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202-034
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Acid Soak Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,155 feet N/A feet true vertical 10,255 feet N/A feet Effective Depth measured 11,392 feet See schematic feet true vertical 8,799 feet See schematic feet Perforation depth Measured depth 10,858 - 13,109 feet True Vertical depth 8,295 - 10,215 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / L-80 10,312 MD 7,802 TVD 335 (MD) Packers and SSSV (type, measured and true vertical depth)Pkrs - See schematic Baker TE5 SSSV 335 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer 7" 5" 10,706 MD 360 2,438 13,152 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 4 Representative Daily Average Production or Injection Data 7062 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 202-034 50-733-20251-02-00 Plugs ADL MGS C32-23RD2 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-086 80 Authorized Signature with date: Authorized Name: 136 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 37 Gas-Mcf 618 Pumped 32.7 bbl of Oilsafe AR followed with 50 bbl FIW. Final pressure 2750psi Oil-Bbl 21 Water-Bbl Intermediate 11,426 - 13,109 Junk 5. Permit to Drill Number: 2 Middle Ground Shoal / MGS Oil PoolN/A measured 3,199 10,706 Size 831 Production Casing Structural Liner 2,790 Length 360 2,438 Conductor Surface slotted 5,410psi 24" 13-3/8" 9-5/8" 3,199 5,750psi 907 777-8387 7,240psi 360 2,123 2,823 8,155 10,252 Collapse Mark McKinley mmckinley@hilcorp.com Tubing Pressure 1,540psi 3,090psi 3,090psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: slotted Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:17 pm, Jun 16, 2020 Daniel Marlowe I am approving this document 2020.06.16 06:12:33 -08'00' Daniel Marlowe DSR-6/16/2020 Perforate Acid Soak RBDMS HEW 6/16/2020 gls 6/17/20 ther StimulateOt _____________________________________________________________________________________ Updated By: JLL 06/15/20 SCHEMATIC Middle Ground Shoal Well: C32-23RD2 Last Completed: 4/30/2002 PTD: 202-034 API: 50-733-20251-02 PBTD: 13,106‘ TD: 13,155’ KB: 35’ MSL = 73’ 7” A - G 13 13-3/8” 9-5/8” 1 14 15 16 2-12 Fish: 40.50’ Perf Gun W/LIVE SHOTS @ 11,355’ 5” HK2 Tag scale in liner at 11,392’ MD 5/2/20 X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 24 Conductor Surf 360’ 13-3/8 61 K-55 BTC 12.515” Surf 2,438’ 9-5/8 40 N-80 BTC 8.835” Surf 3,199’ (TOW) 7 29 L-80 BTC 6.184” Surf 7,468’ 26 L-80 LTC 6.276” 7,468’ 10,706’ 5 18 L-80 Hyd 513 4.276” 10,362’ 13,152’ TUBING DETAIL 2-7/8 6.5 L-80 EUE 8rd 2.441” Surf 10,312’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status HK2 10,858’ 10,897’ 8,295’ 8,332’ 39’ 05/22/20 Open HK2 11,024’ 11,092’ 8,451’ 8,515’ 68’ 05/22/20 Open HK2 11,113’ 11,152’ 8,535’ 8,573’ 39’ 05/21/20 Open HK2 11,206’ 11,312’ 8,624’ 8,724’ 106’ 05/21/20 Open Slotted Liner Double Penetration: HC, HE, HI, HK, HN, HK, HI, HE & HC 11,426’ 12,394’ 8,831’ 9,699’ 968’ 04/20/2002 Open 12,572’ 12,660’ 9,824’ 9,883’ 88’ 04/20/2002 Open 12,792’ 13,109’ 9,973’ 10,215’ 317’ 04/20/2002 Open JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 33.35’ 33.35’ Cameron Hanger 1 335’ 335’ 2.310” 4.630” Baker TE5 SSSV 2 1,948’ 1,818’ 2.347” 4.750” GLM 1 – SFO-1 3 3,721’ 3,202’ 2.347” 4.750” GLM 2 – SFO-1 4 5,024’ 4,104’ 2.347” 4.750” GLM 3 – SFO-1 5 6,043’ 4,805’ 2.347” 4.750” GLM 4 – SFO-1 6 6,844’ 5,353’ 2.347” 4.750” GLM 5 – SFO-1 7 7,515’ 5,817’ 2.347” 4.750” GLM 6 – SFO-1 8 8,096’ 6,214’ 2.347” 4.750” GLM 7 – SFO-1 9 8,677’ 6,615’ 2.347” 4.750” GLM 8 – SFO-1 10 9,227’ 6,996’ 2.347” 4.750” GLM 9 – SFO-1 11 9,805’ 7,397’ 2.347” 4.750” GLM 10 – SFO-1 12 10,195’ 7,703’ 2.347” 4.750” GLM 11 – SFO-1 (Orifice) 13 10,237’ 7,738’ 2.313” 2.875” Otis X Nipple 14 10,276’ 7,771’ 2.500” 3.680” X-Over 2-7/8” 8R Box x 3-1/2” BTC Pin 3.000” 4.250” Locator w/10’ seals 4.000” 5.850” 7” Baker FB1 Packer (85-40) 4.675” 5.970” Baker B Guide 4.000” 5.035” 10’ Seal bore Extension 80-40 2.441” 5.870” X-Over 80-40 SBE Box to 2-7/8” 8R L80 15 10,300’ 7,792’ 2.205” 3.700” OTIS XN Nipple 2.313 w/ 2.205 No-Go 16 10,312’ 7,802’ 2.441” 3.650” WLREG Production Liner Detail A 10,362’ 7,846’ 4.408” 5.970” Baker ZXP Liner Packer #2 w/ tieback stem B 10,371’ 7,854’ 4.408” 5.990” Baker ZXP Liner Packer #1 w/ tieback extension C 10,392’ 7,872’ 4.400” 5.875” Baker HMC Hanger D 10,805’ 8,246’ 3.948” 5.600” HES 4.5” ES Cement Stg Valve E 10,809’ 8,249’ 4.000” 5.625” Baker Payzone ECP F 10,843’ 8,281’ 3.937” 5.040” HES 4.5” Landing Collar G 13,145’ 10,246’ 4.276” 5.000” Banana Peeled Bullnose 10,858’ 10,897’ 8,295’ 8,332’ 39’ 05/22/20 11,024’ 11,092’ 8,451’ 8,515’ 68’ 05/22/20 11,113’ 11,152’ 8,535’ 8,573’ 39’ 05/21/20 11,206’ 11,312’ 8,624’ 8,724’ 106’ 05/21/20 HK2 11,113’ 11,152’8,535’8,573’39’05/21/20 Open HK2 11,206’ 11,312’8,624’8,724’106’05/21/20 Open HK2 11,024’ 11,092’8,451’8,515’68’05/22/20 Open HK2 10,858’ 10,897’8,295’8,332’39’05/22/20 Open HK2 Rig Start Date End Date Pumping Unit 4/15/20 5/22/20 05/10/2020 - Sunday MIRU on C32-23RD2. Spot ELU on well. MU riser & WLV to WH. Build firing head & Perf Guns #1 & 2. Clean & secure pipe & drill decks. SDFN 05/02/20 - Saturday Rig up wireline and pressure test lubricator. Run in hole with 2” x 8’ drive down bailer with mule shoe flapper bottom. Tubing good. Tag scale in liner at 11,357’ WLM / 11,392’ MD. Bail & POOH. Bailer about ½ full scale. Reran bailer two more runs to 11,357’ WLM / 11,392’ MD. Bailers were ¼ to ½ full. Not making a lot of hole in liner. Tubing and liner above this depth are clear. POOH. Consult Foreman. Our tag / drift runs are below proposed perf depth of 11,312’ MD. Rig down wireline. 04/18/20 - Saturday Continue filling back side with 319Bbls of FIW 04/20/20 - Monday Finished pumping 50BBL FIW. Shut in well for 5 days for Oilsafe AR soak Finished filling back side with 319Bbls of FIW. Started to pump the 5 totes of Acid. Start pumping Oilsafe AR, 1st Tote. Initial tubing pressure 120psi. Tubing pressure increased to 175psi. Pressure increased to 400-450 psi. Pressure decreased to 300-350 psi. Peak pressure observed @ pump was 600psi. 2nd Tote pumped. Steady injection psi 450 average. 3rd Tote pumped. Steady injection psi 450 average. 4th Tote pumped. Steady injection psi 450 average. 5th Tote pumped. Steady injection psi 450 average. Finished pumping Oilsafe AR. Started the 50 Bbl FIW chase. Rate of 60 Bbls a day. Tubing pressure Start:1300psi, Max:2750, Final: 2750psi. 04/19/20 - Sunday Continue pumping the 50 BBL FIW. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20251-02-00 202-034 Well Name MGS C32-23RD2 04/15/20 - Wednesday Rigged up, pressure tested surface piping (3500psi Waterflood MAX). SI well and started filling back side with 319Bbls of FIW 04/16/20 - Thursday Continue filling back side with 319Bbls of FIW 04/17/20 - Friday Tag scale in liner at 11,357’ WLM / 11,392’ Finished pumping 50BBL FIW. Shut in well for 5 days for Oilsafe AR soak SI well and started filling back side with 319Bbl s of FIW Rig Start Date End Date Pumping Unit 4/15/20 5/22/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20251-02-00 202-034 Well Name MGS C32-23RD2 No operations to report 05/13/2020 - Wednesday PJSM. MIRU ELU. Rehead 5/16" ELU RS (2&1). MU GR-CCL/Firing Head tool suite. Surface test CCL & FH. PU Perf Gun#2: 1.75" X 29' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. Move to well. PT WLV & Lubricator 250/3500 - Good Test. Open swab & RIH w/ Perf Gun#2 to 5000'. 5000' Weight Check, PUW = 1500#. ELU power pack is surging. PUH, power pack stalls. Set brake. Inspect power pack & check hydraulic oil level. Hydraulic oil in tank is contaminated w/ diesel. Pump off hydraulic tank volume to 2 empty barrels to remove contaminated fluid. Re- load hydraulic tank w/ 55 gal. new, clean hydraulic oil. Break off return line, circulate system to barrel until hydraulic fluid w/ good viscosity flows to barrel. POOH @ full system power to 2600' when system power falls back. Still able to winch cable @ surface under reduced power. POOH & bump up in lubricator. Close swab, slack off on EL cable for crane to make pick off well, sheave falls to pipe deck floor. Break off well, NO BHA, all EL cable retrieved to rope socket tattle tale. FISH IN HOLE, 29' Perf Gun BHA w/ live shots. RD 5/16" ELU prepping to return same to beach. RD & secure well, turn over well to production. Pack up ELine kit securing all. Clean drill & pipe decks. Fly ELine crew to beach in morning. Job Suspended. 05/11/2020 - Monday PJSM & permit. MU Perf Gun#1 BHA: GR/CCL, firing head & Perf Gun#1 - 1.75" X 19' RTG, 6spf, 60* phase, 5.1 gm HMX Geodynamic Razor charge, GeoRazor carrier. Rope socket tied 4&2. PU Lub and hoist Perf Gun#1 BHA, move to well. PT 250/3500 - Good Test. Open Swab. T/IA/OA/OOA = 68/829/143/10. RIH w/ Perf Gun#1 BHA. PU @ 10200', heavy pickup w/ Tension = 3000#. Exit 2-7/8" tbg @ 10,312' KB. Set down @ top of 5" liner @ 10362' KB. PU into tbg, T = 2600#, RBIH w/ setdown @ same. PU & RBIH w/ more speed and fall past top of 5" Liner. TIH to 10,500, PUH w/ T= 2800#. POOH to re-tie rope socket lighter. CCL-to Top Shot = 8.8'. CCL to Bottom Shot = 27.8',OOH. LD lubricator & Perf Gun BHA#1. EL Operator re-ties rope socket @ 2&1. Move back to well. Open swab, T =50. RBIH w/ Perf Gun#1 to 11370' CCL. Log up to 10350' CCL for correlation, T = 3200# w/ swings to 3500#. Send logging pass to Town for analysis. Correct -10' & resend. 2nd log pass requested due to poor quality of GR. RBIH to 11370' CCL and pull 2nd pass to 10350', T= 3600# w/ swing to 3750#. Send to Town. Correct +7'. RE confirms corrected log. RBIH to 11341' CCL. T/IA = 68/829. Log up from 11341' CCL to 11284.2' CCL to place shots on depth (11284.2' + 8.8' = 11293' Top Shot). Fire Perf Gun#1 to perf Zone HK2 11293' - 11312'. Log up 200', T = 3600# off bottom & falling back as continue PUH. Pull into 2-7/8" tbg, T= 2800#, & continue to POOH. T/IA = 68/828. OOH w/ all shots fired. LD Perf Gun#1 & lubricator. Secure well & ELU. SDFN. Job in Progress. 05/12/2020 - Tuesday FISH IN HOLE, 29 ft live gun in well (fish) Fire Perf Gun#1 to perf Zone HK2 11293' - 11312'. Rig Start Date End Date Pumping Unit 4/15/20 5/22/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20251-02-00 202-034 Well Name MGS C32-23RD2 05/21/2020- Thursday PJSM & permit. RU ELU. Surface test CCL & FH. PU Perf Gun#3: 1.75" x 29' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. Move to well. CCL-to Top shot = 10' CCL-to-Bottom shot = 39'. T/IA = 68/809 psi. Open swab & RIH w/ Perf Gun#3 to 11300' CCL. Log up to 10360' CCL for correlation to Perf Gun#2 correlation log. Correct -6'. RBIH to 11250' CCL. Log up to 11225' CCL to place shots on depth (11225' + 10' = 11235' Top Shot). Fire Perf Gun#3 to perf Zone HK2 11235' - 11264'. Log up 200' & POOH. OOH w/ all shots fired. Surface test CCL & FH. PU Perf Gun#4: 1.75" x 29' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to Top shot = 10' CCL-to-Bottom shot = 39'. Open swab & RIH w/ Perf Gun#4 to 11231' CCL. Log up to 11101' CCL. Correct -4'. RBIH to 11230' CCL. Log up to 11196' CCL to place shots on depth (11196' + 10' = 11206' Top Shot). Fire Perf Gun#3 to perf Zone HK2 11206' - 11235'. Log up 200' & POOH. OOH w/ all shots fired. Surface test CCL & FH. PU Perf Gun#5: 1.75" x 21' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to Top shot = 10' CCL-to-Bottom shot = 31' T/IA = 74/824 psi. Open swab & RIH w/ Perf Gun#5 to 11200' CCL,11200' CCL log up to 10500' CCL for correlation. Send log for correction verification. Correct log -3' & re-send. Correction confirmed. RBIH to 11176' CCL. Log up 11121' CCL to place shots on depth (11121' + 10' = 11131' Top Shot). Fire Perf Gun#5 to perf Zone HK2 11131' - 11152'. Log up 200' & POOH. OOH w/ all shots fired. Surface test CCL & FH. PU Perf Gun#6: 1.75" x 18' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to-Top Shot = 10' CCL- to- Bottom Shot = 28'. Open swab & RIH w/ Perf Gun#6 to 11114' CCL. Log up to 10800' CCL, correct -4.2'. RBIH to 11140' CCL. Log up to 11103' CCL to place shots on depth (11103' + 10' = 11113' Top Shot). Fire Perf Gun#6 to perf Zone HK2 11113' - 11131'. Log up 200' & POOH. OOH w/ all shots fired. Secure well & ELU. Turn over well to Prod. Op. & flow to test separator. SDFN. Job in Progress. 05/20/2020 - Wednesday Arrive Platform. PJSM & permit. RU ELU. MU RS(2&2), GR/CCL & FH. Surface test CCL & FH. PU Perf Gun#2: 1.75" X 29' RTG carrier, 6spf, 60* phase, 5.1 gm HMX Razor Charges. CCL-to-Top Shot = 10' CCL-to- Bottom Shot = 39'. Move to well. PT WLV & Lubricator = 250/3500 - Good Test. Open swab & RIH w/ Perf Gun#2 to 11311' CCL. Log up to 10272' CCL. Correct log -9.5' and send for log for correlation verification. Correct -3' & re-send log. Correlation correction confirmed. RBIH to 10311' CCL. Log up to 11254.0' CCL to place shots on depth (11254.0 + 10' = 11264' Top Shot). Fire Perf Gun#2 to perf HK2 11264' - 11293'. Log up 200' & POOH. OOH w/ all shots fired. Secure well & ELU. Turnover well to Prod Op. and flow to test separator. SDFN. Job in Progress. Fire Perf Gun#3 to perf Zone HK2 11206' - 11235'. Fire Perf Gun#6 to perf Zone HK2 11113' - 11131'. Fire Perf Gun#2 to perf HK2 11264' - 11293'. Fire Perf Gun#5 to perf Zone HK2 11131' - 11152'. Fire Perf Gun#3 to perf Zone HK2 11235' - 11264'. Lo Rig Start Date End Date Pumping Unit 4/15/20 5/22/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20251-02-00 202-034 Well Name MGS C32-23RD2 05/22/2020 - Friday PJSM & permit. Fire up ELU. Surface test CCL & FH. PU Perf Gun#7: 1.75" x 25' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to-Top shot = 10' CCL-to-Bottom Shot = 35' T = 71 psi. Open swab & RIH w/ Perf Gun#7 to 11147' CCL. Log up to 10780' CCL to correlate, correct +2'. RBIH to 11144' CCL. Log up to 11057' CCL to place shots on depth (11057' + 10' = 11067' Top Shot). Fire Perf Gun#7 to perf Zone HK2 11067' - 11092'. Log up 200' & POOH. OOH w/ all shots fired. Surface test CCL & FH. PU Perf Gun#8: 1.75" x 25' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to-Top shot = 10' CCL-to-Bottom Shot = 35' T = 77 psi. Open swab & RIH w/ Perf Gun#8. Perf Gun BHA tool weight is very light & floating in hole followed by abrupt falls in hole. Request Prod Op. pinch back production @ flowline choke, T = 84 psi. EL BHA falling smoothly. RIH w/ Perf Gun#8 to 11148' CCL. Log up to 10850' CCL to correlate, correct -2.5'. RBIH to 11130' CCL. Log up to 11032' CCL to place shots on depth (11032' + 10' = 11042' Top Shot). Fire Perf Gun#8 to perf Zone HK2 11042' - 11067'. Log up 200' & POOH. OOH w/ all shots fired. T/IA =68/820 psi. Surface test CCL & FH. PU Perf Gun#9: 1.75" x 18' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to-Top shot = 10' CCL-to-Bottom Shot = 28'. RIH w/ Perf Gun#9 to 11172' CCL. Log up to 10868' CCL to correlate, correct -3.8'. RBIH to 11144' CCL. Log up to 11014' CCL to place shots on depth (11014' + 10' = 11024' Top Shot). Fire Perf Gun#9 to perf Zone HK2 11024' - 11042'. Log up 200' & POOH. OOH all shots fired. Surface test CCL & FH. PU Perf Gun#10: 1.75" x 21' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to-Top shot = 10' CCL-to- Bottom Shot = 31'. RIH w/ Perf Gun#10 to 10991' CCL. Log up to 10750' CCL to correlate, correct -1.75'. RBIH to 10965' CCL. Log up to 10866' CCL to place shots on depth (10866' + 10' = 10876' TS). Fire Perf Gun#10 to perf Zone HK2 10876' - 10897'. Log up 200' & POOH. OOH all shots fired. Surface test CCL & FH. PU Perf Gun#11: 1.75" x 18' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to-Top shot = 10' CCL-to-Bottom Shot = 28'. RIH w/ Perf Gun#11 to 11001' CCL. Log up to 10694' CCL to correlate, correct -5.5'. RBIH to 11001' CCL. Log up to 10848' CCL to place shots on depth (10848' + 10' = 10858' TS). Fire Perf Gun#11 to perf Zone HK2 10858' - 10876'. Log up 200' & POOH. OOH all shots fired. RDMO ELU prepping for backload to boat. Secure well and turn over to Plat C Ops. & flow to test separator. Clean pipe and drill deck. Job Complete. Fire Perf Gun#7 to perf Zone HK2 11067' - 11092'. Fire Perf Gun#8 to perf Zone HK2 11042' - 11067'. Fire Perf Gun#11 to perf Zone HK2 10858' - 10876'. Fire Perf Gun#9 to perf Zone HK2 11024' - 11042'. Fire Perf Gun#10 to perf Zone HK2 10876' - 10897'. Lo THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Daniel Marlowe Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o gcc. a l a ska.gov Re: Middle Ground Shoal Field, Middle Ground Shoal Oil Pool, MGS C32-23RD2 Permit to Drill Number: 202-034 Sundry Number: 320-086 Dear Mr. Marlowe: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, J m . Price Chair DATED this el. day of March, 2020. 1BDM 4� j MAR 0 4 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS RECEIVED FEB 2 4 2020 OTS -31Z-12-o- 1. /;=/20 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate LJ Repair Well J • %vk Waaerrs,enumuwo u , a z -rte "asp- ?t7 �N�A Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 202-034 ' 6. API Number: 3. Address: 3800 Centerpoint Drive, Suite 1400 50-733-20251-02-00 i Anchorage, AK 99503 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 44A Will planned perforations require a spacing exception? Yes El No Q MGS C32-23RD2 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): I Middle Ground Shoal / MGS Oil Pool ADL0018756 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 13,155 10,255 13,106 10,212 3,053 psi N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 360' 24" 360' 360' Surface 2,438' 13-3/8" 2,438' 2,123' 3,090 psi 1,540 psi Intermediate 3,199' 9-5/8" 3,199' 2,823' 5,750 psi 3,090 psi Production 10,706' 17" 10,706' 8,155' 1 7,240 psi 5,410 psi Liner 2,790' 15" 13,152' 10,252' slotted slotted Perforation Depth MD (ff): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11,426 - 13,109 8,662 - 10,215 2-7/8" 6.5# / L-80 10,312 Packers and SSSV Type: Packers and SSSV MD (ff) and ND (ft): Packers (see schematic) & Baker TE5 SSSV See schematic & 335' (MD) 335' (ND) 12. Attachments: Proposal Summary ❑✓ Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/9/2020 OIL ❑✓ - WINJ ❑ WDSPL ElSuspended El GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Daniel E. Marlowe Contact Name: Joe Kaiser Authorized Title: Operations ManagerContact Email: Lkaiser(Whilcom&orn 4 5t Contact Phone: 907 777-8393 Authorized Signa Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Q Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1BDMSL�✓ MAR 0 4 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ / Spacing Exception Required? Yes El No Subsequent Form Required: l i) —YdLl APPROVED BY a, Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 03 Revise 4/ 017 App oved applicationc is valid rt�approval. Attachments in Duplicate U Hik.p AI.Aa, LLC Well Work Prognosis Well: MGS C-32-23 RD2 Well Name: MGS C-32-23 RD2 API Number: 50-733-20251-02 Current Status: Producer (Gas Lift) Leg: Leg #1 Estimated Start Date: 3/9/2020 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 202-034 First Call Engineer: Joe Kaiser Office: 907-777-8393 Cell: 907-952-8897 Second Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Current Bottom Hole Pressure: 3,926 psi @ 8,724' TVD 0.45 psi/ft (8.67 ppg) injector gradient to surface Maximum Expected BHP: 3,926 psi @ 8,724' TVD 0.45 psi/ft (8.67 ppg) injector gradient to surface Max. Allowable Surface Pressure: 3,053 psi 0.1 psi/ft (gradient per 20 AAC 25.280(b)( 4)) Brief Well Summary MGS C 32-23 RD2 was originally completed with a slotted liner across the west flank Hemlock. This work will perforate hemlock sands above the slotted liner not previously open to production. Procedure: 1. MIRU E -line, PT lubricator to 3,500 psi Hi 250 Low. 2. RU a -line guns and perforate 3. RD E -line. 4. Turn well over to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic n Ililco" Alaska, LLC KB: 35' MSL =73' I I I sl PBTD: 13,106' TD: 13,155' Middle Ground Shoal Well: C32-23RD2 SCHEMATIC Last PTD: 02 0134 d: 4/30/2002 API: 50-733-20251-02 CASING DETAIL Size Wt Grade Conn ID Top Btm 24 33.35' Conductor (MD) Surf 360' 13-3/8 9-5/8 61 40 29 K-55 BTC N-80 BTC L-80 BTC 12.515" 8.835" 6.184" Surf Surf Surf 2,438' 3,199' (TOW) 7,468' 7 26 L-80 LTC 6.276" 7,468' 10,706' 5 18 1-90 Hyd 513 4.276" 10,362' 13,152' TUBING DETAIL 2-7/8 6.5 L-80 EUE 8rd 1 2.441" Surf 10,312' IFWFLRY DETAIL No Depth (MD) Depth (TVD) ID OD Item FT 33.35' 33.35' Zone (MD) Hanger 1 335' 335' 2.310" 4.630" SSSV jGLM3—SFO-1 fi 2 1,948' 1,818' 2.347" 4.750" FO -1 3 3,721' 3,202' 2.347" 4.750" FO -1 4 5,024' 4,104' 2.347" 4.750" 5 6,043' 4,805' 2.347" 4.750" GLM 4—SFO-1 6 6,844' 5,353' 2.347" 4.750" GUMS—SFO-1 7 7,515' 5,817' 2.347" 4.750" GLM6—SFO-1 8 8,096' 6,214' 2.347" 4.750" GLM 7—SFO-1 9 8,677' 6,615' 2.347" 4.750" GLM 8—SFO-1 10 9,227' 6,996' 2.347" 4.750" GLM 9-5FO-1 11 9,805' 7,397' 2.347" 4.750" GLM 30—SFO-1 12 10,195' 7,703' 2.347" 4.750" GLM 11 —SFO-1(Orifice) 13 10,237' 7,738' 2.313" 2.875" Otis X Nipple 14 10,276' 7,771' 2.500" 3.000" 4.000" 4,675" 4.000" 2.441" 3.680" 4.250" 5.850" 5.970" 5.035" 5.870" X -Over 2-7/8" 811 Box x 3-1/2" BTC Pin Locator w/10' seals 7" Baker FBS Packer(85-40) Baker B Guide 10' Seal bore Extension 80-40 X -Over 80-40 SBE sox to 2-7/8" 8R I RO 15 10,304 7,792' 2.205" 3.700" OTIS XN Nipple 2.313 w/ 2.205 No -Go 16 10,312' 7,802' 2.441" 3.650" WLREG Production Liner Detail A 10,362' 7,846' 4.408" 5.970" Baker ZXP Liner Packer A2 w/ tieback stem B 10,371' 7,854' 4.408" 1 5.990" 1 Baker ZXP Liner Packer kl w/tieback extension C 10,392' 7,872' 4.400" 5.875" 11 Baker HMC Hanger D 10,805' 8,246' 3.948" 5.600" HE54.5"ES Cement Stg Valve E 10,809'5,249' 4.000" 5.625" Baker Payzone ECP F 10,843' 8,251' 3.937" 5.040" 1 HES 4.5" Landing Collar G 13,145' 1 10,246 I 4.276" I 5.000" I banana Peeled Bullnose PERFORATION DETAIL Top Btm Top Btm FT Date Status Zone (MD) (MD) (TVD) (TVD) Slotted Liner 11,426' 12,394' 8,662' 9,699' 968' 04/20/2002 Open Double Penetration: HC, 12,572' 12,660' 9,824' 9,883' 88' 04/20/2002 Open HE, HI, HK, HN, HK, HI, HE & HC 12,792' 13,109' 9,973' 10,215' 317' 04/20/2002 Open Updated By: AL 1/26/17 J KB: 35' MSL=73' I I I I PBTD: 13,106' TD: 13,155 PROPOSED Middle Ground Shoal Well: C32-23RD2 Last Completed: 4/30/2002 PTD: 202-034 API: 50-733-20251-02 CASING DETAIL Size Wt Grade Conn ID Top Btm 24 33.35' Conductor Cameron Hanger Surf 360' 13-3/8 61 K-55 BTC 12.515" Surf 2,438' 9-5/8 40 N-80 BTC 8.835" Surf 3,199' (TOW) 2.347" 4.750" GLM 2—SFO-1 29 L-80 BTC 6.184" Surf 7,468' 7 26 L-80 LTC 6.276" 7,468' 10,706' 5 18 1 -80 Hyd 513 4.276" 10,362' 13,152' TUBING DETAIL 2-7/8 6.5 L-80 EUE Srd 2.441" Surf 10,312' IFWFLRY DETAIL Updated By: JLL 02/19/20 No Depth (MD) Depth (ND) ID OD Item 33.35' 33.35' Cameron Hanger 1 335' 335' 2.310" 4.630" Baker TE5 SSSV 2 1,948' 1,818' 2.347" 4.750" GLM 1—SFO-1 3 3,721' 3,202' 2.347" 4.750" GLM 2—SFO-1 4 5,024' 4,104' 2.347" 4.750" GLM 3—SFO-1 5 6,043' 41805' 2.347" 4.750" GLM4—SFO-1 6 6,844' 5,353' 2.347" 4.750" —SFO-1 7 7,515' 5,817' 2.347" 4.750" —SFO -1 8 8,096' 6,214' 2.347" 4.750" —SFO -1 9 8,677' 6,615' 2.347" 4.750" —SECA tGLM 10 9,227' 6,996' 2.347" 4.750" —SFO -1 11 9,805' 7,397' 2.347" 4.750GUVI —SFO - 1 12 10,195' 7,703' 2.347" 4.750" 1 GLM 11 —SFO-1(orifice) 13 14 10,237' 101276' 7,738' 71771' 2.313" 2.875" OtisX Nipple 2.500' 3.680 X -Overt -7/8" 8R Boxx 3-1/2" BTC Pin 3.000" 4.250" Locator w/30' seals 4.000" 5.850" 7" Baker FBI Packer 185-40) 4.675" 5.970" Baker a Guide 4.000" 5.035" 10' Seal bore Extension 80-40 2.441" 5.870' X -Over 80-40 SBE Box to 2-7/8" 8R L80 15 10,300 7,792' 2.205" 3.700" OTIS XN Nipple 2.313 w/ 2.205 No -Go 16 10,312' 7,802' 2.441" 3.650" WLREG Production Liner Detail A B 10,362' 10,371' 7,846' 7,854' 4.408" 5.970" Baker ZXP Liner Packer#2w/tieback stem 4.408" 5.990" Baker ZXP Liner Packer el wJ tieback extension C 10,392' 7,872' 4.400" 5.875" Baker HMC Hanger D 10,805' 8,246' 3.948" 5.600" HES 4.5' ES Cement Stg Valve E 10,809' 8,249' 4.000" 5.625" Baker Payzone ECP F 10,843' 8,281' 3.937" 5.040" HE54.5" Landing Collar G 13,145' 10,246' 4.276" 5.000" Banana Peeled Bullnose PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (ND) Btm (TVD) FT Date Status HK2 ±10,858' ±10,897' ±8,295' ±8,332' ±39' Future Proposed HK2 ±11,024' ±11,092' ±8,451' ±8,515' ±68' Future Proposed HK2 ±11,113' ±11,152' ±8,535' ±8,573' ±39' Future Proposed HK2 ±11,206' ±11,312' ±8,624' ±8,724' ±106' Future Proposed Slotted Liner 11,426' 12,394' 8,831' 9,699' 968' 04/20/2002 Open Double Penetration: HC,12,572' 12,660 9,824' 9,883' 88' 04/20/2002 Open HE, HI, HK, HN, HK, HI, HE & HC 12,792' 1 13,109' 1 9,973' 1 10,215' 1 317' 04/20/2002 Open Updated By: JLL 02/19/20 • • From: Patricia Bettis To: Well History File Date: February 9, 2017 Re: Well Name Change (PTD 202-034) At the request of Hilcorp, the well name for MGS C32-23LW was changed to MGS C32-23RD2 effective February 9, 2017. SCANNED JUN 0 2 2017. 0 • I_ IIIIIIIIIIIII • a) ...,i co N L. ,ice. `� 4.1:10) U N N W N CO N M N V M N V w V r N EIN 4 El y a r ,. • • a) E ca Z N cu p m M 3 N a) N Z M U X ci' X O \ C = X co = X v `O X aJ _ /3 N > E c E aJCl)o 46 U Z+ r (I)J Q I 73Y Y a) 0 dA U U R C �.., to N Ccu E73 J N a) N C !o 4--I N C to ++ N 06 oZ$ a a +.+ ++ ++ C C C Cl) a) a) f6 0. 0. O 0. 0 U v a a) > > > a) a) a) 0 0 0 N in •:r 0 O O O d i M Vi1 N N N 0 1-i .--1 N O OO 9 O 0 O .21 O 0 a `n in "' < 0 0 0 T N N N Mcen Q M en en H o O 0 Ln If) U1 CU L Cl) O 3 .12 aJ CD RS C - a O 'I en M 1 � ,-1N N i i N N ni o U U U • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, February 09, 2017 10:31 AM To: Larry Greenstein (Igreenstein@hilcorp.com) Subject: MGS C32-23LW (PTD 202-034) Larry, Per Hilcorp's request dated (1/26/2017), the AOGCC is changing the name of MGS C32-23LW to MGS C32-23RD2. Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission Sa�NEQ JUN 2�)1!; 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@ alaska.gov. 1 • Bettis, Patricia K (DOA) PT1) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Thursday,January 26, 2017 9:18 AM To: Bettis, Patricia K(DOA) Subject: FW: Middle Ground Shoal - Last Three Well Name Changes Attachments: 20170113 MGS Well Name Changes.xlsx; MGS A34-11 name change.pdf; MGS A41A-11 name change.pdf; MGS C32-23 name change.pdf; Swanson River Well Naming Conventions diagram.pdf Hi Patricia Did the explanation below of the problem with showing all the old holes on a single schematic make sense?? Would you like to discuss the options for changing the well names to something more appropriate to the API number than using the lateral designations?? These last three wells are the most confusing of the name changes because the first sidetrack changed the well number completely due to the new bottomhole location (using the federal naming convention method—attached above). That naming convention has caused problems for SRF wells too, but it is what it is and we find a way to make it work even though there are a good number of exceptions to the basic naming rules. It's why I summarized the abandoned completions on the schematic with dates and APIs rather than draw them in. Call me anytime to discuss and thank you for working through all these name changes. Larry 777-8322 From: Larry Greenstein Sent: Friday,January 20, 2017 2:02 PM To: 'Bettis, Patricia K (DOA)'<patricia.bettis@alaska.gov> Subject: RE: Middle Ground Shoal: Well Name Changes Understand, Patricia I was trying to get these name changes done with historical information so we can get on with making the new well signs for the platforms. For a 'clear and understandable public record' we unclutter most all of our schematics to show only the current producing or injecting wellbore, not all the lost holes, P&A'd completions and previous well names. They can just get too busy for a single sheet of paper. We continually try not to confuse people, that use the schematics, with obsolete information crammed on the page. As you allude, the current wellbore sketch is what we build for public use. With proposed schematics (like the KRU 1 B- 15A schematic you included), we do show the current and proposed future wellbores. Once completed (ie the original wellbore has been abandoned) and reported, we show only the current wellbore on future schematics (as with KRU 1 B- 15A pgs 6 &29 in your electronic well files). Imagine carrying this on when there are 4 or 5 sidetracks in the historical record. There's no way to show all that on one page. This is different from a multi-lateral well, where you have a number of currently active completions (.60, .61, .62 etc). These would be shown on the schematic branching off of the mother wellbore as they are open for production/injection. Are you sure you want all this extra abandoned information on the current wellbore schematic?? This isn't meant to be an as-built, it's a schematic to know what's looking at you when you run into the well with wireline tools. That's why I took our 1 current schematics and added the hi orical references to previous abandoned versions of the well to the existing wellbore on the schematics. Larry From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday,January 20, 2017 11:07 AM To: Larry Greenstein<Igreenstein@hilcorp.com> Subject: Middle Ground Shoal: Well Name Changes Larry, Please see highlighted paragraph. For a clear and understandable public record, Hilcorp needs to provide a current wellbore sketch for C34-11LS2, A41A11LN, and C32-23LW that shows all sidetracks drilled from the original well. The original well and all sidetracks need to be clearly labelled. I have attached a simple example from the Kuparuk River Unit of such a sketch. This wellbore sketch shows the original wellbore and the initial proposed sidetrack. Other sidetracks or lateral could be added in the future to this sketch to show the progression of the wells' history. Thanks, Patricia From: Bettis, Patricia K(DOA) Sent:Thursday,January 12, 2017 11:40 AM To: Larry Greenstein (Igreenstein@hilcorp.com)<Igreenstein@hilcorp.com> Subject: Middle Ground Shoal: Well Name Changes Larry, I'm in agreement with all the requested well name changes, except: C34-11LS2,A41A11LN and C32-23LW. The first sidetrack from each of these wells had a name change from the original well drilled. For example, C24-14 was drilled. It was later sidetracked and that sidetrack was renamed C32-23. The second sidetrack was named C32-23LW. This would make the revised name C32-23RD2, which agrees with the API No. 50-733-20251-02-00. For C34-11LS2, A41A-11LN,and C32-23LW, please provide a current wellbore sketch of each well that shows all sidetracks drilled from the original well. Please label the original well and all sidetracks.. Thank you, Patricia 2 • S ) -�.o - 6) 3 (.=' pr2 BDP 3-1-2014 HCurrent Cotlip(etion . ..., KB:35' MGS C32-23LW ■ ■ Water Depth: 73'MSL Cook Inlet,Alaska Tbg:2 7/8",6.511,L80 EUE 8rd @ 10,312' Log 1,Conductor 2 J Set on 4-30-02 API No.: 60.733.20261.02 • `'•• Spud Original Well C24-14:6-22-73 Item MD TVD Psc Pso Port Sidetrack LW:2-26-02 GLM 1 1,948 1,818 910 950 10 J GLM 2 3,721 3,201 900 931 10 Surf Csg:13 3/8",6111 K55 BTC. GLM 3 5,024 4,103 890 929 12 Set @ 2,438'. Cmt'd w/2,550 sx. • GLM 4 6,043 4,803 880 913 12 • J "• GLM 5 6,844 5,352 870 898 12 ELM 6 7,515 5,816 860 883 12 Intermediate:9 5/8"N80 BTC. iiiiii GLM 7 8,096 6,214 850 888 16 Window @ 3,199'. ELM 8 8,677 6,614 840 871 16 (Original was set @ 8,883'for the J ELM 9 9,227 6,994 830 854 16 C24-14.Cmt w11,140 sk.) ELM 10 9,805 7,396 820 836 16 40#from Surf-3,632'. ELM 11 10,195 7,702 ORIFICE 16 43.5#from 3,632-8,883'. J J Baker TE5 SSSV @ 335' J X Nipple 2 7/8"(2.313"ID)8R 9Cr @ 10,237' 2nd Intermediate:7"L80 Set @ 10,706'. 11t 2 7/8"6.5#8R 29#BTC:Surf-7,468' 6'Pup it.2 7/8"6.5#8R L80 @ 10,269' 26#LTC:7,468-10,706' X-over 2 7/8"811 Box x 3 1/2"BTC Pin Cmt w/674 sx.TOC by CBL @ 5,540'. J Locator w/12'Seals @ 10,276' 7"Baker FB1 Perm Packer(85-40)@ 10,276' J Baker B Guide @ 10,178' 10'Sealbore Extension 80-40 @ 10,279' X-over 80-40 SBE Box to 2 7/8"8R L80 ■ 10'Pup it.2 7/8"6.5#8R L80 XN Nipple 2 7/8"(2.205"ID)8R 9Cr @ 10,300' II10'Pup Jt.2 7/8"6.511 8R L80 WL REG @ 10,312' Slotted Prod Liner:5"1811180 Hydric 513 -if- 1 5 66,-ve-e Set @ 10,362-13,152'. Cmt w/37 sk. ..111... Z t/ Baker ZXP Liner Packer#2 @ 10,362'. we i6 241 "'! .� Baker ZXP Liner Packer 111 @ 10,377'. (� /� Ia'r� 5 7/8"HMC Hangar @ 10,391'. ` �� G�'7 j rt C / r ryJ X-Over 5"H513 Bx x 4.5"NSCT Pn @10800' • (� / R�j 10'Pup Jt.41/2"12.611 NSCT " ' �,)�yrt,� 6 I_'l, 1 17L� ��a HES 4.5"ES Cmt Stg Valve @ 10,811' Y_.�{-� (' X-Over 4.5"NSCT Box x 4.5"Hydril 521 Pin /IAA v� �`^ Baker 5 5/8"ECP(4.0"ID)@ 10,815' Liner Across DBL Penetration:HC,HE,HI, X•Over 4.5"Hydril 521 Pin x 4.5"NSCT Pin HK,HN,HK,HI,HE&HC. L 10'Pup 1t.41/2"12.6#NSCT I L t 547 HES 4.5"(3.9"ID)Landing Collar @10,849' �� X-Over 4,5"NSCT Box x 5"Hydril 513 Pin Top of 1st set slotted section @ 11,384' S"Blank Sections: 5"1811 L80 Hydril 513 Guide Shoe @ 13,152' 10,362 11,384' 12,391-12,569' 12,656-12,789' 13,106-13,152' PBTD:13,106'MD(10,211'TVD) 4 IL TD:13,155'MD(10,255'TVD) (_eMe. 44447-- _ t • • Well History Well: C32-23LW(Original Well: C24-14&C24-14RD) Field: Middle Ground Shoal West Flank Producer 4-21-11 SUMMARY: The C32-231.W was sidetracked in Feb 2002 from the East Flank, Section 23, into the West Flank, Section 14, double penetrating the HC to HN back to the HC reservoir. The original well, C24-14, was drilled in May 1973 and IP'd in Aug 1973 for 1,905 BOPD & 145 BWPD. It was decided in 1975 to sidetrack the C24-14 @ 4,000' and drill to Section 23. The well file contains all reports as the C24-14RD but in 1976, the well name was changed to C32-23 to reflect its new location. The drilling of C32-23LW required a shallow kick-off point to reach target, therefore, the 7" Longstring was cut& pulled @ 3,350'. (The plan was to kickoff @ 4,000'in the 9-5/8"casing but was unable to pull the 7" pipe deeper than 3,350'.) The purpose of the new 7" Intermediate casing was to isolate the high water flood pressure in the Hemlock East Flank from the lower pore pressure in the West Flank. After the 7" was set & cemented, the 9.4 ppg water based mud was changed out to 8.6 ppg oil based mud. Apparently, the shoe of the 7" was set too shallow as drilling the 6" hole for the 5" slotted liner encountered water & gas flows that dictated that the mud weight be increased to 9.3 ppg for well control. Prior to running the 5" slotted liner, it was decided to make an attempt to contain the water flow from the East Flank. An open hole inflatable external casing packer with a cement stage valve was set 110'below the 7"shoe & a liner packer was set on the liner top. The ECP was set and 37 sk of cement was pumped. There no evidence when cleaning out the liner top of good, quality cement. The liner packer would not hold a pressure test & was flowing water. Therefore, a second 7" liner packer was set above the 15'packer and remedied the water flow problem. Most of the new drills were cleaning up within 2 days after being on gas lift, however, the C32-23LW was still producing 25-40%OBM 6-7 days after being on production. The well IP'd at 183 BO, 75 BW&297 MCF on May 14, 2002 & quickly declined to ±110 BO & 50 BW within 6 weeks while lifting at the orifice valve #11. The production has been relatively flat from Jan '04 through May '05 @ 95 BO & 5 BW. It is perceived that the production on this well covering over 1,400' of high resistivity pay is lacking due to the drilling induced damage from the overbalanced oil based mud countering the East Flank water flood. Pertinent Well History for the C24-14: 5-22-73 Spudded C24-14 well w/ 17 '/"bit. 5-31-73 Set 13-3/8"61#K55 BTC Surface Casing @ 2,438'. Cmt w/2,550 sk. Cmt circ to surface. 6-2-73 Drill ahead w/12-W OH. 6-21-73 Ran Dual Induction Log from 2,438—8,720'. 6-27-73 Set 9-5/8" Intermediate @ 8,883'. Ran 40#N80 BTC from Surf to 3,632'&43.5# N80 BTC from 3,632—8,883. Cmt w/ 1,140 sk. 6-30-73 Drilled ahead w/8-W OH. 7-8-73 Milling on lost hit cones @ 10,157'. Well started flowing water w/8.5 ppg mud in hole. Raised mud weight to 9.5 ppg. 7-14-73 TD'd hole @ 10,900'. Failed to successfully run OH logs due to tools sticking. 7-18-73 Set 7"29# N80 Production Liner from 8,525 10,852'. Cmt w/500 sk. 7-19-73 No cmt on TOL. Sqz liner top 2 times w/228 sk cmt ea time. • • 2 7-21-73 TOL tested. 7-23-73 SLB ran CBL,VOL&GR. 8-14-73 Completed well C24-14. Pertinent Well History for the C32-23(C24-14RD): 7-30-75 RU on well C24-14 to redrill for the C24-14RD. 8-1-75 POH w/prod string. Tbg parted &stuck in hole. 8-2-75 Lost tbg in hole. Start fishing operations. 8-2/21-75 Unsuccessful @ retrieving fish. Left tbg& Packer#3 in hole. TOF @ 9,900'. 8-22-75 Set cmt retainer @ 9,895'. Pumped 250 sk cmt. Set 2nd cement retainer @ 9,745' & pumped 150 sk cmt. 8-23-75 Shot 4 ea W holes @ 4,000' in the 9-5/8" Intermediate. RIH &set cmt retainer @ 3,938'. Pumped 400 sk cmt. 8-24-75 Drill out cmt&retainer to 4,100'. Test sqz holes to 1,500 psi. RIH with BH milling assembly. Start milling on 9 5/8"@ 4,005'to 4,047'. 8-25-75 Milled to 4,061'in 9 5/8". Set 200 sk cmt plug @ 4,072'. 8-27-75 Start directional drilling 8'/"OH from 4,010—72' (37-27°). 9-20-75 Lost returns @ 8,800'. Mixed& pumped LCM®ained circ. Lost±800 bbl mud. Drilled to 9,136' &well began to kick. Cond mud &circ through choke. 9-30-75 TO hole @ 9,831'. 9-31-75 Schlumberger run DIL—SP OH log. 10-1-75 Ran Sonic log. Lost lower belly spring off tool. Pushed fish to bottom. Lost complete returns after circ 30 min. Circ LCM ®ained returns. 10-2-75 RU SLB and run FOC log. 10-3-75 Run 7"26#S95 LTC Longstring. Csg stopped short @ 9,778' (shoe), float collar @ 9,695' & DV tool @ 4,219'. Cmt Stage 1 w/520 sk Lead+600 sk Tail. Open DV tool &cmt Stage 2 w/400 sk Lead + 100 sk Tail. Lost complete returns after displacing 336 sk through the DV tool. 10-6-75 CO cmt to 9,725'. Ran Sperry Sun survey 3,800—9,700'. RU SLB&run CBL, GR& CCL. CBL shows TOC for Stg 1 @ 8,370' & Stg 2 cmt b/w 4,700—3,590'(very poor bond on Stg 2). 10-8-75 RIH w/prod string: 3-W 9.3#N80 EUE to 8,895'. Set Guiberson VII Packer @ 8,824'. 10-10-75 Perfd HC-HD: 9,020—53' (33'). Well tested @ 600 BWPD w/trace of oil. 10-15-75 SLB ran temp survey. 10-16-75 Pulled GLV#8 @ 8,808'. Killed well w/mud. POH w/prod tbg. 10-17-75 RIH &CO fill from 9,720—25'. Cond mud to sqz off HC-HD perfs @ 9,020—53'. 10-18-75 Sqz HC-HO perfs w/285 sk cmt. Could not Reverse Out. Cement was contaminated. 10-19-75 Drill out cmt. Failed press test. • • 3 10-20-75 Performed 2"d sqz on HC-HD perfs w/220 sk cmt. 10-21-75 Drill out cement&tested ok. 10-23-75 Rill w/3-W 9.3#N80 EUE prod string. 10-24-75 Set packers @ 8,992 &9,064'. Tbg tail @ 9,135'. Ball Valve @ 297'. GLV#1 @ 2,175'MD GLV#2 @ 4,398'MD GLV#3 @ 5,885' MD GLV#4 @ 6,952' MD GLV#5 @ 7,714'MD GLV#6 @8,215'MD GLV#7 @ 8,617' MD GLV#8 @ 8,834'MD 10-25-75 Gas lifting @ GLV#4. RU SLB. Perf HK-HN: 9,336—9,404'(68'). Tested well @ 1,248 BLPD. 10-26-75 Perf'd: HN-HR: 9,426—79' (54'), 9,509—64' (56'). IP'd well @ 2,064 BLPD for the HK-HN &HN- HR zones. 10-27-75 Perf d HR-HZ: 9,579—690' (112'). IP'd well @ 2,160 BLPD for HK-HZ. 2-1-76 Paperwork filed renaming well from C24.14RD to C32-23. 12-17-82 Re-perf HR-HZ: 9,648—78'&9,610—40'. 12-20-82 Re-perf HK-HN: 9,340—400'. 9-5-85 RU Dresser Atlas. Re-pert HR-HZ: 9,579—672'&9,534—64'. 11-6-90 Performed a coil tbg acid treatment w/75 bbl 7-V2% HCL on the HR-HZ. Pre-job Prod: 49 BOPD+ 105 BWPD Post job Prod: 120 BOPD + 1,076 BWPD 1-15-01 RU Dowell coil tbg unit to drill out scale. Hit hard scale @ 8,224'. Drilled to 8,539'. POH. 4 ft of slickline wrapped around BHA. Problems reported @ this same depth on 3 previous workovers but were able to work through tight spots. RIH w/2.12"chisel jetting nozzle. 1-16-01 Unable to wash through 8,539'w/chisel jetting nozzle. Spot 5 bbl 7-%% HCL @ EOT. Unable to wash down past 8,539'. Spot 1,500 gal xylene. Sqz xylene into perfs. Unable to achieve objective to CO fill&add pert's. Pre-job Prod: 11 BOPD + 171 BWPD Post-job Prod: 36 BOPD+ 368 BWPD 5-25/30-01 Slickline work on GLV's to improve gas lift. Set 5/16'orifice in GLV#3. 9-26-01 Slickline ran BHT flowing survey to determine the 100 BLPD prod drop. Survey shows well lifting good @ GLV#3. Prod must be restricted downhole. Well History for the C32-23LW: 2-23-02 MIRU rig for sidetrack. 2-24-02 RU slickline &RIH. Stopped @ 4398'. POH w/valve. RIH. Pulled valve @ 7714'WLM. Attempted to re-install valve @ 4398', no success. Mixed kill wt mud to 11.6 ppg. 2-25-02 Bullhead tbg w/mud. RU to bullhead do annulus. Tbg press 2500 psig &annulus press 2750 psig. Cont'd to bleed into fmt. 2-28-02 RU WL. RIH w/2.7"jet cutter. Cut tbg ©8170'. Pulled on tbg&worked free. Std LD 3-1/2"tbg. • • 4 3-1-02 Fin POH & LD 3-1/2"tbg (266 jts). RIH w/cmt ret to 8160'. Stung in & inj 14 bbls of mud @ 2.6 BPM &4900 psi. Form broke dn, ppd in @ 1.5 BPM &4250 psig. Ppd 47 bbls(230sx)of cmt. 3-2-02 Welded slips to 7"csg. NU BOP. 3-3-02 RIH wI 7" hyd csg cutter to 4000' &cut 7"csg. Broke cin cutter&chg'd out blades. MU cutter assembly& RIH. Cut 7"csg @ 60' RKB. TIN w/csg spear& pulled csg &slips free. POH & LD 7" csg cut/off. Speared csg @ 60'. Attempted to pill csg, no success. RU WL. RIN w/free pt, showed 7"csg free to 2076'. Csg will then have to be milled to kick off point(+1-600'to approx 2676'to get below 13-3/8"csg shoe @ 2438'). TIH w/csg cutter&cut 7"csg @ 2075'. Engaged spear& pulled csg free from 2075'. 3-4-02 POH& LD 7"csg. TIH w/mech csg cutter. Cut 7"csg @ 2675'. TIH w/spear&grapple. Caught fish @ 2075'&pulled free. LD±600'of 7". 3-5-02 TIH w/csg spear assmbly. Engaged csg @ 2675'. Attempted to jar&pull (cut @ 4000'), no success. Rel spear& POH. TIH w/mech cutters&cut 7"csg @ 3350'. RIH w/spear to 2675'. Pulled free w/o jarring. LO remainder of 7"csg. Top of 7"csg @ 3350'. RIH 9-5/8" csg scraper. Tagged up on 7"csg stub. 3-6-02 Ran 9-5/8"cmt retainer on WL&set @ 3340'. Ppd 73 sx cmt. 3-8-02 Dress cmt plug to 3231'. 3-9-02 RIH 9-5/8" Baker whipstock&milling assmbly. 3-10-02 Milled from 3199'-3230'. 3-11-03 Drilled ahead w/8"bit wI 9 ppg wtr based mud. 3-20-02 Rot drld fr/8143'-8155'. Lots of coal. Slide drld fr/8155'-8168'(sticky). 3-29-02 Top drive mtr failed. Unable to rot pipe. Waiting on parts. 3-31-02 Inst replacement fuel inj unit on CAT. Began rot pipe. Rot&circ btms up. 4-1-02 Rot drld @ 10,706'. TOH to 3430'. RIH to 10,706', smooth. C&C hole w/9.5 ppg mud. Prep to run 7"csg. 4-3-02 Set Intermediate Csg: 7"26#LTC &29# BTC L80 @ 10,706'. Cmt'd w/674 sk: Lead slurry 218 bbls @ 12.5 ppg &Tail w/ 18 bbls @ 15.8 ppg. Good circ throughout job. 4-7-02 Displ hole w/8.6 ppg OBM. RU SLB&ran CBT log under 1,000 psi. Tagged up w/logging tool @ 10,543'. TOC @ 5,540. 4-8-02 Drld out shoe jt. Drld new hole from 10,706'-10,726'. Performed LOT. Press up to 1544 psig (12 ppg MWE), no Ik off. Raised MW from 8.3 ppg due to gas cut to 8.6 ppg. 4-9-02 Drld ahead w/6" bit. Incr mud weight to 8.8 ppg. 4-10-02 Had to pmp BHA off btm & back ream to 10,114'. Circ out water&gas. MW @ 9.1 ppg. 4-11-02 Drilling @ 11,407'. !nor MW to 9.3 ppg 4-14-02 Disposed of 215 bbls of wtr cut mud. 4-20-02 TD'd hole @ 13,155'. TOH. Tight spot fr/12,840'..12,817'. LD Baker Inteq tools. RIH conventional BHA& hit to condition hole for 5" liner. 4-21-02 Fin TIH w/conventional BHA. Smooth going to btm. C&C mud for 5"slotted liner. • • 5 4-22-02 POOH. Some over pull @ 12,855' & 12,807'. LD BHA. Ran 5"slotted liner. 4-23-02 Cont'd in hole w/5"liner on DP. Tagged btm @ 13,148' (7' high). Dropped dart. Set liner hanger @ 10,385'. Inflated ECP. Opened Howco ES cmtg valve. Pmpd 7.6 bbls of 16 ppg cmt slurry. Dropped dart, closed ES cmtg valve. Set Baker ZXP liner top pkr @ 10,371'. RIH w/bit& scraper to CO TOL. 4-2.4-02 Tagged TOL pkr @ 10,377'. Circ btms up. Could not identify contaminated cmt or spacer. POH. Press tstd top of liner pkr to 500 psi. Press incr to 25 psig w/slight flow. SWI. Press incr to 450 psi in 1.5 hrs (wtr flow). RIH w/Baker pkr setting BHA. Re-set pkr @ 10,377'. Still had slight flow. Circ hole. Still had slight flow. 4-25-02 RIH w/2nd Baker liner top pkr&seal assmbly. Tagged liner pkr#1 @ 10,377'. Set seal assmbly &dropped ball. Set liner top pkr#2 w/3200 psi. Top pkr#2 @ 10,362'. POH. 4-26-02 RIH w/4-1/8" mill. DO cmt from top pkr to x-over @ 10,794'. POH. RIH w/3-3/4"mill. Worked thru liner top to x-over @ 10,794'. DO cmt to landing collar @ 10,843'. TIH to TD @ 13,145'. Mud out of balance but appears to be no wtr flow. 4-28-02 RIH w/pkr assembly on DP. Dropped ball. Set pkr @ 10,276'w/WLREG @ 10,312'. TOI-I wl DP. TIH w/2-718"tbg. 4-29-02 Attempted to stab in top of pkr @ 10,278'w/seal assmbly. Could get+1-1' into pkr&press up to 1000 psig. Attempted several times, no success. Ordered out mill, mtr&stinger assmbly to CO pkr bore&tailpipe. POH w/2-7/8"tbg. LD seal assmbly, no junk marks on muleshoe or seals. RIH w/2-1/8" mill&mtr, 1 jt of 1.25 CS Hydrill DP. Stabbed into pkr @ 10,276'&CO fr top of pkr to 2' above shear out plug in tbg tail @ 10,310'. Pmpd Hi-Vis sweep. PO of pkr&circ Hi-Vis sweep. 4-30-02 Circ Hi-Vis sweep. Got partial sweep back w/very little sand. TIH. Located pkr. Tagged sand 8' into pkr bore. Unable to lift sand w/diesel, POH. Mtr& 1.25"CS Hydril jt were bent. RIH w/new 1.25"CS Hydril DP stinger w/muleshoe btm. TIH to pkr @ 10,255'. Washed from 10,255-10,310' (in tbg tail 2' above shear out). RO sand from pkr&tbg tail. Got sand back to surf. POH. 5-1-02 RIH 2-7/8"completion tbg. PU SSSV. Stabbed into pkr @ 10,276', 3'of seals(out of 10') in. Press tstd tbg to 1000 psig for 15", tstd okay. Had trouble getting last 7'of seals into pkr. Press up&sheared tbg tail plug @ 2500 psig. Got last of seals in&spaced out. RIH &stabbed back into pkr. NU tree. Rel rig. 5-4-02 Well SI until May 4th while derrick moved to well C34-23 to allow deck space for the test tank. Put well on gas lift. 5-5-02 Flowing 97% mud cut fluid to test tank @±15 BPH @ 870 psi csg press. Lifting b/w GLV 4& 5. Rec±350 bbls of load. 5-6-02 Producing±15 BPH @ 860 psi csg press. Lifting between GLV 5 &6. Fluid is 53%oil, 35%wtr& 12% OBM. Req'd solvent to break emulsion. 5-7-02 Initial well test: 20 BPH w/55%OC. 5-8-02 Well test:16 BPH w/40%OC. Contains mainly OBM. 5-9-02 Prod 15 BPH w/30%OC. 5-10-02 Well test: 14 BPH w/±40% OC w/mostly OBM. 5-11-02 Well Test: 13 BPI I w/25% OBM + 75%wtr. 5-12-02 Well test:184 BOPD, 136 BWPD &297 MCFPD. CP =- 820 psig &WHP := 80 psig. • • 6 5-14-02 IP well: 183 BOPD, 75 BWPD &297 MCFPD. Lift Gas 1002 MCF. CP=780 psi&WHP 80 psi. 2-15-03 RU WL. RIH w/2.50"scratcher. No problems in the tbg. Sat dn @ 4.5"x 5"liner crossover @ 10,795'. Had light wax on scratcher. RIH w/2.30"gauge ring. Sat dn on XN nipple @ 10,285'. Tbg was clear. 2-16-03 RIH w/Panex gauge for gas lift survey. Well lifting on bottom 5-20-05 Prod: 92 BO, 5 BW& 190 MCF. Inj @ 572 MCF w/CP= 570 psi&WHP=70. 5-08-07 RIH w/2.5"scratcher. No prob in tbg. Sat down on 5"x 4.5" Liner X-over @ 10,978'WLM. Logs on File for C32-23LW: • 7"CBL& CCL on 4-6-02 • GR/Resistivity VS MD on 4-20-02 • GR I Resistivity VS TVD on 4-20-02 Paul Figel Engineering Manager 1 STATE OF ALASKA AA.OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations El Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown El Performed: Suspend ❑ Perforate ❑ Other Stimulate (Acid)El Alter Casing El Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development I] Exploratory❑ 202-034 3.Address: 3800 Centerpoint Drive,Suite 1400 StratigraphicE Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20251-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ECEIVED ADL0018756 MGS C32-23LW R. 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NOV Y 1 8 2016 N/A Middle Ground Shoal/E,F and G Oil Pools 11.Present Well Condition Summary: AOGCO Total Depth measured 13,155 feet Plugs measured N/A feet true vertical 10,255 feet Junk measured N/A feet Effective Depth measured 13,106 feet Packer measured See Schematic feet true vertical 10,212 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,438' 13-3/8" 2,438' 2,123' •.._." ,b90 psi 1,540 psi Intermediate 3,199' 9-5/8" 3,199' 2,823' 5,750 psi 3,090 psi Production 10,706' 7" 10,706' 8,155' 7,240 psi 5,410 psi Liner 2,790' 5" 13,152' 10,252' slotted slotted Perforation depth Measured depth 11,384-13,106 feet SCANNED M 3::: ',F True Vertical depth 8,792-10,212 feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 10,312(MD) 7,802(TVD) 335'(MD) Packers and SSSV(type,measured and true vertical depth) Packers:See Schematic Baker TE5 SSSV 335'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11,384-13,106' Treatment descriptions including volumes used and final pressure: 550 gallons of Oil Safe AR(synthetic acid),80 bbls FIW -Final pressure 2150 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 11 24 52 621 91 Subsequent to operation: 7 9 106 728 72 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development CI Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-534 Contact Dan Marlowe(907)283-1329 Email dmarlowe(Dhilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature N...,, L)(-1,,,e,;., Phone (907)777-8356 Date 1.1 ' 1$ t(� 1 , G— a4 RBDMS L" NOV 2 8 2016 Form 10-404 Revised 5/2015 Submit Original Only • • Et .. .. BDP 3-1-2014 Current Completion n u,,.�, si:,.�:1.i.r.� KB:35' MGS C32-23LW ■ ■ Water Depth: 73'MSL Cook Inlet,Alaska Tbg:2 7/8",6.5#,L80 EUE 8rd @ 10,312' Leg 1,Conductor 2 J Set on 4-30-02 API No.: 50-733-20251-02 Spud Original Well C24-14: 5-22-73 Item MD ND Psc Pso Port Sidetrack LW:2-25-02 GLM 1 1,948 1,818 910 950 10 111 J GLM 2 3,721 3,201 900 931 10 Surf Csg:13 3/8",61# K55 BTC. GLM 3 5,024 4,103 890 929 12 Set @ 2,438'. Cmt'd w/2,550 sx. GLM 4 6,043 4,803 880 913 12 J GLM 5 6,844 5,352 870 898 12 GLM 6 7,515 5,816 860 883 12 Intermediate: 9 5/8"N80 BTC. GLM 7 8,096 6,214 850 888 16 Window @ 3,199'. GLM 8 8,677 6,614 840 871 16 (Original was set @ 8,883'for the J GLM 9 9,227 6,994 830 854 16 C24-14. Cmt w/1,140 sk.) GLM 10 9,805 7,396 820 836 16 GLM 11 10,195 7,702 ORIFICE 16 40#from Surf-3,632'. 43.5#from 3,632-8,883'. J J Baker TE5 SSSV @ 335' J X Nipple 2 7/8"(2.313"ID)8R 9Cr @ 10,237' 2nd Intermediate: 7"L80 Set @ 10,706'. 1 it 2 7/8"6.5#8R 29#BTC: Surf-7,468' 6'Pup Jt.2 7/8"6.5#8R L80 @ 10,269' 26#LTC: 7,468-10,706' X-over 2 7/8"8R Box x 3 1/2"BTC Pin Cmt w/674 sx.TOC by CBL @ 5,540'. J Locator w/12'Seals @ 10,276' 7"Baker FB1 Perm Packer(85-40)@ 10,276' J Baker B Guide @ 10,178' 10'Sealbore Extension 80-40 @ 10,279' X-over 80-40 SBE Box to 2 7/8"8R L80 IN ■ 10'Pup it.2 7/8"6.5#8R L80 i>"‹ XN Nipple 2 7/8"(2.205"ID)8R 9Cr @ 10,300' IP' • II10'Pup Jt.2 7/8"6.5#8R L80 WL REG @ 10,312' Slotted Prod Liner:5"18#L80 Hydril 513 ►/ ►kA Set @ 10,362-13,152'. Cmt w/37 sk. M MI Baker ZXP Liner Packer#2 @ 10,362'. Baker ZXP Liner Packer#1 @ 10,377'. 5 7/8"HMC Hangar @ 10,391'. X-Over 5"H513 Bx x 4.5"NSCT Pn @10800' 10'Pup Jt.4 1/2"12.6#NSCT ' HES 4.5"ES Cmt Stg Valve @ 10,811' 11 X-Over 4.5"NSCT Box x 4.5"Hydril 521 Pin Baker 5 5/8"ECP(4.0"ID)@ 10,815' I Liner Across DBL Penetration:HC,HE,HI, X-Over 4.5"Hydril 521 Pin x 4.5"NSCT Pin I HK,HN,HK,HI,HE&HC. 10'Pup it.4 1/2"12.6#NSCT HES 4.5"(3.9"ID)Landing Collar @10,849' X-Over 4.5"NSCT Box x 5"Hydril 513 Pin 5"Blank Sections: Top of 1st set slotted section @ 11,384' I 10,362 11,384' 5"18#L80 Hydril 513 Guide Shoe @ 13,152' I 12,391 12,569' 12,656-12,789' 13,106-13,152' PBTD:13,106'MD(10,211'TVD) TD:13,155'MD(10,255'TVD) • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS C32-23LW Pumping Unit 50-733-20251-02 202-034 11/4/16 11/4/16 Daily Operations: 11/04/16- Friday Consult& review AOGCC permit with production engineer. On site safety meeting reference Safe acid, PPE and MSDS review. Pressure test ARO pump and %2" transfer line with water to 5000 PSI.Test good. Shut in gas injection.Tubing at 69 PSI and casing at 678 PSI. Begin injecting 10 drums (13.09 BBL's) of Heartland Energy Group-Safe AR Acid down tubing with ARO pump. Injection pressure at 400 PSI. Casing at 571 PSI.All acid successfully injected. Break off acid lines, purge and clean work area. Run %2" high pressure transfer hose to tree cap of WIW C34-13. Shut in master valve of C34-23 and zero Panametrics. Chase safe acid down hole using FIW from C34-23. Source pressure 3500 PSI. C32-23 tree cap pressure recorded was 2150 PSI. Injection rate varied 390 to 426 BPD. Injected 80 BBL's FIW. FIW injection complete. Well was left shut in to let acid soak. Secure equipment&SDFN.Turn over to production. V of T�t�t, • • g\��/7,1 • BA THE STATE Alaska Oil and Gas ofALASKA Conservation Commission 333 West Seventh Avenue ^ti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 _`""" Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager Hilcorp Alaska, LLC ,=, 3800 Centerpoint Drive, Suite 1400NHUI MAR v y 1 Anchorage,AK 99503 Re: Middle Ground Shoal Field, E, F, and G Oil Pool, MGS C32-23LW Permit to Drill Number: 202-034 Sundry Number: 316-534 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this_day of October, 2016. RBDMS I,V u61 L. 0 LU I6 • • RECEIVED • STATE OF ALASKA OCT 1 201 6 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOG t"' 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well LI Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate [](Acid). I Tubing LI Change Approved Program El Plug for Redrill ❑ Perforate New Pool Cl Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0• 202-034 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20251-02-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A UJ Pi Will planned perforations require a spacing exception? Yes ❑ No 0 / MGS C32-231W • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018756 • Middle Ground Shoal/E,F and G Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 13,155 ' 10,255 . 13,106 • 10,212 . 5,000 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,438' 13-3/8" 2,438' 2,123' 3,090 psi 1,540 psi Intermediate 3,199' 9-5/8" 3,199' 2,823' 5,750 psi 3,090 psi Intermediate 10,706' 7" 10,706' 8,155' 7,240 psi 5,410 psi Liner 2,790' 5" 13,152' 10,252' slotted slotted Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,384-13,106 8,792-10,212 2-7/8" 6.5#/L-80 10,312 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): See Schematic See Schematic 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/31/2016 Commencing Operations: OIL 0• WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature 34. G/ rtvi Phone (907)777-8356 Date Q t't r ID COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. \LQ _ Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS L`' UL.I L d 201'0 Spacing Exception Required? Yes ❑ No E( Subsequent Form Required: 10 4u,4 .4sF tlte APPROVED BY _ Approved by: Pi C447 COMMISSIONER THE COMMISSION Date: /0 —/6 *tl• 11623 iCc) At (07204 ///'''��� n ^^ A Submit Form and Form 10-403 Revised 11/2015 Approved application is val d&Rr�oBstrh�ya�of appro al. Attachments in Duplicate 14 . • Well Work Prognosis Well: C32-23LW Hilcorp Alaska.1.1A: Date: 10/13/16 Well Name: MGS C32-23LW API Number: 50-733-20251-02 Current Status: Gas Lifted Producer Leg: Leg#1 (west) Estimated Start Date: October 31, 2016 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 202-034 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: 3,956 psi @ 8,792'TVD(11,384'MD) 0.450 lb/ft(8.65 ppg) Maximum Expected BHP: 3,956 psi @ 8,792'TVD(11,384'MD) 0.450 lb/ft(8.65 ppg) Max Potential Surface Pressure(MPSP): 5,000 psi treatment pump pressure limit Brief Well Summary C32-23LW is a gas-lifted producer with known scaling issues.This project will soak the slotted liner to restore productivity. / Procedure 1. MIRU pumping equipment. 2. Pressure test surface lines to ±5,000 psi (treatment pump limit). 3. Pump ±550 gallons acid at maximum pump rate followed by 80 bbls produced water. 4. Shut down pump and let acid soak for 24 hours. 5. RD Pumping equipment. 6. Return production. Attachments: 1. As-built Schematic 2. Pumping Unit Diagram • 0 rit . .. BDP 3-1-2014 Current Completion MGS C32-23LW • ■ Water Depth: 73'MSL Cook Inlet,AlaskaTbg:2 7/8",6.5#,L80 EUE 8rd @ 10,312' Leg 1,Conductor 2 J Set on 4-30-02 API No.: 50-733-20251-02 Spud Original Well C24-14:5-22-73 Item MD TVD Psc Pso Port Sidetrack LW:2-25-02 GLM 1 1,948 1,818 910 950 10 J iiiiii GLM 2 3,721 3,201 900 931 10 Surf Csg:13 3/8",61# K55 BTC. GLM 3 5,024 4,103 890 929 12 Set @ 2,438'. Cmt'd w/2,550 sx. GLM 4 6,043 4,803 880 913 12 J GLM 5 6,844 5,352 870 898 12 GLM 6 7,515 5,816 860 883 12 Intermediate:9 5/8"N80 BTC. GLM 7 8,096 6,214 850 888 16 Window @ 3,199'. GLM 8 8,677 6,614 840 871 16 (Original was set @ 8,883'for the J GLM 9 9,227 6,994 830 854 16 C24-14. Cmt w/1,140 sk.) GLM 10 9,805 7,396 820 836 16 40#from Surf 3,632'. GLM 11 10,195 7,702 ORIFICE 16 43.5#from 3,632-8,883'. J J Baker TE5 SSSV @ 335' J X Nipple 2 7/8"(2.313"ID)8R 9Cr @ 10,237' 2nd Intermediate: 7"L80 Set© 10,706'. 1 Jt 2 7/8"6.5#8R 29#BTC: Surf-7,468' 6'Pup Jt.2 7/8"6.5#8R L80 @ 10,269' 26#LTC: 7,468-10,706' X-over 2 7/8"8R Box x 3 1/2"BTC Pin Cmt w/674 sx.TOC by CBL @ 5,540'. J Locator w/12'Seals @ 10,276' 7"Baker FB1 Perm Packer(85-40)@ 10,276' J Baker B Guide @ 10,178' 10'Sealbore Extension 80-40 @ 10,279' X-over 80-40 SBE Box to 2 7/8"8R L80 • ■ 10'Pup Jt.2 7/8"6.5#8R L80 '>G1 �C XN Nipple 2 7/8"(2.205"ID)8R 9Cr @ 10,300' ■ II10'Pup Jt.2 7/8"6.5#8R L80 WL REG @ 10,312' Slotted Prod Liner:5"18#L80 Hydril 513 Set @ 10,362-13,152'. Cmt w/37 sk. .MI Z Baker ZXP Liner Packer#2 @ 10,362'. Baker ZXP Liner Packer#1 @ 10,377'. 5 7/8"HMC Hangar @ 10,391'. X-Over 5"H513 Bx x 4.5"NSCT Pn @10800' 10'Pup Jt.4 1/2"12.6#NSCT HES 4.5"ES Cmt Stg Valve @ 10,811' X-Over 4.5"NSCT Box x 4.5"Hydril 521 Pin Baker 5 5/8"ECP(4.0"ID)@ 10,815' Liner Across DBL Penetration:HC,HE,HI, X-Over 4.5"Hydril 521 Pin x 4.5"NSCT Pin I HK,HN,HK,HI,HE&HC. 10'Pup Jt.4 1/2"12.6#NSCT HES 4.5"(3.9"ID)Landing Collar @10,849' X-Over 4.5"NSCT Box x 5"Hydril 513 Pin Top of 1st set slotted section @ 11,384' 5"Blank Sections: 5"18#L80 Hydril 513 Guide Shoe @ 13,152' 10,362-11,384' 12,391-12,569' 12,656-12,789' 13,106-13,152' PBTD:13,106'MD(10,211'TVD) TD:13,155'MD(10,255'ND) • W •a Ct O 3j I oa N Y LL w O O M3 J J ?3 o J yam 5 Y z Ox O $ O u as 1 HMI iffillind � a it lc 0 w w ;.1 2 x aE u a a ❑ Z 5 R W U Z W R 8 8 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 ì - Ó 3 4- Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 1111111111111111 III R~CAN v¡f Color Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NofType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: BY: C Mari;:) Dote Jd-/J--o/ QÇ D other:: 151 f11f 1111111111111111111 Project Proofing BY: ~ Date: IJ-/Mj DS- 2- X D + I Î = TOTAL PAGES Î 7 ~nt does not include cove~ ~ 151 (liP Scanning Preparation BY: ~ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanni.ng Preparation: V YES ~ Date:tá!¿}.()/œ- Stage 1 If NO in stage 1, page(s) discrepancies were found: IIIIIIIIIIIIHIIII p Date: 151 NO BY: 151 VVlP YES NO BY: Maria Date: 151 1111111111111I11111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111I11 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc Reviewed By: Safety Valve & Well Pressures Test Report P.I. Supr '~ = z ~~~ Comm Pad: MGS_xT0_C_PLATF InspDt: 2/22/2008 °~Inspected by John Crisp Interval InspNo svsJCr080225134306 Related Insp: Field Name MIDDLE GROUND SHOAL Operator XTO ENERGY INC Operator Rep Barney Phillips Reason 90-Day `~ _ rc• I -_- - --- __ - - _, _ -_ _ - - -- -- - __-- - ~ _ _ --- nspector ___, _--- --- YP I - __ .f ~ _ _ yi'ell Data _ Pilots SSV ~ SSSV Shutln Dt~ Well T e Well Pressures ~ Gas Li t ~ Waivers _Comments - - - - - --- -- -- Well Permit Se ar Set L/P Test Test Test Date SI Oi1,WAG,G]NJ, Inner Outer Tubing p Number Number PS[ PSI Trip Code Code Code GAS,CYCLE, S[ PSI PSl PSI Yes/No Yes/No ~ C12 23 1900200 ~ 68 ~ 37 ~ 37 T-P P P T 1-OIL ~ ~ ~ ~ - - - -- ----- - - ------ C 13 23 1880990 68 37 T 37 ~ P P P 1-OIL f I ----- C13A 23 -_~- -- 1901060 68 0 ~ _ P P 1-OIL C21 23 ; 1890870 68 ~ 0 ! P 1-OIL --- ------ - -- --_- _--_-- -_--_-~ ___- - _ SSSV out for W/L wo~ic - - _._ --- C2l 26 1890040 ~ 68 0 ~-- ---- --- - -- ------------ - r--- I ----- - ---- ----~ -- -- -- ---- I ~ ~ ~ --- P P l-OIL -- -- -'~I-- ~-_-_- 'T--. -~---_.- - _.-'_-_ __-- --- _- ..- - - ._ _-__-.._. -. -_ i- -.-.-__ _. _-- - - -. .___--"----_~ 21A 23 ~_ 1910440 X68 0 1 P P , 1-O1L ~ i C22-26RD i 1760650 ' 68 0 ~ P P ~ 1-0[L ~ - - --- _ - -- -~ -- -- - - - -~-----~-- - - -- ---- --~- -- - - - -~ _ _- . -- - - -- - --- -J _ - C22A-26LN _2041820 68 I-0 P P 1-OIL _ -~ _ j --- _ _ _ ~ -- C31-26RD 2041400 68 0 I P P t-OIL ~ - ---- -- -- --- ; C32-23LW 2020340 68 i 0 P P I-O!L - '-- --~- -- - - ~ ~. ___ -. -. - - -- - - - - - --- ----- -- - - - ----- -- - -T - - --1- - --- - ---- --- C42-23 1780240 68 ' 0 P P 1-OIL I - - - - C43-14 ~ 1881320 68 ~ 0 ~- P ~ 1-OIL _i- -1----- ~-_ ~ ---- ---- ---- ---- Comments Performance Pilot numbers listed on wells C 12-23 & C 13-23 are for the pilots on the separators. Individual wells are - --- -- - --------_.. not equiped with pilots on this platform. ;/ Wells Components Failures Failure Rate 12 25 0 _ • ~~~4VNE~ MAR ~ 9 ZOQ~ Tuesday, February 2(i, 2008 I e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc ) ) ~TO ~kRGY XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) January 5, 2006 RECEIVED JAN 0 9 2006 Alaska Oil and Gas Conservation Commission Attn: Mr. Howard Okland 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage RE: CD ofOH logs for MGS Well C32-23LW. Dear Mr. Okland: -:#= J] j ~ 1 Enclosed is the CD for OH logs (GR & Resistivity) for the C32-23LW. This should cover all the information that you had requested. Please call me @ 432-620-6743 if you require anything else. Sincerely, YaJ / ¥ Paul L. Figel Engineering Manager SCANNE[J JAN () 6 lQUO Encl:CD - >~o~~U}'1 h~'~ Fw: C32-23LW tops . Sub,icet: Fw: C32-23L W tops From: Paul_ Figd@xlocncrgy.com Date: Thu, 22 Dee 2005 15: I 7:47 -O()OO To: hO\\lard ._okland(fl~adm in.statc.ak.lIs . Here are the formation tops from the geologist. Paul Forwarded by Paul Figel/MID/CTOC on 12/22/2005 03:13 PM ----- Casey Patterson/FTW/CTO C To Paul Figel/MID/CTOC@CTOC 12/22/2005 10:50 AM cc Subject C32-23LW tops C32-23LW Tops FORMATION HC HE HI HK MD TOP 10,675 10,803 11,045 11,102 TVDSS (-8,020) (-8,137) (-8,365) (-8,419) iCANNED DEC 23 2D05 Casey Patterson Staff Geologist XTO Energy, Inc. 817 885-2364 1 of 1 9. () ;1.. - 0 ') c.( f7( 12/23/2005 8:32 AM J J~" (}~.) '~ DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020340 MD 13155 ....- Well Name/No. MGS C32-23LW Operator XTO ENERGY INC 5¡?{¡¡J } D I1k J..tÓÀ API No. 50-733-20251-02-00 TVD 10255 - Completion Date 5/1/2002 /" Completion Status 1-01L Current Status 1-01L UIC N_ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: LWD: GR & Resistivity Well Log Information: Log/ Data ~ f6c Digital Med/Frmt C Electr Dataset Log Log Run Number Name Scale Media No Ú1596 Cement Evaluation 1 Cement Evaluation 5 Blu I nduction/~esistivitÿ 5 Blu 41595 I nd uction/Resistivity Blu Well Cores/Samples Information: Name Interval Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? Y I(@) Chips Received? ....Y..U*-- Analysis Received? Daily History Received? Formation Tops Comments: ~ re~ rtl o.l NA,l ~')1~~ . AJ~ h~ ~ \}!\re It ~ 6. u ~ þ( ."lN~ ~ M () I t"'í-', ~_~J'~lhJi ) ~ Compliance Reviewed By: (data taken from Logs Portion of Master Well Data Maint) Interval OH/ . Start Stop CH Received Comments 200 10543 Case 3/4/2003 I 200 10543 Case 3/4/2003 I 3199 13155 ~ 3/4/2003 3199 13155 ~ 3/4/2003 -~ Sample Set Number Comments ~ y~ . J d ~J.(~ I..( Date: . . ;[!R XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 915-682-8873 915-687-0862 (Fax) February 24, 2003 Alaska Oil and Gas Conservation Commission Attn: Mr. Randy Ruedrich 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report: Well C32-23LW Sidetrack Dear Mr. Ruedrich, XTO Energy, Inc. hereby submits its Well Completion Report (Form 407) for the Sidetrack performed for the C32-23L W on Platform C in the Middle Ground Shoal Field of Cook Inlet. Please find attached the following information for your files: 1. Form 10-407 Well Completion 2. paily Drilling Reports 3. Present Well bore Schematic 4. Well Surveys 5. LWD Logs: GR & Resistivity Logs 6. CBL Log for the 7" Intermediate Casing If you have any questions or require additional information, please contact me at (915) 620-6743. Sincerely, ?a.I-l. Ý Paul L. Figel Sr. Production Engineer Cc: Doug Schultze Doug Marshall Tim Smith . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL Ga GAS D ABANDONED D SERVICE D !):At~' SUSPENDED D 2. Name of Operator Jcr'O EœJ:gy IDe. Leg 1, ~ 2, 547' FSL, 1594' FEL, Sec. 23, At Top Producing Interval 1833' Pm., 2896'FEL, Sec. 23, TSN, R13W, 8M At Total depth 2504' FNL, 3498' FEL, Sec. 23, 5. Elevation in feet (indicate KB, DF, etc.) 105 DF $\J~' '111:::::: _" "i;J, , _ "'-'. \ TaN, ftð"MPL~ÕÑ~' ,S""~~ J') 2 ~mj-- 3. Address 3000 N. Garfield, Ste 175, Midland, TX 79705 4. Location of well at surface TaN, R13W, 8M 16. Lease Designation and Seri AIL 18756 12. Date Spudded Classification of Service Well 7. Permit Number ') ,,",,"" 1'\..2 J --~ M~". ~Vd-.. ~ VJ~ ..~ 8, API Number 50- 733-20251-02 9. Unit or Lease Name Middle Ground ShoaJ. 10. Well Number C32-23 IJi1 11. Field and Pool Middle Ground ShoaJ. . 13. Date T.D. Reached , 14. Date Comp., Susp. or Aband 15. Water Depth, if offshore 16. No. of Completions 3/10/2002 17. Total Depth (MD + TVD) 13,155' (10,255'TVD) 22. Type Electric or Other Logs Run Tr.1r... ,..,. r_ 4/20/2002 5/1/2002 73 feet MSL 1 8, Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 13106' (10211'TVD) YES !XI NO D 335' feet MD NA "'-./IJ~......, 3, I f, , m /) 2- fl'zc.¡ 'rvt> 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 61 1K55 2438' 17-1/2" 2550 ax 9-518" 40-43,5 INaO 319Q' 12-1/4" 1140 ax 7" 26-29 LSO SUrface 10706' 8-1/2" 674 SK 5" 18 LSO 10362' 13152' 6" 37 ax 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. TUBING RECORD DEPTH SET (MD) 1n.~12' PACKER SET (MD) 1n ·Y7t::., SIZE 2-7/8" Slotted liDer: 11384'Me - 13,106' Me (8701' TVD - 10,211' TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST 1 Method of Operation (Flowing, gas lift, etc.) t:!.o.. T.~~" PRODUCTION FOR OIL-BBL GAS-MCF TEST PERIOD 91.5 138 CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE 183 276 CORE DATA 75 Date First Production Date of Test Hours Tested 1::11J1I'?nn'? 12 Flow Tubing Casing Pressure Press. 80 780 28. WATER-BBL 37.5 WATER-BBL Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA . Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE RBDMS BF l -49 - CHOKE SIZE GAS-OIL RATIO 128/64 1509 OIL GRAVITY-API (corr) 35.0 Submit in duplicate Gç 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, GOR, and MEAS. DEPTH TRUE VERT. DEPTH time of each phase. NA 31. LIST OF ATTACHMENTS WellJ:Jore Schesœtic, Daily Drlg Reports,Im logs:GR &: Resistivity,em., &: Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Sr .~ian EngiIJeer Date 2/24/2003 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Form 10-407 -50- Current Completion NERGY MGS C32-23LW Cook Inlet, Alaska Leg 1, Conductor 2 API No.: 50-733-20251-02 Spud: 7-30-75 Original Well Sidetrack: 2-25-02 Surf Csg: 13 3/8", 61 # K55 BTC. Set @ 2,438'. Cmt'd wI 2,550 sx. Intermed Csg: 9 5/8" N80 BTC @ 3, 40# from Surf - 3,632'. 43.5# from 3,632 - 3,199'. (Original 9 5/8" was set @ 8,883' for the C24-14. Cmt w/1, 140 sk.) 2nd Intermed Csg: 7" L80 Set @ 10,706'. 29# BTC: Surf - 7,468' 26# LTC: 7,468 -10,706' Cmt wI 67 4 sx. TOC by CBL @ 5,540'. KO hole in 95/8" @ 3,199'. Slotted Prod Liner: 5" 18# L80 Hydril 513 Set @ 10,362 -13,152'. Cmt wI 37 sk. Baker ZXP Liner Packer #2 @ 10,362'. Baker ZXP Liner Packer #1 @ 10,377'. 57/8" HMC Hangar @ 10,391'. X-Over 5" H513 Bx x 4.5" NSCT Pn @10800' 10' Pup Jt. 4 1/2" 12.6# NSCT HES 4.5" Cmt Stg Valve @ 10,811' X-Over 4.5" NSCT Box x 4.5" Hydril 521 Pin Baker 5 5/8" ECP (4.0" ID) @ 10,815' X-Over 4.5" Hydril 521 Pin x 4.5" NSCT Pin 10' Pup Jt. 4 1/2" 12.6# NSCT HES 4.5" (3.9" ID) Landing Collar @ 1 0,849' X-Over 4.5" NSCT Box x 5" Hydril 513 Pin Top of 1 st set slotted section @ 11,384' 5" 18# L80 Hydril513 Guide Shoe @ 13,152' PBTD: 13,106' MD (10,211' TVD) TD: 13,155' MD (10,255' TVD) PLF 2-25-03 KB: 116' Water Depth: 73' MSL Tbg: 2 7/8", 6.5#, L80 EUE 8rd @ 10,312' Set on 4-30-02 Item MD GLM 1 1,948 GLM 2 3,721 GlM 3 5,024 GLM 4 6,043 GLM 5 6,844 GlM6 GLM7 GLM 8 8,677 GLM9 GLM 10 GlM 11 10,195 TVD 1,818 3,201 4,103 4,803 5,352 5,816 6,994 7,396 7,702 Pac Pso 910 950 900 931 890 929 880 913 870 860 Port 10 10 12 12 12 12 16 16 16 16 20 854 836 ORIFICE Baker TE5 SSSV @ X Nipple 27/8" (2.3 8R 9Cr @ 10,237' 1 Jt 2 7/8" 6.5# 8R 6' Pup Jt. 2 7/8" 6.5# 8R L80 @ 10,269' X-over 2 7/8" 8R Box BTC Pin Locator w/12 7" Baker FBi Perm Packer (85-40) @ 10,276' Baker B Guide @ 10,178' 10' Seal bore Extension 80-40 X-over 80-4 10' Pup Jt. 2 7/8" 6.5# XN 2 (2.205" ID) 8R 9Cr @ 10,300' 10' t. 2 6.5# 8R L80 WL REG @ 10,312' Sections: - 11,384' 12,391 - 12,569' 12,656 - 12,789' 13,106 -13,152' . . MIDDLE GROUND SHOAL C Well # 32-23LW Objective: Rig Move AFE:200096 1st Rept: 02/20/2002 2/20/02 RD flow line. Cleared decks for move. Prep for back load. RD top drive e1ec. Dumped vac tnk to solids unit. Unloaded & reloaded boat. Cleaned out solids unit. Disconnected koomey remote. Split solids unit. RD centrifuge. Moved mud dock. Transferred cutting bbls. Loaded racks w/bbls. Cleared deck for rig move. Unwired solids unit. 2/22/02 Rigging Up. Trouble shooting moving system. Repr jacking plate. Repl jack on skid base (RU surface tnk on C13A-23LN). Fin skidding rig over C32-23LW. Pulled elec wires & hooked up. Set solids unit, mud dock & centrifuge. Prep for boat. 2/23/02 Rigging Up, Trouble With Drains. MIRU 24 hrs. Set top drive & vac equip. RD jacking system. Hooked up service loop for top drive. Hooked up air, steam & wtr to rig. Off loaded boat. Set catwalk, drlg line spool & walk way. Moved 6" & 4" choke lines. RU mud line & 10" flowline. Attempted to CO drains (very plugged). 2/24/02 Building More Kill Wt Mud Vol, MW 11.0, Vis 48, PV 15, yP 23, Gels 12/25, Added 640sx Barite, 5sx caustic soda, 180sx Durogel & 9sx Ao-Vis. MIRU 24 hrs. Installed slop tnk & block valve to deck drains. Installed flowline & 4" mud line. RU solids unit & brake wtr rtn. RU slickline & Rlli. Stopped @ 4,398'. POH w/valve. Rlli & stopped. Pulled valve @ 7,714'WLM. Rlli several times & attempted to re-install valve @ 4,398', no success. Mixed kill wt mud to 11.6 ppg. Bldg more vol. 2/25/02 Monitoring Well After Bullheading KW Mud, MW 11.5. Vis 42, PV 9, YP 20 Gels 10/16. Other 1/4 hr, MIRU 23-3/4 hrs. Mixed kill wt mud vol. Fin RU slop tnk. RU 6" & 4" choke lines. RU to bullhead tbg w/mud. Tbg press 350 psig, annulus press 400 psig @ start of bullhead. Bullheaded dwn tbg w/104 bbls @ 10 SPM (0.7 BPM). Final pmp in press was 3,060 psig on tbg & 3,550 psig on annulus. SD pmp, tbg press dropped to 2,100 psig & annulus press dropped to 2,950 psig. SD for 2 hrs. SITP 500 psig, SICP 890 psig. RU to bullhead dwn annulus. Bullheaded 246 bbls dwn annulus @ 0.4 BPM @ 3,680 psig (tbg press 3,740 psig). SD pmp. Annulus press dropped to 3,500 psig & tbg press dropped to 3,300 psig. Monitored well. Tbg press 2,500 psig, annulus press 2,750 psig. Cont'd to bleed into fmt. Monitored well. Tbg press 2,050 psig, annulus press 2,425 psig. 2/26/02 NU BOP, MW 11.6, Vis 42, PV 10, YP 18, Gels 10/18, Added 120sx Barite, 1sx caustic soda, 18sx Durogel & 1sx Ao-Vis. Monitored Well 11-1/2 hrs, NU/ND BOP/Diverter 6 hrs, NU/ND Tree 4 hrs, Other 2-1/2 hrs. Monitored well & let press bleed to fmt. Tbg press bled fr/2,500 psig to 710 psig, annulus press fr/2,425 psig to 550 psig. Monitored well. Bled press off thru choke to 0 psig. Well dead. RD lines & blew dwn choke manifold. Installed back press valve. ND tree (had bad body seals on tbg hanger). NU riser & BOP. 2/27/02 POHw/APRS & 2.7" GR from 8,190'WLM, MW 11.6, Vis 40, PV 10, YP 18, Gels 10/18. NU/ND BOP/Diverter 10 hrs, Other 5-1/2 hrs, Tstd BOP/Diverter 5 hrs, LD/PU Drill Pipe/Tbg 1-1/2 hr, Circ 1-1/2 hr, Monitor Well 1/2 hr. NU BOP & pollution pan. Tstd BOP 250 - 5,000 psig, tstd OK. Tst witnessed by AOGCC rep. RU & pulled back press valve. RU & pulled tbglhanger loose. Well back flwg (U-tube). Circ well to balance U-tube. Monitored well. RU APRS E-line unit. Well back flwd (U-tube) @ 2 BPH. RU APRS & Rlli w/2.7" gauge ring. Set dwn @ 4,400' & 7,700' (GLM's). Rlli & set dwn @ 8,190'. PU "sticky". POH. 1 . . 2/28/02 POH & LD 3-112" Tbg (Cut @ 8,170'), MW 11.6, Vis 52, PV 7, YP 28, Gels 13/14, pH 8.0, WL 20.0, Cake 3.0, Alk 0.1, CI16,000, Ca 1,080, Solids 13.0. LD/PU Drill Pipe/Tbg 10-1/2 hrs, Other 6 hrs, Circ 6 hrs, Ppd Pill 1 hr, Monitored Well 112 hr. Fin POH w/2.7" gauge ring. Held safety meeting. PU & armed APRS 2.7" jet cutter. RIH, stopped @ 8,185'WLM. Cut tbg @ 8,170'. POH & RD APRS WL. Pulled on tbg & worked free. LD landing joint. Broke out tbg hanger. Circ well thru choke. Mud wt dwn to 10.5 ppg (Barite falling out). Circ well & incr mud wt to 11.5 ppg. Monitored well. Ppd pill. Blew dwn stand pipe & choke lines. Std LD 3-112" tbg (wet after GLM #2). 3/01102 Circ well fr/8,067', MW 11.5, Vis 43, PV 7, YP 17, Gels 10/14, pH 8.0, WL 20.0, Cake 3.0, Alk 0.1, CI16,000, Ca 1,080, Solids 13.0, Oil 0.0, Added 110sx Barite, Isx Caustic Soda, 2sx Durogel & 2sx Flo-Vis. Other 9 hrs, LD/PU Drill Pipe/Tbg 4-112 hrs, Cementing 4-1/2 hrs, Trip 4-112 hrs, Circ 1-1/2 hr. Unloaded cmt equip off of boat. Fin POH & LD 3-1/2" tbg (266 jts & CO + 8 GLMs w/pups). TIH w/5.718" junk basket on APRS WL to 8,170'WLM. POH & RD WL. TIH w/cmt ret, stinger & circ sub to 8,160'. Stung in & injected 14 bbls of.mud @ 2.6 BPM & 4,900 psig. Fonn broke dwn, ppd in @ 1.5 BPM & 4,250 psig. Set retainer, injected 9 bbls @ 2.45 BPM & 5,370 psig. Unstung fr/ret, mixed & ppd 47 bbls (230sx) of Class "G" cmt w/0.2% CD32, 0.4% FL33, 0.3% R3 & 1 gal/100sx FP6L. Mixed @ 15.8 ppg. Held 1,600 psig on annulus, stung in to ret, ppd 4 bbls H20 & 51.5 bbls mud to displace final pmp in rate 2.64 BPM @ 4,200 psig. Cmt in place @ 3:30 am 3/1/02. Unstung fr/ret, pulled 1 stand, dropped dart/wiper, ppd wiper dwn & seated same to open circ sub. Circ well through circ sub. 3/03/02 Building Volume Prior To Pulling 7" Csg, MW 11.5, Vis 41, PV 5, YP 25, Gel 12/27, pH 10.0, WL 20.0, Cake 3.0, Alk 0.1, CI16,000, Ca 1,080, Solids 13.0, Oil 1.0, Added 100sx Barite, Isx caustic soda, Isx citric acid, 40sx Durogel & 4sx Flo- Vis. Other 9 hrs, Trip 6-1/2 hrs, PU/LD BHA & Tools 3-112 hrs, Monitor Well 3 hrs, Circ 1-1/2 hr, LD/PU Drill Pipe/Tbg 1/2 hr. PU & MU 7" hyd csg cutter. TIH w/cutter assbly to 4,000'. C & C mud. Cut 7" csg @ 4,000'. Circ & monitored well. Ppd dry job. POH w/cutter assbly. Broke dwn cutter & chg'd out blades. PU & MU cutter assbly. TIH & cut 7" csg @ 60'RKB. POH & broke dwn cutter asbly. MU csg spear. TIH w/spear. Pulled csg & slips free w/225K. POH & LD 7" csg cut/off, slips & pack off. TIH & speared csg @ 60'. Attempted to pull csg, no success. RU APRS WL unit. RIH w/free point indicator, showed 7" csg free to 2,076'. Called Bill Penrose & Bobby Smith & concluded that the cut will have to be made @ 2,076'. Csg will then have to be milled to kick off point (+/-600' to approx 2,676' to get below 13-3/8" csg shoe @ 2,438'). LD spear & PU cutter assbly. TIH w/csg cutter to 2,075'. Cut 7" csg @ 2,075'. Monitored well. Hole took 29 bbls of fluid when cut, then gave it back. Monitored well. POH w/csg cutter. Engaged spear & pulled csg free fr/2,075' w/100K. Monitored well & built mud vol prior to pulling csg. 3/04/02 Prep To LD +/-600' of 7" Csg, MW 11.1, Vis 38, PV 7, YP 13, Gel 7/18, pH 10.8, WL 20.0, Cake 3.0, Alk 0.1, CI16,000, Ca 680, Solids 14.0, Oil 1.0, Added 270sx Barite & Isx Flo-Vis. LD/PU Drill Pipe/Tbg 9-1/2 hrs, Circ 5 hrs, Other 4-112 hrs, Trip 4-1/2 hrs, PU/LD BHA & Tools 112 hr. Built mud vol. C & C mud. Circ between 7" & 9-5/8" csg strings. POH & LD 7" csg. Rec 51 jts & 2 cut off jts. PU mech csg cutter & TIH. Cut 7" csg @ 2,675'. TOH (wet). LD cutter & PU spear/grapple & TIH. Caught fish @ 2,075' & pulled free. Did not have to jar. Circ btms up. Got cmt contaminated mud back. Ppd pill. TOH to csg @ surf. Unloaded boat & cleaned rig floor, wellhead room & cellar. Will back load boat w/all mill/metal munching equip. Broke out spear/grapple assbly. Back loaded boat. Prep to LD +/-600' of 7" csg. Top of 7" csg @ 2,675'. 3/05/02 TOH w/9-5/8" Csg Scraper, MW 11.2, Vis 39, PV 7, YP 14, Gels 8/18, Ph 10.5, WL 20.0, Cake 3.0, Alk 0.1, CI12,000, Ca 680, Solids 14.5, Oil 1.0, Added 40sx Barite. Trip 9 hrs, LD/PU Drill 2 . . PipefTbg 5 hrs, PU/LD BHA & Tools 4 hrs, Other 3-1/2 hrs, Circ 2-1/2 hrs. LD 7" csg (15 jts & cut off). TIH w/csg spear assbly. Engaged csg @ 2,675'. Attempted to jar & pull (cut @ 4,000), no success. ReI spear & POH. LD jars & spear assbly. Stood back DC's. PU & re-dressed csg cutters. TIH w/mechanical cutters. Cut 7" csg @ 3,350'. Ppd dry job & POH. LD cutter assbly. PU spear & jarring assbly. TIH. Engaged csg @ 2,675'. Pulled free w/o jarring. Circ btms up & ppd dry job. POH to spear assbly. Stood back DC's. ill spear & jars. LD 7" csg. Unloaded cmt, mud, etc. fr/boat. LD remainder of 7" csg. Top of 7" csg stub now @ 3,350' DPM. PU & MU 9-5/8" csg scraper assbly. TIH & tagged up on 7" csg stub. Circ hole clean. Ppd dry job. Std TOH w/9-5/8" csg scraper. 3/06/02 Prep To Test BOP, MW 11.0, Vis 36, PV 7, YP 17, Gels 10/30, pH 11.8, WL 20.0, Cake 3.0, Alk 0.6, ClI2,000, Ca 880, Solids 14.0, Oil 1.0, MBT 10.0, Added Isx citric acid. RU/RD Service Tools 7-1/2 hrs, LD/PU Drill PipefTbg 5 hrs, Cmt Plug 3 hrs, Trip 3 hrs, Circ 2 hrs, Cmt'd 1-1/2 hr, Tstd BOP/Diverter 1 hr, Service Rig 1 hr. TOH. LD 9-5/8" csg scraper. RU APRS WL unit. Ran 9- 5/8" cmt retainer on wire line & set @ 3,340'. TIH w/3-1/2" open ended DP. Circ. Ppd 10 bbls fresh wtr pre-flush, followed by 15 bbls (73sx) of Cl"G" cmt containing 0.2% BWOC CD-32, 1 gal/100sx FP-6L. Disp w/l bbl FW & drlg mud. Pulled DP up to 3,030'. Ppd dwn DP wiper plug. Opened circ sub & circ DP vol. Serviced top drive. Cleared deck. Prep to LD 3-1/2" DP. LD all 3- 1/2" DP. Chg'd out saver sub, pipe handler, stabbing guide, jaws on ruffneck and rams in BOP frl3- 1/2" to 5". Chg'd out small bell nipple. Prep totst BOP. 3/07/02 Circ Out Contaminated Mud, MW 11.0, Vis 36, PV 7, YP 17, Gels 10/30, pH 11.8, WL 20.0, Cake 3.0, Alk 0.6, ClI2,000, Ca 880, Solids 14.0, Oil 1.0, MBT 10.0. LD/PU Drill Pipe/Tbg 11 hrs, Tstd BOP/Diverter 5 hrs, NU/ND BOP/Diverter 3-1/2 hrs, Circ 3 hrs, Others 1-1/2 hr. Tstd BOP to 250- 5,000 psig (Tom Maunder w/AOGCC waived witnessing BOP tst). Fin NU bell nipple & flowline. PU 5" DP, stood back in derrick. Unloaded boat. PU 5" DP. Circ out contaminated mud. Circ @ 3,200'. 3/08/02 Working On Pits Before Mixing Mud, MW 8.6, Vis 28, PV 1. Cleaned Mud Tanks 9-1/2 hrs, Other 7 hrs, Circ 4 hrs, Disp 3 hrs, W & R 1/2 hr. Tagged hard cmt @ 3,205'. Dress cmt plug to 3,231' (109' above retainer). Circ btms up & cleaned pits. Chg'd over to FIW. Cleaned pits & disposed of waste. Installed troughs in mud pit. Flanged up J tube below deck. Removed lazy susan & cleaned. Trouble shot elec prob in generators #5 & #6. RU EPOCH & Baker Inteq dog houses. 3/09/02 Trip In Hole w/Whipstock, MW 9.1, Vis 73, PV 10, YP 23, Gels 10/13, pH 9.5, WL 7.0, Cake 1.0, Alk 0.3, ClI6,500, Ca 1,400, Solids 3.5, Added 192sx Barite, 9sx Drispac S.L., 27sx Flow-Vis, Isx SAPP & 5sx SA. Build Mud Vol 13 hrs, Run/Retrieve Whipstock 5-1/2 hrs, Disp 3 hrs, Trip 2-1/2 hrs. Mixed mud. Fabricated trough to J-tube dump. Trouble shot DC generator. Disp hole w/9.0 ppg mud. Press tstd csg to 1,000 psig. TOH. MU 9-5/8" Baker whipstock & milling assbly. TIH w/whipstock @ 90-120 seconds per stand. 3/10/02 Orient Drlg @ 3,262' (63'/24 hrs), MW 9.2, Vis 83, PV 12, YP 39, Gels 17/23, pH 8.5, WL 6.6, Cake 1.0, Alk 0.2, ClI6,500, Ca 1,200, Sd .25, Solids 3.5, Added 48sx Barite, 2sx Drispac S.L., 26sx Flow-Vis & 3sx Kla-Gard, Bit #2,8" Baker Mill, In @ 3,199', Out @ 3,230' (31 no hrs), ROP 3.10, PP 1,250#, SPM 150, GPM 440, Liner Size 5-1/2" x 10", Bit #3,8-1/2", SEC FM2653, SN# 5013585, Bit/Nozzles 14/14/13/13, In @ 3,230' (32'/1 hr), ROP 32.00, WOB 5K, PP 1,250#, SPM 150, GPM 440, Liner Size 5-1/2" x 10". Mill/Cut Sect. Or Window 10 hrs, PU/LD BHA & Tools 6- 1/2 hrs, Trip 2-1/2 hrs, Run/Retrieve Whipstock 1-1/2 hr, Slide Drld 1 hr, Circ 1/2 hr, Orient Tool Face 1/2 hr, Other 1/2 hr, Rig Repair 1/2 hr, W & R 1/2 hr. Fin TIH & setting 9-5/8" whipstock. Milled fr/3,199'-3,230'. Csg window frl3,199'-3,215'. Top string mill got to 3,218'. Circ btms up. - 3 . . Performed lk off tst @ 2,850' TVD w/9.2 ppg MW. Lk'd off @ 475 psig (12.4 ppg EMW). TOH. Stood back HWDP & DC's. LD MWD & mills. TIH w/9 DC's & LD same. MU BHA. Worked on DC pwr (Gen #6). TIH w/directional tools. Oriented tool face & went through window (smooth). Reamed 8" hole fr/3,218'-3,231'. Orient drld w/TF 40R fr/3,230'-3,262'. 3/11/02 Slide Drlg @ 3,940' (678'/24 hrs), SS, Surveys: 40.10 deg @ 3,280' (342.50 deg Azimuth, 2,887' TVD), 44.50 deg @ 3,469' (348.60 deg Azimuth, 3,027' TVD), 46.80 deg @ 3,661' (354.70 deg Azimuth, 3,160'TVD) & 46.10 deg @ 3,756' (354.00 deg Azimuth, 3,225' TVD), MW 9.0, Vis 49, PV 9, YP 25, Gels 11/14, pH 8.8, WL 7.4, Cake 1.0, Alk 0.2, CI16,500, Ca 800, Sd .35, Solids 3.0, MBT 2.0, Added 9sx caustic soda & 27sx Soltex, Bit #3, In @ 3,230' (710'/23-1/2 hrs), ROP 30.21, WOB lOK, RPM 40, PP 1,350#, SPM 150, GPM 440, Liner Size 5-1/2" x 10". Slide Drlg 13 hrs, Drlg 9-1/2 hrs, Orient Tool Face 1 hr, Survey 1/2 hr. Oriented & rot drld fr/3,262'-3,940'. Now slide drlg w/TF 30L of high side. 3/12/02 Drlg @ 4,830' (890'/24 hrs), SS, Surveys: 47.60 deg @ 4,040' (352.90 deg Azimuth, 3,420' TVD), 46.80 deg @ 4,227' (350.40 deg Azimuth, 3,546'TVD), 46.00 deg @ 4,509' (351.10 deg Azimuth, 3,742' TVD) & 45.70 deg @ 4,702' (351.10 deg Azimuth, 3,876' TVD), MW 9.0, Vis 51, PV 11, YP 25, Gels 10/13, pH 10.0, WL 7.8, Cake 1.0, Alk 0.3, CI16,500, Ca 120, Sd .5, Solids 4.0, MBT 5.0, Added 30sx Barite, 15sx c~ustic soda, lOsx Drispac SL, 2sx Kla-Gard & 20sx Soltex, Bit #3, In @ 3,230' (1,600'/45 hrs), ROP 35.56, WOB lOK, RPM 40, PP 1,450#, SPM 150, GPM 440, Liner Size 5-1/2" x 10". Drlg 21 hrs, Wiper Trip/Short Trip 2-1/2 hrs, Slide Drlg 1/2 hI. Drld fr/3,940'- 4,199'. Made short trip to 3,161'. Drld fr/4,199'-4,830'. 3/13/02 Drlg @ 5,315' (485'/24 hrs), SS, Surveys: 44.90 deg @ 4,891' (351.10 deg Azimuth, 4,009' TVD), 44.70 deg @ 5,073' (350.10 deg Azimuth, 4,138'TVD) & 45.60 deg @ 5,169' (350.80 deg Azimuth, 4,205'TVD), MW 9.1, Vis 54, PV 14, YP 25, Gels 8/13, pH 9.9, WL 7.2, Cake 1.0, Alk 0.3, CI16,500, Ca 60, Sd .35, Solids 5.0, MBT 6.0, Added 42sx Barite, Ilsx caustic soda, Isx Defoam X, 15sx Drispac SL, 32sx Durogel, 3sx Flo-Vis, 4sx Kla-Gard, 20sx Resinex & lOsx Soltex, Bit #3, In @ 3,230' (2,085'/67 hrs), ROP 31.12, WOB 15K, RPM 40, PP 1,450#, SPM 150, GPM 440, Liner Size 5-112" x 10". Drlg 15 hrs, Drill Slide 7 hrs, Wiper Trip/Short Trip 1-1/2 hr, Circ 1/2 hr. Drld fr/4,830'-5,139'. Made short trip to 4,200'. Drld fr/5,139'-5,315. 3/14/02 Prep To Test BOP @ 5,643' (328'/24 hrs), SS, Surveys: 46.60 deg @ 5,357' (350.80 deg Azimuth, 4,335' TVD) & 46.10 deg @ 5,544' (350.80 deg Azimuth, 4,463'TVD), MW 9.2, Vis 47, PV 13, YP 21, Gels 6/11, pH 9.8, WL 7.0, Cake 2.0, Alk 0.2, CI16,500, Ca 60, Sd .25, Solids 5.0, MBT 6.0, Added 50sx Barite, 6sx caustic soda, 6sx Drispac SL, Isx Flo-Vis, Isx Kla-Gard, 5sx Resinex, Isx SAPP & 8sx Soltex, Bit #3, In @ 3,230', Out @ 5,643' (2,413'/83-1/2 hrs), ROP 28.90, WOB 12K, RPM 40, PP 1,500#, SPM 150, GPM 440, Liner Size 5-1/2" x 10". Drlg 14 hrs, Trip 3 hrs, Slide Drlg 2-1/2 hrs, PU/LD BHA & Tools 2-1/2 hrs, Circ 1-1/2 hr, Tst BOP/Diverter 1/2 hr. Drld fr/5,315'-5,643'. MWD failed. TOH. Dwn loaded MWD. Prep to tst BOP. 3/15/02 Drlg 8-1/2" Hole @ 5,900' (257'/24 hrs), SS, Surveys: 46.60 deg @ 5,645' (350.40 deg Azimuth, 4,533' TVD) & 47.20 deg @ 5,735' (350.40 deg Azimuth, 4,595'TVD), MW 9.2, Vis 57, PV 14, yP 21, Gels 6/11, pH 9.3, WL 7.1, Cake 2.0, Alk 0.2, CI16,500, Ca 60, Sd .25, Solids 5.5, MBT 6.0, Added Isx caustic soda & Isx Flo-Vis, Bit #4,8-1/2", SEC FM2643, SN# 5013393, Bit/Nozzles 14/13/14/13, In @ 5,643' (257'/7 hrs), ROP 36.71, WOB lOK, RPM 40, PP 1,600#, SPM 150, GPM 440, Liner Size 5-1/2" x 10". Drlg 7 hrs, Tstd BOP/Diverter 4 hrs, LD/PU Drill Pipe/Tbg 3-1/2 hrs, PU/LD BHA & Tools 3-1/2 hrs, Trip 3 hrs, W & R 2 hrs, Slip & Cut Drlg Line 1 hr. Press tstd BOP (Tom Maunder w/AOGCC waived witnessing of BOP tst). PU 5" DP. Slipped 4 . . & cut drlg line. Fin PU 5" DP. Circ thru DP. PU & MU BHA (new mtr & MWD). Till, reamed thru tight spots @ 3,600' & 4,900'. W & R fr/5,450'-5,643'. Rot drld fr/5,643'-5,900'. 3/16/02 Drlg 8-1/2" Hole @ 6,375' (475'124 hrs), Sd, Coal & Clay, Surveys: 47.30 deg @ 6,019' (350.80 deg Azimuth, 4,787'TVD) & 47.30 deg @ 6,209' (350.40 deg Azimuth, 4,916'TVD), MW 9.2, Vis 50, PV 13, YP 23, Gels 7/12, pH 9.2, WL 7.0, Cake 2.0, Alk 0.3, CI16,500, Ca 50, Sd .25, Solids 5.5, MBT 5.0, Added lOsx caustic soda, 2sx Defoam X, 2sx drlg detergent, lOsx Drispac SL, 11sx Flo- Vis, 1sx Kla-Gard, lOsx Resinex & lOsx Soltex, Bit #4, In @ 5,643' (732'/30 hrs), Rap 24.40, WOB 15K, RPM 40, PP 1,600#, SPM 150, GPM 440, Liner Size 5-1/2" x lO".Drlg 22 hrs, Survey 1 hr, Slide Drld 1 hr. Drld fr/5,900'-6,375'. 3/17/02 Drlg 8-1/2" Hole @ 6,952' (577'/24 hrs), Sd, Coal & Clay, Surveys: 46.90 deg @ 6,398' (350.10 deg Azimuth, 5,045'TVD), 46.70 deg @ 6,572')35.40 deg Azimuth, 5,164' TVD) & 46.10 deg @ 6,767' (349.40 deg Azimuth, 5,298'TVD), MW 9.3, Vis 55, PV 16, YP 25, Gels 8/16, pH 9.5, WL 6.8, Cake 2.0, Alk 0.3, CI16,500, Ca 70, Sd .25, Solids 6.0, MBT 8.0, Added 50sx Barite, 8sx caustic soda, 1sx drlg detergent, lOsx Drispac SL, 9sx Flo-Vis, 2sx Greencide, 1sx Kla-Gard, lOsx Resinex & lOsx Soltex, Bit #4, In @ 5,643' (1,309151 hrs), Rap 25.67, WOB 20K, RPM 40, PP 1,600#, SPM 150, GPM 440, Liner Size 5-1/2" x 10". Drlg 20-1/2 hrs, Wiper Trip/Short Trip 1-1/2 hr, Survey 1 hr, Oriented Tool Face 1/2 hr, Slide Drld 1/2 hr. Drld fr/6,375'-6,400'. Made 10 stand short trip. Drlg fr/6,400'-6,952'. 3/18/02 Drlg 8-1/2" Hole @ 7,581' (629'124 hrs), Sd, Coal & Clay, Surveys: 46.10 deg @ 7,047' (349.40 deg Azimuth, 5,492' TVD), 46.70 deg @ 7,234' (350.40 deg Azimuth, 5,622'TVD) & 46.10 deg @ 7,425' (350.80 deg Azimuth, 5,754'TVD), MW 9.3, Vis 56, PV 15, YP 25, Gels 8/14, pH 9.5, WL 7.5, Cake 2.0, Alk 0.3, CI16,500, Ca 40, Sd .2, Solids 6.0, MBT 10.0, Added 50sx Barite, 9sx caustic soda, 2sx Defoam X, lOsx Drispac SL, 1sx Flo-Vis, 1sx Greencide, 1sx Kla-Gard, lOsx Resinex, 2sx Sapp & lOsx Soltex, Bit #4, In @ 5,643' (1,938'/71-1/2 hrs), Rap 27.10, WOB 20K, RPM 40, PP 1,700#, SPM 150, GPM 440, Liner Size 5-1/2" x 10". Drlg 18-1/2 hrs, Slide Drld 2 hrs, Circ 1 hr, Orient Tool Face 1 hr, Wiper Trip/Short Trip 1 hr, Survey 1/2 hr. Drld fr/6,952'-7,147'. Made wiper trip to 6,171'. Drld fr/7,147'-7,581'. 3/19/02 Drlg 8-1/2" Hole @ 8,120' (539'124 hrs), Sd, Coal & Clay, Surveys: 47.10 deg @ 7,615' (350.10 deg Azimuth, 5,884'TVD), 47.40 deg @ 7,795' (351.50 deg Azimuth, 6,006' TVD) & 46.30 deg @ 7,986' (351.50 deg Azimuth, 6,137'TVD), MW 9.3, Vis 51, PV 16, YP 25, Gels 8/16, pH 9.5, WL 7.6, Cake 2.0, Alk 0.2, CI16,500, Ca 40, Sd .2, Solids 6.0, MBT 10.0, Added 8sx caustic soda, 12sx Drispac SL, 4sx Flo-Vis, 1sx Greencide, 1sx Kla-Gard, 12sx Resinex, 2sx Sapp & lOsx Soltex, Bit #4, In @ 5,643' (2,477'/93 hrs), Rap 26.63, WOB 15K, RPM 40, PP 1,750#, SPM 150, GPM 440, Liner Size 5-1/2" x 10". Drlg 20 hrs, Slide Drld 1-1/2 hr, RU/RD Service Tools 1 hr, Survey 1 hr, Oriented Tool Face 1/2 hr. Drld fr/7,581 '-8,120'. 3/20/02 Drlg 8-1/2" Hole @ 8,217' (97'/24 hrs), Sd, Coal & Clay, Survey: 45.60 deg @ 8,079' (350.80 deg Azimuth, 6,201'TVD), MW 9.3, Vis 55, PV 15, YP 25, Gels 7/15, pH 9.5, WL 7.2, Cake 2.0, Alk 0.3, CI16,500, Ca 40, Sd .2, Solids 6.0, MBT 10.0, Added 50sx Barite, 4sx caustic soda, 6sx Drispac SL, 2sx Flo-Vis, 6sx Resinex & 5sx Soltex, Bit #4, In @ 5,643', Out @ 8,143' (2,500'/95 hrs), Rap 26.32, WOB 15K, RPM 40, PP 1,750#, SPM 150, GPM 440, Liner Size 5-1/2" x 10", Bit #5,8-1/2", mc DP0622, SN# 7100095, Bit/Nozzles 15/15/14/14, In @ 8,143' (74'12-1/2 hrs), Rap 29.60, WOB lOK, RPM 40, PP 1,750#, SPM 150, GPM 440, Liner Size 5-1/2" x 10". Trip 6-1/2 hrs, Drlg 4 hrs, LD/PU Drill Pipe/Tbg 3-1/2 hrs, Test BOP/Diverter 3-1/2 hrs, PU/LD BHA & Tools 3 hrs, Circ 1-1/2 hr, W & R 1 hr, Slide Drld 1/2 hr, Service Rig 1/2 hr. Rot drld to 8,143'. Back reamed. Ran survey. Circ btms up. POH. Broke dwn bit. Dwn loaded MWD. LD MPR, MWD & 5 . . mtr. Tstd BOP 250 psig & 3,000 psig (Tom Maunder w/ AOGCC waived witnessing the tst). PU 63 jts 5" DP. Ppd thru & stood back in derrick. PU MWD, MPR & mtr. Scribed mtr. Programmed MWD & tstd. MU bit. RIH. Serviced rig, top drive & iron rufneck at the window. Rill. Broke circ & washed fr/8,021 '-8,143'. Rot drld fr/8,143'-8,155'. Circ out trip gas (1,000 units), lots of coal. Ran survey & oriented TF. Slide drld fr/8,155'-8,168' (sticky). Rot drld to 8,217'. 3/21/02 Drlg 8-1/2" Hole @ 8,879' (662'/24 hrs), Sd, Coal & Clay, Surveys: 46.30 deg @ 8,171' (350.40 deg Azimuth, 6,265'TVD), 46.90 deg @ 8,359' (349.70 deg Azimuth, 6,395' TVD), 46.80 deg @ 8,545' (349.70 deg Azimuth, 6,523' TVD) & 45.60 deg @ 8,733' (351.50 deg Azimuth, 6,652' TVD), MW 9.4, Vis 49, PV 13, YP 19, Gels 6/13, pH 9.0, WL 8.0, Cake 2.0, Alk 0.2, CI16,500, Ca 40, Sd .2, Solids 6.5, Oil 0.5, MBT 10.0, Added 8sx caustic soda, 12sx Drispac SL, 6sx Flo- Vis, Isx Greencide, 2sx Lubtex, 13sx Resinex & lOsx Soltex, Bit #5, In @ 8,143' (736'123-1/2 hrs), ROP 31.32, WOB 15K, RPM 40, PP 1,650#, SPM 150, GPM 440, Liner Size 5-1/2" x 10". Drlg 15-1/2 hrs, Slide Drlg 5-1/2 hrs, Survey 1-1/2 hr, Orient Tool Face 1 hr, W & R 1/2 hr. Rot drld fr/8,217'-8,335'. Back reamed. Ran survey. Made conn. Oriented TF. Slide drld high side fr/8,335'- 8,358'. Rot drld to 8,424'. Back reamed. Ran survey. Made conn. Rot drld to 8,516'. Back reamed. Ran survey. Made conn. Rot drld to 8,609'. Back reamed. Ran survey. Made conn. Rot drld to 8,805'. Back reamed. Ran survey. Made conn. Oriented TF. Slide drld high side fr/8,805'-8,818'. Rot drld to 8,852'. Slide drld high side fr/8,852'-8,867'. Back reamed. Ran survey. Rot drld to 8,879'. 3/22/02 Drlg @ 9,096' (217'/24 hrs), Sd, Coal & Clay, MW 9.4, Vis 51, PV 15, yP 21, Gels 7/14, pH 9.5, WL 7.0, Cake 2.0, Alk 0.3, CI16,500, Ca 80, Sd.2, Solids 6.5, Oil 0.5, MBT 10.0, Added 80s x Barite, llsx caustic soda, 15sx Drispac SL, 12sx Flo-Vis, 2sx Lubtex, 14sx Resinex & lOsx Soltex, Bit #5, In @ 8,143', Out @ 8,990' (847'/31-1/2 hrs), ROP 26.89, WOB 15K, RPM 40, PP 1,450#, SPM 75, GPM 220, Liner Size 5-1/2" x 10", Bit #6,8-1/2", SEC FM2843, SN# 5013156, Bit/Nozzles 13/13/13/14, In @ 8,990' (106'/4 hrs), ROP 26.50, WOB lOK, RPM 50, PP 1,450#, SPM 75, GPM 220, Liner Size 5-1/2" x 10". Drlg 12 hrs, Trip 6 hrs, PU/LD BHA & Tools 2-1/2 hrs, Wiper Trip/Short Trip 1 hr, Ppd Pill 1/2 hr, W & R 1/2 hr, Circ 1/2 hr, LD/PU Drill Pipe/Tbg 1/2 hr, RU/RD Service Tools 1/2 hr. Drld fr/8,879'-8,894'. Made wiper trip to 7,770'. Till. Drld fr/8,894'-8,990'. Circ. Ppd dry job. TOH (smooth). Till. W & R fr/8,913'-8,990'. Rot drld fr/8,990'- 9,096'. 3/23/02 Drlg @ 9,432' (336'/24 hrs), Sd, Coal & Clay, Surveys: 47.20 deg @ 9,126' (349.40 deg Azimuth, 6,926' TVD) & 46.90 deg @ 9,314' (350.10 deg Azimuth, 7,053'TVD), MW 9.3, Vis 59, PV 16, YP 25, Gels 7/13, pH 9.8, WL 6.0, Cake 2.0, Alk 0.3, CI16,500, Ca 80, Sd .2, Solids 6.0, Oil 0.5, MBT 8.0, Added 12sx caustic soda, 17sx Drispac SL, llsx Flo-Vis, Isx Greencide, 17sx Resinex & lOsx Soltex, Bit #6, In @ 8,990' (442'128 hrs), ROP 15.79, WOB 15K, RPM 60, PP 1,700#, SPM 75, GPM 220, Liner Size 5-1/2" x 10". Drlg 22-1/2 hrs, Slide Drlg 1-1/2 hr. Rot drld fr/9,096'- 9,104'. Slide drld fr/9,104'-9,124' w/HS TF. Rot drld fr/9,124'-9,432'. 3/24/02 Drlg @ 9,601' (169'/24 hrs), Sd, Coal & Clay, Survey: 45.90 deg @ 9,500' (351.10 deg Azimuth, 7,181' TVD), MW 9.3, Vis 56, PV 17, YP 25, Gels 7/14, pH 9.4, WL 6.1, Cake 2.0, Alk 0.2, Cl 16,500, Ca 80, Sd .1, Solids 6.0, Oil 0.5, MBT 8.0, Added 40sx Barite, 8sx caustic soda, lOsx Drispac SL, 5sx Flo-Vis, Isx Greencide, lOsx Resinex & lOsx Soltex, Bit #6, In @ 8,990' (611 '/50 hrs), ROP 12.22, WOB 15K, RPM 50, PP 1,700#, SPM 75, GPM 220, Liner Size 5-1/2" x 10". Drlg 22 hrs, Wiper Trip/Short Trip 1 hr, Circ 1 hr. Drld fr/9,432'-9,475'. Circ. Made wiper trip to 8,536' (smooth). Drld fr/9,475'-9,601'. 6 . . 3/25/02 Slide Drlg @ 9,789' (188'/24 hrs), Sd, Coal & Clay, Survey: 45.90 deg @ 9,690' (350.40 deg Azimuth, 7,313' TVD), MW 9.3, Vis 60, PV 18, YP 27, Gels 8/15, pH 9.3, WL 6.2, Cake 2.0, Alk 0.2, ClI6,500, Ca 80, Sd .1, Solids 6.0, Oil 0.5, MET 9.0, Added 5sx caustic soda, 9sx Drispac SL, Isx PIo-Vis, lOsx Resinex & lOsx Soltex, Bit #6, In @ 8,990' (799'/72-1/2 hrs), ROP 11.02, WOB 15K, RPM 50, PP 1,700#, SPM 75, GPM 220, Liner Size 5-1/2" x 10". Drlg 16 hrs, Slide Drld 6-1/2 hrs, Wiper Trip/Short Trip 1 hr, W & R 1/2 hI. Drld fr/9,601 '-9,754'. Made wiper trip to 8,910' (smooth). Drld fr/9,754'-9,789' w/TF of 150R. 3/26/02 Circ Hole, Prep To TOH @ 9,954' (165'/24 hrs), Sd, Coal & Clay, Survey: 41.60 deg @ 9,876' (354.00 deg Azimuth, 7,448' TVD), MW 9.3, Vis 63, PV 17, YP 28, Gels 7/17, pH 9.6, WL 6.3, Cake 2.0, Alk 0.3, ClI6,500, Ca 50, Sd .2, Solids 6.0, Oil 0.5, MET 9.0, Added 7sx caustic soda, 6sx Drispac SL, Isx Greencide, lOsx Resinex, 3sx SAPP & lOsx Soltex, Bit #6, In @ 8,990', Out @ 9,954' (964'/95-1/4 hrs), ROP 10.12, WOB 15K, RPM 50, PP 1,700#, SPM 75, GPM 220, Liner Size 5-1/2" x 10". Drlg 13-3/4 hrs, Slide Drld 9 hrs, Circ 1-1/4 hr. Drld fr/9,789'-9,954'. Circ. Prep to TOH. 3/27/02 Drlg @ 10,013' (59'/24 hrs), Sd, Coal & Clay, MW 9.3, Vis 62, PV 17, YP 28, Gels 7/17, pH 9.6, WL 6.0, Cake 2.0, Alk 0.3, ClI6,000, Ca 50, Sd .2, Solids 6.0, Oil 0.5, MET 9.0, Added 80sx Barite, 4sx caustic soda, 2sx Defoam X, 3sx Drispac SL, 5sx Resinex & 5sx Soltex, Bit #7,8-1/2", STC MGR45, SN# JS7571, BitINozzles 12/12/12/11, In @ 9,954' (59'/3 hrs), ROP 19.67, WOB lOK, RPM 50, PP 1,700#, SPM 75, GPM 220, Liner Size 5-1/2" x 10". Trip 7-1/4 hrs, PU/LD BHA & Tools 6 hrs, Tstd BOP/Diverter 3-1/2 hrs, Slide Drld 2 hrs, Slip & Cut Drlg Line 1 hrs, Drlg 1 hr, LD/PU Drill Pipe/Tbg 1 hr, RU/RD Service Tools 1 hr, W & R 1 hr, Circ 1/4 hr. Circ hole. Ppd dry job. TOH. Chg'd out bit. Dwn loaded MWD. Press tstd BOP to 250-5,000 psig, tstd OK. Serviced rig & top drive. PU 24 jts of 5" DP. Circ clean & stood back in derrick. Chg'd out mtr & MWD MPR. Scribed & programmed same. Chg'd out jars & bumper sub. MU Bit #7. TllI to window @ 3,215'. Slipped & cut drlg line. Cont'd TllI to 8,880'. W & R fr/8,880'-8,913'. TllI t 9,854'. Reamed fr/9,854'-9,954'. Slide drld fr/9,954'-9,979'wffF of 155R. Rot drld fr/9,979'-1O,013'. 3/28/02 Running Short Trip/Wiper Trip @ 10,340' (327'/24 hrs), Sd, Coal & Clay, Surveys: 34.00 deg @ 10,158' (357.50 deg Azimuth, 7,670'TVD) & 31.40 deg @ 10,253' (375.10 deg Azimuth, 7,750' TVD), MW 9.4, Vis 61, PV 16, YP 24, Gels 7/16, pH 9.4, WL 6.3, Cake 2.0, Alk 0.3, ClI5,550, Ca 40, Sd .2, Solids 6.5, Oil 0.5, MET 9.0, Added 7sx caustic soda, Ilsx Drispac SL, 2sx Greencide, Ilsx Resinex, 3sx SAPP & lOsx Soltex, Bit #7, In @ 9,954' (386'/24 hrs), ROP 16.08, WOB 15K, RPM 50, PP 1,800#, SPM 75, GPM 220, Liner Size 5-1/2" x 10". Drlg 11-1/2 hrs, Slide Drld 9-1/2 hrs, Orient Tool Face 1-1/2 hr, Circ 1 hr, Wiper Trip/Short Trip 1/2 hr. Rot drld fr/1O,013'-1O,034'. Oriented tool face. Slide & orient drld fr/1O,034'-1O,064'w/TF of 165L. Rot drld fr/1O,064'-1O,128'. Oriented tool face. Slide & orient drld fr/1O,126'-1O,166'w/TF of 140L. Rot drld fr/1O,166'-1O,221'. Oriented tool face. Slide & orient drld fr/1O,221 '-10,266' w/TF of 160L. Rot drld fr/1O,266'-1O,340'. Circ. Ppd dry job & prep for short wiper trip. Running wiper trip/short trip. 3/29/02 Circ & Trouble Shooting Top Drive @ 10,410' (70'/24 hrs), Sd, Coal & Clay, MW 9.4, Vis 66, PV 21, YP 25, Gels 8/17, pH 9.5, WL 6.2, Cake 2.0, Alk 0.3, ClI5,550, Ca 40, Sd .2, Solids 6.5, Oil 0.5, MET 9.0, Added 80sx Barite, 8sx caustic soda, Isx Defoam X, 15sx Drispac SL, 2sx Greencide, 15sx Resinex & lOsx Soltex, Bit #7, In @ 9,954' (456'/35-1/2 hrs), ROP 12.85, WOB 15K, RPM 50, PP 2,000#, SPM 75, GPM 220, Liner Size 5-1/2" x 10". Rig Repair 10-1/2 hrs, Slide Drld 7 hrs, Drlg 4-1/2 hrs, Wiper Trip/Short Trip 1-1/2 hr, W & R 1/2 hI. TOH for wiper trip to 8,726'. TllI. W & R fr/1O,280'-1O,340'. Slide drld fr/1O,340'-1O,385'wffF of 170R. Rot drld fr/1O,385'-1O,41O'. Circ hole. Top drive mtr (CAT 398) failed (fuel inj cam). Unable to rot pipe. Trouble shooting same & circ hole. NC CAT in Anchorage attempting to find re-built parts. 7 . . 3/30/02 Circ OM Btm, Waiting On Parts For Top Drive @ 10,410', Sd, Coal & Clay, MW 9.3, Vis 64, PV 19, YP 21, Gels 6/13, pH 9.5, WL 5.5, Cake 2.0, Alk 0.3, CI15,550, Ca 40, Sd .2, Solids 6.0, Oil 0.5, MBT 10.0, Added 3sx caustic soda, Isx Defoam X, 13sx DESCO Chrome Free & 3sx Drispac SL, Bit #7, In @ 9,954' (456'/35-112 hrs), ROP 12.85, WOB 15K, RPM 50, PP 2,000#, SPM 75, GPM 220, Liner Size 5-112" x 10". Rig Repair 24 hrs. Waiting on parts to repr top drive (fuel inj pkg fr/CAT 398 top drive). Gathered parts from CAT in Anchorage & Nabors Drlg Co. NC CAT's mech specialist arrived in Anchorage frNaldez. Mech specialist will be @ XTO heliport w/parts & tools this am. Circ hole fr/btm. No problems w/hole @ present. 3/31102 Drlg @ 10,522', (112'/24 hrs), Sd, Coal & Clay, Survey: 27.90 deg @ 10,440' (1.70 deg Azimuth, 7,913' TVD), MW 9.4, Vis 64, PV 18, YP 21, Gels 7/13, pH 9.5, WL 5.6, Cake 2.0, Alk 0.3, CI 15,550, Ca 40, Sd .2, Solids 6.5, Oil 0.1, MBT 9.0, Added 40sx Barite, 3sx caustic soda, 2sx Defoam X, 4sx Drispac SL, Isx Greencide & 5sx Soltex, Bit #7, In @ 9,954' (568'/44 hrs), ROP 12.91, WOB 15K, RPM 50, PP 1,750#, SPM 75, GPM 220, Liner Size 5-112" x 10". Rig Repair 12 hrs, Drlg 5 hrs, Slide Drlg 3-112 hrs, Wiper Trip/Short Trip 1-1/2 hr, Circ 1-112 hr, W & R 112 hr. Circ hole & worked pipe @ 10,410' while repairing top drive mtr. NC CAT mech specialist arrived on first chopper w/parts & tools. Installed replacement fuel inj unit on CAT 398. Std mtr & warmed up same. Began rotating pipe. Rot & circ btms up. Ppd dry-job. Made wiper trip to 8,726' (smooth). W & R fr/1O,320'-1O,41O'. Rot drld fr/1O,41O'-1O,440'. Slide drld fr/1O,440'-1O,485'w/TF of 160R. Rot drld fr/1O,485'-1O,522'. 4/01102 C & C Hole For 7" Csg @ 10,706', (184'/24 hrs), Sd, Coal & Clay, Surveys: 25.00 deg @ 10,532' (5.90 deg Azimuth, 7,995' TVD) & 25.10 deg @ 10,641' (8.00 deg Azimuth, 8,094' TVD), MW 9.4, Vis 61, PV 22, yP 22, Gels 6/17, pH 9.7, WL 5.8, Cake 2.0, Alk 0.3, CI16,000, Ca 60, Sd .1, Solids 6.5, Oil 0.1, MBT 10.0, Added 5sx Aquapac-LV, 60sx Barite, 6sx caustic soda, 4sx Defoam X, 5sx Drispac SL, Isx Flo-Vis, 2sx Greencide & 5sx Soltex, Bit #7, In @ 9,954', Out @ 10,706' (752'/57-1/2 hrs), ROP 13.08, WOB 15K, RPM 50, PP 1,750#, SPM 75, GPM 220, Liner Size 5,. 1/2" x 10". Drlg 13-112 hrs, Trip 7 hrs, Circ 3 hrs, W & R 1/2 hr. Rot drld fr/1O,522'-1O,706'. Drld 2 marker coals & verified w/Mike Langler. Will stop & run 7" csg. Circ hole clean & ppd dry job. TOH to 3,430'. W & R out coal fr/3,430'-3,455'. Pulled bit into window @ 3,215'. TIH to 10,706', smooth, no fill. C & C hole. Prep to run 7" csg. 4/02/02 Running 7" Casing @ 10,706', Sd, Coal & Clay, MW 9.5, Vis 58, PV 19, yP 15, Gels 5/12, pH 9.7, WL 5.8, Cake 2.0, Alk 0.3, CI16,000, Ca 60, Sd .1, Solids 6.5, Oil 0.1, MBT 10.0, Added 3sx Aquapac-LV, 40sx Barite, 2sx caustic soda, 2sx Defoam X, 12sx DESCO Chrome Free, Isx Greencide & 6sx Resinex. RunlRetrieve Casing 9 hrs, Circ 4-112 hrs, Trip 3-1/2 hrs, RU/RD Service Tools 3 hrs, PU/LD BHA & Tools 2-112 hrs, Other 1-1/2 hr. C & C hole for 7" csg. TOH, very smooth trip. LD BHA. Pulled wear ring. Changed rams to 7". Tstd BOP to 2,000 psig, tstd OK. RU to run 7" csg. Held pre-job safety meeting. Ran 7" csg to window. Circ one csg vol. Cont'd running 7" csg, 129 jts in hole @ rpt time (5,841). 4/03/02 NU BOP @ 10,706', Sd, Coal & Clay, MW 9.5, Vis 58, PV 19, yP 15, Gels 5/12, pH 9.7, WL 5.8, Cake 2.0, Alk 0.3, CI16,000, Ca 60, Sd .1, Solids 6.5, Oil 0.1, MBT 10.0, Added 5sx caustic soda. Other 8-3/4 hrs, RunlRetrieve Csg 6 hrs, Circ 3 hrs, Cmt'd 2-3/4 hrs, NU/ND BOP/Diverter 2-112 hrs, RU/RD Service Tools 1 hr. Fin running 7" csg to TD (10,706). Circ thru csg. Reciprocated pipe. RD csg fill up line. RU cmt'g head. Held pre-job safety meeting. Press tstd surf lines to 4,000 psig, tstd OK. Ppd 30 bbls mud sweep @ 11.5 ppg. Mixed & ppd 218 bbls of CI "G" cmt containing 1 % SMS, 0.4% CD-32, 0.6% FL-52, 0.4% R-3 & 1 GPS FP-6L. Mixed @ 12.5 ppg. Tailed w/18 8 . . bbls of Cl"G" cmt containing 0.6% FL-33, 0.2% CD-32, 0.15% R-3 & FP-6L. Mixed @ a slurry wt of 15.8 ppg. Disp w/397.7 BW. Good circ throughout job. Will run CBl @ a later date to determine TOe. FCP 1,700 psig @ 2 BPM. Bumped plug to 1,700 psig. Floats held. PD @ 19:00 hrs (7:00 pm) 4/2/02. ND BOP stack & riser. Set slips w/145K. Cut off csg & dressed off same. LD cmt'g head, long bails & 350 ton elevators. Chg'd out spacer spool & DSA. MU & installed tbg spool & DSA. Set BOP stack & tstd tbg spool & pack off to 3,000 psig, tstd OK. 4/04/02 Prep to PU 3-1/2" DP @ 10,706', MW 8.6, Vis 28, PV 1, CI16,000. RU/RD Service Tools 8-1/2 hrs, LD/PU Drill Pipe/Tbg 8-1/2 hrs, Tst BOP/Diverter 5 hrs, NU/ND BOP/Diverter 2 hrs. Fin NU BOP, kill, choke & flow lines. Repl bails & rams. Set tst plug. Inserted mouse hole. RU to LD 5" DP. LD 5" DP. Chg'd out saver-sub & top drive equip to 3-1/2" IF. Chg'd rams to VBR's for 3-1/2" DP. Pull tstd plug & MU tst assbly. Press tstd BOP to 250-3,000 psig, tstd OK. LD tst assbly. Set wear ring. RU to PU 3-1/2" DP. 4/05/02 PU 3-1/2" DP @ 10,706', MW 8.6, Vis 28, PV 1, CI16,000. LD/PU Drill Pipe/Tbg 14 hrs, Other 8- 1/2 hrs, Trip 1 hr, Circ 1/2 hr. Picked up & strapped in hole wl3-1/2" DP (rabbited DP). SD to use crane to move groceries fr choppers. Contd in hole w/3-1/2" DP. Cleaned pits while repairing lattice on crane. Contd in hole w/3-1/2" DP. Tagged top of cmt @ 10,495' (113' above FC). Circ 1 volume thru DP. TOH & stood back 35 stands of 3-1/2" DP. Back loaded boat. Cleaned pits. Removed troughs fr shakers. Contd PU 3-1/2" DP (tallying & rabbiting pipe going in hole). 4/06/02 Waiting On Boat Containing OBM @ 10,706', Sd, Coal, Clay, MW 8.6, Vis 28, PV 1, CI16,000. Other 22 hrs, LD/PU Drill Pipe/Tbg 2 hrs. Contd TIH & picking up 3-1/2" DP. Tallying & drifting while picking up. Cleaned pits. Removed shaker trough. Plugged "J" tube outside pits. Replaced auger & MTR. Removed spacer spool & DSA fr WH room. Unloaded OBM ISO tnks fr boat. Emptied OBM into pits. Installed auger. Backloaded boat. Cleaned trip tnk & organized mud products. Waiting for boat w/remainder of OBM. 4/07/02 Prep To TIH @ 10,706', Sd, Coal, Clay, MW 8.6, Vis 130, PV 23, YP 8, Gels 7/19, HTHP 2.2, Cake 2.0, Alk 0.9, CI16,000, Solids 3.9, Oil 87.0, Added 30sx Barite & 7,560 gals MAPCO-200. Other 9 hrs, PU/LD BHA & Tools 8 hrs, Trip 3-1/2 hrs, Displ 3-1/2 hrs. Off loaded OBM & logging unit fr boat. Displ hole w/OBM. Pmpd dry job. TOOH. RU SWS & ran CBT log. Tagged up w/logging tool @ 10,543'. Logged to top surf. Very little cmt fr 5,500' to TOL. PU Bit #8 & BHA. MPR pulser not working. Attempted to re-program, no success. Broke down BHA & picked up 2nd pulser sub. Programmed same. Picked up HWDP & prep to TIH. 4/08/02 Drlg, Increasing MW to 8.6 PPG @ 10,924' (218'/24 hrs), Sd, Coal, Clay, Survey: 22.00 deg @ 10,792' (6.60 deg Azimuth, 8,232' TVD), MW 8.3, Vis 85, PV 24, YP 10, Gels 10/20, HTHP 2.4, Cake 2.0, Alk 1.1, CI20,000, Solids 4.5, Oil 87.0, Added 30sx calcium chloride, 2sx Greencide, 5sx 1m & 3,780 gals MAPCO-200, Bit #8,6", SEC FM2643, SN# 5013392, Bit/Nozzles 17/12/11/17, In @ 10,706' (218'/13-1/2 hrs), ROP 16.15, WOB 8K, RPM 50, PP 2,500#, SPM 65, GPM 191, Liner Size 5-1/2" x 10". Drlg 8 hrs, Slide Drlg 5 hrs, Drld Cmt/Float Equip 3-1/2 hrs, Trip 3 hrs, Circ 1- 1/2 hr, Slip & Cut Drlg Line 1 hr, Other 1 hr, Oriented Tool Face 1/2 hr, Tstd Csg 1/2 hI. TIH w/BHA. Drld cmt stringers to FC @ 10,608'. Press tstd csg to 1,500 psig, tstd okay. Drld out shoe jt. Drld new hole fr 10,706'-10,726'. Performed L.OT. Press up to 1,544 psig (12 ppg MWE), no lk off. Drld new hole fr 10,726'-10,924'. Raising MW due to gas incr (to 8.6 ppg). 9 . . 4/09/02 Drlg 6" Hole @ 11,277' (353'/24 hrs), Sd, Surveys: 20.00 deg @ 10,975' (7.0 deg Azimuth, 8,404' TVD) & 17.40 deg @ 11,165' (8.0 deg Azimuth, 8,584' TVD), MW 8.9, Vis 91, PV 31, YP 17, Gels 14/27, HTHP 3.2, Cake 2.0, Alk 1.4, C128,000, Sd .25, Solids 6.0, Oil 75.0, Added 265sx Barite, 50sx calcium chloride, 15sx 1m, 8,400 gals MAPCO-200, 2sx Versacoat, Isx Versamod & 2sx Versawet, Bit #8, In @ 10,706' (571 '/36 hrs), Rap 15.86, WOB lOK, RPM 40, PP 3,100#, SPM 75, GPM 220, Liner Size 5-1/2" x 10". Drlg 13-1/2 hrs, Slide Drlg 9 hrs, Survey 1 hr, Orient Tool Face 1/2 hI. Drld fr/l0,924'-11,277'. 4/10/02 Orient Drlg With Toolface Of 85L @ 11,407' (130'/24 hrs), Sd, MW 9.1, Vis 132, PV 29, YP 18, Gels 14/25, HTHP 3.8, Cake 2.0, Alk 1.2, C130,000, Sd .25, Solids 7.0, Oil 73.0, Added 119sx Barite, 40sx calcium chloride, 8sx 1m, 4,200 gals MAPCO-200, 3sx Versacoat & Isx Versawet, Bit #8, In @ 10,706', Out @ 11,290' (584'/36-1/2 hrs), Rap 16.00, WOB lOK, RPM 40, PP 3,000#, SPM 70, GPM 205, Liner Size 5-1/2" x 10", Bit #9,6" STC XR20H, SN# MK1137, Bit/Nozzles 16/18/18, In @ 11,290' (117'/4-1/2 hrs), Rap 26.00, WOB lOK, RPM 40, PP 3,000#, SPM 70, GPM 205, Liner Size 5-1/2" x 10". Trip 7 hrs, Slide Drlg 4-1/2 hrs, PU/LD BRA & Tools 4 hrs, W & R 3 hrs, Serviced Rig 2-1/2 hrs, Circ 1 hr, Pmpd Pill 1 hr, Drlg 1/2 hr, Survey 1/2 hr. Drld fr 11,277'- 11,290'. TOH. Had to pmp BHA off btm & back ream to 10,114'. Pmpd dry job. TOH to chg BHA. Down loaded MWD. Adjusted MTR setting to 1.6 deg AKa. TIH. W & R fr 11,220'-11,290'. Drld fr 11,290 '-11 ,407'. Now slide drlg w /TF of 85L. 4/11/02 Circ, Prep To Trip For Bit @ 11,712' (305'/24 hrs), Sd, Surveys: 21.70 deg @ 11,443' (317.40 deg Azimuth, 8,846' TVD) & 20.20 deg @ 11,630' (295.20 deg Azimuth, 9,019'TVD), MW 9.3, Vis 82, PV 30, YP 20, Gels 13/18, HTHP 3.8, Cake 2.0, Alk 1.0, C133,000, Sd .25, Solids 7.0, Oil 72.0, Added 186sx Barite, 80sx calcium chloride, 20sx 1m, 8sx Versacoat & 4sx Versawet, Bit #9, In @ 11,290', Out @ 11,712' (422'/26-1/2 hrs), Rap 15.92, WOB 12K, RPM 40, PP 3,000#, SPM 72, GPM 211, Liner Size 5-1/2" x 10". Drlg 15 hrs, Slide Drlg 7 hrs, Circ 1 hr, Orient Tool Face 1/2 hr, Survey 1/2 hr. Drld fr 11,407'-11,712'. Circ hole. Prep to trip for bit. 4/12/02 Drlg 6" Hole @ 11,822' (110'/24 hrs), Sd, MW 9.3, Vis 82, PV 30, YP 21, Gels 13/19, HTHP 3.8, Cake 2.0, Alk 1.0, C132,000, Sd .25, Solids 8.0, Oil 71.0, Added 100sx Barite, 25sx calcium chloride, 25sx 1m, 3sx Versacoat & Isx Versawet, Bit #10,6", SEC 2643R, SN# 5013391, Bit/Nozzles 12/14/14/18, In @ 11,712' (110'/5 hrs), Rap 22.00, WOB lOK, RPM 40, PP 2,800#, SPM 64, GPM 188, Liner Size 5-1/2" x 10". Trip 7 hrs, Test BOP/Diverter 5 hrs, PU/LD BHA & Tools 4-1/2 hrs, Drlg 3 hrs, Slide Drld 2 hrs, Service Rig 1/2 hr, Survey 1/2 hr, Pump Pill 1/2 hr, Orient Tool Face 1/2 hr, Monitor Well 1/2 hI. TOH to 10,600' (had to pmp first 2 stds out of hole). Pmpd dry job & blew dn top drive. Fin TOH. Broke out bit. Down loaded MWD. LD MTR. Monitored well. Pulled wear ring. Press tstd BOP to 250-3,000 psig (John Crisp w/AOGCC waived witnessing of tst). Press built below test plug to 450 psig, while tstg BOP. Std lkg past tst plug @ that point, so no definitive SI press obtained. Set wear ring. Picked up new mud MTR & MWD. Surf ckd same. MU bit. TIH. TIH to 10,674'. Serviced top drive. Contd TIH. WTB 30' (hole in good shape), 850 units trip gas. Inj 250 bbls of wtr cut mud. Drld fr/11,712'-11,822'. 4/13/02 Circ For 6" BHA Change @ 12,044' (222'/24 hrs), Sd, Surveys: 18.20 deg @ 11,756' (294.90 deg Azimuth, 9,138'TVD), 17.50 deg @ 11,849' (293.10 deg Azimuth, 9,226'TVD), 19.70 deg @ 11,942' (292.80 deg Azimuth, 9,314'TVD) & 25.00 deg @ 12,034' (288.60 deg Azimuth, 9,399' TVD), MW 9.3, Vis 89, PV 30, YP 24, Gels 13/17, HTHP 3.5, Cake 1.0, Alk 1.4, C135,000, Sd .25, Solids 8.0, Oil 70.0, Added 120sx Barite, 20sx calcium chloride, lOsx 1m, 12,600 gals MAPCO 200, 4sx Versacoat & 2sx Versawet, Bit #10, In @ 11,712', Out @ 12,044' (332'/23-1/2 hrs), Rap 14.13, WOB lOK, RPM 40, PP 2,800#, SPM 64, GPM 188, Liner Size 5-1/2" x 10". Slide Drld 18 hrs, Rig Repair 4 hrs, Wiper Trip/Short Trip 1-1/2 hrs, Survey 1/2 hr. Slide drld fr 11,822'-11,873' (100R). 10 . . TOH to 7" csg shoe. Closed rams. Changed swivel packing. Changed rubber in gooseneck. Replaced nipple in stand pipe. Press tstd all to 3,000 psig, tstd okay. Csg press steadily built to approx 900 psig while making repairs (was still increasing). Bled press off. TIH. Oriented TF. Slide drld fr 11,873'-11,972'w/TF of 30R. Back reamed hole. Pmpd up survey. Oriented TF. Slide drld fr 11,972'-12,044' w/TF of 30R. 4/14/02 Drlg 6" Hole @ 12,191' (147'/24 hrs), Sd, MW 9.3, Vis 96, PV 31, YP 22, Gels 12/15, HTHP 3.5, Cake 1.0, Alk 1.4, Cl 35,000, Sd .25, Solids 8.0, Oil 68.0, Added 150sx Barite, 40sx calcium chloride, 20sx 1m, 9sx Versacoat & 4sx Versawet, Bit #11,6", Smith, XR20HT, SN# MKl138, Bit/Nozzles 16/18/18, In @ 12,044' (147'/10-1/2 hrs), ROP 14.00, WOB 12K, RPM 40, PP 2,600#, SPM 64, GPM 188, Liner Size 5-1/2" x 10". Trip 6-1/2 hrs, Slide Drld 6-1/2 hrs, Drlg 4 hrs, PU/LD BHA & Tools 3 hrs, Circ 1-1/2 hr, Slip & Cut Drlg Line 1 hr, Orient Tool Face 1/2 hr, W & R 1/2 hr, Survey 1/2 hr. Circ btms up. Mixed & pmpd dry job. TOH for BHA change. Down loaded MWD. Changed mud motor. Set motor @ 1.2 deg AKO. Oriented BHA. Surf checked MWD. MU bit. Prep to Tlli w/new bit. Tlli to 10,659'. Slipped & cut drlg line. TIH to 11,958'. W & R fr 11,958'-12,044'. Slide drld fr 12,044'-12,133'w/TF of 60R to 90R. Disposed of 215 bbls ofwtr cut mud. Had 820 units of trip gas. Back reamed hole. Pmpd up survey. Rot drld fr 12,133'-12,175'. Back reamed hole. Pmpd up survey. Oriented TF. Slide drld fr 12,175'-12,191'. 4/15/02 Rlli w/New 6" Bit @ 12,328' (137'/24 hrs), Sd, Surveys: 29.20 deg @ 12,128' (308.60 deg Azimuth, 9,483'TVD) & 33.40 deg @ 12,224' (317.40 deg Azimuth, 9,565' TVD), MW 9.3, Vis 78, PV 30, YP 20, Gels 8/11, HTHP 4.0, Cake 2.0, Alk 2.0, C137,000, Sd .25, Solids 8.0, Oil 68.0, Added 120sx Barite, lOsx 1m, 12sx Versacoat & 6sx Versawet, Bit #11, In @ 12,044', Out @ 12,328' (284'/23 hrs), ROP 12.35, WOB 15K, RPM 40, PP 2,900#, SPM 68, GPM 199, Liner Size 5- 1/2" x 10", Bit #12,6", HTC, STX408, SN# 7000200, Bit/Nozzles 13/13/18, In @ 12,328', PP 2,600#, SPM 64, GPM 188, Liner Size 5-1/2" x 10". Slide Drld 6-1/2 hrs, Drlg 6 hrs, Trip 6 hrs, PU/LD BHA & Tools 3-1/2 hrs, Circ 1 hr, Survey 1 hr. Slide drld fr 12,191 '-12,225' (40R). Rot drld to 12,255'. Back reamed, ran survey & oriented TF. Slide drld to 12,315' (35R). Back reamed, ran survey & made conn. Rot drld to 12,328'. Circ btms up. Mixed & pmpd dry job. POOH. Broke dn bit. Changed out motor. Down loaded MWD. Adjusted motor & scribe. MU bit & RIH w/BHA. Rlli. 4/16/02 Slide Drlg @ 12,567' (239'/24 hrs), Sd, Surveys: 39.60 deg @ 12,315' (324.80 deg Azimuth, 9,638' TVD) & 43.60 deg @ 12,406' (324.40 deg Azimuth, 9,706' TVD), MW 9.3, Vis 78, PV 28, YP 19, Gels 8/10, HTHP 4.2, Cake 2.0, Alk 1.4, C133,000, Sd .25, Solids 8.0, Oil 67.0, Added 100sx Barite, 20sx calcium chloride, 5sx 1m, 12,600 gals MAPCO 200, 6sx Versacoat & 2sx Versawet, Bit #12,6", HTC, STX408, SN# 7000200, Bit/Nozzles 13/13/18, In @ 12,328' (239'/21-1/2 hrs), ROP 11.12, WOB 15K, RPM 50, PP 3,000#, SPM 64, GPM 188, Liner Size 5-1/2" x 10". Drlg 13-1/2 hrs, Slide Drlg 8 hrs, Survey 1 hr, Trip 1 hr, W & R 1/2 hr. Fin TIH. W & R fr 12,248'-12,328'. Drld fr 12,328'-12,567'. 4/17/02 Tripping For 6" Bit & BOP Test @ 12,729' (162'/24 hrs), Sd, Surveys: 45.40 deg @ 12,501' (325.50 deg Azimuth, 9,774' TVD) & 48.30 deg @ 12,591' (327.90 deg Azimuth, 9,836' TVD), MW 9.3, Vis 79, PV 30, YP 19, Gels 8/10, HTHP 4.5, Cake 2.0, Alk 2.6, Cl 38,000, Sd .25, Solids 8.0, Oil 65.0, Added 50sx Barite, 50sx calcium chloride, 45sx 1m, 8sx Versacoat & 4sx Versawet, Bit #12, In @ 12,328', Out @ 12,729' (401'/40-1/2 hrs), ROP 9.90, WOB 15K, RPM 50, PP 3,000#, SPM 65, GPM 191, Liner Size 5-1/2" x 10". Drlg 16 hrs, Slide Drlg 3 hrs, Circ 1-1/2 hr, Trip 1-1/2 hr, Wiper Trip/Short Trip 1 hr, Open Hole Logging 1 hr. Drld fr 12,567'-12,729'. Circ. Pmpd dry job. Std TOH for bit. 11 . . 4/18/02 Drlg 6" Role @ 12,857' (128'/24 hrs), Sd, Survey: 47.50 deg @ 12,684' (326.20 deg Azimuth, 9,898' TVD), MW 9.2, Vis 100, PV 30, YP 20, Gels 8/10, HTHP 4.5, Cake 2.0, Alk 2.7, CI39,000, Sd .25, Solids 8.0, Oil 64.0, Added 80sx Barite & 8,400 gals MAPCO 200, Bit #13, 6", Smith MGR341, SN# JS7823, Bit/Nozzles 13/13/14/18, In @ 12,729' (128'17-1/2 hrs), ROP 17.07, WOB lOK, RPM 50, PP 3,000#, SPM 64, GPM 188, Liner Size 5-1/2" x 10". Drlg 5-3/4 hrs, Test BOP/Diverter 5-1/2 hrs, PU/LD BRA & Tools 5 hrs, Trip 5 hrs, Slide Drld 1-3/4 hr, W & R 1/2 hr, Survey 1/2 hr. Fin TOR. LD jars & MTR. Downloaded MWD. Pulled wear ring & ran tst plug. Press tstd BOP to 250-3,000 psig (John Crisp w/AOGCC waived witnessing of BOP tst). Picked up new MTR (set to 1.2 deg AKO). Picked up new MWD, scribed & ckd. MU bit. Picked up new jar & bumper sub. TIH to 12,714'. W & R fr 12,714'-12,750'. Drld fr 12,729'-12,857'. Raving trouble sliding. 4/19102 Drlg 6" Role @ 13,009' (152'124 hrs), Sd, Surveys: 46.90 deg @ 12,779' (329 deg Azimuth, 9,963' TVD) & 47.50 deg @ 12,871' (329 deg Azimuth, 10,025' TVD), MW 9.3, Vis 87, PV 32, YP 18, Gels 8/9, HTHP 4.7, Cake 2.0, Alk 2.3, CI40,000, Sd .25, Solids 8.0, Oil 61.0, Added 100sx Barite, 30sx calcium chloride, 20sx caustic soda, 20sx 1m, 4,200 gals MAPCO 200, 4sx Versacoat & 2sx Versamod, Bit #13, In @ 12,729', Out @ 12,918' (189'/14~1/2 hrs), ROP 13.03, WOB 12K, RPM 50, PP 3,000#, SPM 64, GPM 188, Liner Size 5-1/2" x 10", Bit #14,6", SEC FM2643, SN# 5011530, Bit/Nozzles 13/13/14/18, In @ 12,918' (91 '/5 hrs), ROP 18.20, WOB lOK, RPM 40, PP 3,100#, SPM 65, GPM 191, Liner Size 5-1/2" x 10". Trip 8 hrs, Drlg 6 hrs, Drill Slide 6 hrs, PU/LD BRA & Tools 1-1/2 hr, Slip & Cut Drill Line 1 hr, Rig Repair 1/2 hr, Survey 1/2 hr, W & R 1/2 hr. Drld fr/12,857'-12,918'. TOR for new bit. TIH. Drld fr/12,918'-13,009'. 4/20102 TIH wlSlick BRA To Prep For Liner @ 13,155' (146'124 hrs), Sd, Surveys: 38.80 deg @ 12,965' (327.60 deg Azimuth, 10,094' TVD), 29.00 deg @ 13,097' (316.70 deg Azimuth, 10,203' TVD) & 24.00 deg @ 13,155' (314.00 deg Azimuth, 10,255' TVD), MW 9.3, Vis 77, PV 31, YP 20, Gels 8/9, . HTHP 4.7, Cake 2.0, Alk 3.2, CI44,000, Sd .25, Solids 8.0, Oil 62.0, Added 120sx Barite, 80s x calcium chloride, 40sx 1m, 8sx Versacoat & 4sx Versawet, Bit #14, In @ 12,918', Out @ 13,455' (237'/17 hrs), ROP 13.94, WOB lOK, RPM 50, PP 3,150#, SPM 67, GPM 196, Liner Size 5-1/2" x 10". Slide Drld 11-1/2 hrs, Trip 7 hrs, Circ 3 hrs, PU/LD BRA & Tools 1-1/2 hr, Survey 1/2 hr, Drlg 1/2 hr. Slide drld fr 13,009'-13,084'wffF of 180. Backreamed hole. Pmpd up survey & oriented TF. Slide drld fr 13,084'-13,145'w/TF of 180. Rot drld fr 13,145'-13,155'. This will be TD per Mike Langeler. C & C mud. Pmpd dry job. TOR. Tight spot fr 12,840'-12,817'. LD Baker Inteq tools. PU conventional BRA & Bit #10 RR. TIH to condition hole for 5" liner. 4/21/02 Waiting On Boat wÆCP, Pup's & Tools @ 13,155', Sd, MW 9.2, Vis 90, PV 31, YP 20, Gels 8/9, HTHP 4.7, Cake 2.0, Alk 2.9, CI47,000, Sd .25, Solids 8.0, Oil 61.0, Added 80sx calcium chloride, 26sx 1m, 4sx Versacoat & 2sx Versawet. Circ 23-1/2 hrs, Trip 1/2 hr. Fin TIH w!conventional BRA. Smooth going to btm. C & C mud for 5" slotted liner. Pup jt w/threads cut @ Unique Machine (Anchorage) was trucked to Kenai & @ Baker's Shop @ 18:00 hrs. Ready for boat @ 22:00 hrs. Boat was canceled due to Unocal's King Salmon fire. WO boat. 4/22/02 Running 5" Liner On DP @ 13,155', Sd, MW 9.2, Vis 90, PV 31, YP 20, Gels 8/9, HTHP 4.7, Cake 2.0, Alk 2.9, CI47,000, Sd .25, Solids 9.0, Oil 60.0, Added 98sx Barite, 55sx calcium chloride, 40sx 1m & lsx Versacoat. RunIRetrieve Csg 13-1/2 hrs, Circ 4-1/2 hrs, Trip 4 hrs, RU/RD Service Tools 1-1/2 hr, PU/LD BRA & Tools 1/2 hr. C & C mud & hole for 5" slotted liner while WO boat wlequipment. TOR, some over pull @ 12,855' & 12,807'. LD BRA. RU to run 5" liner. Conducted pre-job safety meeting. Picked up & ran 5" liner as per program. Contd in hole w/5" liner on DP (3 minlstand). Csg @ 10,414' @ report time. 12 . . 4/23/02 Till w/Bit & Scraper To Clean Out To Top Of Liner @ 13,155', Sd, MW 9.3, Vis 115, PV 37, YP 24, Gels 9/10, HTHP 5.0, Cake 2.0, Alk 2.9, CI43,000, Sd .25, Solids 8.0, Oil 57.0, Added 40sx Barite. Circ 7 hrs, Trip 6-112 hrs, RunlRetrieve Csg 4 hrs, Other 3-1/2 hrs, LD/PU Drill Pipe/Tbg 3 hrs. Contd in hole w/5" liner on DP. Tagged btm @ 13,148' (7' high). Circ btms up (had to circ trip gas out). Dropped dart, pmpd dn same. Set liner hanger @ 10,385'. Inflated ECP. Opened Howco ES cmtg valve. Press tstd surf lines w/BJ to 3,500 psig, tstd okay. Pmpd 11.5 ppg spacer. Mixed & pmpd 7.6 bbls of 16 ppg cmt slurry. Dropped dart, closed ES cmtg valve. Followed w/5 BW. Displaced wlrig pmp. Bumped plug @ 18:45 hrs 4/22/02. Set Baker ZXP liner top pIa @ 10,371'. POOH wllO stands. Circ hole. Pmpd dry job. LD cmtg head & 1 jt ofDP. TOH. Contd TOH. LD 107 jts 3-112" DP. Picked up bit & scraper. TIH to clean out to top of liner. 4/24/02 TOH To Pick Up Packer #2 @ 13,155', Sd, MW 9.4, Vis 150, PV 42, YP 24, Gels 10/11, HTHP 5.5, Cake 2.0, Alk 1.9, CI40,000, Sd .25, Solids 8.0, Oil 53.0, Added 80sx Barite, 6sx Versacoat & 2sx Versawet. Trip 7-112 hrs, Other 5-1/2 hrs, Monitor Well 4 hrs, Circ 3-112 hrs, Slip & Cut Drlg Line 1 hr, PU/LD BHA & Tools 1 hr, Service Rig 1 hr, Pmpd Pill 112 hr. TIH w/6" bit & 7" scraper. Tagged top of liner pIa @ 10,377' DPM. Circ btms up, could not identify contaminated cmt or spacer. TOH wlbit. Press tstd top of liner pIa. Press to 500 psig, press incr to 25 psig wlslight flow. Slipped & cut drlg line. Fin POOH. Serviced rig. Monitored well & waited on pIa tools. Shut well in, press incr to 450 psig in 1.5 hrs (wtr flow). Picked up Baker pIa setting BRA. Till. Re-set pIa @ 10,377' DPM. Press tstd to 500 psig, press held wIno incr. Still have slight flow. Circ hole. Still had slight flow. Re-tstd pIa to 500 psig. Still have slight flow. Mixed & pmpd dry job. Std TOH. Conferred wIMidland & agreed that we should run 2nd pIa. Will flow check when out of hole to eliminate U-tube imbalance. 4/25/02 LD 3-112" HWDP, 4 - 3/4" DC's & Baker Tool @ 13,155', Sd, MW 9.8, Vis 193, PV 41, yP 26, Gels 10/12, HTHP 5.8, Cake 2.0, Alk 3.2, Cl 48,000, Sd .25, Solids 8.0, Oil 53.0, Added 40sx Barite. Trip 12 hrs, Test BOP/Diverter 6 hrs, Other 3 hrs, PU/LD BHA & Tools 2-112 hrs, Circ 1/2 hr. POOH. Stood back HW & DC's. ill Baker tools. Drained stack. Retrieved wear ring. MU tst tools (overhauled dart valve). Set tst plug. Tstd BOP w/AOGCC replwitness, tstd okay. Good tst w/exception of H2S alarm (repaired), tstd okay. PU 2nd Baker liner top pIa & seal assy. Rill slowly. Tagged liner pIa #1 @ 10,377' (10,371' liner detail). Broke circ. Set seal assy & dropped ball & waited for same. Set liner top pIa #2 w/3,200 psig. Unsting fr pIa & shear ball seat w/5,000 psig. Top pIa #2 @ 10,362' DPM. Circ & pmpd dry job. POOH. LD 3-1/2" HWDP & 4 - 3/4" DC's & Baker running tool. 4/26/02 Circ Btms Up @ TD @ 13,155', Sd, MW 9.6, Vis 250, PV 58, YP 32, Gels 12/14, HTHP 5.8, Cake 2.0, Alk 3.2, Cl 38,000, Sd .25, Solids 10.0, Oil 46.0, Added 80sx Barite. Trip 9 hrs, Drill Cmt/Float Equip 6-1/2 hrs, PU/LD BRA & Tools 4-1/2 hrs, LD/PU Drill Pipe/Tbg 2-1/2 hrs, Circ 1-112 hr. Fin LD 4-3/4" DC's & 3-112" HWDP. Picked up 4-1/8" mill & MTR on 2-7/8" DP to drill out cmt. TIH to top of liner pIa. Drilled out cmt fr top pIa to x-over @ 10,794'. Pmpd dry job & TOH. LD 4-118" mill. Picked up 3-3/4" mill & MTR assy. Till & picked up 75 jts of 2-7/8" DP. Till. Worked thru liner top to x-over @ 10,794'. Drilled out cmt fr 10,794' to landing collar @ 10,843'. Drld landing collar to 10,844'. Till to TD 13,145' (no cmt in liner). Circ btms up. Mud out of balance but appears to be no H20 flow. 4/27/02 Running PIa Assy On DP @ 13,155', Sd, MW 7.4, Added 40sx Barite, 13,860 gals MAPCO 200, 3sx Versacoat. Circ 6-1/2 hrs, Displ6 hrs, Trip 10 hrs, Monitor WeIll hr, PU/LD BHA & Tools 112 hr. C & C mud. Dropped ball & opened drc sub. Monitored well, no flow. C & C mud. Cleaned pit & unloaded boat wlbase oil. Displ hole wlbase oil (7.4 ppg). Monitored well, no flow. POOH & stood back 3-112" DP, 2-7/8" DP & 2 stands of 3-118" DC's. LD x-over's, drc sub, motor & 3-3/4" 13 . . mill. Picked up & MU prod pkr w/tail pipe assy. Std TIH w/pkr assy on DP (slowly). At report time pkr assy @ 6,250'. 4/28/02 Running Tbg @ 13,155', Sd, MW 7.4, Added 60sx Durogel. LDIPU Drill PipelTbg 13 hrs, Trip 7 hrs, Other 2 hrs, RU/RD Service Tools 1 hr, Pump Pill 1/2 hr, Slip & Cut Drill Line 1/2 hI. Fin TIH w/pkr assy on DP. Broke circ & dropped ball. Set pkr @ 10,276' wlWL reg @ 10,312' (50' above top liner pkr). Pmpd dry job. TOH wIDP. Slipped & cut drlg line. FIN TOH. LD 18 jts of 3-112" DP. LD pkr setting tool. TIH w/6 - 3-118" DC's & 84 jts of 2-7/8" DP. TOH & LD same. Pulled wear ring. RU to run 2-7/8" tbg. Held pre-job safety meeting. TIH w/2-7/8" tbg. Have approx 8,000' in @ report time. 4/29/02 Circ Hi-Vis Sweep After Clean Out ofPkr Bore @ 13,155', Sd, MW 7.4. Other 13-112 hrs, Circ 6 hrs, Trip 3-1/2 hrs, PUILD BHA & Tools 1 hr. Fin TIH w/2-7/8" tbg. Attempted to locate & stab-in ... top of pkr @ 10,278' w/seal assy. Could get +/-1' into pkr & press up to 1,000 psig. Press would bleed off. Attempted several times, no success. Circ btms up. Conferred w/Midland. Ordered out mill, motor & stinger assy to clean out pkr bore & tailpipe. POOH w/2-7/8" tbg. Stood back all tbg (except GLM's). LD seal assy, no junk marks on muleshoe or seals. Picked up 2-118" mill w/2-1I8" motor, 1 jt of 1.25 CS Hydrill DP. Picked up 18 jts DP & RIH w/motor assy. Stabbed into pkr @ 10,276' & cleaned out (feels like sd) fr top of pkr to 2' above shear out plug in tbg tail @ 10,310'. Pmpd Hi-Vis sweep (made w/a batch of our old mud). Pmpd dn to mill & around comer. Pulled out of pkr & circ Hi-Vis sweep (limited to 28 SPM w/small motor). 4/30/02 Running 2-7/8" Tbg @ 13,155', MW 7.4. Added 3sx IMG-400, Isx Versacoat & Isx Versamod. Trip 8-112, Other 7-114 hrs, Circ 3-1/2 hrs, PU/LD BHA & Tools 1 hr, Rig Repair 1 hr, RUIRD Service Tools 1 hr, W & R 1 hr, Service Rig 3/4 hr. Circ Hi-Vis sweep. Got partial sweep back w/very little sand. Reapaired link stop on top drive. TIH. Located pkr. Tagged sand 8' into pkr bore. Unable to lift sand w/diesel. POOH w/wet string. Motor & 1.25" CS Hydril joint were kinked & bent. LD same. Serviced top drive. Waited on new jt of 1.25" CS Hydril DP. MU 1.25" CS Hydril DP stinger w/muleshoe btm. TIH to pkr @ 10,255'. Washed fr 10,255'-10,310' (in tbg tail 2' above shear out). Rev circ sand fr pkr & tbg tail. Got sand back to surface. POOH. LD stinger assy. RU to run 2-7/8" completion tbg. Ran 2-7/8" tbg. At report time picking up SSSV. 5/01102 Rig Released @ 13,155', MW 7.4. Added 40sx MI-Bar. Other 8-1/2 hrs, NUIND BOPlDiverter 5-112 hrs, NUIND Tree 4 hrs. Fin running 2-7/8" completion tbg. Picked up SSSV. Press tstd control line .. & banded same. Stabbed into pkr @ 10,276',3' of seals (out of 10) in. Press tstd tbg to 1,000 psig for 15", tstd okay. Had trouble getting last 7' of seals into pkr. Press up & sheared tbg tail plug @ 2,500 psig. Finally got last of seals in. Picked up & spaced out tbg. Picked up hanger & control line. RIH & stabbed back into pkr. Landed tbg. Tstd pack off w/cameron, tstd okay. Set BPV. ND BOPE & riser. NU tree & production valves. Pulled BPV & installed 2-way check. Tstd hanger, pack off & ~ tree to 250-5,000 psig, tstd okay. RD Koomey lines. Cleaned pits. Released rig @ 2400 hrs 4/30/02. 5/04/02 Well SI fr May 1st through May 4th while derrick moved to well C34-23 to allow deck space for the 250 bbl production test tank. Tank was first needed to hold scale that was cleaned out w/coil tbg on C34-23 before unloading the OBM fr C32-23LW. Put well on gas lift @ 9:00 pm. Flowed 1 hour to production facilities unloading about 40 bbls diesel. Switched to the 250 bbl production test tank once OBM was in flow stream and pumped to disposal well. 5/05/02 Flowing 97% mud cut fluid to prod tank @ +/- 15 BPH @ 870 psi Csg press. Lifting between GL V #4-#5. Recovered about 350 bbls of load. 14 . . 5/06/02 Producing into production test tank @ +/- 15 BPH @ 860 psi Csg press. Lifting between GL V #5- #6. Fluid is 53% oil, 35% water & 12% OBM. Required solvent to break emulsion. Total load recovered after 56 hrs was 820 bbls (avg 14.6 BPH). 5/07/02 Ran initial well tsts. FlowTest Zone: <-- N/ A --> Event Desc: Initial Well Test Top Interval: 0 Bottom Interval: 0 WH CP Gas Bbls Oil Time psig psig Inj Rec BPH Cut% Comments 09:00 90.0 840.0 965 0.00 0.000 95.000 Unloaded 820 bbls into tst tnk (35% wtr + sart tst). 10:00 80.0 835.0 978 15.00 15.000 95.000 12:00 80.0 830.0 978 30.00 15.000 46.000 14:00 80.0 820.0 929 30.00 15.000 55.000 19:00 90.0 840.0 1,052 100.00 20.000 55.000 23:00 90.0 830.0 965 80.00 20.000 16.000 8% wtr & 8% OBM. Ttl Bbls: 255.00 5/08/02 Continuation of initial well tsts. FlowTest Zone: <-- N/A --> Event Desc: Top Interval: 0 Bottom Interval: 0 WH CP Gas Bbls Oil Time psig psig Inj Rec BPH Cut% Comments 00:00 0.0 0.0 0 0.00 0.000 0.000 01:00 95.0 825.0 1,052 20.00 20.000 20.000 8% wtr & 12% OBM. 02:00 80.0 830.0 965 20.00 20.000 20.000 04:00 80.0 830.0 984 40.00 20.000 32.000 26% wtr & 6% OBM. 05:00 80.0 835.0 1,002 22.00 22.000 32.000 06:00 80.0 835.0 1,009 25.00 25.000 32.000 07:00 80.0 835.0 1,003 15.00 15.000 32.000 09:00 90.0 830.0 1,000 33.00 16.500 14.000 12:00 90.0 830.0 1,000 47.10 15.700 17.000 13:00 90.0 830.0 1,000 14.00 14.000 21.000 14:00 90.0 830.0 1,000 18.00 18.000 21.000 15:00 90.0 820.0 966 15.00 15.000 27.000 16:00 90.0 820.0 966 15.00 15.000 27.000 17:00 80.0 835.0 1,002 22.00 22.000 27.000 18:00 85.0 835.0 1,009 25.00 25.000 27.000 19:00 85.0 815.0 1,009 16.00 16.000 40.000 27% wtr & 13% OBM. 22:00 80.0 820.0 966 45.00 15.000 56.000 23:00 80.0 820.0 966 15.00 15.000 19.000 Ttl Bbls: 407.10 5/9/02 Continuation of well test. FlowTest Zone: <-- N/ A --> 15 . . Event Desc: Top Interval: 0 Bottom Interval: 0 WH CP Gas Bbls Oil Time psig psig Inj Rec BPH Cut% Comments 01 :00 80.0 820.0 966 30.00 15.000 39.000 0.25% & 38.75% OBM. 03:00 80.0 820.0 966 29.00 14.500 39.000 05:00 80.0 820.0 966 33.00 16.500 17.000 08:00 90.0 820.0 966 45.60 15.200 32.000 09:00 90.0 810.0 966 17.10 17.100 17.000 10:00 90.0 810.0 966 15.40 15.400 18.000 11:00 90.0 810.0 966 13.80 13.800 18.000 13:00 90.0 810.0 966 30.00 15.000 51.000 16:00 90.0 810.0 966 40.80 13.600 51.000 17:00 90.0 810.0 966 15.10 15.100 17.000 19:00 85.0 825.0 1,000 30.20 15.100 31.000 21:00 85.0 835.0 1,000 31.80 15.900 31.000 22:00 85.0 835.0 1,065 13.70 13.700 31.000 23:00 80.0 840.0 1,035 13.90 13.900 38.000 Ttl Bbls: 359.40 5/10/02 DWC: $0 CWC: $0 DMC: $0 CMC: $0 FlowTest Zone: <-- N/A --> Event Desc: Top Interval: 0 Bottom Interval: 0 WH CP Gas Bbls Oil Time psig psig Inj Rec BPH Cut% Comments 01:00 80.0 840.0 1,035 26.00 13.000 38.000 03:00 80.0 840.0 1,060 31.80 15.900 27.000 1% Wtr & 26% OBM. 04:00 80.0 840.0 1,047 10.90 10.900 27.000 1% Wtr & 26% OBM. 05:00 80.0 840.0 1,057 12.50 12.500 18.000 18% wtr. 06:00 90.0 840.0 1,057 16.60 16.600 18.000 07:00 80.0 835.0 1,047 15.50 15.000 18.000 09:00 80.0 840.0 1,047 26.00 13.000 56.000 13:00 80.0 840.0 1,047 57.20 14.300 55.000 15:00 80.0 840.0 1,060 27.20 13.600 49.000 16:00 80.0 840.0 1,060 14.00 14.000 37.000 17:00 80.0 840.0 1,060 14.00 14.000 34.000 19:00 80.0 840.0 1,032 25.40 12.700 44.000 20:00 80.0 840.0 1,032 16.40 16.400 44.000 21:00 85.0 840.0 1,053 14.00 14.000 44.000 22:00 80.0 840.0 1,040 12.40 12.400 48.000 23:00 80.0 840.0 1,053 14.00 14.000 48.000 Ttl Bbls: 333.90 5/11/02 Contd initial well tstg. FlowTest Zone: <-- N/A --> Event Desc: Initial Well Tstg Top Interval: 0 Bottom Interval: 0 WH CP Gas Bbls Oil Time psig psig Inj Rec BPH Cut% Comments 01:00 80.0 840.0 955 25.00 12.500 25.000 0.1% wtr & 24.9% OBM. 16 . . 02:00 80.0 835.0 994 17.50 17.500 25.000 0.1% wtr& 24.9% OBM. 03:00 80.0 820.0 1,007 14.20 14.200 43.000 04:00 80.0 820.0 1,007 12.60 12.600 43.000 05:00 80.0 820.0 983 12.40 12.400 43.000 Ttl Bbls: 81.70 5/12/02 Prod Flow Tst: 320 total bbls per day, clean prod 184 BOPD, wtr cut 42.5%. Prod gas 297 MCFPD, gas inj 994 MCFPD. Csg press 820 psig & tbg press 80 psig. 5/13/02 Prod Flow Tst: 320 total bbls per day, clean prod 184 BOPD, wtr cut 42.5%. Prod gas 297 MCFPD, gas inj 1,007 MCFPD. Csg press 780 psig & tbg press 80 psig. 5/14/02 Prod Flow Tst: 258 total bbls per day, clean prod 183 BOPD, wtr cut 29.0%. Prod gas 297 MCFPD, gas inj 1,002 MCFPD. Csg press 780 psig & tbg press 80 psig. 17 '. . . XTO Energy, Inc. C PLATFORM C32-23LW slot #1-2 Middle Ground Shoals Cook Inlet, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref OUr ref License MHD <3200 - 13155> svy6720 Date printed Date created Last revised 21-Feb-2003 ll-Mar-2002 22-Apr-2002 Field is centred on n60 50 4.803,w151 29 11.941 Structure is centred on n60 46 36.826,w151 29 36.377 Slot location is n60 45 50.217,w151 30 8.484 Slot Grid coordinates are N 2474234.577, E 231360.866 Slot local coordinates are 4733.00 S 1595.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North . XTO Energy, Inc. C PLATFORM,C32-23LW Middle Ground 8hoals,Cook Inlet, Alaska Measured Inclin Depth Degrees 0.00 100.00 150.00 200.00 250.00 300.00 350.00 400.00 450.00 500.00 550.00 600.00 650.00 700.00 750.00 800.00 850.00 900.00 950.00 1000.00 1050.00 1100.00 1150.00 1200.00 1250.00 1300.00 1350.00 1400.00 1450.00 1500.00 1550.00 1600.00 1650.00 1700.00 1750.00 1800.00 1850.00 1900.00 1950.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 4.47 6.32 8.23 9.65 11.20 11.88 12.00 12.35 12.57 12.55 12.40 13.90 16.02 18.63 21.25 23.73 26.02 28.57 30.50 32.58 33.92 35.58 36.58 37.02 36.72 36.03 35.85 36.10 36.05 36.03 36.33 36.57 36.65 36.07 35.73 36.07 36.48 36.83 36.95 37.10 Azimuth Degrees 0.00 0,38 0.40 0.45 0.67 0.00 242.00 245.00 229.00 235.00 True Vert Depth 0.00 100.00 150.00 200.00 249.99 299.99 349.99 399.98 449.97 499.93 549.83 599.60 649.20 698.60 747.77 796.76 845.68 894.56 943.38 992.18 1041.00 1089.69 1137.99 1185.72 1232.72 1278.92 1324.28 1368.71 1412.21 1454.82 1496.63 1537.72 1578.13 1618.16 1658.16 1698.42 1738.91 1779.37 1819.78 1860.21 1940.93 2021.37 2101.64 2182.17 2263.18 2344.18 2424.80 2505.02 2585.00 2664.84 . 8URVEY LI8TING Page 1 Your ref MWD <3200 - 13155> Last revised : 22-Apr-2002 R E C TAN G U L A R Dogleg Vert COO R DIN ATE 8 Deg/l00ft 8ect 4733.008 4733.168 4733.318 4733.518 4733.818 4734.148 4734.39S 4734.098 4733.068 4731.138 4727.948 4723.288 4716.998 4709.47S 4701.22S 4692.48S 4683.568 4674.488 4665.098 4655.588 4646.09S 4636.048 4624.958 4612.798 4598.898 4582.678 4564.45S 4544.60S 4523.048 4499.845 4475.415 4449.795 4423.225 4396.42S 4369.465 4342.695 4316.105 4289.275 4262.37S 4235.395 4181.265 4126.578 4071.095 4015.745 3960.82S 3905.905 3850.66S 3794.935 3738.895 3682.86S 1595.00W 1595.29W 1595.60W 1595.90W 1596.29W 1596.84W 1597.47W 1597.90W 1598,05W 1597.99W 1597.61W 1597.05W 1597.20W 1599.00W 1602.64W 1607.50W 1612.75W 1618.10W 1623.41W 1628.68W 1633.83W 1639.17W 1645.75W 1654.32W 1664.19W 1674.29W 1684.81W 1696.27W 1708.21W 1720.28W 1732.72W 1745.21W 1757.88W 1771.25W 1784.40W 1797.16W 1809.57W 1821.51W 1833.49W 1845.22W 1868.76W 1891.97W 1913.82W 1935.07W 1955.61W 1976.14W 1997.35W 2018.74W 2040.25W 2062.32W 0.00 0.38 0.06 0.26 0.45 0.00 -0.09 -0.18 -0.32 -0.53 G RID Easting 231360.87 231360.57 231360.26 231359.95 231359.56 231359.00 231358.37 231357.94 231357.81 231357.92 231358.37 231359.04 231359.03 231357.40 231353.95 231349.29 231344.25 231339.11 231334.01 231328.96 231324.02 231318.91 231312.58 231304.30 231294.74 231285.01 231274.92 231263.91 231252.46 231240.93 231229.04 231217.14 231205.07 231192.32 231179.79 231167.64 231155.84 231144.51 231133.15 231122.04 231099.73 231077.77 231057.19 231037.21 231017.92 230998.64 230978.70 230958.58 230938.35 230917.56 COO R D 5 Northing 2474234.58 2474234.43 2474234.28 2474234.09 2474233.80 2474233.48 2474233.25 2474233.55 2474234.59 2474236.51 2474239.69 2474244.34 2474250.64 2474258.19 2474266.52 2474275.37 2474284.40 2474293.61 2474303.12 2474312.74 2474322.35 2474332.51 2474343.75 2474356.11 2474370.22 2474386.67 2474405.12 2474425.23 2474447.06 2474470.53 2474495.23 2474521.12 2474547.98 2474575.08 2474602.33 2474629.38 2474656.24 2474683.34 2474710.50 2474737.74 2474792.39 2474847.59 2474903.56 2474959.37 2475014.75 2475070.12 2475125.82 2475182.03 2475238.54 2475295.05 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from NE Corner of 8ec. 23, T8N, Rl3W, 5M and TVD from rotary table (105.00 Ft above mean sea level) . Bottom hole distance is 7483.16 on azimuth 345.27 degrees from wellhead. Vertical section is from wellhead on azimuth 348.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.80 0.77 0.88 1.53 2.90 241. 00 257.00 344.00 356.00 5.00 8.00 6.00 353.00 341. 00 332.00 330.00 329.00 330.00 331.00 331.00 332.00 332.00 327.00 323.00 326.00 330.00 330.00 330.00 332.00 333.00 333.00 335.00 334.00 333.00 335.00 334.00 336.00 336.00 336.00 337.00 336.00 338.00 339.00 339.00 340.00 339.00 339.00 339.00 339.00 338.00 0.30 0.44 2.28 1.39 2.82 -0.75 -0.86 -0.48 0.56 2.44 3.16 3.72 5.02 4.67 4.49 5.48 9.94 16.13 23.85 32.67 1.58 0.48 0.82 0.62 0.04 42.22 52.01 62.00 72.27 82.65 0.53 3.00 4.96 5.74 5.62 93.00 103.92 116.11 129.77 145.38 5.83 4.58 5.10 4.33 4.29 163.32 183.29 205.07 228.60 253.78 2.68 4.03 2.32 1.49 2.47 280.22 307.84 336.44 365.40 394.47 1.82 2.38 0.50 0.10 1.18 423.28 451.84 480.54 509.31 538.11 0.66 1.21 0.60 0.58 0.68 595.90 654.16 712.93 771.45 829.40 0.68 0.41 0.35 0.12 0.62 887.35 945.74 1004.66 1063.91 1123.25 . . XTO Energy, Inc. 5URVEY LI5TING Page 2 C PLATFORM,C32-23LW Your ref MWD <3200 - 13155> Middle Ground Shoals , Cook Inlet, Alaska Last revised : 22-Apr-2002 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COORD5 Depth Degrees Degrees Depth COORD INATE5 Deg/100ft Sect Easting Northing 3100.00 37.17 339.00 2744.56 3626.705 2084.45W 0.61 1182.75 230896.72 2475351.71 3200.00 37.32 340.00 2824,17 3570.015 2105.64W 0.62 1242.56 230876.82 2475408.86 3280.00 40.10 342.50 2886.59 3522.635 2121.69W 3.99 1292.21 230861.86 2475456.59 3373.00 42.00 345.50 2956.73 3463.935 2138.49W 2.94 1353.10 230846.40 2475515.65 3469.00 44.50 348.60 3026.66 3399.845 2153.18W 3.42 1418.84 230833.16 2475580.06 3566.00 46.60 351.70 3094.59 3331.635 2164.99W 3.14 1488.02 230822.91 2475648.52 3661.00 46.80 354.70 3159.75 3262.99S 2173.17W 2.31 1556.89 230816.29 2475717.33 3756.00 46.10 354.00 3225.20 3194.485 2179.95W 0.91 1625.35 230811.08 2475785.98 3850.00 45.80 353.30 3290.56 3127.335 2187.42W 0.62 1692.62 230805.13 2475853.28 3947.00 47.60 352.90 3357.08 3057.255 2195.90W 1.88 1762.95 230798.25 2475923.53 4040.00 47.60 352.90 3419.79 2989.105 2204.39W 0.00 1831.41 230791,31 2475991. 85 4133.00 47.60 351.80 3482.50 2921. 04S 2213.53W 0.87 1899.91 230783.72 2476060.10 4227.00 46.80 350.40 3546.37 2852.905 2224.20W 1.39 1968.79 230774.61 2476128.47 4321. 00 46.10 351. 50 3611.14 2785.625 2234.92W 1.13 2036.84 230765.42 2476195.97 4416.00 46.10 351. 50 3677.01 2717.925 2245.04W 0.00 2105.18 230756.85 2476263.88 4509.00 46.00 351.10 3741. 56 2651.745 2255.16W 0.33 2172.04 230748.23 2476330.28 4608.00 45.70 351.50 3810.51 2581.525 2265.91W 0.42 2242.98 230739.08 2476400.72 4702.00 45.70 351.10 3876.17 2515.025 2276.09W 0.30 2310.16 230730.42 2476467.43 4797.00 45.40 350.80 3942.69 2448.055 2286.75W 0.39 2377 . 90 230721.28 2476534.63 4891.00 44.90 350.10 4008.99 2382.33S 2297.81W 0.75 2444.49 230711.72 2476600.58 4984.00 45.30 350.40 4074.63 2317.415 2308.96W 0.49 2510.33 230702.05 2476665.74 5073.00 44.70 350.10 4137.57 2255.395 2319.62W 0.72 2573.22 230692.81 2476727.99 5169.00 45.60 350.80 4205.27 2188.275 2330.91W 1.07 2641. 23 230683,05 2476795.34 5263.00 46.90 350.80 4270.27 2121.24S 2341.76W 1.38 2709.06 230673.72 2476862.60 5357.00 46.60 350.80 4334.68 2053.66S 2352.71W 0.32 2777.46 230664.31 2476930.41 5448.00 46.70 350.40 4397.14 1988.375 2363.52W 0.34 2843.58 230654.99 2476995.92 5544.00 46.10 350.80 4463.35 1919.795 2374.87W 0.69 2913.04 230645.20 2477064.75 5645.00 46.60 350.40 4533.06 1847.695 2386.81W 0.57 2986.06 230634.91 2477137.10 5735.00 47.20 350.40 4594.56 1782.895 2397.77W 0.67 3051.73 230625.42 2477202.12 5827.00 47.30 350.80 4657.01 1716.245 2408.80W 0.34 3119.23 230615.91 2477269.01 5924.00 47.30 351.10 4722.79 1645.845 2420.02W 0.23 3190.44 230606.30 2477339.64 6019.00 47.30 350.80 4787.21 1576.905 2431.00W 0.23 3260.18 230596.89 2477408.82 6111.00 47.40 350.40 4849.55 1510.145 2442.05W 0.34 3327.79 230587.36 2477475.81 6209.00 47.30 350.40 4915.94 1439.075 2454.07W 0.10 3399.82 230576.96 2477547.14 6303.00 46.60 350.10 4980.11 1371.375 2465.70W 0.78 3468.47 230566.87 2477615.08 6398,00 46.90 350.10 5045.20 1303.215 2477.60W 0.32 3537.63 230556.53 2477683.50 6489.00 46.90 350.40 5107.38 1237.725 2488.85W 0.24 3604.03 230546.77 2477749.22 6572.00 46.70 350.40 5164.20 1178.065 2498.94W 0.24 3664.49 230538.04 2477809.09 6667.00 47.00 350.10 5229.17 1109.765 2510.68W 0.39 3733.76 230527.86 2477877 . 64 6767.00 46.10 349.40 5297.94 1038.325 2523.59W 1.03 3806.33 230516.57 2477949.36 6863.00 45.60 349.70 5364.81 970.585 2536.09W 0.57 3875.20 230505.62 2478017.36 6956.00 46.30 349.70 5429.47 904.815 2548.04W 0.75 3942.02 230495.17 2478083.38 7047.00 46.10 349.40 5492.46 840.22S 2559.95W 0.32 4007.68 230484.73 2478148.22 7141.00 45.80 349.70 5557.81 773.78S 2572.21W 0.39 4075.22 230473.99 2478214.92 7234.00 46.70 350.40 5622.12 707.62S 2583.81W 1.11 4142.37 230463.89 2478281. 34 7332.00 46.60 351.10 5689.40 637.285 2595.27W 0.53 4213.56 230454.04 2478351. 91 7425.00 46.10 350.80 5753.59 570.835 2605.85W 0.59 4280.78 230444.97 2478418.59 7520.00 46.80 350.40 5819.04 502.905 2617.10W 0.80 4349.58 230435.27 2478486.75 7615.00 47.10 350.10 5883.89 434.485 2628.85W 0.39 4418.96 230425.08 2478555.42 7708.00 47.00 351. 50 5947.26 367.295 2639.74W 1.11 4486.96 230415.72 2478622.84 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from NE Corner of 5ec. 23, T8N, Rl3W, 5M and TVD from rotary table (105.00 Ft above mean sea level) . Bottom hole distance is 7483.16 on azimuth 345.27 degrees from wellhead. Vertical section is from wellhead on azimuth 348.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . , . . XTO Energy, Inc. SURVEY LISTING Page 3 C PLATFORM,C32-23LW Your ref MWD <3200 - 13155> Middle Ground Shoals,Cook Inlet, Alaska Last revised : 22-Apr-2002 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID C OORDS Depth Degrees Degrees Depth COORD I N ATE S Deg/100ft Sect Easting Northing 7795.00 47.40 351.50 6006.37 304.15S 2649.17W 0.46 4550.69 230407.73 2478686.17 7888.00 47.00 351.10 6069.56 236.70S 2659.49W 0.53 4618.83 230398.94 2478753.84 7986.00 46.30 351.50 6136.83 166.26S 2670.27W 0.77 4689.99 230389.77 2478824.51 8079.00 45.60 350.80 6201. 49 100.21S 2680.56W 0.93 4756.75 230380.99 2478890.77 8171.00 46.30 350.40 6265.46 34.98S 2691.36W 0.82 4822.82 230371.68 2478956.23 8266.00 45.90 351.10 6331.33 32.58N 2702.36W 0.68 4891.20 230362.21 2479024.02 8359.00 46.90 349.70 6395.47 98.98N 2713.60W 1.53 4958.50 230352.49 2479090.66 8451.00 46.90 349.40 6458.33 165.04N 2725.78W 0.24 5025.66 230341.81 2479156.98 8545.00 46.80 349.70 6522.62 232.48N 2738.22W 0.26 5094.22 230330.91 2479224.69 8640.00 46.40 351. 50 6587.89 300.57N 2749.50W 1.44 5163.18 230321.19 2479293.02 8733.00 45.60 351.50 6652.50 366.74N 2759.39W 0.86 5229.97 230312.81 2479359.39 8829.00 45.60 350.80 6719.66 434.51N 2769.94W 0.52 5298.47 230303.80 2479427.38 8924.00 46.10 349.40 6785.84 501.65N 2781.66W 1.18 5366.60 230293.61 2479494.77 9031.00 45.60 350.80 6860.37 577 .28N 2794.86W 1.05 5443.33 230282.13 2479570.68 9126.00 47.20 349.40 6925.88 645.05N 2806.70W 1.99 5512.09 230271.83 2479638.69 9218.00 47.30 350.40 6988.33 711.56N 2818.55W 0.81 5579.62 230261.50 2479705.45 9314.00 46.90 350.10 7053.68 780.86N 2830.46W 0.48 5649.90 230251.18 2479775.01 9409.00 46.90 351. 10 7118.59 849.30N 2841. 79W 0.77 5719.20 230241.41 2479843.68 9500.00 45.90 351.10 7181.35 914 .40N 2851.98W 1.10 5785.02 230232.69 2479909.00 9594.00 46.10 350.10 7246.65 981.11N 2863.02W 0.79 5852.58 230223.17 2479975.94 9690.00 45.90 350.40 7313.33 1049.17N 2874.72W 0.31 5921.60 230213.03 2480044.25 9785.00 43.20 353.60 7381.04 1115.14N 2884.04W 3.70 5988.08 230205.21 2480110.41 9876.00 41.60 354.00 7448.23 1176.14N 2890.67W 1.78 6049.15 230199.97 2480171. 54 9971.00 39.30 356.40 7520.53 1237.54N 2895.85W 2.92 6110.32 230196.18 2480233.05 10063.00 36.70 358.20 7593.02 1294.10N 2898.55W 3.07 6166.26 230194.78 2480289.66 10158.00 34.00 357.50 7670.50 1349.02N 2900.60W 2.87 6220.44 230193.98 2480344.61 10253.00 31.40 357.10 7750.43 1400.29N 2903.01W 2.75 6271.12 230192.73 2480395.91 10348.00 29.80 357.50 7832.20 1448.59N 2905.29W 1.70 6318.88 230191.55 2480444.25 10440.00 27.90 1.70 7912.79 1492.95N 2905.65W 3.02 6362.39 230192.20 2480488.61 10532.00 25.00 5.90 7995.16 1533.82N 2903.01W 3.75 6401.86 230195.77 2480529.41 10641,00 25.10 8.00 8093.91 1579.62N 2897.43W 0.82 6445.57 230202.39 2480575.07 10792.00 22.00 6.60 8232.31 1639.45N 2889.72W 2.09 6502.58 230211.46 2480634.71 10884.00 20.10 5.20 8318.17 1672.31N 2886.30W 2.14 6534.06 230215.62 2480667.48 10975.00 20.00 7.00 8403.66 1703.33N 2882.99W 0.69 6563.76 230219.64 2480698.42 11069.00 18.50 4.50 8492.40 1734.16N 2879.86W 1.82 6593.30 230223.47 2480729.16 11165.00 17.40 8.00 8583.73 1763.56N 2876.67W 1.60 6621.44 230227.33 2480758.48 11256.00 18.70 5.60 8670.25 1791. 55N 2873.35W 1.65 6648.17 230231.28 2480786.39 11353.00 20.30 345.50 8761.79 1823. 35N. 2876.05W 7.07 6679.86 230229.31 2480818.25 11443.00 21.70 317.40 8846.02 1850.79N 2891.26W 11.19 6709.81 230214.73 2480846.02 11536.00 24.40 300.20 8931.68 1873.13N 2919.54W 7.77 6737.45 230186.97 2480869.01 11630.00 20.20 295.20 9018.64 1889.82N 2951.02W 4.90 6760.19 230155.87 2480886.40 11756.00 18.20 294 . 90 9137.63 1907.37N 2988.55W 1.59 6785.01 230118.75 2480904.80 11849.00 17.50 293.10 9226.15 1918.97N 3014.59W 0.96 6801.66 230092.98 2480916.99 11942.00 19.70 292.80 9314 .29 1930.53N 3041.90W 2.37 6818.54 230065.94 2480929.17 12034.00 25.00 288.60 9399.35 1942.75N 3074.65W 6.01 6837.16 230033.48 2480942.13 12128.00 29.20 308.60 9483.19 1963.44N 3111. 49W 10.61 6864.92 229997.12 2480963.66 12224.00 33.40 317.40 9565,24 1997.54N 3147.71W 6.46 6905.67 229961.69 2480998.56 12315.00 39.60 324.80 9638.39 2039.73N 3181.43W 8.35 6953.85 229928.93 2481041. 52 12406.00 43.60 324.40 9706.43 2088.97N 3216.43W 4.41 7009.17 229895.07 2481091.53 12501. 00 45.40 325.50 9774.19 2143.48N 3254.66W 2.06 7070.32 229858.09 2481146.90 All data in feet unless otherwise stated. Calculation uses min~um curvature method. Coordinates from NE Corner of Sec. 23, T8N, R13W, SM and TVD from rotary table (105.00 Ft above mean sea level) . Bottom hole distance is 7483.16 on azimuth 345.27 degrees from wellhead. Vertical section is from wellhead on azimuth 348.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . . XTO Energy, Inc. SURVEY LISTING Page 4 C PLATFORM,C32-23LW Your ref MWD <3200 - 13155> Middle Ground Shoa1s,Cook Inlet, Alaska Last revised 22-Apr-2002 Measured Inc1in Azimuth True Vert RECTANGU LAR Dogleg Vert G RID C OORDS Depth Degrees Degrees Depth COORD I NA T E S Deg/100ft Sect Easting Northing 12591.00 48.30 327.90 9835.74 2198.36N 3290.67W 3.76 7131.38 229823.33 2481202.59 12684.00 47.50 326.20 9898.09 2256.27N 3328.19W 1.61 7195.71 229787.14 2481261. 33 12779.00 46.90 329.00 9962.64 2315.11N 3365.54W 2.25 7260.91 229751.14 2481321. 00 12871.00 47.50 329.00 10025.15 2372.97N 3400.31W 0.65 7324.64 229717.70 2481379.64 12965.00 38.80 327.60 10093.66 2427.64N 3434.00W 9.31 7385.03 229685.26 2481435.06 13059.00 32.30 318.80 10170.15 2471.48N 3466.38W 8.79 7434.53 229653.88 2481479.62 13097.00 29.00 316.70 10202.84 2485.83N 3479.39W 9.13 7451. 23 229641.20 2481494.26 13155.00 24.00 314 .00 10254.73 2504.27N 3497.53W 8.87 7472.97 229623.49 2481513.11 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from NE Corner of Sec. 23, T8N, Rl3W, SM and TVD from rotary table (105.00 Ft above mean sea level) . Bottom hole distance is 7483.16 on azimuth 345.27 degrees from wellhead. Vertical section is from wellhead on azimuth 348.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . . XTO Energy, Inc. C PLATFORM,C32-23LW Middle Ground Shoals,Cook Inlet, Alaska SURVEY LISTING Page 5 Your ref MHO <3200 - 13155> Last revised : 22-Apr-2002 Comments in wellpath ------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 3200.00 2824.17 3570.01S 2105.64W KOP 3280.00 2886.59 3522.63S 2121.69W Interpolated Azimuth 3373.00 2956.73 3463.935 2138.49W Interpolated Azimuth 3469.00 3026.66 3399.845 2153.18W Interpolated Azimuth 3566.00 3094.59 3331.63S 2164.99W Interpolated Azimuth 13155.00 10254.73 2504.27N 3497.53W Projection to TD Casing positions in string 'A' -------------- ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 4733.005 1595.00W 10705.00 8152.17 1605.86N 2893.86W 7" Casing Targets associated with this wellpath -------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- C32-23LW Tgt TD Rvsd C32-23LW Tgt M/HN Rv C32-23LW TgtT/HC(l) 10155.00 9155.00 8105.00 2400.00N 2000.00N 1600.00N 3490.00W 365.00W 2911.00W 25-Feb-2002 25-Feb-2002 18-Mar-2001 . ------------- ---------------.-- - -----------------~ - reoted by SutherlOndFor: M Langeler Dote plotted; 22-Apr-2002 Plot Reference is MWO <3200 - 13155>. Coordinates ore in feet reference slot #1-2. True Vertical Depths ore reference rotary table. IIi. .... INTEQ XTO Inc. Energy, Structure: C PLATFORM Well: C32-23LW Field: Middle Ground Shools Location: Cook Inlet, Alaska 2500 3000 3500 4000 4500 ~ 5000 +- Q) Q) ..... .......... 5500 ..r: +- a. Q) 6000 0 C 6500 () :¡:: L Q) > 7000 Q) ::J L 7500 ~ I V BOOO B500 9000 9500 10000 10500 <- West (feet) 2500 2000 1500 1000 500 0 7500 to TO 7000 6500 6000 5500 5000 ^ I 4500 Z 0 ~ -+ 4000 ::r ~ -. <D 3500 <D -- .......... 3000 2500 2000 1500 KOP-Sidetrack 1000 7 Casing 500 . ~TO ~kRGY Projection to TO ~ 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 BOOO Vertical Section (feet) -> Azimuth 348.26 with reference 0.00 N, 0.00 E from slot #1-2 . MEMORANDUM . State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor \Ø' Chair THRU: Tom Maunder A Q4y!1 P.I. Supervisor ~S\pO~ FROM: Jeff Jones Petroleum Inspector Operator Rep.: Larry McAllister Contractor Rep.: Jerry Sandidae Test Pressures Rams: 250/3000 MISC. INSPECTIONS: P/F Location Gen.: P Housekeeping: P PTD On Location P Standing Order: P BOP STACK: Quantity 1 1 P/F Sign: --..!:.. Rig cond: --..!:.. Hazard: P Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Size P/F 135/8 P 2 3/8x3.5 P 1 1 1 2 135/8 3 3 2 DATE: April 24, 2002 SUBJECT: Blowout Preventer Test Inlet Drilling Cross Timbers Oil Platform C .....1 iØ.W' 202.034 MGS NON- CONFIDENTIAL Op. phone: 776-2534 Rig phone: 776-3982 Op. E-Mail: Rig E-Mail: MUD SYSTEM: Visual Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Alarm P P P P F ACCUMULATOR SYSTEM: Time/Psi System Pressure 2950 After Closure 2050 200 psi Attained 0:30 Full Pressure 2:40 Blind Covers (All Stations): N2 Bottles (avg): 6@ 2170 P/F P P P P P P Test's Details April 24, 2002: I traveled to Cross Timbers' offshore platform XTOC in Cook Inlet where Inlet Drlg. Co. was drilling well C32-23L W, to witness a weekly BOPE test. Annular: 250/2500 Choke: 250/3000 TEST DATA FLOOR VALVES: Quantity P/F Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P P P P P CHOKE MANIFOLD: Quantity P/F No. Valves 12 P Man. Chokes 1 P Hyd. Chokes 1 P Inlet Drlg. Co. personnel were not ready to test BOPE on my arrival at 0800 hrs. due to delays in rigging up the test equipment. Testing began at 1130 hrs. and was accomplished in a safe and proficient manner with one failure observed. The audible H2S gas alarm located on the rig floor failed to operate. A portable H2S monitor was stationed on the rig floor to measure gas concentrations if the H2S low level warning light activates and the platform intercom system will be used to warn personnel of a high level H2S gas event until the audible alarm is repaired. Inlet Drlg. rig supervisor Jeny Sandidge willl10tify the AOGCC bye-mail when the alarm system has been repaired and re-tested successfully. All other components passed the tests and the rig and platform appeared clean, orderly and in good condition. Summary: I witnessed a weekly BOPE test on the XTOC offshore platform, where Inlet Drlg Co. personnel were drilling well C32-23L W in the Middle Ground Shoal Field. Total Test Time: 3.5 hrs. Number of failures: cc: BOP Test (for inspectors) BFL 11/02/01 1 Attachments: º BOP MGS XTOC 4-24-02 JJ.xls It ~1r~1rŒ mJ~ ~~~~[K\~ It AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul L. Figel XTO Energy, Inc. 3000 North Garfield Suite 175 Midland Texas 79705 Re: Middle Ground Shoal C32-23LW XTO Energy, Inc. Permit No: 202-034 Sur Loc: 547' FSL, 1594' FEL, Sec. 23, T8N, R13W, SM Btmhole Loc. 2360' FSL, 1326' FWL, Sec. 14, T8N, R13W, SM Dear Mr. Figel: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. Annular disposal has not been requested as part of the Permit to Drill application for Middle Ground Shoal C32-23L W. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, G {)cdv,L - Jwcr c~echsli Taylor Chair cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. , {J.¡ (ì , glV ¿ r /05 1'\ .1,ìl ~[. r I¡} ~?lo9- ,10 J BY ORDER OF THE COMMISSION DATED this ~ day of March, 2002 jjc/Enclosures e ~VIÄlVŒ (ID~ 1Äl~1Äl~[K{1Äl - AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 44.070 Re: The Application of XTO Energy Inc. for the Drilling of the MGS C32-23L W Sidetrack Well in the Middle Ground Shoal Mr. Bobby L. Smith, Drilling I Operations Manager XTO Energy, Incorporated 3000 North Garfield, Suite 175 Midland, TX 79705 Dear Mr. Smith: An application, dated February 13, 2002 and received by the Alaska Oil and Gas Conservation Commission ("Commission") on February 14, 2002, requested approval to drill the MGS C32- 23LW sidetrack well, which would be the 4th producer in the SW y.¡ of Section 14, T8N, R13W, SM. It is understood by the Commission that the drilling and completion of this sidetrack well will increase recovery of reserves from this structurally complex portion of the Middle Ground Shoal Field. The Commission hereby authorized drilling and completion of the MGS C32-23LW well pursuant to Rule 6(d) of Conservation Order No. 44. DONE in Anchorage, Alaska this 5th day of March 2002. ~MJ~ Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION . ~'. -;,¥';:~ ~TO ~kRGY . . February 13,2002 Mr. Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, #100 Anchorage, Alaska 99501 ~, ~~C ~~? ""1 RE: XTO Energy, Inc. C32-23LW Middle Ground Shoal Field Dear Mr. Davies: XTO Energy requests an exception to Pool Rule #1-B in Conservation Order 44, so that we may drill our C32-23LW extended reach Hemlock producer in the Middle Ground Shoal Field. This new well will be the 4th producer in the SWV.. of section 14 and will develop reserves in the structurally complex south central portion of the west flank of the field. The proposed well path will be an extended reach high-angle producer sidetracked to the north from the C32-23LW, which is an active east flank completion. The proposed well path was carefully designed to optimize spacing in all six Hemlock sub-intervals. Thank you for your time and assistance in this matter. Please do not hesitate to contact me (817) 885-2581 with any questions or comments you may have. Sincerely, /?Jt;iJ úfj~ Michael W. Langeler Senior Geologist MWL:kjw XTO Energy Inc. · 810 Houston Street · Fort Worth, Texas 76102-6298 · (817) 870-2800 . Fax: (817) 870-1671 _ STATE OF ALASKA .. ALASKA ~ AND GAS CONSERVATION COMW3SION PERMIT TO DRILL v.J4Ít 20 AAC 25.005 \l4GA 7-/2- ¿fð 2- 1-"') (L{ --0::::> 1 a. Type of work [': Drill [)C] Redrill 1 b. Type of well [ ] Service [ ] Development Gas [ X] Single Zone [ ] Multiple Zone r 1 Re-Entrv r í Deepen r 1 Exploratorv 1 Stratioraphic Test r Xl Development Oil 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool XTO ENERGY, INC. 105' DF 3. Address 6. Property Designation MGS 3000 NORTH GARFIELD, SUITE 175, MIDLAND, TEXAS 79705 ADL 18756 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 547' FSL, 1,594' FEL, Sec. 23, T8N, R13W, SM Middle Ground Shoal Blanket At top of productive interval 8. Well Number Number io3~~C1) 2,100' FSL, 2,542' FWL, Sec 14, T8N, R13W, SM C32-23LW ~4 At total depth 9. Approximate spud date Amount . 2,360' FSL, 1,326' FWL, Sec. 14, T8N, R13W, SM 2/24/2002 $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 3,500' NW At~':.64ß' from ~3 5,120 13,836' MD, 10,065' TVD 16. To be completed for deviated wells (2'Sso' iI' Au -{'if.. S "'"* 17. Anticipated pressure I {see 20 AAC 25.035 (e) (2)) Kick Off Depth 3,900' MD Maximum Hole Angle 48 deg Maximum surface ~ psig, At total depth (TVD) 3,400 psio 18. Casing Program Setting Depth ~Z-~5 í;.JC:¡Ao Size Specifications Top Bottom -Quantity of Cement Hole Casing Weioht Grade Couplino Length MD TVD MD TVD (include stage data) 8.5" 7" 29# L-80 BTC 7,052' 116' 116' 7,168' 5,581' 8.5" 7" 26# L-80 LTC 3,600' 7,168' 7,423' 10,768' 8,105' 6" 5" 17.95# L-80 STL 3,268' 10,568' 7,944' 13,836' 10,065' Slotted liner - no cement ¡" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9,831 feet Plugs (measured) None true vertical 9,073 feet Effective depth: measured 9,725 feet Junk (measured) None true vertical 8,968 feet Casing Length Size Cemented MD TVD Structural Conductor Surface 2,322' 13-3/8" 2,200 sx 2,438' 2,213' Intermediate 3,889' 9-5/8" 1140 sx 4,005' 3,548' Production 9,662' 7" Stage 1: 1200 sx, Stage 2: 500 sx 9,778' 9,035' Liner RECEIVED FP{ o 6 zorJZ Perforation depth: measured 9,020' " 9,053' (Squeezed), 9,336' - 9,690' (4 intervals) Aiask.a Oil & Gas COOS, Commìssíoo true vertical 8,293' - 8,325' (Squeezed), 8,603' - 8,950' (4 intervals) Anchorage 20. Attachments [ X] Filing Fee [ ] Property Plat [X] BOP Sketch [ ] Diverter Sketch [ X] Drilling Program [ X] Drilling Fluid Program r 1 Time vs Depth Plot r 1 Refraction Analysis r ] Seabed Report r 1 20AAC25.050 Req. Contact Engineer Name/Number: Bill Penrose (907)258-3446 Prepared By Name/Number: Bill Penrose (907)258-3446 21. I her~~~rtifY that the foregoing is true and correct to the best of my knowledge Signe r . Date .:2 -i.f- ,,;¿ .1;:/. -1-'-..-. Title Bobby L. Smith, Drilling / Operations Manager V Commission Use Only Permit Number >3-t./ API Number fß)1 ftlal f¡~t~ See cover letter 2...0 2,.. -0..;: ~() - 733 - 2-ö 'Z5' 1-0 2- for other requirements Conditions of Approval: . Samples Required: [ ] Yes P<J No Mud Log "F!equired [ ] Yes ['o(No Hydrogen Sulfide Measures: Þ4 Yes [ ] No Directional Survey Req'd ~Yes [ ] No Required Wor~g Pres;>ure for BOPE: [] 2M, [] 3M, [] 5M, [ ] 10M, [ ] 15M . Other: \"e,:) fxJP E 4v ~ 000 f U. j¡;£~ Date ~ /Ä I, Original Signed By by order of I),~ Approved By Cammy Oechsli Commissioner the commission Form 10-401 Rev. 12-01-85 Submitlln Triplicate llL f \ HEMLOCK FORMATION 1" LINER T/HC MD TVDSS EAST FLANK WEST FLANK FAULT BLOCK 2 EXIT POINT T/HC MD1 TVDSS ASSUMED AVERAGE BED DIP: 750 MIDDLE GROUND SHOAL FIELD Kenai County Offshore Cook Inlet, Alaska PROPOSED SIDETRACK MAP VIEW GEOLOGIST: M. LANGELER DATE: MAY 22, 2001 LATERALp2. CDR E , WEST FLANK EAST FLANK 1" LINER lœ T/HC MD: 10.122' X: -2,911 Y: 1,600 z: -8,000 -8,105 TVD T/HC MD;..lU!!Q' X: -3,410 Y: 2,360 z; -9,960 1VDSS -10,065 1VD Kenai Offshore Cook inlet Alaska Cross Section E-E' PROPOSED WEST fLANK SIDETRACK SECTION 14, T-8-N, R-13·W GEOLOGIST: M. LANGELER DATE: MAY 22, 2001 SCßßP.cdr Cross Timbers on ,...... ~ ~ ,.".' ",. ,'> - , ",'" ,,, ~- ~ ..... '.,' -,- "... ...."".,.·:,.1 ~ . '" <" ¥' \--- C\ o A22-14LS () _IS';@276__ --- NL -- I I I I I I I I I ------ --- ~""""""-~........ç I I ~ -~- I I I I ~ I I ... ... I I I Q Q Q ~ Q \"""4 .< ,.'~ . ." ,~ """ -----. C24A·14 7t @ 2760 34 ~o A34-11lS 75' @ 2800 31' est. Non LOG ~~ 15 MLS EST. cyW .10,150 C11·2 67"@ 18 - -------~-----~ ~~-~- ----~ .-. ;..-'~-~---__ft__~_______---- C11·23ST. '1~ ,ii' 710' 10 10 10 ~ 10 10 a.t) ,..... o v' ",.,- <",.,~ ,'- ------------ C2§A·14 . 75"@ 276 12 UM/TfD A34-11LS 7S:)@ 280" 23' est. NO IJ P LOG \Q A31·14lW 7(® 28se NLÇJ . I I I f ~ A22·14LS 7S"@276c NL op ........ ::::...... ....... ~.... ......... .,.,.,., ............ .....,.,.... ............ ........ -...- ........ I --~ -"'.-~-::;- - - ~ -- ~:;;==- r:11·7'J~ ....... ~ I I I I I I I I I I A34-11LS 7SíãJ 21m 93'est.~ :/.20 NOS _____ ~ 1A221 LOG ./00 ~65'@~74'- Top ¡ 143 Top o "" .... ... .... "'- ........... I - ........ .......... .......... .......... ........ ........ ......... 75@ 276~ 5285# 1988 82 A22.141S 75 @ 27{¡' -- ----------------- ------ 91' est. - --~---- I I I OIW -10,150' - C. 3l-t. 3- Hb: N/5TP/rY I _---ø----~---------------... I I ....................-...,........ I I _---......J........................................ ~_.. ~"h. t"''''''''.''"_ I -........:..-.........::-...:-....-....- .-.:..........:-:.- I I . -,- "",.- -- I D I A22.14 I -- 3Q'@2l3'* 42 fo~ '*~ Q o Q ~ ~ '!""'4 . I I I \ I o . 1"" "... .. '" I I I I , " ,-,_:,.;:'-'", .',':-)'<. - "; ..-.r~-~'" ..~--_ ~'~_.. I I I I J.......... ... I I ---" --¥--"~-'--~--"--'- - .-"""'!íFi::::"'- - .... .... .... ....... ....- 'J. ..-.... ..IiiIII/IIìI..................._"" ---~_..--+-----_.,. ~ A22·14LS "j13'@27&' NA I 'HZ NOT PENETRATED -1-· I I I 5: C24A-14 &5'@271" 00---- 93 _1- C21A·23 75'@218 SO ..--- 47+ TD L' 65 .f: ___.._..,_"u. ___.,~" _m ___ - _" __'W .._n____.._~__·· -.--.. .-------- ," .,-'."-' -- , r-----------------------zP-r--- 0 -- --EST. O.W .jQ,15Q ------- - -,---- -- ---- --- -- I : HOT P£IV~rd¡';'í,;¡J l -- " __........ ___,_.l________._..~_..____L__.....___.. ,---' ,............ _____ I I ----------rcj¿-23-L0 -.." :..!:!ß: NMPlfY ._.....__......l"...._..· ...-.............. I e e XTO Energy, Inc. MGS C32-23LW Sidetrack Procedure / With the rig over C32-23, the BOPE installed and tested and the C32-23 wellbore plugged with cement: RIH with 9-5/8" one-trip whipstock. Orient and set whipstock on the cement plug at j ±3,900'MD and mill a window in 9-5/8" casing using an 8-1/2" mill. / Directionally drill 8-1/2" hole &om 3,900' to 10,768' MD. \.QT~ '";}.~E."~ ~~,~ Run and cement 7", 26#, N-80, BTC ~rmediate casing at 10,768' MD. Top of cement will be planned to be at ±9,000' MD. I Clean out casing to float collar and pressure-test casing to 3,000 psi. I Drill out casing shoe and displace well to 8.5 ppg oil-base drilling mud. / Drill approximately 20' of new hole and conduct leak-off test (not to exceed 14.0 ppg EMW). / Directionally drill 6" hole &om 10,768' to 13,836' MD. I Run 5", 17.95#, L-80, STL slotted liner to 13,836' MD with TOL at approximately 10,668' (~100' oflap). Displace well to fihered InIcj water. - ~"...... ....."',,\";) "<> 'to ~'to\<>._.I., '<-c- ~~ ~ Run 2-7/8", 6.5#, L-80, 8rd EVE completion with gas lift design. Pickle inside oftubing with HCl/xylene and circulate inhibited filtered Inlet water into annulus before setting packer. / N/D BOPE, N/U tree. Test treeto 5,000 psi. Release rig. e e XTO Energy, Inc. Drilling Fluid Program, Pressure Calculations, and Drilling Area Risks MGS C32-23L W Sidetrack Drilline: Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids 8-112" Hole Section 3,900' -10,768'MD 8.8 -11.8 ./ 18 - 30 15 - 20 55 - 80 12 -18 18 - 25 <10 9 -10 <5 Drilline: Fluid System: 6" Hole Section (10,768' -13,836'MD 8.8 - 9.4 /' 20 - 25 18 - 22 75 - 115 8-20 15 - 30 4-5 Oil Base <5 Two Derrick Shale Shakers Pit Level Indicator (Visual and Audio Alarms) Desander, Desilter, Mud Cleaner Trip Tank Centrifuge Fluid Flow Sensor Degasser Fluid Agitators Maximum Anticipated Surface Pressure: The maximum anticipated surface pressure (MASP) for both hole sections in this sidetrack will be the lesser of the formation pore pressure (less a full gas column to the surface) or the formation rracture pressure at the last casing shoe (less a full gas column to the surface). Based on offset well data, the highest formation pressure expected in the 8-112" hole section is the Hemlock reservoir pressure of 3,400 psi at the section TD of 8,105' TVD (or 0.419 psi/ft) and the formation rracture pressure at the sidetrack depth of 3,381' TVD is a minimum of 12.5 ppg EMW (0.650 psi/ft). Complete evacuation ofthe wellbore, except for a 0.11 psi/ft gas gradient, is assumed. 8-112" hole section MASP (pore pressure) MASP (fm breakdown) (8,105 ft)(0.419 - 0.11) = 2,504 psi (3,381 ft)(0.650 - 0.11) = 1,826 psi / e e Therefore, MASP in the 8-1/2" hole section is 2,504 psi and it is proposed that the BOPE be routinely tested to 3,000 psi. Again, based on offset well data, the highest formation pressure expected in the 6" hole section is 3,400 psi (Hemlock reservoir pressure) at the section TD of 10,065' TVD (or 0.338 psi/ft) in the target Hemlock Formation. The formation rracture pressure at the 7" liner shoe depth of8,105' TVD is 14.5 ppg EMW (0.754 psi/ft). Complete evacuation of the wellbore, except for a 0.11 psi/ft gas gradient, is assumed. (10,065 ft)(0.338 - 0.11) = 2,295 psi/ (8,105 ft)(0.754 - 0.11) = 5,220 psi / Therefore, MASP in the 6" hole section is 2,295 psi and it is proposed that the BOPE be routinely tested to 3,000 psi. 6" hole section MASP (pore pressure) MASP (fin breakdown) Well Proximity Risk: <;A:.R- (,Jh.'l..k<€~. ~Æ- The nearest wellbore to that ofC32;:2JBWÍs C31-23. This well will pass 646' rrom Well C31-23 at the kickoff depth of3~900'MD. Drilline: Area Risks: The primary drilling risk in the C32-23L W area are those of stuck pipe in the coals of the Tyonek and Hemlock Formations. The risk of stuck pipe in the coals will be countered in three ways: 1.) Drillers experienced at drilling the formations of the Cook Inlet Basin will be used. 2.) Bit selection will include those which experience a slower rate of penetration when entering coal beds, thus giving warning of coals being encountered and preventing the BRA rrom entering them until the coals can be reamed open. 3.) Casing will be set below the base ofthe East Flank ofthe Hemlock Fm., thus isolating the coals before lowering the mud weight and drilling the target Hemlock West Flank. Disposal of Muds and Cuttine:s: ./ MGS Platform C has a dedicated Class II disposal welL All waste wellbore fluids will be injected down the disposal well as will cuttings after they are ground. C32-23L W Casine: Properties and Desie:n Casing Performance Properties Internal Collapse Tensile Strength Size Weight Yield Resistance Joint Body TVD MD Design Safety F actor* (in.) (lb/ft ) Grade Cnxn Ú!W Ú!W (1.000Ibs) (ft RKB) (ft RKB) T B C 7 29 L-80 BTC 8,160 7,020 746 676 5,581 7,168 2.62 2.44 2.55- 7 26 L-80 LTC 7,240 5,410 519 604 8,105 10,768 6.48 12.07 1.61 - 5 17.95 L-80 STL Slotted Slotted 396 422 10,065 13,836 7.91 N/A N/A e * Tensile design safety factors are calculated using pipe weight less buoyancy. Burst design safety factor for 7" casing is calculated using ASP. Safety factor for 5" liner does not apply since liner is slotted. Collapse design safety factor for 7" casing is calculated assuming complete evacuation of the casing. Safety factor for 5" liner does not apply since liner is slotted. Casing Setting Depth Rationale e 7" 10,768' RKB, MD 5" 13,836' RKB, MD Drilling liner to provide sufficient ftacture gradient and well control until TD is reached as well as casing off the portion of the hole containing troublesome coal beds. Production liner to provide hole stability for production operations. e e !\,t 0I-\\t¿L-~ vJ!r C32023LW/ M1""'¿.J, Summary of Drillio(rAazards /^", hY\ POST THIS NOTICE IN THE DOGHOUSE " There is a potential for lost circulation as the well bore penetrates the Hemlock reservoir. " Pipe sticking tendency is possible in the coals above and in the Hemlock reservoir. " This wellbore is planned to pass within 646' of Well C31-23 at the sidetrack depth of 3,900' MD. This is the closest that this well will approach any other wellbore " There is no H2S risk anticipated for this well. CONSULT THE C32-23LW WELL PLAN FOR ADDITIONAL INFORMATION Created t>( ion.. For: B Penrose Date platted: 24-Jan-2002 Plot Ref~rence ie C32-23LW Vereion 16. Coordinotea or. in feet reference slat #1-2. True Vertical ~pth. ore referenoe rotary toble. .Jr: TN",O'n -- XTO Energy, Inc. structure: C PLATFORM Well: C32-23LW Field : Middle Ground Shoals Location : Cook Inlet, Alaska =====:II ======:I =====::I ====== PROFiLE COMMENT DATA ==== -======:. c==::=== r:=. ----- Point ----- MO Inc Oir TVO North East V. Sect Oeg/1 00 KOP-Sidetrack pt 3900.00 37.25 342.00 3380.64 1562.75 -653.89 1663.10 0.00 EOC # 1 4272.68 48.27 344.76 3653.86 1804.98 -725.53 1914.84 3.00 Bgn Orp/Trn 9455.09 48.27 344.76 7103.07 5536.81 -1742.25 5775.47 0.00 Tgt-T/HC - EOC#2 10768.44 36.91 42.30 8104.98 6332.99 -1600.01 6526.06 3.00 Bgn Fnl Bld/Trn 11894.08 36.91 42.30 9005.00 6833.00 -1145.00 6923.04 0.00 Final EOC 13013.64 73.76 266.94 9834.93 7135.18 -1571.39 7305.65 9.00 Tgt - T/HC - TO 13836.21 73.76 266.94 10065.00 7093.00 -2360.00 7424.80 0.00 XTO Inc.. , structure: C PLATFORM Well: C32-23LW Field: Middle Ground Shoals Location: Cook Inlet, Alask <- 3600 3300 3000 2700 2400 21 00 1800 1500 1200 900 600 300 300 600 7000 o Tgt - C32-23LW TgtT/He Rv"d TO TGT HC 2360' FSL, 1326' FWL SEC. 14, TaN, R13W, SM TARGET - HR 2100' FSL, 2542' FWL SEC, 14, T8N, R13W. SM TARGET - T I HC 1600' FSL. 2086' FWL SEC. 14, T8N R13W SM 348.26 AZIMUTH 7425' (TO TD) ***P!ane of Proposal***, For; a Penrose Dot~ plotted : 24-Jon-2002 Plot Refe",nce is C32-23tY/ Version #5. C""rdinotes ore in f"et ref"",""" slot #1-2. Verticol Depths "r.. ",fer"nce r"wry Fnl Bld/Tm T/HR Tgt 1S-Mor-01 7200 6900 6600 6300 6000 5700 5400 5100 4800 ^ I 4WO 4200 r-. ..... <b 3900 <b ...... ......... 3600 3300 3000 2700 2400 2100 1800 1500 1200 ~ Tgt-T/HC - EOefj2 C32-23LW TgtT/HC(1) Rvsd 18-M,¡y-01 3200 ~.. KOP-SîdetroGk pt 40.20 3600 46.12 mc #1 4000 4400 4800 5200 "-,, 5800 ..- <II <II '- '--" 6000 6400 6600 7200 <II :J L 7600 l- I V 8000 8400 8800 9200 9600 10000 10400 Inc. , Structure: C PLATFORM Well: C32-23LW Field : Middle Ground Shoals Location : Cook Inlet, by í"""$ Dote plotted: 24--,,1on-2oo2 PI<>I: Reference is C32-23LW Version {!5. VertÌ-e:ol Dëptha .ore. tßfefence rotary MAXIMUM ANGLE 48.27 DEG (This Section) 47,47 44.15 41.29 39.02 37.45 36.66 36.70 ~è". Tgt-TjHC - EOC¡;2 18-Mcy-01 7 Casing C32.-23LW AVERAGE ANGLE 36.91 DE (This Section) C32-23LW TjKI< T! t 8g" DrpjT rn DL.S: 3.00 deg per 100 ft DLS: 9.00 deg per 100 It Unlisted Tgt - TjHC - TO),~ RMI mc C32-23LW TgtTjHC Rvsd 18-Moy-01 ..... Vertical Section -> 1600 2000 2+00 2800 3200 3!íOO 4000 4400 4800. 5200 5600 6000 6400 6600 7200 7600 Azimuth 3.48.26 with reference 0.00 N, <J.OO E from slot #1-2 e e XTO Energy, Inc. C PLATFORM C32-23LW slot #1-2 Middle Ground Shoals Cook Inlet, Alaska PRO P 0 S ALL I S TIN G by Baker Huqhes INTEQ Your ref Our ref T.i r.ense C32-23LW Version #5 prop4572 Date printed Date created Last revised 24-Jan-2002 18-Mar-2001 24-Jan-2002 Field is centred on n60 50 4.803,w151 29 11.941 Structure is centred on n60 46 36.826,w151 29 36.377 Slot location is n60 45 50.217,w151 30 8.484 Slot Grid coordinates are N 2474234.577, E 231360.866 Slot local coordinates are 4733.00 S 1595.00 W ojection type: alaska - Zone 4, Spheroid: Clarke - 1866 R€ference North is True Narth XTO Energy, Inc. e PROPOSAL LISTING.e 1 C PLATFORM,C32-23LW Your ref : C32- LW Version #5 Middle Ground Shoa1s,Cook Inlet, Alaska Last revised : 24-Jan-2002 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID C o 0 R D S G E 0 G RAP B I C Depth Degrees Degrees Depth C 00 RDINAT E S Easting Northing C 00 RDINAT E S 3900.00 37.25 342.00 3380.64 1562.75N 653.89W 230742.71 2475811. 77 n60 46 05.60 w151 30 21. 65 4000.00 40.20 342.86 3458.65 1622.39N 672.75W 230725.20 2475871.82 n60 46 06.19 w151 30 22.03 4100.00 43.16 343.62 3533.33 1686.06N 691. 91W 230707.50 2475935.91 n60 46 06.82 w151 30 22.42 4200.00 46.12 344.31 3604.47 1753.58N 711.31W 230689.64 2476003.86 n60 46 07.48 w151 30 22.81 4272.68 48.27 344.76 3653.86 1804.98N 725.53W 230676.60 2476055.56 n60 46 07.99 w151 30 23.10 4500.00 48.27 344.76 3805.15 1968.67N 770.12W 230635.74 2476220.22 n60 46 09.60 w151 30 23.99 5000.00 48.27 344.76 4137.93 2328.72N 868.22W 230545.86 2476582.40 n60 46 13.15 w151 30 25.97 5500.00 48.27 344.76 4470.71 2688.76N 966.31W 230455.99 2476944.58 n60 46 16.69 w151 30 27.95 6000.00 48.27 344.76 4803.49 3048.81N 1064.40W 230366.11 2477306.76 n60 46 20.24 w151 30 29.92 6500.00 48.27 344.76 5136.27 3408.86N 1162.50W 230276.23 2477668.94 n60 46 23.78 w151 30 31. 90 7000.00 48.27 344.76 5469.05 3768.91N 1260.59W 230186.36 2478031.11 n60 46 27.33 w151 30 33.88 7500.00 48.27 344.76 5801. 83 4128.96N 1358.68W 230096.48 2478393.29 n60 46 30.87 w151 30 35.85 8000.00 48.27 344.76 6134.61 4489.01N 1456.78W 230006.60 2478755.47 n60 46 34.42 w151 30 37.83 8500.00 48.27 344.76 6467.39 4849.05N 1554.87W 229916.73 2479117.65 n60 46 37.96 w151 30 39.81 9000.00 48.27 344.76 6800.17 5209.10N 1652.97W 229826.85 2479479.83 n60 46 41.51 w151 30 41.79 9455.09 48.27 344.76 7103.07 5536.81N 1742.25W 229745.05 2479809.48 n60 46 44.74 w151 30 43.59 9500.00 47.47 346.22 7133.19 5569.05N 1750.60W 229737.43 2479841. 91 n60 46 45.05 w151 30 43.75 9600.00 45.76 349.61 7201. 89 5640.09N 1765.84W 229723.81 2479913.27 n60 46 45.75 w151 30 44.06 9700.00 44.15 353.19 7272.67 5709.91N 1776.43W 229714.81 2479983.31 n60 46 46.44 w151 30 44.28 9800.00 42.65 356.98 7345.34 5778.34N 1782.35W 229710.45 2480051. 85 n60 46 47 .12 w151 30 44.40 9900.00 41.29 0.98 7419.69 5845.18N 1783.58W 229710.74 2480118.70 n60 46 47.77 w151 30 44.42 10000.00 40.08 5.19 7495.54 5910.24N 1780.10W 229715.70 2480183.67 n60 46 48.41 w151 30 44.35 10100.00 39.02 9.60 7572.66 5973.36N 1771. 94W 229725.29 2480246.58 n60 46 49.04 w151 30 44.19 10200.00 38.14 14 .20 7650.84 6034.35N 1759.12W 229739.50 2480307.27 n60 46 49.64 w151 30 43.93 10300.00 37.45 18.96 7729.88 6093.06N 1741.66W 229758.29 2480365.56 n60 46 50.21 w151 30 43.58 10400.00 36.95 23.85 7809.55 6149.31N 1719. 62W 229781. 60 2480421. 30 n60 46 50.77 w151 30 43.13 10500.00 36.66 28.84 7889.64 6202.96N 1693.06W 229809.37 2480474.33 n60 46 51. 30 w151 30 42.60 10600.00 36.57 33.87 7969.92 6253.86N 1662.05W 229841.53 2480524.51 n60 46 51.80 w151 30 41. 98 10700.00 36.70 38.89 8050.18 6301.87N 1626.68W 229877.98 2480571. 70 n60 46 52.27 w151 30 41. 26 10768.44 36.91 42.30 8104.98 6332.99N 1600.01W 229905.36 2480602.21 n60 46 52.58 w151 30 40.73 10768.46 36.91 42.30 8105.00 6333.00N 1600.00W 229905.37 2480602.21 n60 46 52.58 w151 30 40.73 11894.08 36.91 42.30 9005.00 6833.00N 1145.00W 230371.61 2481091. 73 n60 46 57.50 w151 30 31. 56 11900.00 36.53 41. 69 9009.74 6835.63N 1142.63W 230374.04 2481094.30 n60 46 57.53 w151 30 31. 52 12000.00 30.59 29.39 9093.13 6880.12N 1110.28W 230407.39 2481138.04 n60 46 57.97 w151 30 30.87 12100.00 26.25 12.74 9181. 20 6923.95N 1092.88W 230425.78 2481181.46 n60 46 58.40 w151 30 30.52 12200.00 24.38 352.04 9271. 77 6966.05N 1090.86W 230428.76 2481223.51 n60 46 58.81 w151 30 30.47 12300.00 25.53 330.78 9362.62 7005.38N 1104.26W 230416.26 2481263.13 n60 46 59.20 w151 30 30.74 12400.00 29.34 312.99 9451.50 7040.96N 1132.76W 230388.58 2481299.35 n60 46 59.55 w151 30 31. 32 12500.00 34.96 299.71 9536.24 7071. 94N 1175.66W 230346.40 2481331. 29 n60 46 59.86 w151 30 32.18 12600.00 41. 65 289.96 9614.74 7097.53N 1231. 89W 230290.77 2481358.16 n60 47 00.11 w151 30 33.32 12700.00 48.97 282.56 9685.07 7117.12N 1300.07W 230223.04 2481379.29 n60 47 00.30 w151 30 34.69 12800.00 56.66 276.69 9745.50 7130.21N 1378.54W 230144.90 2481394.17 n60 47 00.43 w151 30 36.27 12900.00 64.58 271.78 9794.54 7136.50N 1465.34W 230058.27 2481402.42 n60 47 00.49 w151 30 38.02 13000.00 72.65 267.49 9830.99 7135.81N 1558.35W 229965.27 2481403.85 n60 47 00.48 w151 30 39.89 13013.64 73.76 266.94 9834.93 7135.18N 1571. 39W 229952.21 2481403.52 n60 47 00.48 w151 30 40.15 13500.00 73.76 266.94 9970.96 7110.24N 2037.67W 229485.49 2481389.19 n60 47 00.23 w151 30 49.55 13836.21 73.76 266.94 10065.00 7093.00N 2360.00W 229162.86 2481379.29 n60 47 00.06 w151 30 56.04 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1-2 and TVD from rotary table (105.00 Ft above mean sea level). Bottom hole distance is 7475.31 on azimuth 341.60 degrees from wellhead. Total Dogleg for wellpath is 151.35 degrees. Vertical section is from wellhead on azimuth 348.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid e XTO Energy, Inc. C PLATFORM,C32-23LW Middle Ground Shoals,Cook Inlet, Alaska Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----~~--------------------------------------------------~-------------------------------------------------- PROPOSAL LISTING~ge 2 Your ref : C3~W Version #5 Last revised : 24-Jan-2002 3900.00 3380.64 1562.75N 653.89W KOP-Sidetrack pt 4272.68 3653.86 1804.98N 725.53W EOC #1 9455.09 7103.07 5536.81N 1742.25W Bgn Drp/Trn 10768.44 8104.98 6332.99N 1600.01W Tgt-T/HC - EOC#2 10768.46 8105.00 6333.00N 1600.00w C32-23LW TgtT/HC[l) Rvsd 18-May-Ol 11894.08 9005.00 6833.00N 1145.00w C32-23LW T/HR Tgt 18-Mar-Ol 13013.64 9834.93 7135.18N 1571. 39W Final EOC 13836.21 10065.00 7093.00N 2360.00W C32-23LW TgtT/HC Rvsd 18-May-Ol Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a n/a 653.89W 10768.46 8105.00 653.89W 13836.21 10065.00 ----------------------------------------------------------------------------------------------------------- 1600.00W 7" Casing 2360.00w Unlisted 3380.64 3380.64 1562.75N 1562.75N 6333.00N 7093.00N Target name T.V.D. Targets associated with this wellpath Revised ===================================== Geographic Location Rectangular Coordinates ----------------------------------------------------------------------------------------------------------- C32-23LW TgtT/HC(l} C32-23LW T/HR Tgt 18 C32-23LW TgtT/HC Rvs 8105.00 9005.00 10065.00 6333.00N 6833.00N 7093.00N 1600.00W 1145.00W 2360.00w 18-Mar-2001 18-Mar-2001 20-Mar-2001 - XTO Energy, Inc. C PLATFORM C32-23LW slot #1-2 Middle Ground Shoals Cook Inlet, Alaska PRO P 0 S A L SUMMARY Your ref Our ref License Date printed Last revised C32-23LW Version #5 prop4572 22-Jan-2002 17-Jan-2002 e Slot location is n60 45 50.217,w151 30 8.484 Slot Grid coordinates are N 2474234.577, E 231360.866 Slot local coordinates are 4733.00 S 1595.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Measured Inclin. Azimuth True Vert R E C T A N G U LA R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/l00ft Sect 3900.00 37.25 342.00 3380.64 1562.75 N 653.89 W 1663.10 4272.68 48.27 344.76 3653.86 1804.98 N 725.53 W 3.00 1914.84 9455.09 48.27 344.76 7103.07 5536.81 N 1742.25 W 5775.47 10768.46 36.91 42.30 8105.00 6333.00 N 1600.00 W 3.00 6526.07 11894.08 36.91 42.30 9005.00 6833.00 N 1145.00 W - /6923.04 13013.64 73.76 266. 94 9834.93 7135.18 N 1571. 39 W 9.00 7305.65 13836.21 73.76 266.94 10065.00 7093.00 N 2360.00 W 7424.80 Corrunents in wellpath ==================== - KOP - End of Build/Turn - End of Hold - End of Drop/Turn & C32-23LW TgtT/HC - End of Build & C32-23LW T/HR Tgt 18 - End of Build/Turn - T.D. & C32-23LW TgtT/HC Rvsd 18-May Measured Inclin. Azimuth True Vert R E C TAN G U LA R Dogleg Vert Depth Degrees Degree" Depth C 0 0 R D I NA T E S Deg/l00ft Sect 3900.00 37.25 342.00 3380.64 1562.75 N 653.89 W 1663.10 KOP-Sidetrack pt 4272.68 48.27 344.76 3653.86 1804.98 N 725.53 W 3.00 1914.84 EOC #1 9455.09 48.27 344.76 7103.07 5536.81 N 1742.25 W 5775.47 Bgn Drp/Trn 10768.44 36.91 42.30 8104.98 6332.99 N 1600.01 W 3.00 6526.06 Tgt-T/HC - EOC#2 11894.08 36.91 42.30 9005.00 6833.00 N 1145.00 W - /6923.04 Bgn Fnl Bld/Trn 13013.64 73.76 266.94 9834.93 7135.18 N 1571. 39 W 9.00 7305.65 Final EOC 13836.21 73.76 266.94 10065.00 7093.00 N 2360.00 W 7424.80 Tgt - T/HC - TD Targets associated with this well path ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- C32-23LW TgtT/HC(l) C32-23LW T/HR Tgt 18 C32-23LW TgtT/HC Rvs 8105.00 9005.00 10065.00 6333.00N 6833.00N 7093.00N 1600.00W 1145.00W 2360.00W 18-Mar-2001 18-Mar-2001 20-Mar-2001 All data is in feet unless otherwise stated. Coordinates from slot #1-2 and TVD from rotary table (105.00 Ft above mean sea level). Total Dogleg for wellpath is 151.35 degrees. Vertical section is from wellhead on azimuth 348.26 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e XTO Energy, Inc. C PLATFORM C32-23LW slot #1-2 Middle Ground Shoals Cook Inlet, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License C32-23LW Version #5 prop4572 Date printed Date created Last revised 24-Jan-2002 l8-Mar-200l 24-cTan-2002 Field is centred on n60 50 4.803,w15l 29 11.941 Structure is centred on n60 46 36.826,w15l 29 36.377 Slot location is n60 45 50.2l7,w15l 30 8.484 Slot Grid coordinates are N 2474234.577, E 231360.866 Slot local coordinates are 4733.00 S 1595.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North XTO Energy, Inc. PROPOSAL LISTING Page 1 C PLATFORM,C32-23LitIIÞ. Your re~32-23LW Version #5 Middle Ground Shoals,Cook Inl Alaska Last revise 4-Jan-2002 Measured Inclin. Azimuth True Vert R E C T A N G U LA R Dogleg Vert Depth Degrees Degrees Depth COO R D I NA T E S Deg/l00ft Sect 3900.00 37.25 342.00 3380.64 1562.75 N 653.89 W 0.00 1663.10 KOP-Sidetrack pt 4000.00 40.20 342.86 3458.65 1622.39 N 672. 75 W 3.00 1725.33 4100.00 43.16 343.62 3533.33 1686.06 N 691. 91 W 3.00 1791.57 4200.00 46.12 344.31 3604.47 1753.58 N 711. 31 w 3.00 1861. 63 4272.68 48.27 344.76 3653.86 1804.98 N 72 5.53 W 3.00 1914.84 EOC #1 4500.00 48.27 344.76 3805.15 1968.67 N 770.12 W 0.00 2084.18 5000.00 48.27 344.76 4137.93 2328.72 N 868.22 W 0.00 2456.65 5500.00 48.27 344.76 4470.71 2688.76 N 966.31 W 0.00 2829.13 6000.00 48.27 344.76 4803.49 3048.81 N 1064.40 W 0.00 3201. 60 6500.00 48.27 344.76 5136.27 3408.86 N 1162.50 w 0.00 3574.08 7000.00 48.27 344.76 5469.05 3768.91 N 1260.59 W 0.00 3946.55 7500.00 48.27 344.76 5801. 83 4128.96 N 1358.68 W 0.00 4319.03 8000.00 48.27 344.76 6134.61 4489.01 N 1456.78 W 0.00 4691. 50 8500.00 48.27 344.76 6467.39 4849.05 N 1554.87 W 0.00 5063.98 9000.00 48.27 344.76 6800.17 5209.10 N 1652.97 W 0.00 5436.45 9455.09 48.27 344.76 7103.07 5536.81 N 1742.25 W 0.00 5775.47 Bgn Drp/Trn 9500.00 47.47 346.22 7133.19 5569.05 N 1750.60 W 3.00 5808.74 9600.00 45.76 349.61 7201. 89 5640.09 N 1765.84 W 3.00 5881. 39 9700.00 44.15 353.19 7272.67 5709.91 N 1776.43 W 3.00 5951.91 9800.00 42.65 356.98 7345.34 5778.34 N 1782.35 W 3.00 6020.11 9900.00 41.29 0.98 7419.69 5845.18 N 1783.58 W 3.00 6085.80 10000.00 40.08 5.19 7495.54 5910.24 N 1780.10 W 3.00 6148.80 10100.00 39.02 9.60 7572.66 5973.36 N 1771. 94 W 3.00 6208.93 10200.00 38.14 14.20 7650.84 6034.35 N 1759.12 W 3.00 6266.04 10300.00 37.45 18.96 7729.88 6093.06 N 1741.66 W 3.00 6319.97 10400.00 36.95 23.85 7809.55 6149.31 N 1719.62 W 3.00 6370.56 10500.00 36.66 28.84 7889.64 6202.96 N 1693.06 W 3.00 6417.69 10600.00 36.57 33.87 7969.92 6253.86 N 1662.05 W 3.00 6461. 21 10700.00 36.70 38.89 8050.18 6301. 87 N 1626.68 W 3.00 6501.02 10768.44 36.91 42.30 8104.98 6332.99 N 1600.01 W 3.00 6526.06 Tgt-T/HC - EOC#2 10768.46 36.91 42.30 8105.00 6333.00 N 1600.00 W 3.00 6526.07 C32-23LW TgtT/HC(l) Rvsd 18-May- 01 11894.08 36.91 42.30 9005.00 6833.00 N 1145.00 W ~. 6923.04 C32-23LW T/HR Tgt 18-Mar-Ol 11900.00 36.53 41. 69 9009.74 6835.63 N 1142.63 W 6925.13 12000.00 30.59 29.39 9093.13 6880.12 N 1110.28 W 6962.11 12100.00 26.25 12.74 9181.20 6923.95 N 1092.88 W 7001. 48 12200.00 24.38 352.04 9271.77 6966.05 N 1090.86 W f .00 7.042.29 12300.00 25.53 330.78 9362.62 7005.38 N 1104.26 W .00 7083.52 12400.00 29.34 312.99 9451. 50 7040.96 N 1132.76 W 19.00 7124.16 12500.00 34.96 299.71 9536.24 7071. 94 N 1175.66 W I 9.00 ,7163.22 12600.00 41. 65 289.96 9614.74 7097.53 N 1231. 89 W \ 9.00 /7199.72 \ I 12700.00 48.97 282.56 9685.07 7117.12 N 1300.07 W ".ovnn." 12800.00 56.66 276.69 9745.50 7130.21 N 1378.54 W \9.00 . 7261.55 12900.00 64.58 271.78 9794.54 7136.50 N 1465.34 W 9.00 7285.36 13000.00 72.65 267.49 9830.99 7135.81 N 1558.35 W 9\~0 7303.61 13013.64 73.76 266.94 9834.93 7135.18 N 1571.39 W 9.0' 7305.65 Final EOC 13500.00 73.76 266.94 9970.96 7110.24 N 2037.67 W 0.00 7376.10 13836.21 73.76 266.94 10065.00 '7093.00 N 2360.00 W 0.00 7424.80 C32-23LW TgtT/HC Rvsd 18-May-Ol All data is in feet unless otherwise stated. Coordinates from slot #1-2 and TVD from rotary table (105.00 Ft above mean sea level) . Bottom hole distance is 7475.31 on azimuth 341.60 degrees from wellhead. Total Dogleg for wellpath is 151.35 degrees. Vertical section is from wellhead on azimuth 348.26 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ XTO Energy, Inc. C PLATFORM,C32-23L~ Middle Ground Shoals,Cook In11lll'Alaska Comments in wellpath -------------------- -------------------- MD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- TVD PROPOSAL LISTING Page 2 Your re~32-23LW Version #5 Last reviSe~4-Jan-2002 3900.00 3380.64 1562.75 N 653.89 W KOP-Sidetrack pt 4272.68 3653.86 1804.98 N 725.53 W EOC #1 9455.09 7103.07 5536.81 N 1742.25 W Bgn Drp/Trn 10768.44 8104.98 6332.99 N 1600.01 W Tgt-T/HC - EOC#2 10768.46 8105.00 6333.00 N 1600.00 W C32-23LW TgtT/HC(l) Rvsd 18-May-Ol 11894.08 9005.00 6833.00 N 1145.00 W C32-23LW T/HR Tgt 18-Mar-Ol 13013.64 9834.93 7135.18 N 1571.39 W Final EOC 13836.21 10065.00 7093.00 N 2360.00 W C32-23LW TgtT/HC Rvsd 18-May-Ol Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a n/a 653.89W 10768.46 8105.00 653.89W 13836.21 10065.00 ----------------------------------------------------------------------------------------------------------- 1600.00W 7" Casing 2360.00W Unlisted 3380.64 3380.64 1562.75N 1562 .7 5N 6333.00N 7093.00N Ta:cget name Geographic Location T.V.D. Targets associated with this wellpath Rectangular Coordinates Revised ------------------------------------- ------------------------------------- ----------------------------------------------------------------------------------------------------------- C32-23LW TgtT/HC(I) C32-23LW T/HR Tgt 18 C32-23LW TgtT/HC Rvs 8105.00 9005.00 10065.00 6333.00N 6833.00N 7093.00N 1600.00W 1145.00W 2360.00W 18-Mar-2001 18-Mar-2001 20-Mar-2001 XT Ene , Ine. . StrU(:~ture : C PLATFORM Well: C32-23LW : Middle Ground Shoals Location: Cook Inlet, Alaska For: II P Date plotted : 2~(m-2002 Plat R«fIr"l!!r1Cl!!: is CJ2-23lW \fenöIQn #5. Coord"nok!$ ore in fed. f'~ skrl: #1-1. Verliool Depths ro:tary TRUE NORTH 350 10 340 20 240 330 280 30 320 40 310 50 300 60 290 70 280 80 270 90 260 100 250 110 120 230 130 220 140 190 180 \,;~",?6QO \ "~'\1,,~BOO 48oo~ 1.60 1 7 0\. 6200 \ '''\0\, 630Q 49ÚO~ ~,640Q ~ ~ 150 210 200 Normal Plane Travelling Cylinder - All depths shown Dre MeDsured depths on Reference Well XT Ener , Structure: C PLATFORM Well: C32-23LW Field: Middle Ground Shoals Location: Cook Inlet, rc;:~t;;~'by ~.Q For: B Penròße I O¡;¡ù:o plotted; :24-JolI-:2ôQ2 ¡ Ph:¡ : Reference ia -c;i2-2JLW VßtSioo #5. ! Coord1Mœs Qfè 1n fee.t reference slot #1-2. !Truelkrtíé.aI~W rotary-tobie, I 5200 5000 4800 4600 44-00 4100 4Goo 3800 ^ 3600 ¡ "'""' - 3400 <I) Q) '*- '--' .r:. 3200 1: 0 Z 3000 2800 2600 24.00- 2200 2+00 ¡¡j j I , 8QQOJ J I l i ,,/"'" 9500$"/ <- West (feet) 14UQ 1200 1000 800 600 4GO 200 Q 200 400 L , 5200 {jj I 5000 7700/ / I 4800 74001 I , 4600 J 7100l Hmo 'r§0 77oo¡ /' i ./)/'/ 1~1Í;¡OO /I i/ ~'74QO /' 1 I i I I I p100 l i i 9200 9500 9800 ßf{';;;;;~+I~~~- EJ \ \ \ 6200 '\ \. 5900 " \ " \ 9800 ~~~~Q'\'é600~'8 v \, 8 ,\5300 I 6500.8 / / 6200. 5900 . \~ 4400 \ \ \ 5000 ~OO,B 8$QOp/"( I 8300./ j '7700 " 4700 m I (74GO W i J 7100 j 5900' 9800] ~\ l ~ 6800 '\ / \ .9:~\ fg5Q(). ", ,..""' , <& 1~600 HOO \+100 00 \,,+700 \\ 4100"14400 j~ 3800 " 4100 3800'\ \ 3800 , \ 5900 J J 3800 3500 ~ 3500 ,I ! \ 56DO~ \ . TIe an - 3380.64 Tvd, 1562;?,5 N. 65~.89 W j 5300. "JovO <\' ~ ~ . 5600. 18 6800¡ \ 8900 I '\ I '. 8600 I '. 6500. I \, 620~ I I . 5301;) J 5900 !\ \ '5600 \ \ 8300 \ .~ 8000 ì \ 7700 5000. ~5300 EI .lvoo 8900~ I 8600~ . 8300. \5000 8Qoo\ \ 7700" \\7400 440041 "øl1 000 47001 0 8 ;', ag~80 \ 3800 \ 8300 \\" \,~~ aooo \. 7700 .~ "'.3500 ~ 14-:00 1200 aoo wco <~ West (feet) Inc. \ 7400 \\ \ 7100 4400 EJ. 4200 9500 \ ~ 4000 3800 3£00 ^ I 34QO Z 0 ..., ..... :r 3200 "'""' -;,. ( ) ( ) 3000 ..... '--' 2800 2600 \6800 \" 6500 . \ \ 6200 A 9200 I \ j . 5900\ ~ a900 \ì 8600 5600, I \ ~ 8300 \1 800d~ 5300 I 7700?\ I . 5000 7400~ \ t ; 7100~ '~4700 680;~ \ HOO 6500ì \ , , 62oo¡ '~4100 j 2400 2200 95~ 2000 9200\ <& 18QO 160() 1400 600 10ù 4ÆìO o 200 4QO 7200 7100 7000 690D 6800 6700 " 6600 6800 6400 ^ 6300 ¡ ~ +- \' ) 6200 i!) - ~ .r::. 6100 +- '- 0 Z 6000 5;)00 5800 5700 5600 5500 5400 BJOO 52úO XT Inc. . 2500 , Structure: C PLATFORM Well: C32-23LW : Middle Ground Shoals Location: COQk Inlet, <- 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100: 2400 <><> "," o :-,¿> " o Et <'0 .<¡\¿ "", 0:>", , 7(1 "6¿ '(1 ";, ~'" '>. 0", 'too 4- '", '{yo '12 ".". . 9500 , 9300 Q. -9100 TQrget 9005.00 Tv<!, 6833"00 N, 1145.00 W . Q. 8900 {> 8700 <:I 8500 o 8300 a1oo~ TO(9.t - 8105,00 Tvd. 6333.00 N, 1600.00 W ,7900 5100 G 77ÖO o 7500 Q 7300 i)Q"\:4 plottlut ~ .:u".".,,¡œJ~2002 Ploi; Rèferer1<2 is C32-;23LW V-trsion #5. ,6900 2500 2400 2300 2200 2100 2000 1900 1800 1700 Hmo 1500 1400 1300 1200 1100 1000 <- West (feet) 1000 nap 7100 7000 6900 6800 6700 ^ ¡ ~ £1:00 .... (!) (Ij - '-' 6000 5900 -5800 5700 5600 5500 5400 5300 5200 5100 . XTO Energy, Inc. C PLATFORM C32-23LW slot #1-2 ~iddle Ground Shoals Cook Inlet, Alaska . 3-D M I N I MUM D 1ST A NeE C LEA RAN C ERE P 0 R T by Baker Hughes IN'l'EQ Your ref Our ref License C32-23LW Version #5 prop4572 Date printed i)3te created Last revised 24-Jan-2002 18-Mar-2001 24-Jan-20ü2 Field is centred on 060 50 4.803,w151 29 11.941 Structure is centred on n60 46 36.826,w151 29 36.377 Slot location is 060 45 50.2J7,w151 30 8.484 Slot Grid coordinates are N 2474234.577, E 231360.866 Slot local coordinates are 4733.00 S 1595.00 w Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Obl€ct_ wellpat_h DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* GMS <265-12290'>"C21A-23,C PLATFORM MMS <310B-12013'>"C11-26,C PLATFORM MSS <310B-9S5S'>"Cll-23,C PLA~FORM GMS <0-12265'>,.C11-23,C PLATFORM GMS <265-13092'>"C11-23,C PLATFORM C23-26LW Version #2"C23-26LW,C PLATFORM GygO <306-5000' >, r C23-26, C FLA_TFORM GYRO <0-11299~>"C13-23,C PLATFORM C31-26LS2 Version #2"C31-26LS2,C PLATFORM MSS <361-9935'>"C31-26,C PLATFORM GMS <4094-10027'>"C22-26RD,C PLATFonM GMS <3039-999S'>"C22-26,C PLAT~ORM MSS <9176-11216'>"C24-26,C PLATFORM MSS <3054-9872'>"C43-23,C PLATfORM MSS <651-l2600'>I,C43-11,C PLATFOFM MSS <1001-11151'>"C41-26,C PLATFORM MSS <3160-10712'>IIC41-23,C PT~TFORM MSS <3056-10656'>"C33-26,C PLATFORM MSS <3133-11282' >, , C34-26, C J? lJ-ì.'l'?ORM MSS <19S2-9642'>"C34-23,C PLATFORM MSS <3053-10254'>"C31-23,C PLATFORM MMS <551-1221S'>"C24A-14,C PLATFORM GMS<601-10jOb'>"C22-23,C PLATFORM GMS <6837-11400'>I,C44-14RD1C PLATFORM GMS <901-11800'>"C21-23,C PLATFORM C22A-26LS Verso #2"C22A-26LS,C PLATFORM GYRO <O-12140'>"C22A-26,C PLATFORM C241\-23LN Vcrs. #1, ,C24A-23LN,C PLATFORM GYRO <0-10620'>"C24A-23.C PLATFORM GYRO <0-11895'>"C12-23,C PLAT'~RM GYRO <O-1148S'>"C21-26,C PLATFORM MSS <0-9660'>"C23-23,C PLATFORM MMS <O-9850'>"C42-23,C PLATFORM MSS <3165-119181>"C-LINE,C PLATFORM C13A-23LN Vcrs. #2, ,C13h-23LN,C PL1Yl't'ORM MWD <10617 - 11163'>"C13A-23,C PLATFORM MWD <11065 - ???'>"C13A-23,C PLATFORM PGMS <~-11698'>"C13A-23,C PLATFORM MMS <4124-10900'>"C24-14~C PLATFORM Closest approach with J-D Last revised Distance 8-Jun-2000 1122.7 22-May-2000 1878.2 8-Jun-2000 1878.2 22-May-2000 1125.4 22-May-2000 1122.7 3-0ct-2000 3558.5 ?9-Jan-7000 2566.9 29-Jan-2000 1598.1 2-0ct-2000 3738.7 29-Jan-2000 1757.7 8-Jun-2000 2068.2 8-Jun-2000 2064.2 29-Jan-2000 2617.9 29-Jan-2000 1475.1 29-Jan-2000 1342.6 29-Jan-2000 2006.7 29-Jan-2000 1469.8 29-Jan-2000 2617.0 29-Jan-2000 7658.2 29-Jan-2000 1679.7 29-Jan-2000 646.3 29-Jan-2000 579.1 29-Jan-2000 918.7 29-Jan-2000 1172.9 29-Jan-20QO 1104.3 21-Mar-2001 7466.1 26-Jan-2000 23)4.5 21-Mar-2001 4283.8 29-Jan-2000 1926.0 29-Jan-2000 1199.4 29-Jan-2000 2003.5 29-Jan-20QO 1218.5 26-Jan-2000 884.0 29-Jan-2000 2787.1 2Q-J0n-2002 2767.5 17-Jan-2002 1683.8 24-Jan-2002 1683.8 9-Jan-20G2 1683.8 22-May-2000 0.0 Minimum D~sl0nce nethod Diverginq from M.D. 13080.0 13160.0 j~JOO.O 13836.2 13836.2 3900. 0 M.D. 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 4155.6 3900.0 3900.C. 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 3900.0 4540.0 3900.0 9280.0 3900.0 3900.0 3900.0 3900. 0 3900.0 3900.0 13836.2 3900.0 3900.0 3900.0 3900.0 3900.0 13540.0 4155.6 3900. 0 12853.3 3900. 0 3900. 0 3900. 0 12160.0 3900. 0 11700.0 3900.0 3900.0 3900.0 10900.0 12220.0 1]310.0 12U40.0 13400.0 13836.2 13500.0 13836.2 13320.0 13620.0 13580.0 3900.0 10700.0 3900.0 13836.2 13836.2 13836.2 13540.0 11500.0 XTO Energy, Inc. CLEARANCE LISTING Page 4 C Ph~TFORK,C32-23L~ Your- r.3?-?3LW Version #0 Middle Ground Shoals, Cook. Inl Alaska Last revise 4-Jan-2002 Reference wellpath Object wellpath GMS <0-9831'>"C32-23,C PLATFORM "Horiz r·1in'm TCyl M.D. T.V.D. Reet Coordinates M.D. T.V.D. Reet Coordinates Bearing Dist Dist 3900.0 3380.6 1562.8N 653.9W 3900.0 3380.6 1562.8N 653.9W 270.0 0.0 0.0 3911.1 3389.5 1569.2N 656.0W 3911.1 3389.5 1569.1N 656.0W 161. 5 0.0 0.0 3922.2 3398.3 157:'J."/N 658.1W 39/:/.2 339D.~ 1575.5N 658.0¡iI 161 .5 0.2 0.2 3933.3 3407.0 1582.2N 660.1W 3933.3 3407.2 1581.9N 66D.OW 161.5 0.4 0.4 3944.4 3415.7 1588.8N 662 .2W 3944.4 3416.2 1588.2N 662.0W 161. 5 0.7 0.7 3955.6 3424.4 159~'. 4N 664.3W 3955.5 342::>.1 1594.5N 661.0W 161. 5 1.2 1.7 3%6.7 3433.0 1602.1N 666.4W 3966.6 3434.0 1600.8N 666.0W 161. 5 1.1 1.1 3977.8 3441.6 160B.8N 668.5W 3977.1 3442.9 1607.0N 667.9w 161. 5 2.3 2.3 3988.9 3450.1 161S.6N 670.6W 3988.8 3451.9 1613.3N 669.9v¡ 161. 5 3.0 3.0 4000.0 3458.6 1622.4N 672.8W 3999.8 3460.8 1619.5N 671. ew 161. 5 3.B 3.8 4011.1 3467.1 1629.3N 674.9w 4010.9 3469.8 1625.6N 673.7W 161. 6 4.7 4.7 4022.2 3475.5 1636.2N 677. OW 4022.0 3478.9 1631.1N 675.5W 161. 9 5.8 5. B ,1033.3 3483.9 1643.2N 679.1W 4032.9 3487.8 1637.7N 6Fl.3w 162.2 7.0 7.0 4044.4 3492.3 1650.2N 681.2W 4043.9 3497.0 1643.6N 679.2W 162.5 8.4 8.4 4055.6 3500.6 1657.3N 683.4W 4054.8 3506.0 1649.4N 680.9W 162.8 9.9 10.0 4066.7 3508.8 1664.4N 685.5W 4065.7 3515.2 1655.IN 682.7W 163.1 11. 6 11.7 4017.8 3517.0 1671.6N 687.6W 407ó.4 3524.2 1660.1N 684. 4W 163.4 13.4 13.6 4088.9 3525.2 1678.8N 689.8W 4087.4 3533.4 1666.2N 686.1W 163.6 15.4 15.1 4100.0 3533.3 1686.1N 691.9W 4098.3 3542.7 1671.7N 68'1. dl·J 163.8 17.6 18.0 4111.1 3541. 4 1693.4N 694.1W 4108.8 3551. 1 1671. ON 689.4W 164.0 19.9 20.3 4122.2 3549.4 1700.1N 696 .2W 4119.1 3561. 0 1682.4N 691. OW 164.2 22.3 22.9 4133.3 3551.4 170B.IN 69B.4W 4130.2 3510.0 1681.5N 692.6W 164.4 24.8 25.6 4144.4- 3565.4 1715.6N 70C.5W 4111. 0 3579.3 1692.7N 694.2Y] 164. '::' 27.5 28.4 4155.6 3573.3 1123.IN 102.1W 4151. 3 3588.3 1697.7N 695.7W 164.7 30.3 31. 4 4166.1 3581. 2 1730.7N 704.8w 4162.1 3597.6 1702.8N 697.3W 164.8 33.2 34.5 4177.8 3589.0 1738.3N 707. OW 4172.8 3606.9 1707.8N 698.8W 164.9 .,6.2 37.8 4188.9 3596.7 1745.9N 709.1W 4182.9 3615.1 1712.6N 700.2W 165.0 39.4 41.2 4200.0 3604.5 1753.6N 711. 3W 4193.5 3625.0 1717.5N 701. 7W 165.2 42.1 44.8 ~ 21 0.4 3611. '/ 1760.8N 713.3W <1702.7 3633.1 1721.71' 7!J3.ÜW 165.2 45.8 48.3 4220.8 3618.8 1768.1N 715.4W 4212.6 3641.8 1726.1N 7D4.4W 165.3 49.1 52.0 4231. 2 3625. 9 1775.4N 111.4W 4222.4 3650.5 1730.5N 7QS.7W 165.4 52.5 55.8 4241. 5 3632.9 1782.1N 719.4W 4231. 3 3658.4 1734.4N 106.9W 165.5 56.0 59.8 4 2S1. 9 3640.0 1790.1N 721.SW 42111. 0 3667.0 1738.6N "/08.2w 165.5 59.7 61.0 4262.3 3646.9 1791.5N 123.5W 4249.6 3614.7 1742.3N 709.3W 165.6 63.4 68.4 4272.7 3653.9 l80S.0N 725.5W 4259.2 3683.4 1146.4N 7l0.6W 165.7 67.3 12.9 4300.0 36·12.0 1824.6N 730. 9'~v 4283./ 3704.9 1i56.3N 713.6W' 16,).8 n.8 8.4.9 4400.0 3738.6 1B96.7N 150.5W 4372.7 3786.6 1791.7N 724.0W 165.8 118.4 130.3 4500.0 3805.2 1968.1N 770.1W 4463.0 3869.3 1826.8N 132 . 9W 165.3 160.1 176.2 4600. 0 3871.7 ?040.7N 789.7W 1553.6 3952.3 1861.9N 741.7W 165.0 701.9 222.4 4100.0 3938.3 2112.1N B09.4W 4643.9 4035.1 1896.7N 750.9W 164.9 243.8 269.3 4800.0 4004.8 2184.7N 829. OW 4133.0 4117.0 1930.7N 759.5W 164.7 286.2 316.7 4900.0 4071. 4 2256.7N 848.6W 4822.3 4199.2 1964.5N 767.9W 164.6 329.0 364.3 5000.0 4137.9 2328.7N 868.2" 4912.6 4282.4 1:.'98.6N 776.4W 1511.5 ]71. 8 412.9 5100.0 4204.5 2400.7N 887.8W 4999.3 4362.4 2031.2N 784.2W 164.3 415.0 464.1 5200.0 4271. 0 2472. IN 907.5W 5081.8 4444.3 2064.0N 791. BW 164.2 458.8 520.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coord-inates from slot #1-2 a.nd ':'VD from rotary table (105.00 YL above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 348.26 degrees. Calculation uses the minimum curvature method. Present.ed by Baker Hughes INTEQ XTO Energy, Ifie.. CLEARANCE ~G Page 2 C pr,ATPORM, C32-23LVJ Your ref C32~2JL\o¡ Version #é Middle Ground Shoals, Cook Inlet, Alaska Last revised : 24-Jan-2002 Reference wellpath Obj ect we11path MMS <4124-10900'>"C24-14,C PLATFORM lIoriz Min'ill TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bear ing Dist Dist 3900.0 3380.6 1562.8N 653.9W 3900. 0 3380.6 1562.8N 653.9W 270,0 0.0 0.0 3911.1 3389.5 1569.2N 656. OW 3911. 1 3389.5 1569.2N 656.0W 175.3 0.0 0.0 3922.2 339B.3 :"'S75.7N 658.1W 3922.2 3393. :3. :"'S75.5N 658.0W 175.3 0.1 D .1 3933.3 3407.0 1582.2N 660.1W 3933.3 3407.2 1581. 9N 660.1W 175.3 0.3 0.3 3944.4 3415.7 1588.8N 662.2W 3944.4 3416.0 1588.3N 662.2W 175.3 0.5 0.5 3950.6 3424.4 1595.4N 664.3W 3955.5 3424.9 1594.7N 664. 3¡'¡ 175.3 0.8 0.8 3966.7 3433.0 1602.1N 666.4W 3966.7 3433.7 1601.1N 666.4W 175.3 1.2 1.2 3977. 8 3441. 6 1608.8N 668.5W 3977 . 8 3442.5 1607.5N 668.4W 175.3 1.6 1.6 3988.9 3450.1 1615.6N 670.6W 3988.9 3451.4 1613.9N 670. SW 175.3 2.1 2.1 4000.0 3458.6 1622.4N 672.8W 4000.0 3460.2 1620.3N 672.6W 175.3 2.6 2.6 4011.1 3467.1 1629.3N 674.9W 4011.0 3469.0 1626.7N 674.7W 175.3 3.2 3.2 4022.2 3475.5 1636.2N 677.0W 4022.1 3477.9 1633.1N 676.7W 175.3 3.9 3.9 4033.3 3183. 9 1643.2N 679.lW 40:)3.2 3486.7 1639.4N 678.6vJ 175.3 4. "! 4.7 4044.4 3492.3 1650.2N 681.2W 4044.3 3495.5 1645.8N 680.9W 175.3 5.5 5.5 4055.6 3500.6 1657.3N 683.4W 4055.4 3504.3 1652.2N 682.9W 175.3 6.3 6.4 4066.7 3508.8 1664.4N 685.5W 4066.5 3513.1 1658.6N 685.0vJ 17=,.3 7.3 7.3 4077.8 3517.0 1671. 6N 687.6W 4077.5 3521. 9 1(;64.9N 687.1W 175.3 8.3 8.3 4088.9 3525.2 1678.8N 689.8W 4088.6 3530.8 1671.3N 689.2W 175.3 9.3 9.4 '1100.0 3533.3 1686.1N 691. 9W 4099.6 3539.5 167ï.7N 691.2W 175.3 10. Ò 10.5 4111.1 3541.4 1693.4N 694 .1 W 4110.7 3548.3 1684.0N 693.3W 175.3 11.7 11. 7 4122.2 3549.4 1700.7N 696.2W 4121. 7 3557.1 1690.4N 695.3W 175.3 12.9 13.0 4133.3 3557.4 1708.1N 698.4W 4132.7 3565.9 1696.7N 697.4W 175.3 14.2 14 .3 4111. 4 J56:-'.4 1715.6N 7 CO .5T,\1 4143. c¡ 3574.7 17D3.0N 699.5W 175.3 15.6 1~. 8 4155.6 3573.3 17 23 .1N 702.7W 4154.7 3583.4 1709.4N 701. 5W 175.2 17.1 17. ] 4166.7 3581. 2 1730.7N 704.8W 4165.7 3592.2 17lS.7N 703.5W 175.1 18.7 18.9 4] 77.8 3589.0 1738.JN 707.0W' 4176.7 3601. 0 1721.9N 705.6N 17.5. ] 20.3 20.6 4188.9 3596.7 1745.9N 709.1W 4187.7 3609.8 1728.2N 707.6W 175.0 22.0 22.3 4200.0 3604.5 1753.6N 711. 3W 4198.5 3618.4 1734.4N 709.6W 174.8 23.8 24.2 4210.4 3611.7 1760.8N fl3. 3~.¡r 4208.7 3626. 6 1740.2N 711.1W 174.8 25.6 26.0 4220.8 3618.8 1768.1N 715.4W 4219.0 3634.8 1746.0N 713.3W 17L 7 27.4 27.8 4231. 2 3625.9 1775.4N 717.4W 4229.2 3643.1 1751.8N 715.2W 174.6 29.3 29.8 4241. 5 3632. 9 1782.7N 719.4W 4239.4 3651. 3 1757.6N 717 . OW 174.5 31.2 31. 8 42~1. 9 3640.0 U90.1N 721. 5W 4249.6 3659. 5 1763.3N 718.9írJ 174.4 33.2 33.9 4262.3 3646.9 17 97 . 5N 723.5W 4259.5 3667.4 17 68 . 9N 720.6W 174.3 35.3 36.1 4272.7 3653.9 1805.0N 725.5W 4269.6 3675. 6 1774.7N 722.5W 174.2 37.5 38.3 4300.0 .3 67 2. 0 1824.6N 73::1.9Í'J 4296. :3 3597.2 1789.7N 727. /'W 174.0 13.2 44.3 4400.0 3738.6 1896.7N 750.5W 4393.0 3775.7 1843.6N 744.2W 173.2 65.1 66.8 4500.0 3805.2 1968.7N 770.1W 4489.7 3854.8 1896.6N 760.6W 172 .5 88.0 90.5 4600.0 3871.7 2Q40.7N 789.7w 4586.5 3934.5 1949.1N 776.7TN 171.9 111.3 115.1 4700.0 3938.3 2112.7N 809.4W 4684.0 4014.8 2002.0N 792.9w 171.5 135.6 139.4 4800.0 4004.8 2184.7N 829.0W 4784.4 4096.8 2057.3N 809.8W 171. 4 158.3 162.1 4900. 0 4071. 4 2256.7N 848.6W 4886.1 4178.6 211S.4N 826.6W 171.2 178.8 181. 9 5000.0 4l37.9 2328.7~,' 868.2W 4989.3 4759.9 2176.8N 843.0W 170.6 196.4 199.1 5100.0 4204.5 2400.7N 887.8W 5089.5 4337.9 2237.9N 858.2w 169.7 212.6 215.4 5200.0 4271. 0 2472.7N 907.SW 5187.9 4414.5 2298.1N 872 .1W 168.6 228.8 231. 9 5300.0 4337.6 2544.7N 927.1W ::>2B6.1 4491.1 2358.2N 885. Hi 167.3 245.2 248.6 5400.0 4404.2 2616.8N 946.7W 5388.1 4570.5 2420.7N 898.4W 166.2 261.6 264.7 5500.0 4470.7 2688.8N 966.3W 5492.1 4650.3 2486.0N 912.2W 165.1 276.2 278.4 ;'600.0 10537.3 2760.8N 985. g'd 5602.7 47 37.6 2558.6N 926. OW 163.5 2én.4 288.7 5700.0 4603.8 2832.8N 1005.5W 5701. 9 4805.1 2625.3N 937.4W 161.8 297.0 298.4 5800.0 4670.4 2904.8N 1025.2W 5801. 1 4877.7 2692.0N 948.4W 160.2 306.8 308.4 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordirlates from slot #1-7 and TVD from rot,qry tablË (105.00 ft aDove mean sea leve;:). Total Dogleg for wellpath is 0.00 degrees. VcrLical section is f~om we1!head on azimuth 348.26 degrees. Calculation uses the minimum curvature method. XTO Energy, Inc. CLEARANCE ~G Page 3 C PT,ATFORM, C3?-23I,í. Your r 32-23LW VersiOD #: Middle Ground Shoals, Cook Inl Alaska Last revise 4-Jan-2002 Reference wellpath Object wellpath MMS <4124-10900'>"C24-14,C PLATFORM Horiz Min'IT: TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 5900.0 4736.9 2976.8N 1044.8W 5897.1 4948.3 2756.3N 958.9W 158.7 317.3 319.5 6000.0 4803.5 3048.8N 1064.4W 5992.4 5019.3 2818.8N 969.7W 157.6 329.3 332.0 6100.0 4870.0 3120.8N 1084.mll 6088.2 5091.2 2881. 2N 980.3" 156.6 J42.2 345.3 6200.0 4936.6 3192.8N 1103.6" 6185.4 5164.7 2944.1N 990.SW 155.5 355.9 359.8 6300.0 5003.2 3264.8N 1123.3w 6277.4 5234.9 3002.8N 999.7W 154.8 371. 0 376.0 6400.0 5069.7 3336.9N 1142.9W 6370.6 5306.9 3061. 3N lOO8.6W '54. G 387.6 J9J.9 6500.0 5136.3 3408.9N 1162.5W 6464. 5 5380.2 3119.4N 1016.9W 153.3 405.6 412.7 6600.0 5202.8 3480.9N 1182.1W 6562.2 5456.7 3179.7N 1025. OW 152.5 424.1 431. 6 6700.0 52(9.4 3552.9N 1201.7W 6659.9 5533.1 3240.0N 1032.7W 151.6 442.7 450.5 6800.0 5335.9 3624.9N 1221.4W 6761. 7 5612.6 3303.0N 1041. OW 150.7 461. 2 468.7 6900.0 5402.5 3696.9N 1241. 01/1 6861. 2 5689.9 3365.1N 1049.1W 1~O.O 4'1~. 0 486.9 7000.0 5469.1 3768.9N 1260.6w 6956.9 5764.2 3425.1N lOS6.5W 149.3 497.0 505.6 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #1~2 and TVD from rotary tahle (105.00 Ft_ ahove mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from I-¡ellhead on azimuth 348.26 degrees. Calculation uses the minimum curvature method. # Operator Name: Well Name: Job Description: Date: XTO Energy . MIDDLE GROUND SHOAL C-32-23-RD 7" Production Casing February 15, 2002 . !£j Proposal No: 179651990D JOB AT A GLANCE Depth (TVD) Depth (MD) Hole Size Casing SizelWeight : Pump Via 8,105 ft 10,768 ft 8.5 in CasinQ 7" O.D. (6.276" .I.D) 26 # 7 in, 26 Ibslft Total Mix Water Required Weighted Spacer Wieghted MCS-4D Density Lead Slurry 12;5 ppg Lead Slurry Density Yield Tail Slurry Class G Cement Density Yield Displacement Drilling Mud Density 6,600 gals 30 bbls 11.5 ppg 521 sacks 12.5 ppg 2.09 cflsack 88 sacks 15.8 ppg 1.15 cf/sack 344 bbls 10.5 ppg ?'-MP, irJt.Æ í 0 L ;:..,,'jtyOL) PROPOSAL BHT HAS BEEN ADJUSTED TO 130F. MUD WEIGHT ARE ESTIMATES, BASED ON WELL A-12-12LW DATA. RECEIVED >,-r:: e J £.: Alasi¡aOi/ &: ~ COliS. Gommíss¡O)1 Anchoragp Report Printed on: Fetrua1y 15,200211:18 AM Page 8 Gr4109 Operator Name: XTO Energy . Well Name: MIDDLE GROUND SHOAL C-32-23-RD Job Description: 7" Production Casing Date: February 15, 2002 . ~ Proposal No: 179651990D WELL DATA ANNULAR GEOMETRY I ANNULAR I.D. DEPTHlft\ (in) MEASURED I TRUE VERTICAL 8.835 CASING (~- s{¡¡" (D) I 3,900 I 3,900 8.500 HOLE I 10,768 I 8,105 SUSPENDED PIPES . I DIAMETER 'in\ WEIGHT DEPTH(ft) !O.D. I I.D. (Ibslft) MEASURED I TRUE VERTICAL 7.000 I 6.276 I 26 I 10,758 I 8,095 Float Collar set @ Mud Density Mud Type EsL Static Temp. Est. Circ. Temp. 10,678 ft 10.50 ppg Water Based 145 0 F 1300 F VOLUME CALCULATIONS 245ft x 0.1268cflft' 80ft x O.2148cflft with 30 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 40.4 cf 1~ (ip,de pipe) (5.6cf, 10 bbls = RtpOrtPrirtedon: Fetfuar} 15,2002 t1:18AM Page 9 Gr4115 Operator Name: Well Name: Job Description: Date: XTO Energy I MIDDLE GROUND SR AL C-32-23-RD 7" Production Casing February 15, 2002 . tm Proposal No: 179651990D FLUID SPECIFICATIONS Weighted Spacer FLUID VOLUME CU-FT VOLUME FACTOR Lead Slurry 1087 2.09 Tail Slurry 58 I 1.15 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Estimated Pumping Time - 70 BC (HH:MM) Free Water (mls) @ 120 0 F @ 90 0 angle Fluid Loss (ccl30min) at 1000 psi and 120 0 F RHEOLOGIES FLUID Tail Slurry TEMP @ 120 0 F 30.0 bbls Wieghted MCS-4D + 6 Ibs/bbl MCS-D + 21.64 Ibs/bbl Bentonite + 146 Ibslbbl Barite, Bulk@ 11.5 ppg AMOUNT AND TYPE OF CEMENT / = 521 sacks Class G Cement + 0.4% bwoc R-3 + 0.4% bwoc CD-32 + 0.6% bwoc FL-52 + 1 gals/100 sack FP-6L + 1% bWoc Sodium Metasilicate + 105% Fresh Water ,/ = 88 sacks Class G Cement + 0.1 % bwoc R-3 + 0.2% bwoc CD-32 + 0.6% bwoc FL-33 + 1 gals/100 sack FP-6L + 43.8% Fresh Water 344.1 bbls Drilling Mud @ 10.5 ppg SLURRY NO.1 12.50' 2.09 11.83 11.84 SLURRY NO.2 15.80 1.15 4.93 4.94 3:55 0.0 66.0 600 178 200 73 100 40 3 3 6 4 300 102 RepoI1 Printed en: FetnIary 15. 2002 11:1 S NI6 Page 10 Gr4129 , . . . E & P SERVICES., INC Fcbruary 21, 2002 RECEiVED ~, ,-, ~ :; t' I Mr. Winton Aubert Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 9950 I ;!laSKij :;.1 <), " . ~. '~umrr)ISSIl]'" n,.:r0!Bqf., RE: Additional Infonnation: C32-23L W Sidetrack Dear Winton, This is to provide the AOGCC with additional infonnation relative to XTO Energy's Application for Permit to Drill Well C32-23L W. While preparing the large-scale directional well-planning plots for XTO's upcoming well C32-23L W, the directional well planning contractor discovered that the planned wellbore will pass relatively close to a previously un-noticed well tha; was earlier drilled :ITom ' another platfonn. The planned well will pass approximately 81 feet :ITom XTO Well A22- 14LS at 12,350'MD. Attached find a 3-D Minimum Distance Clearance Report that indicates the relative proximities of the two wellbores. Also attached is the listing of potential hazards that will be posted on the rig, updated with the new proximity infonnation. / Being aware of the proximity issue at 12,350', XTO will ensure the C32-23L W well steers clear of the A22-24LS well. If you have any questions or require additional infonnation, please give me a call at 258- 3446. Sincerely, FAI~~rE & P SERVICES, INC. ~ Bill Penrose Senior Project Manager enclosures cc: Mr. Bobby Smith ~ XTO Energy, Inc. ""'In r. f ) h..' I -; 715 L Street Anchorage, Alaska 99501 (907) 258·3446 FAX (907) 258-5557 . . XTO Energy, Inc. e PLATFORM C3223LW slot #1-2 Middle Ground Shoals Cook Inlet, Alaska 3-D M I N I MUM D 1ST A NeE C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our Tcf License c32-23LW Version #5 prop4577 Date printed Date created Last revised 14-Feb-2002 18 Mar 2001 24-Jan-2002 Field is centred on n60 50 4.803,w151 29 11.941 Structure is centred on n60 46 36.826tw151 29 36.377 Slot location is .'160 45 Slot Grid coordinates are N Slot local coordinates are 50.217,w151 30 8.484 2474234.577, E 231360.866 4733.00 S 1595.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk. e.g. 487.4* Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. I-Jun-2000 80.5 12346.7 12346.7 ~ss <10230-12880'>..A22-14LS,A PLATFORM . . XTO Energy, Inc. CLEARANCE LISTING Page 1 C PLATFORM,C32-23LW Your ref C32~23LW Version #5 Middle Ground Shoals,Cook Inlet, Alaska Last revised : 24-Jan-2002 Reterence wellpath Obj ect wellpath PMSS <10230-12880'>"A22-14LS,A PLATFORM Horiz Minim TCyl M.D. T.V.D. Reet Coordinates M.D. T.V.D. Reet Coordinates Bearing Dist Dist 12153. -3 9229. -3 6946.7N 1089,9W 11274.9 9376.4 7029.0N 1192.5W 308.7 19'( .J B2D,l 12160.0 9235.4 6949.5N lO89.8W 11275.3 9376.6 7028.6N 1192.6W 307.6 191.7* 813.0* 12166.7 9241. 4 6952.3N lO89.8W 11275.7 9376.8 7028.3N 1192.6w 306.5 186.F 805.5* 12173.3 9247.5 6955.1N lO89.9W 11276.1 9376.9 7028.0N 1192.6w 305.4 1 BO . 6* 797.8* 12180.0 9253.6 6957.8N lO90.0W 11276.5 9377.1 7Q27.6N 1192.6w 304.2 175.1* 789.8* 12186.7 9259.6 6960.6N lO90.2Vi 11276.9 9377.3 7027.2N 1192.6W 303.1 169.6* 781.5* 12193.3 9265.7 6963.3N 1090.5W II2T1.3 9377.5 7026.9N 1192.6w 301. 9 164.2* 772.9* 12200.0 9271,8 6966.0N 1090,9W 11277.8 9377.7 7Q26.5N 1192.6W 300.7 158.9* 763.8* 12206.7 9277.8 6968.8N 1091.3W 1127H.2 9378.0 7026.QK 1192.6W 299.5 153.6* 754.4* 12213.3 9283.9 6971.5N 1091. 8w 11278.7 9378.2 7Q25.6N 1192.7W 298.2 148.3* 744.6* 12220.0 9290.0 6974.2N 1092.3W 11279.2 9378. , 7Q25.2N 1192.7W 296.9 143.2* 734.3* 12226.7 9296.1 6976.8N 1092.9W 11279.7 9378.6 7024.8N 1192.7W 295.6 138.1* 723.4* 12233.3 9302.1 6979.5N 1093.6W 11280.2 9378.9 7024.3N 1192.7W )94.3 133.1* 712.0* 12240. C 9308. :2 6982.2N lO94,4W 11280.7 9379.1 7823.8tJ 1192.7W L~3.:J 128.2* 70C.0* 12246.7 9314.3 6984.8N 1095.2w 11281. 3 9379.4 7023.3N 1192.8W 291.6 123.5* 687.0* 12250.0 9317.3 6986.1N 1095.6W 11281.6 9379.5 7023.1N 1192.8W 290.8 121.1* 680.4* 12253.3 9320.3 6987.4N 1096.1W 11281. 9 9379.7 7022.9N 1192.8W 290.1 118.8* 673.4* 12260.0 9326.4 6990.0N 1097.1W 11282.4 9379,9 7022.3N 1192.8w 288.6 114.3* 658.9* 12266.7 9332.4 6992.6N 1098. H'l L283.0 9l80.2 7021. AN 1192.m;¡ 287.1 110.0* 643.0* 12273.3 9338.5 6995.2N 1099.2w 11283.6 9380.5 7021. 3N 1192.8w 285,6 105.9* 625.9* 12280.0 9344.5 6997.8N 1100.4W 11284.2 9380.8 7020.8N 1192.9w 284.0 102.0* 607.1* 12286.7 9350.6 7000.3N 1101. 6w 11284.8 9381.1 7020.2N 1192.9w 282.3 98.3* 586.0* 12293.3 9356.6 7002.9N 1102.9W 11285.5 9381.4 7019.6N 1192.9W 280.6 94.9* 561.6* ILJOO .0 9362.6 ?COS.4N 1:.04.3W 1:286.1 9381.7 7019.IN 1192.9W 278.8 91. '(X ~31. 6-~ 12306.7 9368.6 7007.9N 1105.7W 11286.8 9382.0 7018.5N 1193. OW 276.9 88.9> 493.3'" 12313.3 937'.6 7010. 'N 1107.2w 11287.5 9382.3 7017.9N 1193.0" 275.0 86.5* 442. 6~ 12320.0 9380,6 70I2.8N 1108.8w 11288.2 9382.6 7017.3N 1193. Ow 273.0 84.4* 364.8* 12326,7 9386.6 70IS.3N 1110.4W 11288.9 9382.9 7016.7N 1193,1w 271.0 82.7* 220.1* 12333.3 9392.6 70-17.7N III J. 1¡'¡ 1-1289.6 9383..3 7016.0N IJ 93.1 ¡.¡ 768.8 81.5'" 140.8* 12340.0 9398.5 7020.1N 1113.9W 11290.3 9383.6 7015.4N 1193.1W 266.6 80.8* 100.3* 12346.7 9404.5 1022.5N 1115.7W 11289.6 9383.3 10Hi .J.N 1193.11'1 265.2 80.5-!- BO.7-t- / 1235D, Ü 9407.4 7023. iN 1116.7\1 11289.9 9383.4 7015.7N 1193.11'1 264.0 80.5 83. 12353.3 9410.4 7024.9N 1117.6W 11290.3 9383.6 7015.4N 1193.1W 262.8 80.7 92.1 12360.0 9416.3 7027.2N 1119.6W 11291.1 9384.0 7014.7N 1193.2W 260.3 81. 3 121. 0 12366.7 9422,2 7029.6N 1121. 6W 11291. 9 9384.4 7013.9N 119J.2w 257.7 82,5 157.5 12373.3 9'28.1 7031. 9N 1123.71'1 11292.8 9384.8 7013.2M 1193.21'1 255.0 84. 0 194.9 12380.0 9434.0 7034.2N 1125.9w 11293.6 9385.2 7012.5N 1193.3w 252.1 86.0 228.8 12186.7 9439,8 7036.SN 1128.1w 11294.4 9385.5 70ll.7N 1193.3w ?49.? 88.4 258.9 12393.3 9445.7 7038.IN 1130.4í'l] 11L'9~.3 9:)86.0 7Ull.0N 1193.4W 246.2 91.1 285,2 12400.0 9451. 5 7041. ON 1132. 8N 11296.2 9386.4 7010.2N 1193. .<IW 243.1 94.2 308.3 12406.7 9457.3 70B.2N 1135.2W 11297.1 9386.8 7009.4N 1193.4W 239.9 97.5 328.8 12413.3 9463.1 7045.4N 1137.7W 11298.0 9387.2 7008.6N 1193.5W 236.6 101.1 347 .3 12420,0 9468.9 7047.6N 1140.21'1 11298.9 9387.6 7007.8N 1193.5W 233.3 105.0 364.5 12426.7 9474.6 7049.7N lH2.8W 11299,8 9388.1 7007.0N 1193. [,W 229.9 109,0 380.6 12433.3 9480.3 7051. 8N 1145.5w 11300.8 9388.5 7006.2N 1193.61'1 226.5 113.3 395.6 12440.0 9486.0 7054.0N 1148.2W 11301,7 9388,9 7005.3N 1193.7W 223.1 117.7 409.5 12446.7 9491,7 7056.0N 1151. OW 11302.7 9389.4 7004.5N 1193.7W 219.6 122.3 422.5 12450.0 9494.5 7057.1N 1152.51'1 11303.2 9389.6 7004.1N 1193.81'1 217.9 124.6 428.6 1:24 ~3.::5 9497,3 7058.1N lIS3.9V') 11303.6 9389.8 7003.6N 1193.8Í'J 216.2 127.0 434.6 12460.0 9503.0 7060.2N 1156.8w 11304.6 9390.3 7002.0N 1193.9w 212.8 131. 8 445.9 12466.7 9508.6 7062.2N 1159.8W 11305.6 9390.8 7001.9N 1193.9W 209.5 136.7 456.6 All data is in feet unless otherwise stated. casing dimensions are not included. Coordinates from slot #1-2 and TVD from rotary table (105.00 Ft above mean sea level). Total Doq:eq for wellp~th is 0.00 dp.qrees. vertical section is from wellhead on azimuth 348.26 degrees. Ca1cu1atiO::l uses the mir:imurn curvature metr.od. Presented by Baker Hughes INTEQ . . XTO Energy, Inc. CLEARANCE LISTING Page 2 C PLATFORM,C32-23LW Your ref C32-23LW Version H5 Middle Ground Shoals,Cook Inlet, Alaska Last revised : 24-Jan-2002 Reference wellpath Object wellpath PMSS <10230-12880'>, ,A22-14LS,A PLATFORM Horiz Min'm Tey! M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 12473.3 9514..2 7064.2N 1162.9W 11306.6 9391.3 7001. ON 1194.. OW 206.2 141.7 466. 'J 12480.0 9519.7 7066.2N 1166. ow 11307.7 9391.7 7000.1N 1194. OW 203.0 146.8 4'/6.0 12486.7 9525.3 7068.1N 1169.1w 11308.7 9392.2 6999.2N 1194.1W 199.9 151. 9 484.9 12493.3 9530.8 7070.0N 1172.4W 11309.2 9392.4 6998. BN 1194.1W 197.0 157.1 493.5 12500.0 9_536.2 7071. 9N 1175.7W 11310.3 939/.9 6997. BN 1194.2W 194. 0 162.4 501.6 12506.7 9541.7 7Q73.8N ll7g.0W 11311.4 9393.5 6996.8N 1194.3w 19J.2 167.7 509.3 12513.3 9541 .1 7075.7N 1182.4W 11312.5 9394.0 6995.8N 1194.4W 188.5 173.1 516.7 12520.0 9552.5 7077.5N 1185.9W 11313.7 9394.5 6994.8N 1194.4W 185.9 178.5 523.6 :'2526.7 9557.9 7079.3N 11[19.4W 11314.9 9395.1 6993.7N 1194. 51;'¡- 183.4 le4.0 530.4 12533.3 9563.2 7081.1N 1193. Ow 11316.0 9395.6 6992.7N 1194.6w 181. 0 189.5 536.9 12540.0 9568.5 7082.9N 1196.6w 11317.2 9396.2 6991. 6N 1194.7W 178.8 195.0 543.1 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #1-2 and TVD from rotary table (105.00 ~t above mean sea level). Tol~l Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 348.26 degrees. Calculation uses the minimum curvature method. Presented by Baker Eughes INTEQ o . . C32-23LW Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE ....¡ There is a potential for lost circulation as the wellbore penetrates the Hemlock reservoir. ....¡ Pipe sticking tendency is possible in the coals above and in the Hemlock reservoir. ....¡ This wellbore is planned to pass approximately 81' from Well A22- 14LS at the sidetrack depth of 12,350' MD. This is the closest that this well will approach any other wellbore ....¡ There is no H2S risk anticipated for this well. CONSULT THE C32-23LW WELL PLAN FOR ADDITIONAL INFORMATION \ ;[19 . . .I F'''I.t-v..~;;¡. ....¡ Jatl1:l81)' 8:2002 Ms. Cammy Oechsli-Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 If12CÞ clflj~ t- - !'/:'" ·D '~..è 0 ~ <4~oi^,. t .2a ""'f:~. V? ~~:, RE: Application for Pennit to Drill: C32-23LW Sidetrack Dear Ms. Oechsli-Taylor, XTO Energy, Inc, hereby applíes for a Pennit to Drill an offshore development well from Platfonn C in the Middle Ground Shoal Field of Cook Inlet. The well is planned as a sidetrack of the existing C32-23 we]}bore in order to penetrate and develop an un-drained portion of the Hemlock conglomerate in the vicinity of Platfonn C. Approval of the associated pre-drilling work plan for the existing we]}bore has been requested via a Sundry Notice submitted under separate cover. The anticipated spud date of C32-23LW is approximately February 24,2002. The 7" casing will be cut and pu]}ed and the we]} sidetracked via a window milled in the 9-5/8" casing. The 8-1/2" hole wi]} be direction ally drilled to the top of the Hemlock ./ reservoir where 7" intermediate casing will be set. After penetrating the reservoir with a 6" hole, a 5" slotted production líner will be set in place and a 2-7/8" gas lift completion installed. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent infonnation attached to this apphcation includes the following: 1) Fonn 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the well's proposed surface and bottomhole locations per 20 AAC 25.050 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25,050. 5) Diagrams and descriptions of the BOP equipment to be used as required by 20 AAC 25.035 (a)(1) and (b) were previously submitted to your office and are on file. 6) A complete proposed casing program is attached as per 20 AAC 25.030. 7) The drilling fluid program, in addition to the requirements of 20 AAC 25.033 are attached. 8) A copy of the proposed drilling program is attached. ORIG!NAL XTO Energy Inc. . 3000 N. Garfietd . Suite 175 . Midland, Texas 79705 . (915) 682·8873 . Fax: (915) 687·0862 J ........ . . Ms. Cammy Oechsli-Taylor Page 2 9) XTO Energy does not anticipate the presence of H2S in the formation to be encountered in this well. However, H2S monitoring equipment will be functioning on the rig at all times during sidetracking, drilling and completion operations. 10) While this welJ is considered to be a development well, basic mud logging wi11 be performed while drilling to aid in tracking the location, thickness and quality of the intervals penetrated. 11) A Summary of Drilling Hazards is attached. 12) The following are XTO Energy's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Bill Penrose, Senior Dri11ing Engineer (907) 258-3446 2) Geologic Data and Logs (20 AAC 25.071) Mike Langeler, Senior Geologist (817) 885-2581 If you have any questions or require additional information, please contact me at (915) 620-6718 or Bill Penrose at (907) 258-3446. Sincerely, XTO ENERGY, INC. 94J c4 - Y ~ '6oBBV 5""".-fi. RECEIVED enclosures t:- r: ':! f: ~)ri OJ' 1\1 " C..,'. asK8()ìl&G',.. iIS >-{)(;k ." ArrChora; l,()fi)I!IISs!0!' Bobby L. Smith Drilling/Operations Manager cc: BilJ Penrose " I' i' /,~"l\ L_ . . CROSS TIMBERS OPERATING COMPANY MIDLAND OFFICE PETTY CASH FUND 3000 N, GARFIELD, STE. 175 MIDLAND, 1)( 79705 1751 ~ r;l~~ OF ~ 6 !1f!.æs~ JtJk~~~~ ~ · NationsBank DATE ~/ c¡i¿ /I 32-111110 TX o 1$ 100.170 DOLLARS [fiE:..-"::' NationsBank. N.A. ---~¿~~~ DB ~ 3~1;~ i · ~ " ~ · Fo;;;;rlh¡"f -t-ø '),-1/1 t: 1~ _éX:Jt...W 11·00 ~ 7 5 ~II· .: ~ ~ ~oooo ¡, 2': 375 & . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ¡t(G~ ~ 3¿ -23 LtJ CHECK I CHECK WHAT APPLIES STANDARD LETTER ADD-ONS (OPTIONS) "CLUE" DEVELOPMENT MULTI LATERAL The permit is for a new wellbore segment of existing weD ----J Permit No, API No. (If apl number last two (2) Production shoutd continue to be reported as a function.of digits are between 66-69) the original API number stated above. DEVELOPMENT PILOT HOLE (PH) In accordance wltb 20 AAC 25.005(t), aD records, data and REDRlLL / logs acquired for the pilot hole must be clearly / differentiated in both name (name 00 permit plus PH) and API number (SO -70180) from records, data and logs acquired for well (name on permit). / EXPLORATION ANNULAR DI~AL Annular disposal has not been requested. . . ( \. 0 V INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . <.-> YES INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . REDRlLL THIS WELL DISPOSAL INTO OTHER Please note that an disposal of Ouids generated.. . ANNULUS <.-> YES + SPACING EXCEPTION Enclosed is the approved application for permit to drill tbe above referenced well. The permtt is approved. sùbjeet to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Comnanv Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY FIELD & POOL 2..':¡ I ADMINISTRATION 1. Permit fee attached. . . . . . . . . . , , . . . . . , , . . . . 2. Lease number appropriate. . . . . . . . . . , . . . . . . , , 3. Unique well name and number. ., . . , . . , . . . , , , . . . 4. Well located in a defined pool.. . . . . . . . . . . , , . . . . 5, Well located proper distance from drilling unit boundary. ,. 6, Well located proper distance from other wells" . . . , , . . , 7, Sufficient acreage available in drilling unit.. . . . . . , , . . , 8. If deviated, is well bore plat included.. . . . , . . . . . . . . , 9, Operator only affected party.. . . . . . . . . . . . . , . . . , 10, Operator has appropriate bond in force. . . . . . , . . . . . . 11. Permit can be issued without conservation order. . . . , . . . 12. Permit can be issued without administrative approval.. . . , . 13. Can permit be approved before 15-day wait.. . , . . , . . . . 14. Conductor string provided . . . . . . . . . . . . , , . , . . . 15. Surface casing protects all known USDWs. . . , . . . . , . 16. CMT vol adequate to circulate on conductor & surf csg. 17, CMT vol adequate to tie-in long string to surf csg. . . . . 18. CMT will cover all known productive horizons. . . . . . . , . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pi\.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22, Adequate well bore separation proposed.. . . . . . . . . , . , 23. If diverter required, does it meet regulations . . , . , . . . . . 24. Drilling fluid program schematic & equip list adequate. . . , . 25. BOPEs, do they meet regulation . , . . . . . , . . . . . . . . 26. BOPE press rating appropriate; test to ?) 000 psig. 27. Choke manifold complies w/API RP-53 (May 84). , , . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . , . . , , , . . . . 30. Permit can be issued wlo hydrogen sulfide measures. . . , . 31. Data presented on potential overpressure zones . . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . , . , . DATE 33. Seabed condition survey (if off-shore). . . , . , . . . . . z.' 13 .~ 34. Contact namelphone for weekly progress reports [exp/o ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . , . . (B) will not contaminate freshwater; or cause drilling waste, ., to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25,412. Y N GEOLOGY' E~' UIClAo""." COMMISSION, RPC~ TE . '3/~ COT T '" SFD WGA DTSO'?h9"Þ¿ "'7 ,/ JMH JfJV }+-- 3J 5/ð Z A;¡;t DATE 'J·,"¡.o-V- - ENGINEERING APPR DATE, ll:Þm .JdBdPz- "3/'1.-0':> GEOLOGY AP APPR DATE - - Wellbore seg AlA Ann, disposal para req ON/OFF SHORE ð¡::-F Dev Serv UNIT# . iQ ,*,-e L ico P {.;? -S9cc/ ¡VI D· {i' It. '55'0' MD. t<;t "" ,a'o r [..,;. MMÞ ~ 2. z.qS f>~'.. éF)<.f¿~~ ~I/ò/r ~U/,.L i4 '6, I ~ on¿¿l (Ó. '-IZf,.;¿ft:r ) . Y N Y N {lI() C1.A.¡< iA.i.~/ ¿~ ( ,,) 1...\0.""-"'> '1I'" ~~\.\. VI.P fU.ßcÞi. V~~~ ~'::, c:. ð Comments/Instructions: G:\geologylpermitslchecklist.dOC
