31 25 N 52 Z3 E lff~.g~ 278ff. ZSg I.E~Z 3~3E.B~ 3Z Z5 N 51 54 E 1~0.~0~ 2864°887 310~.~8 33 18 W 51 39 E lfff.~E 2948.248 32~.~E~ 34 12 N 51 36 E 1~.~ 3~3~.956 33~g.BB~ 35 24 N 51 44 E l~g. BB~ 3112.45B 1.~g~ 34~g.B~ 37 Z8 ~ 51 Z4 E 1~.00~ 3191.98~ t.~gl 35~.~g 38 45 W 51 6 E 10~.ggff 3269.969 I.Eg~ 3600.~88 4ff 31 N 5ff 59 E 180.~ 3345,9~0 37ff~.~ 42 33 N 5~ 42 E I~.BO~ 3419.659 1.961 38~ff,B~g 44 33 N 50 Z~ E 1~,~0~ 349~.923 . 1.~gl 39~.~ 45 58 B 5~ I7 E 1~.8~ 35&g,431 40~g,~8 47 22 ~ 50 32 E 188.~ 3628.161 41~.W8~ 49 33 N 50 3~ E i~E.~ 3693.S4~ 1.~! 42Y~,~ 5~ 11 ~ 52 19 £ {Z~.~Zg 3755.723 ~3~0.0~ 52 6 ~ 5E 18 E I~Z.~8 3827,I51 l,Zgg 44~0.E~g 51 48 N 5~ 29 E l~.~g~ 3878.992 47~8.~E 5~ 54 N 51 3 E I~,8~E 4~66,356 490~.~8~ 5~ 56 N 51 14 E I~N,~O~ 4192,266 5208.8~ 58 59 N 52 I E i~E,~Z~ 4382. 458 1 .~ff 530~.~Z~ 58 56 N 52 I1 E 1~8.~ 4445.48~ 1.0~ 54~.~g~ 51 6 ~ 51 51 E lZ~.YZZ 4528.277 55~.~g~ 5~ 37 E 5t 39 E l~E.g~O 4571.728 I.E~ g.512 S ff. ll~ E 9,~57 S 8.055 E ].317 S g,E12 W 2.097 $ ~,44~ E 3.582 S 2.~32 E $.~3~ S 4.743 E 5.53~ S 8.285 E 5.~64 S ~1,949 E 4.]86 S ~5.9Z5 ~,752 S 21.6I$ E 2.27~ N 29.643 E ' 8.3~ N 38,846 E ?\ 15.77~ N 49.4~8 E 26,22I N G8,703 E 3G.885 N 73,923 E ~9.21~ N 89.897 E 62.96~ N 108,692 79.232 N 129.357 E 9~.322 N 152.052 E 119.417 N 176,812 142.195 N 293.596 E I66.182 N 232.925 E 191,g16 ~ 264,9~Z E Z[5.923 N 299.22~ E 244.244 N 335,6~8 E 273,~59 N 373.64~ E 3~2.979 N 412.655 E 333.796 N 452.792 E 365.612 N 494.~$Z E 398.59N N S36.267 E 432,754 # 579.323 467.658 H 623.374 E 5~3,544 N 668,855 E 54!.380 H 716,250 E 58~,685 N 764,963 E 621.585 N 8£5.,439 E 66~,416 H 867.769 E 709.196 N 9ZI.771 E 755.136 N 977,272 E 8g1.899 N 1~33.868 85~.3~3 ~ I092.587 9~,056 N 1152.549 E 950,(60 N 12]3.26I E 1~D~.~64 N [273.886 E 1WSW, 321 ~ 1334.654 E lff99.722 H 1395.118 I148,5~8 N 1455.471 E 1197,192 N 15IS.E94 E 1245,8~7 ~ 1576.63I E I293.778 N 1636.9~4 E 1341.494 ~ 1697.685 E 1389,31I N 1758.924 E 143G.916 N 182~.259 E i484.989 N 1881.46~ E I532.945 ~ 194~.~75 Z7~M~R-gi 14:18 Projects TB9 Nellt M-27 P=ge: Oep th An9 le O t r eot ! on Inter v = I Depth Sever I t¥ (feet} {deg m~n) (de9 mln) (fset) [feet) Cdeg/~ ft} {feet} {feet) 5~EN,gf~ 5~ 59 N 5] 42 E l~.S3'~ 570~,f~S 51 41 H 51 27 E l~.SZ~ 58~.~ 51 16 N 51 ~ E 1~.~ 4759.252 59~.0£~ 5[ 22 ~ 50 4! E l~o~ 4821.686 6[~.EB~ 51 24 N 5~ I3 E I~N.8~E 494&.553 G2gE.~O 51 4~ N 4~ 18 E l~g.~E 5ffE8.577 6308.09~ 51 55 H 48 52 E tgg.8~g 5~7~.257 64E~.ORE 51 56 E 40 5N E [~E.~Og 5131.915 650~.~BE 52 3! N 48 32 E 1~.~8 51~2.768 6700.0~g 5I ~G N 48 38 E L~.8~B 5315.991 680~,~80 51 34 N 48 34 E [~,gg~ 5378.]51 7lOe.~ge 49 5~ . 4a 57 E 1~.~08 5568.673 7200.B~ 49 47 N 49 47 E IESo~ 5633.24! 730~.gg~ 5~ 38 N S~ 5 E IgS.~g~ 5696,659 74E~.~ 5E 48 N 58 t9 E 1~.800 5759.872 75EE.~8 5~ 44 N 5E 8 E [~,88~ 5~23.165 76~.~ 51 ! N 49 55 E 10~.~8~ 588G.E75 7700.E8~ 5t 28 N 5~ IE E ]EE.~8 5948.372 788~.B~ 51 37 N 5~ 22 E ]~.8~8 6~1~,463 79~g.~ 51 54 N 56 42 E lg~.gSE 6872.367 80.~o00~ 52 3 N 5~ 59 E l~.8~g 6t33,665 B]08,~O~ 51 53 E 51 20 E ~Ee,~NO G1~5,391 820B,EBE 52 29 ~ 51 34 E l~'8.~g 6256.2~1 83~.~ 52 9 N 51 43 E 1~,OO6 6317,656 84~,~ 52 56 N 51 48 E 1~g.~ 6377.925 858E.~0~ 52 54 N 51 49 E ~08.8e0 ~438.246 B&88,~B~ S3 3 N 5~ 44 E 1~8,~ 6498,357 87~,8~ 53 16 N 51 aZ E t88,~ 6558,167 8800.E8~ 53 27 N 5! 28 E i~8,~8 6617.7~9 89E~.~8~ 52 39 N 51 Zg E ]88.80~ 6676,387 90EE.88~ 51 2 N 5! 25 E ]0~,~8 6741.274 9IE~.~B~ 5~ 42 ~ 51 ~9 E 100.B~B 6804,612 9Z~.~g 5~ g ~ 51 31 E 19~.~00 6868.8~1 930~.~8~ 49 1~ N 52 8 E 1~8,~0 6934.188 940~,~0~ 4~ 47 N 52 39 E IEE.O~8 6998.756 95EE,~ 50 5 N 53 lB E lgg,O~ 7062,924 9E3G,$89 5~ Z~ N 53 10 E ]9~.~9Z 7tZ6.756 97~O,~K 5~ I7 N 53 11 E 1OO,~ 719~,655 98~0.6Z~ 51 9 N 53 13 E lg~.Eg~ 7253.383 99~.~ 51 53 N 5Z ZE E IE~,~ 73t5.IIE I~OES.B~E 52 12 N 58 35 E 1N~.088 7376.48E ]O1E~.g~ 51 35 N 48 53 E 1~0,0~8 7438.538 I~Z~o~¢ 51 29 N 48 53 E 100.08~ 1~3~,8E8 51 58 N 49 46 E I~.EEO 7562,424 18400.~E~ 52 3~ ~ 5~ 16 E 1~B,~ 7623.2~8 l~5gE.~ 52 44 N 5~ 2E E I~E.O~ 7683.761 106CE.~ 53 25 N 49 53 E 1~.~08 7743.36~ 1~7~.~08 54 8 N 49 1~ E ~F0,88~ 78E2.~35 1088~.~00 52 5] N 48 23 E 1~.~ 78fi2.520 109~.9E~ 5t 26 N 47 55 E 188.~g~ 7924.871 ll~.g~fl 5ff 4~ N 48 I E lEE.g~g 7988,254 1110~.~e 5E 54 N 48 11 E 180.~ 8~51,321 1.ggg I.~gg 000 1.00~ 1.~00 l.g~g 1.g~g l.£g~ I,~ l.ggO ggO lSBI.lgl ~ 2~E3.049 E 1629,997 N 2~G4.410 E 1670.947 N 2125.14G E 1720.~4] M 2185.501 E 1775,2G3 N 2245.G99 E 1828.272 ~ 23E5.756 E ]879.~23 N 2365.225 E 193t.~8! N 2424.5~9 E 1983.~25 N 2403,777 E Z~25.571 N 2543,239 E Z~7.75N N 26E2,5~8 E 2t39.661 N 2GGI.479 E 2191.498 N 2720.2~8 F 2243.g8B N 277B,750 L mr 2294.35~ N 2g3G.SG5 E 2344.535 N 2894,1~4 E 23~3.839 fl 2952.5ff4 E 2443.447 N 3~1.759 E 24~Z.~31 N 3071.438 E 2542,558 N 3130.86! E 2592.EI~ N 319~,335 E Z$42,7[7 fl 325~.4~5 £ 2692,'719 ~ 331~,774 E 2742,562 ~ 3371,671 E 27~Z,204 N 3432.930 E 2841.36N N 3494,367 E 289~.664 N 355G,5~ff E 2939.585 N 3618.481 E 2980.93~ N 3~81.150 E 3030.235 N 3743.$B1 E 3087,729 N 38~6.G26 E 3~37,4~ N 3869,SZE E 3~$7.591 N 3~3Z.244 E 3237.259 ~ 3~94,313 E 32S5.748 N 4~55.E~1 E 3335.115 N 4!I5,490 3351.794 N ~75.463 E 3~28.413 N 4235.145 E 3474,74~ N 4295.84~ E 352~.576 N 4357,343 3566,723 N 44~8.954 E 2612.819 fl 448~.534 E 3659.452 N 4542.9~$ E 37~7.528 H 4G~5.186 3757.7eE N 4666.229 E 38~9,223 N 4725.257 E 38~.7~9 ~ 4704.173 E 39)1.564 N 4844,3~ E 3862,342 ~ 49~5,37~ E 4813,1~! N 496G.$3~ E 4~64.$8Z N 5~28.N37 £ 4]~7.750 H 5~89.24~ E 417N.71G ~ 514e,837 E 4223.119 N 52~5.B66 E 4274.B57 N 5264,361 E 432G.68~ N 5322.199 E Project: TBU ~ell= H-Z7 Pages 3 Measured Drfft Drift Depth True Vertical Dog Leg Rectangular Coordfnates Depth Angle Oirectfon Interval Depth Severity :feet) (des mtn] (des mfn] {feet) {feet) {deg/lZ~ ft} (feet) (feet) 112~.~£~ 5~ M ~ 48 19 E I~.~N $115.66N 1.~ 4377.5&3 N 5375.4~9 ll3~g.~g 5~ 1~ N 48 56 E I~.NON 8179.455 1.~N II(N~.~N 5N )4 N 49 39 E 1~.~ 8243.421 1,~ 116~.~ 49 32 N 49 40 E 1~.~ 837Z.57~ i.~g 117~.~0 ~8 48 N ~ 3~ E I~.~ 8438.44~ 118~.~0~ 48 26 N 49 I3 E 1~.~ 85~4.796 1.~ 119~.~8~ 48 44 N 48 54 E 1~0.~ 857~.75Z 1.~ lZZ~.~ 48 28 N 48 ~8 E 1~.~ 87~3.Z76 1.~0~ 126~.~ 52 53 N 49 6 E 1~.~ 9~Z~.~11 1,~ 1ZTg~,~B~ 53 19 N 49 11 E 18~.~08 9~79.75U 128~,8~8 53 28 N 49 17 E I~.~B ~135.Z7~ 12988,~8~ 5Z 35 N 4~ Z5 E IE~,g~ 9Z~.~4~ 13~,8~8 52 9 N 49 {5 E 1~,8~8 9Z61,357 131~,~ 52 ]5 N 48 48 E lS~.g~B 9322.621 I3Z~.~88 51 35 R 4) 53 E 18~.~B 9384.759 133~0,~E 51 9 K 49 44 E l~.gB8 9¢47,487 13~8~.~ 5~ 43 ~ 4~ 39 E 1~8.~ 951~.8~3 135~,E68 49 BZ N 49 55 E 1~.~ 9575,26~ 1,~ 136~.Eg~ 49 42 N 5~ 3 E 1~8.~8 9639,938 i3643.~00 49 42 N 5~ 3 E 43.~ 9667,750 I.~B 13655.~ 5~ 26 N 48 44 E 43.860 9695.14~ Z.326 13786,~ff8 Si 3Z N 48 14 E 108.8~B S757.346 I3886.~8 5I 55 N %7 33 E 1~.~ 9819.~Z6 $3986,E~6 52 16 N 47 28 E 15~.898 9556.225 14696.~8~ 55 59 N 47 13 E 1~.~8 9943.18~ 14186.~8~ 49 51 ~ 46 24 E l~ff,8~ 1~g7.659 1.3E~ 14286.~8~ 48 28 ~ 46 34 E tZff.ffB8 1~ff73.965 14386.ff~ 47 34 N 45 53 E [~.ff~ 1ff141.438 1.~ 14486.~ 46 25 N 45 55 E i88.868 i~21~,379 1.~8 14686.~ 45 59 N 46 55 E ]E~.B~ 1~348,859 ].~ 14756.~8~ 45 59 N 45 5I E 1~,8~ 10418,355 I.~ 14586.88~ 46 7 N 45 17 E 1~.0~ l~487.675 15~86,88) 45 I4 N 44 46 E I~.B~ 1~627,583 1,8~ 15186.~8 44 44 ~ 45 lB E 1~.8~ 1~698.622 15Z76,8~ 42 54 W 46 28 E 9~.~8~ 15764.551 1.112 153~.6~ 42 25 N 46 38 E 24.~ 1~782.269 4.157 1535~.~88 41 25 ~ 47 14 E 58.~8~ I0819.765 2.~0 15388.~ 4~ 4~ N 47 35 E 36.~ 1~842.469 3,334 4429.1~g N 5437.43Z E 4477.867 ~ 5496.01t E 4527.4~9 fl 5554.464 E 4576.649 N 5612,458 4625.515 , 5559,572 E 14674.386 ~ 5726.3~3 E 4723.79~ N 5782,965 E 4773.271 ~ 5~39.Z(6 E 4822.)~5 ~ 5a~5.281 E 487Z.~75 N 5951.748 E 492t.t39 N 6669.235 E 4972.aa~ N 6~67.539 F 5~24.39~ N 6126.793 5gYG,6~ N 6187.866 E 5129.918 N 6~{7,758 E 518[.433 ~ 6318.66S E 5~33.1~2 ~ 6368.979 E 5284.1~1 N 6429,~45 E 5335,i57 N 6459.638 5365.642 N 6549.556 5435,979 N 66~8.981 E 547~.f94 N 6667,97~ E 5535.323 N 6726.466 E 558~,295 N 678{.93Z E 56~5.353 N 681~.~73 E 5627.216 N 6834.988 E 5679.37~ N 6893,387 E 6732.496 N 6951.466 E 57~5.9G~ N 7~99.744 5838.733 N 7~$6,767 5891.445 N 71ZZ.]2E E 594Z.91~ N ?!76.479 E 6994.288 N 7229.466 E 6~&.683 N 7281.5~ ~69~.474 N 7334.929 F 614~.5~4 N 7385.687 619~.595 E 7437,287 E 6245.3S8 N 7458.5~3 £ 6Z9~.~99 N 753~,~]3 E 6346,5~6 N 7589,4tt E 6396oZ12 N 7639.438 E 6~3~.313 N 7683.755 E 64~9.4Z9 ~ 7695.5~3 E 6~71.88~ N 7719.8~6 E 6485.115 N 7734.26Z E ~7=MAP-gX 14m18 ProJ~ct~ TBU Vell: M-Z7 Page= FINAL CLOSURE I~FORMATIOH: Oistance Azimuth (feet) (deg mtn) 1~93,356 N 5~ ! E GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR MARATHON OIL COMPANY TBU M-27 TRADING BAY UNIT KENAI, ALASKA SURVEY DATE= 12-JAN-1991 ENGINEER: MCCROSSAN METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged ~eviation and &zimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 50 DEG 34 MIN EAST COMPUTAT[ON DATE: 14-JAN-g1 PAGE 1 MARATHON OIL COMPANV TBU M-27 TRADING BAY UNIT KENAI, ALASKA DATE OF SURVEY: 12-JAN-1991 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -160.00 0 0 N 0 0 E 100.00 99.99 -60.01 0 18 S 12 8 E 200.00 199.99 39.99 0 12 S 9 2 W 300.00 299.99 139.99 0 16 S 8 21 W 400.00 399.99 239.99 0 31 S 30 7 E 500.00 499.97 339.97 1 13 S 48 34 E 600.00 599.94 439.94 1 47 S 60 36 E 700.00 699.88 539.88 2 3 S 81 58 E 800.00 799.81 639.81 2 7 N 82 45 E 900.00 899.74 739.74 2 20 N 77 33 E 0.00 0.00 0.05 0.42 -0.28 0.05 -0.55 0.28 -0.85 0.56 -0.78 0.55 -0.04 0.25 1.69 0.94 4.57 0.14 7.89 0.59 0 00 N 0 88 S 1355 1695 2 31 S 3395 4915 6035 5.94 5 5.28 S 0 00 E 0 78 E 0 74 E 0 68 E 0 79 E 1 78 E 3 99 E 7 14 ~Z 10 8O £ 14 56 £ 0 O0 N 0 0 E 2 3 6 9 12 15 18 S 41 48 E 54 S 28 52 E 82 S 21 46 E 44 S 18 59 E 83 S 27 43 E 33 S 39 6 E 35 S 49 51 E 32' S 61 12 E 49 S 70 4 E 1000.00 999.62 1100.00 1099.32 1200.00 1198.82 1038.82 6 '19 1300.00 1298.06 1138.06 7 47 1400.00 1397.04 1237.04 8 28 1500.00 1495.80 1335.80 9 45 1600.00 1594.07 1434.07 11 36 1700.00 1691.65 1531.65 13 32 1800.00 1788.54 1628.54 15 15 1900.00 1884.52 1724.52 17 15 839.62 3 33 N 66 51 E 12.38 939.32 5 9 N 63 23 E 19.88 N 56 46 E 29.68 N 51 15 E 41.93 N 50 6 E 56.16 N 51 19 E 71.84 N 52 36 E 90.34 N 53 26 E 112.14 N 51 47 E 136.86 N 49 56 E 164.89 2.56 1 .05 1 .82 1 .37 0 54 1 78 1 82 1 60 2 27 1 96 3.75 S 0.48 S 4.47 N 11.77 N 20.83 N 30.78 N 42.17 N 55.25 N 70.22 N 119 87.99 N 141 19.11 5 19.47 S 78 54 E 26.14 5 26.14 S 88 57 E 34.76 5 35.04 N 82 41E 44 61 £ 46 13 N 75 13 E 55 58 E 59 36 N 69 27 E 67 70 E ~74 37 N 65 33 E 82 29 E 92 46 N 62 52 E 99 75 E 114 03 N 61 1 E 46 E 138 57 N 59 33 E 13 E 166 31 N 58 3 E 2000.00 1979.56 1819.56 18 59 2100.00 2073.68 1913.68 20 33 2200.00 2166.76 2006.76 22 18 2300.00 2258.76 2098.76 23 53 2400.00 2349.61 2189.61 25 28 2500.00 2439.31 2279.31 27 4 2600,00 2527.72 2367.72 28 30 2700.00 2615.20 2455.20 29 27 N 49 34 E 195.98 N 49 44 E 229.74 N 50 37 E 266.29 N 52 10 E 305.47 N 52 57 E 347.21 N 53 6 E 391.37 N 52 51 E 438.04 N 52 31 E 486.46 536.30 587.64 2800.00 2701.87 2541.87 30 24 N 52 29 E 2900.00 2787.67 2627.67 31 25 N 52 23 E 1 .36 2.01 1 .65 1 .89 1 .56 1 .70 1.15 0.80 1.12 1.10 108.10 N 164.85 E 197.13 N 56 45 E 129.98 N 190.56 E 230.67 N 55 42 E 153.42 N 218.61E 267.07 N 54 56 E 177.87 N 249.23 E 306.19 N 54 29 E 203.20 N 282.43 E 347.93 N 54 16 E 229.78 N 317.75 E 392.13 N 54 8 E 257.90 N 355.05 E 438.84 N 54 0 E 287.27 N 393.59 E 487.28 N 53 52 E 317.64 N 433.15 E 537.13 N 53 45 E 348.94 N 473.87 E 588.49 N 53 38 E 3000.00 2872.53 2712.53 32 25 N 51 54 E 640 53 3100.00 2956.53 2796.53 33 18 N 51 39 E 694 78 3200.00 3039.67 2879.67 34 12 N 51 36 E 750 33 3300.00 3121.85 2961.85 35 24 N 51 44 E 807 30 3400.00 3202.34 3042.34 37 20 N 51 24 E 866 61 3500.00 3281.11 3121.11 38 45 N 51 6 E 928 21 3600.00 3358.14 3198.14 40 31 N 50 59 E 991 96 3700.00 3433.00 3273.00 42 33 N 50 42 E 1058 26 3800.00 3505.51 3345.51 44 33 N 50 20 E 1127.11 3900.00 3575.78 3415.78 45 58 N 50 17 E 1198.25 0.89 0.87 0.90 1 .88 1 .52 1.63 1 .91 2.02 2.29 1 .07 381 43 N 515.64 E 641.36 N 53 31 E 415 449 484 521 560 600 642 685 731 01N 558.25 E 695.61 N 53 22 E 52 N 601.80 E 751.15 N 53 14 E 86 N 646.49 E 808 11 N 53 8 E 72 N 692.98 E 867 42 N 53 2 E 29 N 741.01E 928 99 N 52 54 E 36 N 790.60 E 992 71 N 52 47 E 24 N 841.99 E 1058 97 N 52 40 E 99 N 895.16 E 1127 78 N 52 32 E 50 N 949.84 E 1198 87 N 52 24 E COMPUTATION DATE: 14-JAN-91 PAGE 2 MARATHON OIL COMPANY TBU M-27 TRADING BAY UNIT KENAI, ALASKA DATE OF SURVEY: 12-JAN-1991 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/5OUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4000.00 3644.51 3484.51 47 22 4100.00 3710.82 3550.82 49 33 4200.00 3774.46 3614.46 51 11 4300.00 3836.56 3676.56 52 6 4400 O0 3898.03 3738.03 51 48 4500 O0 3959.96 3799.96 51 49 4600 O0 4021.89 3861.89 51 20 4700 O0 4084.93 3924.93 50 54 4800 OD 4147.84 3987.84 51 2 4900 N 50 32 E 1270.88 N 50 30 E 1345.73 N 50 19 E 1422.85 N 50 18 E 1501 23 N 50 29 E 1580 11 N 50 38 E 1658 63 N 50 45 E 1737 14 N 51 3 E 1814 77 N 51 14 E 1892 49 O0 4210.79 4050.79 50 56 N 51 14 E 1970 19 2 09 2 06 0 80 1 ,42 0 87 0 29 2 24 0 64 021 0 19 777 78 N 1005.82 E 1271 46 N 52 17 E 825 874 924 974 1024 1074 1123 1172 1220 33 N 1063.62 E 1346 51 N 1123.03 E 1423 57 N 1183.34 E 1501 89 N 1244.08 E 1580 76 N 1304.73 E 1659 53 h 1365.45 E 1737 45 N 1425.73 E 1815 20 N 1486.27 E 1892 86 N 1546.85 E 1970 27 N 52 11 E 36 N 52 6 E 71 N 52 0 E 55 N 51 55 E 05 N 51 51 E 55 N 51 48 E 17 N 51 46 E 89 N 51 44 E 59 N 51 43 E 5000.00 4274.11 4114.11 50 23 5100.00 4337.85 4177.85 50 36 5200.00 4400.98 4240.98 50 59 5300.00 4463.91 4303.91 50 56 5400.00 4526.97 4366.97 51 6 5500.00 4589.93 4429.93 50 37 5600.00 4653.16 4493.16 50 59 5700.00 4715.60 4555.60 51 41 5800.00 4777,83 4617.83 51 16 5900.00 4840.34 4680.34 51 22 N 51 29 E 2047 58 N 51 52 E 2124 N 52 1 E 2202 N 52 11 E 2279 N 51 51 E 2357 N 51 39 E 2435 N 51 42 E 2512 N 51 27 E 2590 N 51 8 E 2668 N 50 41 E 2746 61 15 84 42 O9 55 65 92 97 0 79 0 77 0 20 0 68 1 04 0 66 071 0 66 0 36 0 77 1269.23 N 1607 27 E 2047 99 N 51 42 E 1316.99 N 1667 1364.81 N 1728 1412.55 N 1790 1460.24 N 1851 1508.42 N 1912 1556.45 N 1973 1604.96 N 2034 1653.94 N 2095 1703.12 N 2155 73 E 2125 04 N 51 42 E 79 E 2202 59 N 51 43 E 11 E 2280 31 N 51 43 E 35 E 2357 92 N 51 44 E 28 E 2435 60 N 51 44 E 07 E 2513 08 N 51 44 E 29 E 2591.19 N 51 44 E 36 E 2669.46 N 51 43 E 97 E 2747.51 N 51 42 E 6000.00 4902.82 4742.82 51 20 6100.00 4965,19 4805.19 51 24 6200.00 5027.52 4867.52 51 40 6300.00 5089.51 4929.51 51 55 6400.00 5151.04 4991.04 51 56 6500.00 5212.26 5052.26 52 31 6600.00 5273.31 5113.31 52 10 6700.00 5335.08 5175.08 51 46 6800.00 5397.12 5237.12 51 34 6900.00 5459.32 5299.32 51 17 N 50 21 E 2825.05 N 50 13 E 2903.22 N 49 18 E 2981.41 N 48 52 E 3059.85 N 48 50 E 3138.65 N 48 32 E 3217.67 N 48 39 E 3296.83 N 48 38 E 3375.42 N 48 34 E 3453.80 N 48 37 E 3532.06 061 0 46 0 85 1 36 031 0 68 0 72 0 67 0 50 1 19 1752 83 N 2216.18 E 2825.57 N 51 40 E 1802 1853 1904 1956 2008 2061 2113 2165 2216 74 N 2276.34 E 2903.72 N 51 37 E 25 N 2336.03 E 2981.87 N 51 34 E 70 N 2395.27 E 3060.26 N 5~ 31E 56 N 2454.65 E 3139.02 N 51 27 E 78 N 2514.02 E 3218.00 N 51 22 E 18 N 2573.41E 3297.11 N 51 18 E 13 N 2632.44 E 3375.66 N 51 15 E 02 N 2691.26 E 3454.01 N 51 11E 62 N 2749.97 E 3532.23 N 51 8 E 7000.00 5522.39 5362.39 50 36 7100.00 5586.48 5426.48 49 50 7200.00 5651.07 5491,07 49 47 7300.00 5715.09 5555.09 50 38 7400.00 5778.38 5618.38 50 48 7500.00 5841.56 5681.56 50 44 7600.00 5904.80 5744.80 51 1 7700.00 5967,21 5807.21 51 28 7800.00 6029.45 5869.45 51 37 7900,00 6091,29 5931.29 51 54 N 48 26 E 3609.61 N 48 57 E 3686 33 N 49 47 E 3762 N 50 5 E 3839 N 50 19 E 3916 N 50 8 E 3994 N 49 55 E 4071 N 50 10 E 4149 N 50 22 E 4228 N 50 42 E 4306 65 47 89 40 66 99 26 85 1 32 0 79 0 69 0 53 0 19 041 1 09 1 34 0 45 0 48 2268.18 N 2808.15 E 3609.76 N 51 4 E 2318.93 N 2865.74 E 3686.44 N 51 1E 2368.62 N 2923.70 E 3762.76 N 50 59 E 2418,05 N 2982.50 E 3839.56 N 50 58 E 2467.60 N 3041.98 E 3916.98 N 50 57 E 2517.14 N 3301.60 E 3994.49 N 50 56 E 2566.92 N 3160.95 E 4071.94 N 50 55 E 2617.17 N 3220.79 E 4150.07 N 50 54 E 2667.19 N 3280.98 E 4228.33 N 50 53 E 2717.16 N 3341.64 E 4306.92 N 50 53 E o · COMPUTATION DATE: 14-JAN-91 PAGE 3 aARATHON OIL COMPANY TBU M-27 TRADING BAY UNIT KENAI, ALASKA DATE OF SURVEY: 12-JAN-1991 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERT[£AL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IOD FEET FEET FEET DEG 8000.00 6152.89 5992.89 52 3 N 50 59 E 4385.62 8100.00 6214.43 6054.43 51 53 N 51 20 E 4464.43 8200.00 6276.04 6116.04 52 29 N 51 34 E 4543.19 8300.00 6336.99 6176.99 52 9 N 51 43 E 4622.46 8400.00 6397.82 6237.82 52 56 N 51 48 E 4701.81 8500.00 6458.25 6298.25 52 54 N 51 49 E 4781.47 8600.00 6518.41 6358.41 53 3 N 51 44 E 4861.33 8700.00 6578.28 6418.28 53 16 N 51 42 E 4941.41 8800.00 6637.97 6477.97 53 27 N 51 20 E 5021.63 8900.00 6698.03 6538.03 52 39 N 51 20 E 5101.58 0.31 2766.87 N 3402.75 E 4385 69 N 50 53 E 0.71 2816.32 N 3464.13 E 4464 51 N 50 53 E 1.71 2865.36 N 3525.76 E 4543 27 N 50 54 E 0.69 2914.58 N 3587.91 E 4622 54 N 50 55 E 1.05 2963.70 N 3650.26 E 4701 91 N 50 56 E 0.8B 3012.97 N 3712.87 E 4781 57 N 50 56 E 0.59 3062.41 N 3775.62 E 4861 45 N 50 57 E 0.33 3112.00 N 3838.52 E 4941.54 N 50 58 E 0.62 3161.94 N 3901.31 E 5021.76 N 50 59 E 0.52 3211.83 N 3963.79 E 5101.71 N 50 59 E 9000.00 6759,88 6599.88 51 2 N 51 25 E 5180.14 9100.00 6822.95 6662.95 50 42 N 51 19 E 5257.74 9200.00 6886.83 6726.83 50 0 N 51 31 E 5334.66 9300.00 6951.56 6791.56 49 14 N 52 0 E 5410.87 9400.00 7016.59 6856.59 49 47 N 52 39 E 5486.80 9500.00 7080.86 6920.86 50 5 N 53 18 E 5563.34 9600.00 7144.66 6984.66 50 20 N 53 10 E 5640.27 9700.00 7208.52 7048.52 50 17 N 53 11 E 5717.13 9800.00 7271.92 7111.92 51 9 N 53 13 E 5794.38 9900.00 7333.93 7173.93 51 53 N 52 20 E 5872.76 0.71 3260.91 N 4025.15 E 5180.28 N 50 59 E 0.51 3309.39 N 4085.75 E 5257.89 N 51 0 E 0.19 3357.36 N 4145.89 E 5334.82 N 51 0 E 0.64 3404.59 N 4205.72 E 5411.04 N 51 1 E 0.88 3451.00 N 4265.86 E 5486.99 N 51 2 E 0.65 3497.11 N 4327.04 E 5563.55 N 51 3 E 1.12 3543.18 N 4388.75 E 5640.50 N 51 5 E 0.31 3589.31 N 4450.34 E 5717.40 N 51 7 E 1.52 3635.54 N 4512.33 E 5794.68 N 51 9 E 1.63 3682.85 N 4574.91 E 5873.09 N 51 10 E 10000.00 7395.41 7235.41 52 12 N 50 35 E 5951.62 10100.00 7456.98 7296.98 51 35 N 48 53 E 6030.40 10200.00 7519,23 7359.23 51 29 N 48 51 E 6108.62 10300.00 7581.02 7421.02 51 58 N 49 46 E 6187.23 10400.00 7642.52 7482.52 52 34 N 50 16 E 6266.08 10500.00 7703.07 7543.07 52 44 N 50 20 E 6345.66 10600.00 7763.24 7603.24 53 25 N 49 53 E 6425.53 10700.00 7822.43 7662.43 54 0 N 49 10 E 6506.11 10800.00 7882.03 7722.03 52 51 N 48 23 E 6586.37 10900.00 7943.51 7783.51 51 26 N 47 55 E 6665.17 1.79 3732.00 N 4636.59 E 5951.96 N 51 10 E 1.33 3782.95 N 4696.69 E 6030.72 N 51 9 E 0.50 3834.58 N 4755.51E 6108.92 N 51 7 E 1.5] 3885.87 N 4815.09 E 6187.50 N 51 6 E 1.53 3936.48 N 4875.56 E 6266.34 N 51 5 E 0.21 3987.30 N 4936.81E 6345.91 N 51 4 E 0.83 4038.52 N 4998.09 E 6425.77 N 51 4 E 0.80 4090.83 N 5059.41E 6506.34 N 51 3 E 0.81 4143.80 N 5119.76 E 6586.57 N 51 1E 0.91 4196.39 N 5178.53 E 6665.35 N 50 59 E 11000.00 8006.10 7846.10 50 40 N 48 1 E 6743.07 11100.00 8069.47 7909.47 50 54 N 48 11 E 6820.36 11200.00 8133.42 7973.42 50 0 N 48 19 E 6897.17 11300.00 8197.62 8037.62 50 19 N 48 56 E 6973.80 11400.00 8261.08 8101.08 50 14 N 49 39 E 7051.07 11500.00 8325.29 8165.29 50 1 N 49 43 E 7127.71 11600.00 8389.94 8229.94 49 32 N 49 40 E 7204.00 11700.00 8455.40 8295.40 48 48 N 49 30 E 7279.59 11800.00 8521.39 8361.39 48 26 N 49 13 E 7354.71 11900.00 8587.60 8427.60 48 44 N 48 54 E 7429.62 1.75 4248.62 N 5236.44 E 6743.23 N 50 57 E 0.96 4300.26 N 5294.04 E 6820.49 N 50 55 E 0.74 4351.52 N 5351.33 E 6897.28 N 50 53 E 2.26 4402.27 N 5408.81 E 6973.89 N 50 51 E 1.68 4452.54 N 5467.51 E 7051.15 N 50 51 E 0.77 4502.10 N 5525.99 E 7127.79 N 50 50 E 0.82 4551.47 N 5584.16 E 7204.07 N 50 49 E 0.32 4600.43 N 5641.75 E 7279.65 N 50 48 E 0.48 4649.39 N 5698.75 E 7354.76 N 50 47 E 0.11 4698.54 N 5755.33 E 7429.67 N 50 46 E COMPUTATION DATE: 14-JAN-91 PAGE 4 ~ARATHON OIL COMPANY TBU M-27 TRADING BAY UNIT KENAI, ALASKA DATE OF SURVEY: 12-JAN-1991 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 12000.00 8653.72 8493.72 48 32 12100.00 8719,86 8559.'86 48 28 12200,00 8786.43 8626.43 46 29 12300.00 8851.91 8691.91 49 40 12400.00 8916.04 8756. Da 50 37 1 2500.00 8978.69 8818.69 51 44 12600.00 9039.68 8879.68 52 53 12700.00 9099.47 8939.47 53 19 12800.00 9159.00 8999.00 53 28 12900.00 9219.27 9059.27 52 32 N 48 41 E 7504 61 N 48 28 E 7579 56 N 48 57 E 7654 N 48 57 E 7729 70 N 48 58 E 7806 39 N 49 0 E 7884 30 N 49 6 E 7963 52 N 49 11 E 8043 65 N 49 17 E 8123 98 N 49 25 E 8203.76 0.15 0.94 4797 1.38 4846 1.14 4896 1.67 4946 1.69 4998 0.86 5049 0.74 5102 1.67 5154 1.05 5206 4747 92 N 5811 80 E 7504 65 N 50 45 E 55 N 5868 83 N 5924 42 N 5981 83 N 6038 06 N 6097 99 N 6157 45 N 6218 86 N 6279 86 N 6339 03 E 7579 07 E 7654 10 E 7729 94 E 7806 68 E 7884 55 E 7963 15 E 8043 05 E 8123 59 N 50 44 E 17 N 50 43 E 72 N 5O 42 E 40 N 50 41 E 31 N 50 40 E 53 N 5O 39 E 65 N 50 38 E 98 N 50 37 E 59 E 8203.76 N 50 36 E 13000.00 9280.54 9120.54 52 9 13100.00 9341.90 9181.90 52 15 13200.00 9403.53 9243.53 51 35 13300.00 9466.06 9306.06 51 9 13400.00 9529.02 9369.02 50 43 13500.00 9592.91 9432.91 49 52 13600.00 9657.56 9497.56 49 42 13643.00 9685.38 9525.38 49 42 N 49 45 E 8282.77 N 49 48 E 8361.73 N 49 53 E 8440.47 N 49 44 E 8518,51 N 49 39 E 8596.18 N 49 55 E 8673.11 N 50 3 E 8749.14 N 50 3 E 8781.94 0.73 0.84 0.89 0.54 1 .23 1.19 0.00 0.00 5258.06 N 6399 78 E 8282.78 N 50 36 E 5309.02 N 6460 10 E 8361.73 N 50 35 E 5359.82 N 6520 27 E 8440.47 N 50 35 E 5410.15 N 6579 91 E 8518.51 N 50 34 E 5460.45 N 6639 12 E 8596.18 N 50 34 E 5510.11 N 6697 87 E 8673.11 N 50 33 E 5559.58 N 6755 64 E 8749.14 N 50 33 E 5580.63 N 6780 78 E 8781.94 N 50 33 E COMPUTATION DATE: 14-JAN-91 PAGE 5 ~ARATHON OIL COMPANY TBU M-27 TRADING BAY UNIT KENAI, ALASKA DATE OF SURVEY: 12-JAN-1991 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -160.00 0 0 N 0 0 E 0.00 1000.00 999.62 839.62 3 33 N 66 51 E 12.38 2000.00 1979.56 1819.56 18 59 N 49 34 E 195.98 3000.00 2872.53 2712.53 32 25 N 51 54 E 640.53 4000.00 3644.51 3484.51 47 22 N 50 32 E 1270.88 5000.00 4274.11 4114.11 50 23 N 51 29 E 2047.58 6000.00 4902.82 4742.82 51 20 N 50 21 E 2825.05 7000.00 5522.39 5362.39 50 36 N 48 26 E 3609.61 8000.00 6152.89 5992.89 52 3 N 50 59 E 4385.62 9000.00 6759.88 6599.88 51 2 N 51 25 E 5180.14 0.00 0.00 N 0.00 E 0.00 N 0 0 E 2.56 3.75 S 19.11E 19.47 5 78 54 E 1.36 108.10 N 164.85 E 197.13 N 56 45 E 0.89 381.43 N 515.64 E 641 38 N 53 31E 2.09 777.78 N 1005.82 E 1271 46 N 52 17 E 0.79 1269.23 N 1607.27 E 2047 99 N 51 42 E 0.61 1752.83 N 2216.18 E 2825 57 N 51 40 E 1.32 2268.18 N 2808.15 E 3609 76 N 51 4 E 0.31 2766.87 N 3402.75 E 4385 69 N 50 53 E 0.71 3260.91N 4025.15 E 5180 28 N 50 59 E 10000.00 7395.41 7235.41 52 12 N 50 35 E 5951.62 11000.00 8006.10 7846.10 50 40 N 48 1 E 6743.07 12000.00 8653.72 8493.72 48 32 N 48 41 E 7504.61 13000.00 9280.54 9120.54 52 9 N 49 45 E 8282.77 13643.00 9685.38 9525.38 49 42 N 50 3 E 8781.94 1.79 3732.00 N 4636.59 E 5951.96 N 51 10 E 1.75 4248.62 N 5236.44 E 6743.23 N 50 57 E 0.15 4747.92 N 5811.80 E 7504.65 N 50 45 E 0.73 5258.06 N 6399.78 E 8282.78 N 50 36 E 0.00 5580.63 N 6780.78 E 8781.94 N 50 33 E MARATHON OIL COMPANY TBU M-27 TRADING BAY UNIT KENA2, ALASKA COMPUTATION DATE: 14-JAN-91 PAGE 6 DATE OF SURVEY: 12-JAN-1991 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER: MCCROSSAN [NTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORD]NATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZ[MUTM SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -160.00 0 0 N 0 0 E 160.01 160.00 0.00 0 16 S 7 51 W 260.01 260.00 100.00 0 11 S 15 43 W 360.01 360.00 200.00 0 23 S 12 48 E 460.02 460.00 300.00 0 52 S 42 32 E 560.04 560.00 400.00 1 38 S 56 37 E 660.09 660.00 500.00 1 58 S 72 4 E 760.16 760.00 600.00 2 6 N 86 1 E 860.23 860.00 700.00 2 11 N 79 40 E 960.32 960.00 800.00 2 47 N 70 10 E 0.00 0.00 -0.16 0.08 -0.43 0.00 -0.76 0.48 -0.86 0.57 -0.43 0.55 0.83 1.07 3.35 0.41 6.51 0.35 10.32 1.33 0 O0 N 1 19 S 1 54 S 2 02 S 2 88 S 4 29 S 5 72 S 6085 5 4 0 O0 E 0 0 0 1 2 5 9 58 S 13 55 S 17 0.00 N 0 0 E 77 E 1.41 S 32 52 E 71 E 1.70 S 24 39 E 68 E 2.13 S 18 29 E 26 E 3.14 S 23 33 E 97 E 5.22 S 34 42 E 77 E 8.13 S 45 16 E 34 E 11. 15 S 56 55 E 03 E 14, 17 S 66 48 E 10 E 17.70 S 75 7 E 1060.54 1060.00 900.00 4 40 N 64 55 E 16.60 1160.96 1160.00 1000.00 5 47 N 59 58 E 25.59 1261.61 1260.00 1100.00 7 16 N 52 32 E 36.89 1362.56 1360.00 1200.00 8 17 N 50 11 E 50.71 1463.70 1460.00 1300.00 9 9 N 50 44 E 65.86 1565.26 1560.00 1400.00 10 57 N 52 12 E 83.57 1667.48 1660.00 1500.00 12 58 N 53 25 E 104.68 1770.47 1760.00 1600.00 14 41 N 52 30 E 129.28 1874.34 1860.00 1700.00 16 45 N 50 10 E 157.34 1979.35 1960.00 1800.00 18 39 N 49 37 E 189.38 1 32 1 42 1 45 0 42 1 52 1 87 1 96 1 .91 2.21 1 .58 1.94 S 23.10 E 23.18 S 85 11 E 2.29 N 31.26 E 31.34 N 85 49 E 8.66 N 40.65 E 41.56 N 77 59 E 17.34 N 51.39 E 54.24 N 71 21 E 27.02 N 63.05 E 68.60 N 66 48 E 38.04 N 76.92 E 85.82 N 63 41E 50.80 N 93.76 E 106.64 N 61 33 E 65.57 N 113.46 E 131.05 N 59 59 E 83.14 N 135.35 E 158.84 N 58 26 E 103.82 N 159.82 E 190.58 N 57 0 E 2085.38 2060.00 1900.00 20 15 N 49 39 E 224.59 2192.71 2160.00 2000.00 22 11 N 50 32 E 263.55 2301.36 2260.00 2100.00 23 54 N 52 11 E 306.03 2411.50 2360.00 2200.00 25 39 N 52 58 E 352.13 2523.30 2460.00 2300.00 27 27 N 53 4 E 402.06 2636.80 2560.00 2400.00 28 53 N 52 43 E 455.69 2751.57 2660.00 2500.00 29 54 N 52 29 E 511.99 2867.62 2760.00 2600.00 31 6 N 52 28 E 570.84 2985.16 2860.00 2700.00 32 18 N 51 57 E 632.57 3104.15 2960.00 2800.00 33 21 N 51 38 E 697.05 2.06 1 .65 1 .87 1 .49 1 .64 1 .02 0.93 0.84 0.90 0.87 126.65 N 186,63 E 225.55 N 55 50 E 151.67 N 216.49 E 264.34 N 54 59 E 178.21 N 249.67 E 306.75 N 54 29 E 206.17 N 286.36 E 352.86 N 54 15 E 236.21 N 326.31 E 402.83 N 54 6 E 268.58 N 369.12 E 456.50 N 53 58 E 302.83 N 413.85 E 512.81 N 53 48 E 338.69 N 460.56 E 571.68 N 53 40 E 376.51 N 509.37 E 633.42 N 53 32 E 416.42 N 560.03 E 697.89 N 53 22 E 3224.61 3060.00 2900.00 34 26 N 51 37 E 764.19 3347.06 3160.00 3000.00 36 22 N 51 38 E 834.84 3472.99 3260.00 3100.00 38 20 N 51 9 E 911.37 3602.45 3360.00 3200.00 40 34 N 50 58 E 993 57 3736.87 3460.00 3300.00 43 16 N 50 37 E 1083 36 3877.35 3560.00 3400.00 45 44 N 50 13 E 1182 O0 4022.98 3660.00 3500.00 47 52 N 50 35 E 1287 86 4176.97 3760.00 3600.00 50 57 N 50 20 E 1404 94 4338.20 3860.00 3700.00 52 13 N 50 19 E 1531 40 4500.07 3960.00 3800.00 51 49 N 50 38 E 1658 68 0.97 2.22 1 .36 1 .92 1 .89 1 .03 2.22 1 .24 0.58 456.13 N 612.66 E 765.01 N 53 13 E 501.94 N 668.11 E 835.65 N 53 5 E 549.72 N 727.90 E 912.15 N 52 56 E 601.37 N 791.84 E 994.31 N 52 47 E 658.15 N 861.40 E 1084.06 N 52 37 E 721.10 ~ 937.35 E 1182.63 N 52 26 E 788.57 N 1018.93 E 1288.43 N 52 16 E 863.07 N 1109.24 E 1405.46 N 52 7 E 943.83 N 1206.56 E 1531.86 N 51 58 E 0.29 1024.79 N 1304.78 E 1659.11 N 51 51 E COMPUTATION DATE: 14-JAN-g1 PAGE 7 MARATHON O!L COMPANY TBU M-27 TRADING BAV UNIT KENA!, ALASKA DATE OF SURVEY: 12-JAN-1991 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4660.53 4060.00 3900.00 50 46 4819.33 4160.00 4000.00 51 1 4977.82 4260.00 4100.00 50 32 5134.98 4360.00 4200.00 50 50 5293.79 4460.00 4300.00 50 57 5452.60 4560.00 4400.00 51 1 5610.87 4660.00 4500.00 51 3 5771.45 4760,00 4600.00 51 25 5931.48 4860.00 4700.00 51 21 6091.68 4960.00 4800.00 51 25 N 50 59 E 1784.17 N 51 14 E 1907.51 N 51 23 E 2030.46 N 51 54 E 2151.69 N 52 10 E 2275.01 N 51 35 E 2398.35 N 51 41 E 2521.00 N 51 12 E 2646.62 N 50 29 E 2771.55 N 50 15 E 2896.72 0.56 0.17 0.89 0.55 0.58 1 .03 0.89 0.69 0.46 0.39 1104.19 N 3401 94 E 1784 57 N 51 47 E 1181.61 N 1497 98 E 1907 91 N 51 44 E 1258.56 N 1593 88 E 2030 87 N 51 42 E 1333.70 N 1689 04 E 2152 11 N 51 42 E 1409.59 N 1786 30 E 2275 48 N 51 43 E 1485.60 N 1883 48 E 2398 85 N 51 44 E 1561.69 N 1979 70 E 2521 52 N 51 44 E 1639.95 N 2077 98 E 2647 16 N 51 43 E 1718.73 N 2174.96 E 2772.09 N 51 41 E 1798.58 N 2271.34 E 2897.22 N 51 38 E 6252.33 5060.00 4900.00 51 34 N 48 57 E 3022.43 6414.57 5160.00 5000.00 52 1 N 48 47 E 3150.13 6578.29 5260.00 5100.00 52 19 N 48 38 E 3279.68 6740.25 5360.00 5200.00 51 43 N 48 35 E 3407.01 6901.08 5460.00 5300.00 51 16 N 48 37 E 3532.90 7058.85 5560.00 5400.00 50 2 N 48 37 E 3654.85 7213.83 5660.00 5500.00 49 50 N 49 52 E 3773.21 7370.93 5760.00 5600,00 50 46 N 50 15 E 3894.36 7529.11 5860.00 5700.00 50 41 N 50 3 E 4016.93 7688.43 5960.00 5800.00 51 30 N 50 6 E 4140.94 1 .07 0.54 0.33 0.78 1 .20 0.87 0.74 0.20 0.21 1 .40 1880,10 N 2367.06 E 3022.87 N 51 32 E 1964.13 N 2463.29 E 3150.49 N 51 26 E 2049,84 N 2560.54 E 3279,97 N 51 19 E 2134.03 N 2656.15 E 3407.23 N 51 13 E 2217.38 N 2750,61 E 3533.07 N 51 8 E 2298.17 N 2842.06 E 3654.98 N 51 2 E 2375.44 N 2931.76 E 3773.32 N 50 59 E 2453.21 N 3024.66 E 3894°46 N 50 57 E 2531.59 N 3118.89 E 4017.02 N 50 56 E 2611.36 N 3213.84 E 4141.02 N 50 54 E 7849.31 6060.00 5900.00 51 49 8011.56 6160.00 6000.00 52 3 8173.81 6260.00 6100.00 52 5 8337.58 6360.00 6200.00 52 22 8502.90 6460.00 6300.00 52 55 8669.43 6560.00 6400.00 53 17 8836.92 6660.00 6500.00 53 16 9000.19 6760.00 6600.00 51 2 9158.19 6860.00 6700.00 50 11 9312.92 6960.00 6800.00 49 13 N 50 31 E 4266.97 N 51 1 E 4394.73 N 51 34 E 4522.49 N 51 45 E 4652.17 N 51 49 E 4783.78 N 51 46 E 4916.92 N 51 25 E 5051.25 N 51 26 E 5180.29 N 51 27 E 5302.60 N 52 6 E 5420.65 0.73 0.31 1 .58 0.88 0.88 0.39 1.44 0.70 2691.85 N 3310.83 E 4267.04 N 50 53 E 2772.60 N 3409.83 E 4394.80 N 50 53 E 2852.49 N 3509.55 E 4522.57 N 50 54 E 2932.98 N 3611.24 E 4652.26 N 50 55 E 3014.41 N 3714.70 E 4783.89 N 50 56 E 3096.82 N 3819.29 E 4917,04 N 50 58 E 3180.42 N 3924.46 E 5051.38 N 50 59 E 3261.00 N 4025.26 E 5180.43 N 50 59 E 1.36 3337.39 N 4120.81 E 5302.76 N 51 0 E 0.84 3410.61 N 4213.44 E 5420.82 N 51 1 E 9467.49 7060.00 6900.00 50 5 9624.02 7160.00 7000.00 50 18 9781.06 7260.00 7100.00 50 56 9942.29 7360.00 7200.00 52 2 10104.87 7460.00 7300.00 51 32 10265.85 7560.00 7400.00 52 3 10428.83 7660.00 7500.00 52 46 10594.57 7760.00 7600.00 53 22 10763.37 7860.00 7700.00 53 12 10926.45 7960.00 7800.00 51 25 N 53 8 E 5538.43 N 53 10 E 5658.73 N 53 17 E 5779.68 N 51 33 E 5906.06 N 48 48 E 6034.22 N 49 24 E 6160.32 N 50 19 E 6289.00 N 49 54 E 6421.17 N 48 34 E 6557.12 N 47 56 E 6685.83 0.56 3482.17 N 4307.07 E 5538.63 N 51 3 E 0.90 3554.26 N 4403.55 E 5658.98 N 51 6 E 1.12 3626.75 N 4500.54 E 5779.98 N 51 8 E 1.58 3703.37 N 4601.14 E 5906.39 N 51 10 E 1.17 3785.45 N 4699.57 E 8034.54 N 51 9 E 1.17 3868.42 N 4794.61 E 6160.60 N 51 6 E 0.99 3951.12 N 4893.20 E 6289.26 N 51 5 E 0.87 4035.71 N 4994.76 E 6421.42 N 51 4 E 1.34 4124.40 N 5097.84 E 6557.34 N 51 2 E 0.96 4210.25 N 5193.88 E 6686.00 N 50 58 E COMPUTATION DATE: 14-JAN-91 PAGE 8 MARATHON OIL COMPANY TBU M-27 TRADING BAY UNIT KENA[, ALASKA DATE OF SURVEY: 12-JAN-1991 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORD]NATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST D[ST. AZ1MUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 11085.00 B060 O0 7900.00 50 51 N 48 11 E 6808 74 1241 .36 8160 1398.32 8260 1553.84 8360 1706.98 8460 1858 . 23 8560 2009.49 8660 2160.27 8760 2312.51 8860 2469 . 94 8960 O0 8000.00 50 1 N 48 29 E 6928 84 O0 8100.00 50 15 N 49 39 E 7049 78 O0 8200.00 49 37 N 49 41 E 7168 87 O0 8300.00 48 48 N 49 28 E 7284 84 O0 8400.00 48 34 N 48 58 E 7398 27 00 8500.00 48 33 N 48 40 E 7511.72 O0 8600.00 48 7 N 48 43 E 7624.50 O0 8700.00 49 48 N 48 56 E 7739.23 O0 8800.00 51 23 N 48 54 E 7860.76 1 22 4292 50 N 5285.37 E 6808 87 N 50 55 E 34 4372 56 N 5375.03 E 6928 78 4451 70 N 5466.52 E 7049 06 4528 72 N 5557.37 E 7168 30 4603 84 N 5645.75 E 7284 76 4677 93 N 5731,69 E 7398 22 4752 62 N 5817.15 E 7511 70 4827 31 N 5901.74 E 7624 06 4902.69 N 5988.30 E 7739 75 4982.59 N 6079,92 E 7860 94 N 50 52 E 86 N 50 51E 94 N 5O 49 E 90 N 50 48 E 33 N 5O 47 E 76 N 50 45 E 53 N 50 43 E 26 N 50 42 E 77 N 50 40 E 12633.82 9060.00 8900.00 53 15 N 49 6 E 7990.54 12801.68 9160.00 9000.00 53 28 N 49 17 E 8125.33 12966.53 9260.00 9100.00 52 6 N 49 40 E 8256.36 13129.50 9360.00 9200.00 52 7 N 49 48 E 8385.03 13290.34 9460.00 9300.00 51 10 N 49 46 E 8510.99 13448.67 9560.00 9400.00 50 18 N 49 48 E 8633.72 13603.77 9660.00 9500.00 49 42 N 50 3 E 8752.02 13643.00 9685.38 9525.38 49 42 N 50 3 E 8781.94 1 33 5067.69 N 6177.98 E 7990 55 N 50 38 E 1 75 5155.74 N 6280.07 E 8125 33 N 50 37 E 0 30 5240.98 N 6379.63 E 8256 36 N 50 36 E 0 73 5324.06 N 6477.89 E 8385 03 N 50 35 E 0 44 5405.29 N 6574.17 E 8510 99 N 50 34 E 0 53 5484.71 N 6667.76 E 8633 72 N 50 34 E 0 O0 5561.42 N 6757.84 E 8752 02 N 50 33 E 0 O0 5580.63 N 6780.78 E 8781.94 N 50 33 E MARATHON O'rL COMPANY TBU M-27 TRAD'ING BAY UN]:T KENA!, ALASKA MARKER LAST GCT READING PBTD DRILLERS TD COMPUTATION DATE: 14-JAN-gl PAGE 9 DATE OF SURVEY: 12-JAN-1991 KELLY BUSHING ELEVAT[ON: 160.00 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 974' FNL, 531' FWL. 5EC33 TgN R13W MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 13522.80 9607.63 9447.63 5521.78 N 6710.50 E 13550.00 9625.22 9465.22 5535.09 N 6726.40 E 13643.00 9685.38 9525.38 5580.63 N 6780.78 E COMPUTATION DATE: 14-JAN-91 PAGE 10 MARATHON OIL COMPANY TBU M-27 TRADING BAY UNIT KENAI, ALASKA DATE OF SURVEY: 12-JAN-1991 KELLY BUSHING ELEVATION: 160.00 FT ENGINEER: MCCROSSAN ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 974' FNL. 533' FWL, 5EC33 T9N R13W MARKER MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST LAST GCT READING PBTD DRILLERS TD 13522.80 9607.63 9447.63 13550.00 9625.22 9465.22 13643.00 9685.38 9525.38 5521.78 N 6710.50 E 5535.09 N 6726.40 E 5580.63 N 6780.78 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 13643.00 9685.38 9525.38 8781.94 N 50 33 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY MARATHON OIL COMPANY WELL TBU M-27 FIELO TRAOINO BAY UNIT COUNTRY USA RUN i DATE LOOOEO 12 - JAN - 91 REFERENCE 7428S WELL' '~'BU IX- 27 (974' FNL, 531' FWL, SEC 33, T9N, R13W) HORIZONTAL N~I~?H 10000 REF SCPlL£ = 1/2000 IN/FT 8OOO -20OO ~OUTH -6000 -4000 HEST -~000 0 ~000 4000 6000 8000 10000 12000 EAST 'WELL' TBU M-27 (974' FNL, 531' FWL, SEC 33, T9N, R13W) VERTICAL PROJECTION -2000 0 0 8000 8OOO ] 00o0 ]2OOO 81. PROJ~'C?ION ON V£RTICA~. PLANE SI. - 251. ~CAL£O IN VERTICAl_ DEPTHS m ::::::::::::::::::::::::::::::::::::: R HORIZ SCALE : ]/2000 IN/FT AOGCC L'~r_. ULUL'~I~-.,AL M,q I I-HI~L~ iNVENTORY LiST P~MiT~ ~ - ~ W~LL ~AM~ ~~ ~--Z~ . cfi~ck .ff or Iisi data as it is rcccivcd,'list re,ired d~t~ for 407. ii not required list a~ ~R. j ]'~.7 j'*'~-~ -~'l" J ddlline histO~" I ~ su~e~l ~ ~u ~cs~s I I cor~ ~escri~tiod~ cored intc~als core analysis d~ ditch intc~ais ~ital data i 12| 1~41 16) 181 RUN NO. I1'~ I [to, the nearest foot~ , . [inchl'lO0') i,, 2 :i Unocal North Americ; Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITTAL TO: John Boyle LOCATION: 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION March 28, 1991 GEORGE'S COURIER FROM: R.C. Warthen K. D. Kiloh LOCATION: Alaska Region P. O. Box 190247 Anchorage AK 99519 Transmitting as Follows: Trading Bay Unit - McArthur River Field - Steelhead M-27 q0-~/ 3~ 1 blueline and 1 sepia as follows: Lpg Date Dual Induction SFL BHC Sonic Dual Burst TDT-P Continuous Gyro (GCT) Cement Bond Log (CBT) Cement Bond Log (CBT) Cement Bond Log (CBT) Cement Evaluation Tool 1/23/91 1/23/91 1/31/91 1/12/91 2/1/91 2/7/91 2/13/91 2/7/91 1 Open Hole Tape and LIS Listing i Well Survey 2/19/91 Gas Cons. rJ0mmis~i'or~ Al~.c~iorage Alaska Oil & Gas Conservation Commission Document Transmittal Page Two Washed and dried well cuttings as follows: Box IA 2A 3A 4A 5A 6A 7A 8A 9A Depth 1450-2940 2970-4230 4260-5490 5520-6900 6930-8250 8280-9840 9870-11430 11460-13140 ~ 13140-15380 .. ? PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: A,PR !99i Alaska 0il 8, 6a.s Cons. Cornmisrsior, Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard Re. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: ARCO Date:l 1/06/90 CHEVRON T#:81 629 EXXON MOBIL PHILLIPS STATE OF ALASKA TEXACO GEOSCIENCE ARCHIVES BP OPEN HOLE FINAL Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. ,--- F-38 CNL/GR 10/31/90 #2 2940-10670 ATLAS 2"/5" --- F-38 FMT 10/27/90 #1 3400-6304 ATLAS f- F-38 BHC : 10/26/90 #1 2495-10037 ATLAS 2"/5" "- F-38 DIFL 10/26/90 #1 2495-10065 ATLAS 2"/5" GEeS/ARCO/EXXON/ARCHIVES ONLY. F-38 SSTVD 10/30/90 #2 ATLAS 2" STATE ONLY: Magnetic Single Shot Directional Survey Gyroscopic Directional Inforation Control Well Records LR 2-1 J.. Dietz./S. M¢Curry Date: Job#: Date: Job#: October 24, 1990 Telecopy: (907)276-7542 Mr. Gary S. Bush Regional Drilling Manager Union Oil Company of California P. O. Box 190247 Anchorage, Alaska 99502 Re~ Trading Bay Unit M-27 Union Oil Company of California Permit No. 90-138 Sur. Loc. 974'FNL, 531'F~, Sec. 33, TgN, R13W, SM Bt~ole Loc. !61'FSL, 2904'FWL, Sec. 22, T9N, R13W, SM Dear Mr. Bush: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. ALASKA . ,L AND GAS CONSERVATION C~.,¢,MISSION PERMIT TO DRILL 20 AAC 25.005 I Re-Entry -- Deepen~J Service ~ Developement Gas ~ Single Zone ~, Multiple Zone © 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNOCAL (Marathon Oil Company. Sub-Operator) 160' KB from MLLW feet McArthur River Field "G" Oil Zone 3. Address 6. Property Designation West Foreland P.O. Box 190247, Anchorage, AK 99519-0247 ADL 18730 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC25.025) 974' FNL, 531' FWL, Sec. 33, T9N, R13W, S.M. Trading Bay Unit (See 29 AAC 25.025) SlOtAt4.. in Lea B-i -. Steelhead Platform top of prb'duct~ve ~n~erva~ 8. Well nu ,mber Number 1126' FNL' 1386' 5194234 , FWL, Sec. 27, T9N, R13W @ M-27 9080A't toTtaVI~ depth 9. Approximate spud date Amount 161' FSL, 2904' Fkq], Sec. 22, T9N, R13W October~, 1990 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number n property 15. Proposed depthfMDandTVD property line 15215' 5544 feet 8' at spud feet 3840 10680' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (ell2)) Kickoff depth 975 feet 51.2 Maximum hole angle 0 Maximum surface 3138 psig At total depth(TVD) psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M~- TVD MD TVD (include stage data) Z2" ~, 16" 75 f4-5~ g,,~-~-~'es ;_1,_3.8_,0 73 73 1453 1450 1300 .~x 17-1/2" ~*13-3/8" 61 K-55 Buttre~ 4480 73 73 4553 4000 2850 sx 12-1/4" 10-3/4" 55.5 N-80 Buttres: 427 73 73 500 500 12-1/4" 9-5/8" 47 N-80 Buttres: 13080 500 500 13580 9656 4200 sx 8-1/2" 7" 29 N-80 rKC 1885 1~330 9495 1521~ 10680 600 sx 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 410 ' 34 ' Driven 480' 480 ' Conductor 909 ' 26 ' Surface 979 ' 979 ' Surface Intermediate Production , Liner , Perforation depth: measured true vertical -.. 20. Attachments Filing fee ~ Property plat~J BOP Sketch ~ DiverterSketch ~ Drilling program Drilling fluid program ~X Time vs depth plot~q Refraction analysis ~ Seabed report C 20AAC25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~Ck.~~. (~..z~,-., Title ~,~j~,.kk~ \ Date~o.ta__~ Commission Use O~nly ~ ~' ~" ' Permit Number J AP, number J Approval date I See cover .attar ~0----/~' 50-- ~'..~- ~_.o/-//.~__..~ 10/24/90 for other requirements Conditions of approval Samples requjre, d ~ Yes ~No Mud log requi.red ~ Yes ~"No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ./~Yes ,~ No Required working pr~r BOPE/ ~2M; ~ 3M; ~5M; ~ 10M; ~ 15M Other: ~'-'~--~ ~ by order of Approved 15 Commissioner the commission Date /'"'/','f/'~-~'l~-/~, l~'nrrn lri.4nl pier I?-I-RR Submit in triplicate DE'~"NG AND COMPLETION PROGRAM MA .I'HON OIL COMPANY ALASKA REGION WELL: M-27 LEG: B-1 SLOT: 4 FIELD: AFE No.: TYPE: Trading Bay Unit, Steelhead Platform 8359-0 G-WF water injector REVISION NO.: 1 DATE: 10/9/90 SURFACE LOCATION: 974'FN L,531 ' FWL, Sec.33,T9N, R 13W, S. M. TARGETS: G-Zone: 1126'FNL, 1386' FWL, Sec 27, T9N, R13W @ 9080' TVD W. Foreland: 330'FNL, 2325' FWL, Sec 27, T9N, R13W @ 10070' TVD BOTTOMHOLE LOCATION: KB ELEVATION: 160 ft. GL ELEVATION: 161'FSL, 2904' FWL, Sec 22, T9N, R13W @ 10680' TVD FORMATION AC-1 A-1 B-1 C-1 D-1 E-1 G-1 Hemlock West Foreland TOTAL DEPTH ESTIMATED FORMATION TOPS: DEPTH(MD) POTENTIAL DEPTH(TVD) CONTENT 1474 2866 3451 4366 5011 8317 12666 13463 14243 15215 1470 gas/water 2770 gas/water 3250 gas/water 3870 gas/water 4275 gas/water 6350 gas/water 9080 oil/water 9580 oil/water 10070 oil/water 10680 TYPE SIZE CASING PROGRAM WT. GRADE CONDUCTOR: 26 397 X-56 AUXILIARY: 16 75 K-55 SURFACE: 13.375 61 K-55 PRODUCTION: 10.75 55.5 N-80 9.625 47.0 N-80 LINER: 7.00 29.0 S-95 Page1 SET SET THREAD FROM TO Dril-quip Surf BTC Surf BTC Surf BTC Surf BTC 500' BUTTKC 13330' 979 979'TVD 1453' 1450'TVD 4553' 4O00' TVD 500' 13580' 9656'TVD 15215' 10680' TVD HOLE SIZE in place 17-1/2" U/R to 22" 12-1/4" U/R to 17-1/2 12-1/4" 8-1/2" CASING DESIGN SETTING FRAC GRD FORM PRSS DESIGN FACTORS SIZE WEIGHT GRADE DEPTH,TVD @ SHOE @ SHOE MASP TENS COLL BURST 26" 369# X-56 979' 12 420 500 16" 75.0# K-55 1450' 12.1 663 1077 12.6 1.48 3.23 13.375" 61.0# K-55 4000' > 14.0 1797 1532 1.8 1.24 7.0 10.75" 55.5# N-80 500' 3138 1.8 99.0 2.80 9.625" 47.0# N~0 9656' >14.0 4268 1.6 25.1 2.96 7" 29# S-95 10680' n/a 4720 3559 2.3 24.6 31.7 DIVERTER SYSTEM The diverter system will consist of a 29-1/2" x 500 psi annular preventer, a 30"x 500 psi riser, and two 16" diverter lines each equipped with a 16" hydraulically actuated full-opening ball valve. A preselected diverter valve will open automatically and simultaneously when the annular is closed. The direction of flow can be changed without opening the annular. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 16-3/4" x 5000 psi Hydril type GK annular preventer, a 16-3/4" x 10000 psi Hydril double gate ram type preventer outfitted with blind rams in the bottom and pipe rams in the top, a 16-3/4" x 10000 psi drilling spool (mud cross) equipped with a 4-1/16"x 10000 psi outlet and a 3-1/16" x 10000 psi outlet, and a 16-3/4" x 10000 psi Hydril single gate ram type preventer outfitted with pipe rams. A 16-3/4" x 5000 psi riser will be utilized between the blowout preventers and the casing spools. The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Aisc included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system, both with a readout convenient to the drillers console. The blowout preventers, choke manifold and associated equipment will be pressure tested to 250 psi and to 3000 psi with the exception of the annular which will be tested to 250 psi and to 2500 psi. Page 2 MUD PROGRAM DEPTH WEIGHT VISCOSITY WATER MUD TO ppg sec/qt LOSS TYPE 1450' 9.0-9.2 60-80 <30cc's Spud 4553' 9.2-9.4 40-50 <20cc's PHPA 15215' 9.4-9.8 40-50 < 10cc's PHPA Mud discharges will be monitored and reported per EPA requirements MUD EQUIPMENT The solids control equipment consists of an Brandt dual tandem shale shaker, a Brandt 2-cone desander, a Brandt mudcleaner, and a Brandt centrifuge. WELLHEAD SYSTEM STARTING FLANGE: 30" series 300 MSS x 26" butt weld CASING HEAD: 30" 300 MSS x 21-1/4" 2000 psi FMC segmented clamp hub w/2" L.P. outlets CASING HEAD CLAMP: 21-1/4" 2000 psi FMC segmented clamp CASING HEAD: FMC Unihead Type II, 2 step, 16" pack-off bottom w/21-1/4" 2000 psi clamp hub x 16-3/4" 5000 psi flanged top w/2-1/16" 3000 psi outlets TUBING HEAD: FMC TC-60-ET, SPCL 16-3/4" 5000 psi STD BTM x 16-3/4" 5000 psi FLNGD top w/2-1/16" 5000 psi outlets and four 1/4" SCSSV control line ports Page 3 CEMENTING PROGRAM AUXILIARY: 16"@ 1453' MD LEAD SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME TLW w/ 14% Salt + 5 lb/sack Gilsonite +.80% Halad 344 SURFACE 13.1 ppg. 1.51 cu. ft./sk 6.90 gal/sk 5+ hrs:min 100 % 800 sx TAIL SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium w/.4% GasStop + 1% CaCI2 + .25% SuperCBL + 1/4 Cf/sack Flocele 1240 ft. 15.8 ppg. 1.15 cu. ft./sk 5 gal/sk 4+ hrs:min 100 % 500 sx RUNNING 1. 2. 3. 4. 5. AND CEMENTING DETAILS: Remove thread protectors and visually inspect connections. Pickup shoe joint. Baker-lok float shoe. Fill pipe until circulating. Check float. M/U float collar.(Baker-lok top and bottom of float collar) Fill pipe until circulating. Run remaining casing (filling every joint) and land in the 30" MSS flange (install centralizers on jts. 1,2,4,6,8,10,12,14) 6. Rig up false rotary and run and space out stab-in cementing string. 7. Secure drill pipe and circulate while reciprocating casing. 8. Continue circulating until no gains in circulating efficiency is made. 9. With as little shut down as possible, begin pumping spacer. 10. Pump spacer as follows: 40 bbls 18% NaCI 20 bbls drill water 20 bbls Super Flush (increase if losing circulation) 20 bbls drill water 40 bbls 18% NaCI 12. Mix and pump 215 bbls of lead slurry (800 sx). 13. Mix and pump 102 bbls of tail slurry (500 sx). Reciprocate casing as long as possible. 14. Displace drillpipe. 15. Check float. 16. Pull seals out of float shoe. 17. Pull out of hole w/d.p. 18. WOC 12 hours holding 75 psi on annulus. 19. N/D diverter 20. N/U unihead and BOP stack. Page 4 CEMENTING PROGRAM SURFACE: 13-3/8"@ 4553' MD LEAD SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME TLW w/ .5% Halad 344 + .35% SuperCBL + 2% CaCI2 + .2% CFR-3 SURFACE 13.2 ppg. 1.32 cu. ft./sk 6.70 gal/sk 5+ hrs:min 5O % 1900 sx TAIL SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium w/.3% Halad 344 + .35% SuperCBL +. 1% HR-7 3500 ft. 15.8 ppg. 1.15 cu. ft./sk 5.0 gal/sk 2:20 hrs:min 50 % 950 sx RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED ! 1. Remove thread protectors and visually inspect connections. 2. Pickup shoe joint. Baker-lok float shoe. Check float. Fill pipe until circulating. 3. M/U float collar.(Baker-lok top and bottom of float collar) 4. Fill pipe until circulating. 5. Run remaining casing. M/U cementing head, install bottom plug and test all lines. 6. Circulate and reciprocate until no gains in circulating efficiency is made. 7. With as little shut down as possible, drop bottom plug and begin pumping spacer. Pump spacer as follows: 40 bbls 18% NaCI 20 bbls drill water 20 bbls Super Flush 20 bbls drill water 40 bbls 18% NaCI 8. Load and drop bottom plug w/5 bbls drill water. 9. Mix and pump 447 bbls lead slurry. 10. Mix and pump 200 bbls of tail slurry. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. Install 16"X 13-3/8" packoff. 14. WOC 12 hours holding pressure on annulus. 15. Test BOPE. Run intermediate wear bushing. Page 5 ~-~' CEMENTING PROGRAM ..... ' PRODUCTION: 9-5/8" and 10-3/4" @ 13580' MD LEAD SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME TLW w/.4% Gas Stop + .25% Super CBL + .25% LWL 4000 ft. 13.2 ppg. 1.33 cu. ft./sk 6.70 gal/sk 5 hrs:min 30 % 2300 sx TAIL SLURRY · Premium cement w/.4% Gas Stop + .25% SuperCBL + .12% LWL + .25% CFR-3 TOP OF CEMENT: 8100 ft. WEIGHT: 15.8 ppg, YIELD: 1.18 cu. ft./sk WATER REQ.: 5.0 gal/sk PUMPING TIME: 4:00 hrs:min EXCESS (%): 30 % ESTIMATED VOLUME 1900 sx RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing. M/U cementing head, install bottom plug and test all lines. 6. Circulate and reciprocate until no gains in circulating efficiency is made. 7. With as little shut down as possible, drop bottom plug and begin pumping spacer. Pump spacer as follows: 40 bbls 18% NaCI 20 bbls drill water 20 bbls Super Flush 20 bbls drill water 40 bbls 18% NaCI 8. Load and drop bottom plug w/5 bbls drill water. 9. Mix and pump 545 bbls. lead slurry. 10. Mix and pump 389 bbls. of tail slurry. 11. Displace cement. Reciprocate as long as possible. 12. Bump plug w/500-1000 psi over final circulating pressure. Check floats. 13. Install 16"X 10-3/4" packoff. 14. WOC 12 hours. 15. Test BOPE. Page 6 r~'"CEMENTING PROGRAM LINER: 7"@ 15215' LEAD SLURRY: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium cement w/.4% Gas Stop + .25% SuperCBL + .12% LWL + .25% CFR-3 13300 ft. 15.8 ppg. 1.18 cu. ft./sk 5.0 gal/sk 4:00 hrs:min 30 % 600 sx RUNNING 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 AND CEMENTING DETAILS: Remove thread protectors and visually inspect connections. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. M/U float collar. (Baker-lok all connections below top of float collar) Fill pipe until circulating. Run remaining liner. Make up liner hanger and running tools. Run liner in hole on 5" drillpipe. When shoe of liner is 250' above csg shoe perform rotate and recip, torque test. Continue in hole until 30' from desired depth. M/U swivel, manifold, flag sub and single on top of drill string. Continue to depth, circulate and condition mud. Reciprocate and rotate liner throughout job. Pump 10 bbls. fresh water spacer. Mix and pump 20 bbls. of 11.0 ppg scavenger slurry. Mix and pump 126 bbls slurry. Displace cement. Set liner hanger. Release liner setting tool. Pull 10 stands. Reverse out drillpipe volume. POOH. WOC 12 hours. Page 7 DIRECTIONAL PLAN DESC MD TVD RKB 0 0 TIE-IN & KICKOFF 975 975 BUILD @ 1.5 deg/100ff. END OF BUILD 4244 3807 TOTAL DEPTH 15215 10680 NORTH INCL AZIM COORD EAST COORD 0 0 0 0 2.6 N81.50E -4 51.2 N49.71E 886 51.2 N49.71E 6415 -18 1131 7653 VERT SECTION lO 1435 9986 POTENTIAL INTERFERENCE: WELL DISTANCE (fl:.) DEPTH (MD) M-26 7.72 97O M-28 7.72 970 M-25 23.61 970 M-1 50.01 1271 M-2 98.00 970 M-4 66.51 1171 M-3 89.67 1070 M-5 67.68 1221 RLF-1 14.11 1884 Note: Close approach to Relief well #1 is across a portion of the relief well that was not cased and was abandoned with a balanced cement plug, and therefore presents no true interference problems. Interference checks will be made continually during the drilling of M-27. If M-27 approaches within 50' of another well it will be shutin. CONDUCTOR: LOGGING PROGRAM No logging is planned for this interval. AUXILIARY: No logging is planned for this interval. SURFACE: No logging is planned for this interval. PRODUCTION: GR/SP/Cal/DIL/LSS from 13580'-4553 '. FDC/CNL/Cal/GR from 13580'-4553'. Four arm caliper for cement volumes across open hole. LINER: GR/SP/Cal/DIL/LSS from 15215'-13580'. FDC/CNL/Cal/GR from 15215'-13580'. Four arm caliper for cement volumes across open hole. COMPLETION: A Cement Bond Log (CBL/GR) and a directional gyro- survey will be run prior to perforating. Page 8 DRILLING PROGRAM CONDUCTOR: to 500 psi. 26" casing in place. Weld on starting flange to 26" casing. N/u diverter and test AUXILIARY: Drill a 17-1/2" hole to 1453' RKB per the directional program. Underream hole to 22" from 975' to 1453'. Pull wear bushing. Run and cement 16" auxiliary casing. WOC. Back out and L/D landing joint. N/D diverter and install FMC Unihead w/16" pack-off and test void to 700 psi. N/U bope and test to 2000 psi. Set Unihead wear bushing. Test 16" auxiliary casing to 1850 psi. SURFACE: Drill float equipment and 10' of new formation w/14-3/4" bit. Run leak off test. Do not exceed 14.0 ppg equivalent test pressure. Drill a 12-1/4" hole from 1463' to 4553' per the directional program. Underream the 12-1/4" hole to 17-1/2" from 1453' to 4553'. Pull wear bushing. Run and cement 13-3/8" casing. Set pack-off and test void to 1100 psi. Test BOPE and choke manifold to 3000 psi. Set wear bushing. Test 13-3/8" surface casing to 2150 psi. PRODUCTION: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill a 12-1/4" hole from 4563' to 13580' per the directional program. Log. Pull wear bushing. Run and cement 9-5/8" casing. Set pack-off and test void to 2800 psi. Test BOPE and choke manifold to 4000 psi. Test production casing to 3000 psi. Set wear bushing. LINER: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill a 8-1/2" hole from 13590' to 15215' per the directional program. Log. Run and cement 7" liner. Clean out to liner top and test lap to 4000 psi. COMPLETION: Cleanout casing to PBTD. Run gyro and CBL. Completion procedure to follow. CORING PROGRAM No cores are planned for this well. TESTING PROGRAM No open hole tests are planned for this well. Page9 SENI~ BY-MARATHON OIL CO.ANY ;10-1'7-90 ; 4:02P~ ' Anchora~o~ Alaska Region Domestic Production 92767542;# 1/ 2 Marathon Oil Company DATE: Re. Box 190168 Anchorage, Alaska 9~ %7 Z ~ 1990 FACS IN !..~.E ~w~ a aas CO, s. TIME: ...... ~....~S ~o~or~ PLEASE DELIVER'THE FOLLOWING PAGES TO: COMPANY/FIRM TELECOPY NUMBER ZTr- 75 4z CONFIRMATION NUMBER FROM: NAME ALASKA REGION WE ARE TP, ANSMITTING TELECOPIER NUMBER (907) 564-6489 PAGES (INCLUDING THIS COVER PAGE) IF TRANSMISSION IS NOT COMPLETE, PLEASE CALL: (907) 561-5311 NOTE: TRANSMISSION COMPLETED TVD NS . · .:CALCULATZON OF' LEAST DISTANCE" t,..,:,~. , . . .,:. ...~¢.: - · =: %<.- ... : ,.:. . , .-.:. : . · . . -..' · , ?{ ':: "?~" " CloSest ~o~ition on ~e~l K'23 EW MD TVD NS EW t&'~2'., 36 7720, O0 t'7&'2,~ .17 9770, O0 I841'., 97 9~20, O0 .:::?&,¢::: ..., . :~ : :; 3 4 ....,'..'?..... . . ..: ,. ; . ..... ,.g:~ · .. ~;.-,-: ... .. :" , ..,::f . · ... - .. . .. -. > '.}: : . . ...:' ,. .. .. .:.' .-. .-~ ... ]=7 g' '- , ~' · .~. ~- - :.._'.. .: ::;.: .. ',.:-: 'd'.' ? :.' ,: : -~.-.. ,. ?:: -. :. :' .. .. ... - . .... . . · .,::.., . . ..2 ... : .:. · .::... ...~ :.'... :.:.;:5.:~::~.::: '. '- .:. :.v ... · ..i~,,:- -... -'....- 5642.70 N 5082.93 N 6741.46 E '6788.9.0 E 6836.35 E 14.760.25 9890.27 14760.,, 2.5 9390.2'7 14760.,:.._,°=: 98.~0, 27 5818.66 N 5818.66 N 58!8.66 N 6572.10 E &572. I0 E /:.,.,,7.,:.. I(] E Reef S08303 . 7MA Distance Oirec' 75 E:ett~een Bet~,a ,:_~ id.re 1 I s W e t i ....'.::'5'.'7 .7.!. i'i43 '282.65 ( N57 bi'}:",. --4 --4 O~ Leg~ B-l, Stot~ 4, II Nol M- rimed STEELHEAD Platform ook In mt, mkm 0 . RKB ELEVATIOH~ !$0' 1 o00 2OOO 3000 4O0O 5000 6000 7000 BO00 9OOO 10000 11000 20' CSO PT TVD=950 TMD=950 DEP=IO KOP TVD=9T$ TMD=975 DEP=ll 16= CS9 PT TVD=1450 TM0=1453 DEP=59 t.S DEO/IO0 FT DOGLEG EOC TVD=3807 TMD=4244 DEP=1435EP=1678 AVERAGE ANGLE ~ - TARGET #1./ O ZONE TVD=9080 THD=12661 DEP=7995 ~ ~ TD / T' LINER TVD=IO680 TMD=15215 DEP=9986 I I I I I I I I I I 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 VERTICAL SECTION 10000 HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET 7000 6000 5000 4000 _ 3000 _ 2000 _ 1000 _ 0 1000 _ MARATHON 011Comp~,~ Leg~ 8-1. SIo{~ 4, ~.11 No~ M-27 Revlaod Propoo.l STEELHEAD Pla{form. Cook Inlet, Al.ok. WEST-EAST 1000 0 1000 2000 3000 4000 5000 6000 7000 I I I I I I I TD LOCATION~ 161' FSL, 2904' SEC. 22, TgN. R13~ TARGET w2 TYD-10070 TMD=I4241 DEP-9227 NORTH 5924 EAST 7074 TARGET #2 LOCATION{ 330' FNL, 2325' F~L SEC, 27, rgN, RI3V TARGET #1 TVD=9080 TMD=12661 DEP=?GgS NORTH $128 EAST 6134 TARGET #1LOCATIONt 1126' FNL, 1386' F~L SEC. 27, TGH. SU.rACE ~' 9227' (TO TARGET 2) 9?4, FHL. 531' FVL sec. 33, rG.. 8000 I Fillup Line 16-3/4' 10,000 psi Doublegate Check Valve Kill-'--~Line, Gate Valve Gate Valve Pipe Rams Blind Rams Gate Valve Pipe Rams Flow Line Hydril 16-3/4' 5000 psi Type GK Annular Choke Line HCR Valve 16-3/4' 10,000 psi Singlegate 16-3/4' 5000 psi Riser STEELHEAD pLATFORM Preventer Schematic Ball Valve Wellhead Plan View STEELHEAD PLATFORM - DIVERTER SYSTEM Rig Substructure Ceramite filled ~ ~ ( _ Ceramite fill~o 16;'Diverter Line ' 16' Remo~te~'~~ '6LIDnleVerter Operated Ball Valve Section View Riser 29-1/2' 500 psi Flange I. Conductor. STEELHEAD PLATFORM CHOKE MANIFOLD TO GAS BUSTER TO DERRICK VENT CHOKE LINE I I I I TO SHALE SHAKERS ALL VALVES IN FLOW PATH ARE 3-1/16' 5000 PSI CAMERON GATE TYPE SECTION AA CENTRIFUGE PiT lOO Bbls Cap 0.99 Bbls/in o MUD CLEANER PIT 105 Bbls Cap 1.03 Bbls/in I ._ SUCTION PIT ~2 320 Bbls Cap 3.05 Bbls/in DESANDER PIT 113 Bbls Cap 1.11 Bbla/tn MIX PIT 82 Bbla Cap 0.77 Bbla/in I. RESERVE PIT · 509 Bbla Cap 4.97 Bbla/in PILL PIT 80 Bbla Cap 0.75 Bbla/in DESANDER PIT 113 Bbls Cap 1.11 Bbla/in MUD CLEANER PIT 105 Bbla Cap 1.03 Bbla/in SUCTION PIT ~1 320 Bbla Cap 3.05 Bbla/in CENTRIFUGE PIT 100 Bbls Cap 0.99 Bbls/tn .. MUD RETURN DITCH - EQUALIZER AGITATOR MUD GUN N STEELHEAD PLATFORM MUD PIT LAYOUT 13 TgH-RI 4W , · 1§ I? · ( M-27 Tg H--I~ $ -I- + lcrminoi tor~cnt;o~ mc[hod. ~)l~th lobe~e ore In t~usonds I I I I _]s]'o38, . PROJECTION IHFORMATION Centered on Grayling Platform General Transverse Mercator Spheroid = Crorke 1866 C.M. = 151.613144° West LO, = 60.039779° North Scale Factor -- 1.0000 False EosLIn9, Horthing - 0.0 F'eet MARATHON OIL I COMPAN' TRADING SAY' UNIT McARTIIUI~ RIVER FIELD._ CHE~ LIST FOR NEW ZTLM A~PROVE DATE (2) Loc (10 ~ i3). !l.. 13. (14 :h~ aZ) (23 :hr= 28) Geoio ~: En~er~n~: DwJ ~ LCS -- ~'~' sm~ f rev: 01/30/89 6.0II · ', YES NO Is =he per=i: fee a=uached ,, ..... ' .................................. ". ~ ......... 2. Is well :o' be locaued in a defined pool ............................. 3. Is well loca=ad proper d~s~ance from prope.~-7 line .................. &. Is well Ioca:ed proper dis:ance from o=her wells ........ ~ ........... 5. Is suffi-.ia~= undedica=ed acreage available in =his pool ............ 6. Is well =o be cleric:ed and is ~e!!bore pla: included ................ 7. Is opera:or :he only affected parry ......... i ....................... E. Can permi= be approved before fifteen-day ~ait ...................... l&. 15. 16. 17. i8. !9. 21. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Does operanor have a bond in force .................................. is a conservation order needed ...................................... ' - Is aam~Js=ra~ive approval needed ................................... is :he lease number appro~ria:a ..................................... . Does ~he well have a unique ~Mme and number ..................... ' .... IS c6nduc=or surin§ provided ........................................ · W~! surface casing pro~ec~ all zones reasonably e.x~.ec:ed =o serve as an underground source of drinkin~ wa:ar ..................... Is enough c~men: used =o clr=u!a=e on co:duc:or and surface ......... W~ c~men: :ia in surface and in=ermed/a=e or produc-.ion s=rings ...' Will came:= cover ~%% kno~a produc'~ive horizons ..................... Will al! casing give adequa=a safe=y in collapse, :ansio~ and burs=.. ,,//./~, Is =kis well :o be kicked off from an e~_s:inE w-!~_%ore ............. Is old wei!bore aba:donee:: procedure included on 10-403 ............ Is adequa:e we!lbore separa=ion proposed ' :.T.~ a diver's:er sys~:e.z~ teen.ired. ....................................... Is ~he drilling fluid program schemauic and list of equipmen: adequa:e Are necessary dlagr~-~ and descrip=ions of diver=er and ~OP~ Does ~e ~ake ~u~oi~ c~iy w/~I ~-53 (~y 84) .................. ~ ~e pr~ce of E2S S~s probable ............................. ;... ,. ~larauc~ ~d Scraui~hic we~s: ~e ~:a ~r~sen=ed on 9o=~:i~ ~e~rass~e zones? ................. ~m se~c ~ysis ~:a prms~nad on sh~o~ gas zones ............. ~ ~ offshor~ loc.. =e ~ey ras~:s of seabed con~:ions pres~:ad., ~:io~ r~q=~us ............................................. Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. T° 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 APPENDIXi No special'effort has been made to chronologically organize this category of information. COMPANY NAHE I ~ARA~HON OZb COMPANY WELL NAME I TBU M-27 FIELD NAME ~ MCARTHUR RIVER. BOROUGM ~ KENA! STATE ~ ALASKA API NUMBER % 50'733-20473 REFERENCE NO ~ 7414~ IClIOFILHI D RECEIVEC APR 2 199i AIMka 011 & Gas Cons. ComQl · Tape Veri~Aicatlon L~t~tng ~chlumberger las~a Com uting Center 19-FEB-1991 15:55 ****' REEL HEADKR **** SERVICE NAME : EDIT DATE : 9!/02/19 ORIGIN ' : FLIC REEL NAME : 74342 CONTINUATION # : PREVIOUS REEL : CO~ENT : MARATHON OIL COgPANY,~CARTNUR RIVER,TBU M-27,50-733-20473 **** TAPE HEADER SERVICE NAME : EDIT DATE ~ 91/02119 ORIGIN : FLIC TAPE NAME : 74342 CONTINUATION # : 1 PREVIOUS TAPE COMMENT : MARATHON OIL CO~PANY,~CARTHUR ~IVER,TBU M-27,50-7~20473 **** FILE HEADER :FILK NA~E ~ EDIT .001 SERVICE : FLIC VERSION : DATE : 91/0~/19 MAX REC SIZE ~ t024 FILE TYPE : LO LAST FILE COMPANY NAME{ MARATHON OIL COMPANY WELL: TBU M-27 FIELD: MCARTHUR RIVER BOROUGH: KENAI STATE: ALASKA AP1 NUMBER: 50-733-20473 LOCATION: 974' FNL & 531' FWL SECTIOn: 33 TOWNSHIP: 9N RANGE: DKRMANE~T DATU~ MSL ELEVATION: 0 LOG MFASURED FRO~ K.P. 160 ABOVE PERMANENT DATUM ,¢hlUmerger Alaska Computing Center · 1g-FEB-1991 i5:S8 ELEYATIONS KB: 160 DF~ DATE LOGGED: RUN NUMBER: TO DRILLER: TD LOGGER~ CASING CASING 23-JAM-1991 15380 15330 13 3/8" ~ DRILLER DEPTH OF 4184 9 5/8" ~ DRILLER DEPTH OF 13630 BIT SIZE t: 16 BIT SIZE 2: 12.25 TYPE FLUID IN HOLE: GENERIC # 2 DENSITY: 10.1 VISCOSITY: PH: 8.8 FLUID LOSS: 7 MUD RESISTI¥ITY~ . 2,71 FILTRATE RESISTIVITY: 2.4 MUD CAKE RESISTI¥ITY~ 2.9 B 48 TI~E CIRCULATION ENDED: 0500 1-23-91 M~XIMUM TEMP RECORDED: 176 KENAI TIM $~ITH MR. UNDERWOOD LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: TOOL NUMBERS: DIC 39 ELS 633 EGT 554 A~$ 783 5¸3 DIS 39 BLC 70 TCM 5 FIELD RE~ARKS: bOG PLAYED BACK AND CORRELATED TO SW$ TDT-P RAN 1-3~91 FOUR 8 INCH STANDOFFS RAN ON SONIC THREE 6,5 INCH STANDOFFS RAN ON DITE COMPUTING CENTER REMARKS: THE DATA ON THIS LIBRARY TAPE HAS NOT BEEN DEPTH ADJUSTED BECAUSE T~E DTE/BHC WAS RECORDED IN ONE LOGGING PASS, DATE JOB STARTED: 13-FEB-91 JOB REFERENCE NO~ 74342 LDP/~A: STE~EN DEES ;chluam~erger aska ComputinO Center 19-FEB-1991 15:58 MARATHON OIL COMPANY MCARTHUR RIVER TBU M-27 50-733-20473 MAIN PASS bOG DATA FROM FIELD FILE ,012 DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME DIT-E .DTE BHC .8HC PHA$OR DUAL INDUCTEON SFL BORE.HOLE COMPENSATED SONIC 5~ TO 13 O' 15312, 66~O, 1528 TO i3 ******************************************************************************* TABLE TYPE : CONS TUNI VALU DEFI ................. ,, CN FN WN APIN FL SECT TOWN RANG COUN STAT LONG WITN PDAT EPD ADD EEL TDD TDL BLI DFT D~PH FT FT FT FT FT FT FT FT FT G/C3 TBU 50-733-20473 974' FNL & 531~ FWL 33 9N KgNAI ~R. UNDERWOOD 584526 1~0' 153 1532~. 1363 10.1 8,800001 Company,..Name Field. Name Well Name~ APE Serial Number Field. Location Sectlon~ Township Range County State or Prov~nce Nation Latitude Longitude wltSess'..Name Service Order Number Permanent datum: · Elevation o~ Perm,.D&tum koq Measured From BOVE PERM~NEN~ DATUM .. Elevation ot Kelly ~UShtng Elevat on o~ Derrlc~loo~ Elevation of Ground Level Total Depth ~ Driller Total Depth Logger Bottom boq Interial To~ bog Isterva~ .. Drlllln9 FlUid Type. Drlllin~ Fluid Density Drlllin~ Fluid Ph lS Tape Veriflcat~on 51st~ng 19-FEB-1991 15558 PAGE'~ 4 chlumberger Alaska Computing Center TUNI VALU DEFX DFV CP DF5 F3 7,· RMS OH~M 2.71 MST DEGF 48 RMFS OH~M 2 ~ RMC$ OH~ 2 § TCS 0~60 1-23-91 STEM DEGF -999.25 Dr!Il ng Fluid ¥1SCO~it¥ Drili n~...-.Fluid ~OSS Resistivity of.~ud:'Samp~e~ ~ud~Sa~ple Temperature Resistivity of ~ud.~Filtrate Sampie,'Te~PeF&tu Resistivity of ~ud Cake:Sample Tempera~u're Time circulation Stopged. surface. Temperature:. BHT DEGF 176,. . Bottom Hole Temperature~ ' ......... TABLE TYPE : CURV ./ DEFI DEPT Dept~ C~annel Name SFLU SFh..Resistivlt (unaveraged) IL" Medium InductiOn Standaro Processed Re ~st~Vity) ILD Deep Induction Standard Processed Res~tlr!tV, SP Spontaneous Potential XDpH INDUCTION. DEEP PHASOR RESISTIVITY XMPH INDUCTION MEDIUM PHASOR RESISTI.VITY IFRE Induction Calibrated Frequency IDQF IDQF DEEP INDUCTION QUALITY FACTOR IMQF I~QF MED INDUCTION QUALITY FACTOR CIDP INDUCTION DEEP PHASOR CONDUCTIVITY CIMP INDUCTION MEDIU~ PHA$OR CONDUCTIVITY IIRD Deep Induction Real intermediat ~onducttv~ty IIXD Deep Induction Quad Intermediate Conductivity IIR~ Medium Induction Real intermediate conductivity IIXM Medium Induction Quad Intermediate Conductivity GR Gamma Ray TENS Tension MTE~ ~ud Temperature MRES ~UD ResistiVitY HTEN Head Tension DT DELTA-T TT1 TRANSIT TIME 1 TT2 TRANSIT TIME 2 TT3 TRANSIT TIME 3 TT4 TRANSIT TIME.4 SP Spontaneous Potential GR Gamma Rav TENS Tension MTE~ Mud Temyerature MRE$ MUD Res Stivit¥ HTEN Head Tension TaPe Verification Listing ~chlumberger AlasKa Computing Center i9-FEB-lg91 15:58 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB TYPE REPR~CODE VALUE I 66 0 ~ 66 0 4 66 5 66 6 7 65 9 65 11 66 8 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ~$ SET TYPE - CHAN *~ NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # ~OG TYPE CLASS ~DD NUNB SAMP ELE~ ,CODE (HEX) DEPT FT 584526 00 SFLU DTE OHM~ 584526 00 IL~ D?E OH~ 584526 00 ILD DTE OHM~ 584526 00 SP DTE ~V 584526 O0 IDPH DTE OHM~ 584526 00 IMPH DTE OHMM 584526 00 IFRE DTE HZ 584526 O0 IDOF DTE 584526 O0 IMO[ DTE 58.4526 '00 CIDP DTE MMHO 584526 00 CIMP DTE MMHO 584526 O0 IIRD DTE MMHO 584526 00 IIXD DTE MMHO 584526 00 IIR~ DTE ~HO 584526 00 IIX~ DTE M~HO 584526 00 GR DTE GAP! 584526- 00 TENS DTE LB 584526 00 MTE~ DTE DEGF 584526 00 MRES OTE O~MM 584526 00 HTEN DTE LB 584526 00 DT BHC US/F 584526 00 TT1 BHC US 584526 00 TT2 BHC US 584526 00 000 00 0 1 1 1 '4 ~8 000 00 0 I ! 1 4 68 000 00 0 I ! 1 4 68 000 00 0 ! ! 1 4 68 000 00 0 1 1 1 4 68 000 O0 0 1 1 1 4 6 8 000 00 0 ! 1 I 4 68 000 00 0 1 1 1 4 68 000 00 0 1 1 I 4 68 000 O0 0 1 I 1 4 68 000 00 0 1 I I 4 68 000 00 0 I 1 I 4 68 000 00 0 1 I 1 4 68 000 00 0 1 1 1 4 68 000 00 0 1 1 1 4 68 000 00 0 1 1 1 4 68 000 00 0 1 1 ! 4 68 000 O0 0 1 1 I 4 68 000 00 0 I I I 4 68 000 00 0 1 1 1 4 68 000 O0 0 1 1 I 4 68 000 00 0 1 I I 4 68 000 00 0 I 1 1 4 68 000 O0 0 1 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000~0000 0000 0000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 chlum erger AlasKa Com utlng Center 19-FEB-199/ 15:58 6 NAM~ SERV UNIT SERVICE APl AP1 API APl FILE NUMB NUNB SIZE REPR PROCESS .ID ORDER # 50G TYPE CLASS MOD NUMB SAMP ELEM .CODE (HEX) TT3 BHC US 584526 O0 000 O0 0 ! I I 4 68 0000000000 TT4 BHC US 584526 O0 000 O0 0 I i I 4 68 0000000000 SP BHC MV 584526 O0 000 O0 0 I I 1 4 68 0000000000 G~ BMC GAPI 584526 O0 000 O0 0 I 1 1 4 68 0000000000 TENS BHC LB 584526 O0 000 O0 0 I 1 1 4 68 0000000000 MTE~ BHC DEGF 584526 O0 000 O0 0 I I 1 4 68 0000000000 MRES BHC OHMM 584526 O0 000 O0 0 1 I i 4 68 0000000000 HTEN BHC LB 584526 O0 000 O0 0 1 I I 4 68 0000000000 ** DATA DEPT. SP.DTE IDQF.DTE IXRD.DTE G~.DTE HTE~,DTE TT .BHC TENS.BHC DEPT. SP'DTE IDOF.DTE IIRD,DTE GR.DTE HT~M.DTE TT3,BHC TENS,BMC DEPT. SP.DTE IDQF DTM IIRD:DTE GR.DTE MTEN.DTE TT3.BHC TEN$.BMC DEPT. SPDTE IDoF:DTE IIRD DTE ~R DTE HTEN DTE TT3 BHC TENS.BHC 15433 000 -IO 3 000 206 375 3 ,000 15400 000 -10 461 3 000 206 375 52 313 -122 125 540.000 7995.000 15300.000 11.688 0,000 251.000 58.563 719.000 540,000 9970.000 15200.000 9.563 0 000 109i438 75 938 856 500 715:000 9899.000 SFLU,DTE IDPH,DTE IMOF,DTE IIXD,DTE TENS;DTE DT,BMC TT4.BMC MTEM'BHC SFLUi, DTE IDPH;DTE IMQF.DTE IIXD,DTE TENS,DTE DT.BHC TT4'BHC MTEM.BHC SFLU,DTE IDPH~DTE IMOF.DTE IIXD,DTE TENS, DTE DT.BHC TT4 BHC MTEM:BHC SFbU,DTE IDPH.DTE IMOF,DTE IIXD,DTE TEN$.DTE DT'BHC TT4.BHC MTEM.BHC 26.406 iIRM,DTE 5195;000 MTEM,DTE 78,313 TT1,BHC ,000 SP,BHC 3,467 ISM,DTE 4.176 IMPH'DTE 2~"000 C'IDP,DTE ;406 IiR~'DTE 7995,000 MTEM'.DTE 78.3~3 TTI,BHC 0'000 SP,BHC .998 IL~,DTE CXDP.,DTE 9970,000 MTEM,OTE .78,438 TTI,BHC 380,000 174~200 MRE$;BHC 9 016 8 633 0 000 I 3 989~ 13 000 95,813 510,750 173,750 XLN,DTE IMPH,DTE ClDP.DTE IlRM,DTE MTEM,DTE TT1,BHC SP,BHC MRES,BHC 3'637 ISD D?E ~.,662 XFRE DIE '250 CXMP DTE HTEN BHC ooo ~472500 TT2,.BHC 297;250 CXMP~DT. ' 290,750 175,200 lI,Ol5 IIXM.;:D~E TT2,BHC GR,BHC HTEN,BHC 9 ! 98~ XLD-DTE 79 IFRE,DTE ,813 CXMP.DTE 250 XXXM'DTE 750 MRES,DTE 000 TT2,.BHC 563 GR'BHC 051 HTEN,BHC 856 ,iS Tape Verification Listing 19-FEB-1991 15:58 .chlumberger AlasKa Computing Center D~PT, SP DTE ~DQF DT~ XIRD DTE G~.,DTE HTEN,DTE TT3,BHC' TENS.BHC DEPT, sp'DTE IDOF'DTE' IIRD,DTE G~.DTE HTEN,DTE. TT3,BHC TENS,BMC DEPT, SP,DTE IDQF.DTE IXRD,DTE G~.DTE H~EN.DT~ ~.T3,BH¢ TENS'BMC DEPT, SP,DTE IDQF,DTE IIRD.DTE GR.DTE HTEN.DTE TT3,BHC TENS.BMC DEPT. SP,DTE IDOF.DT£ IIRD.DTE GR.DTE HTEN DTE TT]!BHC TENS BHC DEPT, SP.DTE IDOF.DTE IIRD.DTE G~.DTE HTEN.DTE TT3.BHC TEN$.BHC 15100,000 3 051 0 000 212 625 64.063 761 000 598 000 9540 000 15000 000 -3O 328 0 000 116 75O 44 844 769 500 5O8 5OO 9435 000 14900,,000 '55,500 0 000 230 375 52 781 771 558 000 9010 000 14800,000 0'000 169,625 73 938 8O2 5OO 542,000 8915.000 14700,000 '3,020 0,000 457,750 56,438 788,000 687,000 8935,000 14600,000 '42,500 0 000 7 125 835 50O 521,500 8780.000 SFLU.DTE IDPH DTE IMQF:.DTE IIXD,DTE TEN$.DTE DT'BHC TT4,BHC MTEM.BHC SFLU DTE IDPH DTE IMOF DTE IIXD DTE TEN$~DTE DT.BHC TT4,BHC MTEM'BHC SFLU.DTE IDPM~DTE IMQF,DTE IIXD'DTE TEN$'DTE DT.,BHC TT4."BHC MT£M'BHC SFLU,DTE IDPH,DTE IMOF'DTE IIXD,DTE TEN$.DTE DT,BHC TT4.BHC ~TE~.BHC SFLU,DTE IDPH*DTE IMQF'DTE IIXD,DTE TENS.DTE DT,BHC TT4~BHC ~TEM.BHC SFSU.DTE IDPH,DTE IMQF.DTE ~IIXD.DTE TENS.DTE DTBHC TT4:BHC MTEM.BHC 3,510 3.979 .173.975 14,555 8,063 0 000 .000 7 ,750 3~'125 1 4,425 3,705 8 = I~ oo 908 63 174 8 :ooo 641 8915,000 78,313 383;000 173,863 ,185 0,000 66.375 893);000 10 ~000 47~,000 17 .075 0 000 10 922 8780 000 76 688 38O 75O 172 962 ILM,DTE IMPH.DTE CIDP,DTE IIRM'DTE MTEM.DTE TTI.BHC SP,BHC ~RE$,BHC IL~,DTE IMPH,DTE CIDP;DTE IIRM,DTE TTi,~BHC SP-BHC MRES~BHC IL~,DTE I~PH.~DTE .CIDP,DTE IIRM,DTE MTE~,DTE ,BHC ~RE$,BHC IMPH,DTE CIDP.DTE IIRM DTE MTEM, DTE TTI~HC MRES BHC IbM,DTE IMPH,DTE CIDP,DTE IIRM'DTB MTEM,DTE TTI~BHC SP,BHC MRE~,BHC ILM,DTE IMPH,DTE CIDP.DTE XXRM~DTE ~TE~iDTE TT! BHC SP.BHC MRES.BHC 4.156 ILD'DTE 4.176 IFRE,DTE 251'250 CI~P.,DTE ' 25.375 IIX~'DTE ~73.975 MRE$'DTE 595'000 TT2.BHC '051 GR,BHC ~.067 HTEN.BHC 9.266 ILD DTE 9,742 ~FRE.DTE 124'000 CI~P DTE i02,063 IIXM DTE 174,42~ MRE~.DTE TT~ HC ~09.,250 , 30,.32~ G ~$ 1,008 HTEN~BHC 4,020 ILD*DTE 4'055 IFRE,DTE 269.750 CIMP.'DTE 233~000 IIXM,DTE 174,538 ~'RE$,DTE ~59~000 TT2.BHC 55,500 GR,BHC 1.004 HTEN,BHC 4 898 .IbD 79 200 CI~P MRE$ :goo 2 63 ~GR ! O13 HTEN BHC ,BHC 58ii542 IbD,DTE 588 IFRE,DTE 500 CXMP'DTE 592.000 X73,075 MRE$~DTE TT2,.BHC 029 HTEN'BHC IbD 1~8 000 CZNP 117 688 IIXM 172 962 MRES 518 000 TT2 -42 5OO OR I 018 HT£N DTE DTE ,DTE ,BHC ~BHC BHC PAGEi T 20;000 39'969 ,64~063, 7610000 20, -21, {m5,000 44,844 4~977 0,0 .0 , ,. :20,000 .IS Tape Verification Listing .cblumberger AlasKa Computing Center DEPT. 14500,000 SP.DTE -1!.609 IDQF.DTE 0,000 IIRD,DTE 96,375 GR.DTE 6~.,688 HTEN,DTE 81 ,50'0 TT3,BHC 558~000 TENS.BHC B600.000 DEPT. SP.DTE IDQF.DTE IIRD.DTE G~.DTE HTEN.DTE TT3,BHC TENS.BHC DEPT. SP DTE IDQF.DTE IIRD,DTE G~.DTE HTEN.DTE TT3,BHC TENS'BHC DEPT. SP,DTE IDOF,DTE IIRD,DTE GR,DTE HTEN.DTE TT3,BHC TENS.BEC DEPT. SP OTE IDQF DTE IIRD DTE GP DTE HTEN DTE TT3.BHC TEN$.BHC DEPT. SP.DTE IDQF.DTE IIRD.DTE G~"DTE HTEN.DTE TT3.BHC TENS.BHC 14400 000 -56 281 0 000 144 125 62 250 8t9 500 503 000 8550 000 14300 O0 0,000 127.750 45,969 0 250 8376'000 14200,000 -77,125 0,000 72,375 48,219 927,000 496,750 8155.000 1410O.0O0 -118.625 o: oo 47 44: 804 O0 495.000 8250.000 14000.000 '98.500 0,000 81 188 52 563 813 500 542 50O 8195.000 SFLU.DTE IDPH,DTE IMQF,DTE IIXD.DTE TENS.DTE DT,BHC TT4.BHC MTEM.BHC SFLU,DTE IDPH.DTE IMOF,DTE IIXD,DTE TEN$.DTE DT,BHC TT4.BHC MTEM.BHC SFLU. DTE IDPH DTE IMOF DTE IIXD DTE TENS DTE DT,BHC TT4,BMC MTEM.BHC SFLU,DTE IDPH,DTE IMQF,DTE IIXD'DTE TEN$,DTE DT,BHC TT4,BHC NTEM.BHC SFLU.DTE IDPH,DTE IMQF,DTE IIXD,,DTE TEN$,DTE DT,BHC TT4.BHC MTEN.BHC SFSU.OTE IDPH,DTE IMQF.DTE IIXD.DTE TENS,DTE DT,BHC TT4.BHC ~TEM.BHC 19-FEB-1991 15:58 6,762 9.211 0 000 860~ 600 000 79 250 398 000 172 850 10,125 6 0 00 430 8550 ~0 · 78 8 18,516 12,670 8370'00~ 7t'563 ~60,000 172'513 27,453 !2,570 o'oo0 8155,000 71~500 356,750 172,~75 46,000 19,813 o;ooo 1,~87 8250,000 69'813 359.000 171,613 18:344 11i039 0 000 .° 8195 O0 79 000 . :ooo 17 163 IL~,DTE IMPH,DTE CIDP~DTE IIRM,DTE ~TE~,DTE T ~:BHC ~RES.BHC IL~,PTE IMPH.~DTE CIDP,DTE IIRM'DTE MTEM~DTE TTI,BHC MP~BHC MRE$.BHC ILM,DTE I~PH,~TE CtDP.~TE MTEM,DTE MRES.BHC 2bM,DTE 2MPH,DTE CZDP,DTE 2~R~,DTE MTEM,DTE TTI,BHC SP,BHC MRES,BHC ,Z~N DTE IMPHD~E ZDP DTE ZXR~ D~E ?T1,BHC ~$P+BHC MRES.BHC 2LM,DTE IMPM.DTE C2DP,DTE IZRM.DTE MTE~,DTE TT1,SHC SP'BHC M~E$.BHC 8 7 5 1 16 ILD.DTE 52 IFRE,DTE 500 CINP.DTE 813 IIX~.DTE 850 NRES,DTE 000 TT2,BHC 609 GR.BHC 025 HTEN.BHC 36 IFRE,DTE 166,!25 CIMP,DTE 139'500 172,738 MRES,DTE 500,750 TT2,BHC '-5~,.281 GR.BHC .020' HT£N.BHC 8,64! IbD.. 142,375 CIMP: I09'375 IIXM: 172,513 ~RES' 503'000 TT2 1.023 HTEN DTE DTE~ I5,20~ ILD,DTE 15,53 IFRE'DTE 79,500 CIMP~DTE 62.406 IIXN,,DTE 17.2,~;~ NRE$,D~E 125 GR,.BHC 020 HTE.N..BHC 21,469 ILD. ;438 CI 44,219 IIX~ 171'613 ~RES 49 ,000 TT2 -118,625 OR I,O24 HTEN .BHC BHC ~BHC 12.422 ILD,DTE 12,727 IFRE,DTE 90.500 CZMP.DTE 76 250 XXXN,DTE IIA . 63 ~RES.DTE 00 TT2,BHC '98 500 GR,BHC 1.025 HTEN.BHC PAGE,' 8 65,6 812500 o ~46,:~25: 35'031 114;68 362,:000 .,II: I ~, ..., 4, 44 ;o o 563' 813500 IS Tape Verification Listing chlumberger Alaska Computing Center DEPT, 13~00,000 SP.DTE 88,813 IIRD~DTE 30,016 49,688 GR.DTE 772.000 HTEN.DTE TT3,BHC 479,500 TENS,BHC 8185'000 DEPT, IDOF DTE IIRD DTE HTEN DTE TT3 BHC TENS BHC DEPT, SP DTE IDOF DTE IIRD DTE GR DTE HTEN,DTE TT3.BHC TENS,BHC DEPT SP:DTE IDOF.DTE IIRD.DTE G~.DTE HTEN.DTE TT3,BMC TEN$.BHC DEPT, SP,DTE IDOF.DTE IIRD.DTE HTEN.DTE TT3.BHC TENS,BHC DEPT. SP.DTE IDQF.DTE IIRD.DTE GR,DTE HTEN.DT~ TT].BHC .TENS.BHC 13800 000 -93 938 0 000 40 281 42,094 728,500 488,250 7960.000 13700.000 -127,375 87,063 727~000 541,500 7935.000 I~600,'000 .156,500 0,000 74,938 725 00 338,250 7600,000 13500.000 -158 000 0 000 82 75O 36,344 736.000 408.250 7815,000 13400.000 '161,250 0,000 74.688 36.53i 728,500 407,000 7760.000 SFLU.DTE IDPH,DTE IMOF.DTE IIXD,DTE TENS*DTE DT*BHC TT4,BHC MTEM,BHC SFLU.DTE IDPH,DTE IMQF*DTE IIXD,DTE TENS DTE DT BHC TT4 BHC ~TEM BHC SFLU,DTE IDPH,DTE I~QF~DTE IIXD*DTE TENS.DTE DT.BHC TT4,BHC MTEM,BHC SFLU*DTE IDPH,DTE IMQF;DTE IIXD,DTE TEN$,DTE DT.BHC TT4,BHC MTEM.BMC SFLU,DTE IDPH,DTE IM~F,DTE IIXD,DTE TEN$.DTE DT'BHC TT4,BHC MTE~,BHC IDP DTE IM~F,DTE IIXD,DTE TENS.DTE DT,BNC TT4.BWC MTE~.BHC I9-FEB-lg91 15:58 4 47.3~5 31,3 0,000 0,719 8 000 344, 170,825 3O 24 ~28 88 0 000 0 951 7960 000 70 625 359 §00 170 375 o' oo 4 10 9 688 389 000 ~69 700 9696,000 000 -441,500 7600,000 46,625 294'750 168,913 9696.000 10'906 44~'000 ' ,000 .063 295,000 167,788 9696,000 12.4~1 0.0 0 -441.500 7760'~00 56, 75 294,000 167,113 ILM,DTE IMPH-DTE CIDP DTE IIRM DTE MTEM DTE TT1 BHC SP,BHC MRES,BHC IbM,.DTE I~PM,DTE CIDP,DTE IIRM*DTE MTEM~DTE TTI'BHC SP,BHC MRE$,B~C Ib~,DTE IMPH,DTE CIDP'OTE IIRM,DTE MTEM,DTE TTX.~BHC SP,BHC "RE$"BHC IL~.DTE 'IMPH.DTE CIDPDTE IIR~...DTE MTEN~DTE TTi~BHC 8P~.BHC MRESBHC IhM,'DTE IMPH,DT£ CIDP'D?B IIR~"DTE ~TEM'DTE TTI,,BHC SP.BHC MRE$'BHC ILM,DTE IMPH,DTE CIDP,DTE IIRM,DTE MTE~.*OTE TT1,BHC SP,BHC ~PES.BHC 31'688 XLD*DTE 32.094 IFRE.*DTE 31.859 CINPeDTE 30.000 IIXN,DTE 170,825 MRES~DTE 478.750 TT2,BHC -88'813 GR,BHC 1.o24 ~9'328 ZnD DTE 31'750 XFRE~ DTE 4~..3~3 C!~P DTE 3 IIX~ .~406 DTE 170,375 MRE$~ DTE 490~250 TT2 BHC '93~;958 GR BHC 1.038 HTEN BHC I~,008 'IbD.DTE 10,648 Ir'RE,OTB 97'063 CINP.DTE 86,000 IiX~'DTE 169~700 ~RE$.DTE .540.,509 TT2*BHC 127.375 GR*BHC ~,052 HTEN.BHC 1950~.000 IbD,DTE 1950'000 IFRE.OTE . 80;625 459,500 168,91~ MRE$..DTE 447~000 -156- 0 GR* 1950'000 1950'000 91.62S CXNP,DTE -533,000 408'250 TT2tBHC 000 GR.BHC 1950-000 I~D'DTE 1950!000 IFRE,DTE 80 185 CI~P,DTE .5R5o000 IIXMoDTE 167.~3 MRE$.DTE 408. 0 TT2.BHC -161.250 GR.BHC 1.085 HTEN.BHC PAGE{ 9 .30 0~0 20 :686 77~ 000 7 39,000 .385.,000 725~ 000 0,6~2 0,~00 -543,000 ~43{&800 ~36~000 ~0,000 *S~4,000 X4&t.,O00 294,000 chlumberoer Alas)<a ¢omputinq Center 19-FEB-1991 15{58 PAGE: DEPT. SP.DTE IDQF.DTE IIRD.DT~ GR.DTE HTEN.DTE TT3.BHC TENS.BHC 13300,000 '162,625 0'000 73..563 46.438 721'500 407 000 7460 000 DEPT. SP.DTE IDOF.DTE IIRD.DTE GR.DTE HTEN DTE TT3 BHC TENS BHC 1~289,000 t62,1~5 0,000 77;.375 26,875 737,000 405,500 7560,000 END OF DATA SFLU DTE IDPN:DTE IgOF.DTE IIXD.DTE TENS.DTE DT.BHC TT4.BHC MTE~,BHC SFLU.DTE IDPH.DTE IMOF,DTE IIXD.DTE TEN$.DTE DT'BHC TT4.BHC MTEM.BHC 9696 000 12 609 0 000 -441 500 7460 000 56 375 295 500 166 888 9696,000 1~.672 ,000 '44i,000 7560'000 56.500 292,7~0 1.66'7 5 ILM.DTE IMPM,DTE ClDP.DTE IIRN,DTE MTE~,OTE TTI,BHC SP,BHC MRES.BHC IMPH,DTE CIDP.DTE IIRM,DTE MTEM,DTE TTi,BHC !~P,BHC ~RES,SHC 1950 000 ISD'DTE 1950 ,000 IFRE.DTE 79 250 ClMP'DTE -447 ~50 IIX~.DT~ 166 88 MRE$,DTE 408 250 TT2'.BHC '162 625 GR'.BHC 1,082 HTEN.BHC 1950 O0 85,625 .DTE -648'500 IINP iXM,DTE 166'775 ~RES'DTE 405.000 TT2'BHC 4 HT£N,BHC ,000 124~'000 2~4~750 72~ '438 ..500 **** FILE TRAILER FILE NAME = EDIT .00! SERVICE = FblC VERSION I 001A06 DATE = 91/02/19 MAX AEC SIZE = 1024 FIL~ TYPE : LO **** TAPE TRAILER SERVICE NAME = EDIT DATE = 91/02/19 ORIGIN ~ FLIC TAPE NAME . I 74342 CONTINUATION # I1 PREVIOUS TAPE COMMENT :'~ARATHON OIL COMPAN¥,MCARTHUR RIVER,TBU M-27,50-73~-2047] **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 91/02/19 ORIGIN : FLIC REEL NAME = 74342 CONTINUATION # = PREVIOUS REEL = COMMENT = MARATHON OIL COMPANY,~CARTHUR RIVER.TBU M-27,50-733-20473