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Home My WebLink About201-0731. 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 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 13,842 feet N/A feet true vertical 9,328 feet N/A feet Effective Depth measured 13,754 feet 11,395 feet true vertical 9,303 feet 9,011 feet Perforation depth Measured depth 11,671 - 13,716 feet True Vertical depth 9,249 - 11,011 feet 2-7/8" 6.5 / L-80 9,189 MD 7,001 TVD Tubing (size, grade, measured and true vertical depth)2-3/8" 4.7 / L-80 11,429 MD 8,387 TVD 11,395 (MD) 327 (MD) Packers and SSSV (type, measured and true vertical depth)Baker DB Pkr 9,011 (TVD) Baker T-5 SSSV 327 (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 ~370 measured true vertical Packer Other: CTCO / Oilsafe AR Acid 5" 3-1/2" 24" 11,650 MD ~370 2,393 8,080 13,775 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 61 Representative Daily Average Production or Injection Data 10062 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-073 50-733-20238-60-00 Plugs ADL0018754 MGS A23-01LW 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-346 100 Authorized Signature with date: Authorized Name: 70 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 125 Gas-Mcf 679 Pumped 20 bbls OilSafe AR displaced with 26 bbls FIW. Final Pressures: T/IA/OA = 0/79/75. Oil-Bbl 4 Water-Bbl Production 11,671 - 13,716 Junk 5. Permit to Drill Number: 18 Middle Ground Shoal / MGS Oil PoolN/A measured 9,576 2,358 Size 732 Liner Casing Conductor Liner 2,312 Length ~370 2,393 8,080 Surface Intermediate slotted 10,490psi 13-3/8" 9-5/8" 7" 9,576 7,240psi 907 777-8376 10,140psi 2,214 6,120 7,311 8,479 9,309 Collapse 1,540psi Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 4,750psi 5,410psi 3,090psi 6,870psi 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 9:48 am, Oct 20, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.10.19 11:43:06 -08'00' Dan Marlowe (1267) gls 10/26/20 DSR-10/20/2020 Oil SFD 10/20/2020 CTCO / Oilsafe AR Acid RBDMS HEW 11/13/2020 Updated By: JLL 10-14-20 SCHEMATIC Middle Ground Shoal Well: A23-01LW Last Completed: 08/12/2001 PTD: 201-073 API: 50-733-20238-60 Note: Production reported to State under well name A23-01RD PTD: 187-093 API: 50-733-20238-01 Well currently permitted as Lateral: A23-01LW PTD: 201-073 API: 50-733-20238-60 (technically is a sidetrack not a lateral)A23-01LW is used for internal Production & Petra purposes PBTD: 13,774’ TD: 13,842’ 24” RKB: 116 to MLLW 3-1/2” 3 4 5 6 7 8 13-3/8” 5” 7” 1 2 9-5/8” CTCO to 13,754’ on 09/13/20 X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Surf ~370’ 13-3/8” 61 J-55 BTC 12.515” Surf 2,393’ 9-5/8” 47 N-80 BTC 8.681” Surf 8,080’ (TOW) 7” 26 N-80 LTC 6.276” Surf 9,576’ (TOW) 5” 17.95 N-80 STL 4.276” 9,292’ 11,650’ **3-1/2” 8.81 / 9.2 L-80 STL 2.992” 11,463’ 13,775’ **Liner is a combination of blank and slotted pipe – See Perforation detail for slotted sections TUBING DETAIL 2-7/8” 6.5 L-80 8rd EUE 2.441” Surf 9,189’ 2-3/8” 4.7 L-80 8rd EUE 1.995” 9,189’ 11,429’ PERFORATION DETAIL – INVERTED SECTION Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status HK-2 11,671' 11,916' 8486.98 8586.28 245' 08/06/2001 Slotted Liner HK-2 11,946' 12,191' 8598.92 8711.37 245' 08/06/2001 Slotted Liner HK-2 12,221' 12,680' 8726.90 8944.48 459' 08/06/2001 Slotted Liner HK-1 12,892' 13,143' 9021.05 9094.65 251' 08/06/2001 Slotted Liner HK-1 13,233' 13,495' 9116.62 9207.53 262' 08/06/2001 Slotted Liner HK-1 13,589' 13,716' 9247.55 9292.02 127' 08/06/2001 Slotted Liner JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 36.97’ Tubing Hanger 1 327’ 327’ 2.312” 4.750” Baker T-5 SSSV (19 each ½” SS control line bands) 2,057’ 1,955’ 2.441” 4.625” GLM #1 2 4,143’ 3,355’ 2.441” 4.625” GLM #2 5,778’ 4,500’ 2.441” 4.625” GLM #3 7,058’ 5,407’ 2.441” 4.625” GLM #4 7,946’ 6,018’ 2.441” 4.625” GLM #5 8,579’ 6,534’ 2.441” 4.625” GLM #6 9,145’ 7,028’ 2.441” 4.625” GLM #7 3 9,189’ 7,067’ 1.995” 2.625” X-over 2-7/8” x 2-3/8” 8 round 4 9,649’ 7,474’ 1.995” 2.375” GLM #8 10,087’ 7,864’ 1.995” 2.375” GLM #9 10,751’ 8,451’ 1.995” 2.375” GLM #10 11,317’ 8,944’ 1.995” 2.375” GLM #11 5 11,360’ 8,981’ 1.875” 2.375” Otis X Nipple 6 11,395’ 9,011’ 1.995” 4.625” Baker Locator sub w/ 11’ seal assembly 2.600” 3.960” Baker DB Packer w/ 10’ Sealbore extension 7 11,418’ 9,031’ 1.791” 2.750” XN Nipple 8 11,429’ 9,040’ 2.000” 3.050” WL REG Rig Start Date End Date CTU 9/11/20 9/20/20 09/11/20 - Friday PJSM & permit. Rig up WH riser and BOP. Run hardline to flow tee. Test BOPE as per Hilcorp & AOGCC requirements, witnessed waived 9/10/2020 @ 6:34 PM by AOGCC Inspections Supervisor Jim Regg, 250/4000. Load 20 bbl (3 totes) of OilSafe AR into ISO# IM35 SDFN. Job in Progress. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name MGS A23-01LW 50-733-20238-60-00 201-073 PJSM & Permits. RU CTU & MU Quadco motor & mill BHA. MU BHA #1: CTC(1.68" X 0.30'), DFCV(1.70" X 1.29'), Jar(1.70" X 5.14'), Disco(1.70" X 1.43'), Rupture Sub(1.70 X 0.34, 5K), Circ Sub(1.70" X 0.86'), Titan PDM (1.70" x 11.20'), Junk Mill (1.74" x 0.77') OAL = 21.33'. Disco Ball = 1/2", Circ Sub Ball = 0.406", PT BHA to Disco = 3500. Move to well. PT WHA & Lub = 4500. Open swab (15.5T). Initial T/IA/OA = 100/78/85. RIH w/ 1.70" mill & 3-blade 1.74" junk mill for dry tag. Exit EOT @ 11,429' KB w/o tagging. Continue TIH to dry tag in 3-1/2" Liner @ 11739' KB. PUH, PUW = 13.5K. WT CHKs: 5000' = 2.4K, 8500' = 10K, 10500' = 12.5K, 11350' = 13K. Roll fluid pump & slide past 11,739 KB resistance depth. Stop pump, TIH to tag @ 11,802. PUH, RBIH & slide past 11,802' tag depth w/o pump. Continue dry drift w/ tags @ 11,930', 11970', 12,015'. PUH @ each & dry drift past all to dry tag @ 12,023' KB. PUH to 11,950' KB, bring on pump w/ FIW @ 1.12 BPM, CTP = 4500, to load hole & break circulation. T/IA/OA = 80/79/85. 1:1 returns. 11,950' RIH for cleanout w/ motor & mill. PR = 1.12 bpm pumping FIW w/ CTP = 4500. TIH to 12,450' KB, set weight off & see motor action. Continue milling ahead,12475' KB milling on hard scale. Mill to 12477' KB w/ 10 motor stalls. FIW @ 1.0 bpm, CTP = 2860, w/ 85% returns. T/IA/OA = 37/79/85,12,477' KB mill to 12,480' KB w/ 4 stalls. FIW @ 1.0 bpm, CTP = 2860, w/ 85% returns. T/IA/OA = 37/79/85,12,480' KB mill to 12,490' KB w/ 2 stalls. FIW @ 1.0 bpm, CTP = 2860, w/ 85% returns. T/IA/OA = 37/79/85,12,490' KB mill to 12,530' KB w/ 2 stalls. FIW @ 1.0 bpm, CTP = 2860, w/ 85% returns. T/IA/OA = 37/79/85,12,530' KB mill to 12,531' KB w/ 2 stalls. FIW @ 1.0 bpm, CTP = 2860, w/ 85% returns. T/IA/OA = 37/79/85,12,531' KB mill to 12,532' KB w/ 5 stalls. FIW @ 1.0 bpm, CTP = 2860, w/ 85% returns. T/IA/OA = 37/79/85,12,532' KB mill to 12,545' KB w/ 6 stalls. FIW @ 1.0 bpm, CTP = 2860, w/ 85% returns. T/IA/OA = 37/79/85,12545' KB. POOH for the night chasing returns to surface. Small amount of solids in 1 minute sample catch, appear to be black, scale cuttings w/ no metal shavings in sample. Shipped 575 bbls FIW to MGS Onshore & emailed copy of non-produced fluid transfer to MGS Onshore Operators. OOH. Close swab. Final T/IA OA = 44/79/70 Bleed all pressures, break off well & stand back injector & lubricator. LD BHA & lubricator. Set down and secure injector. Secure well, drill & pipe deck. SDFN. Job in Progress. 09/12/20 - Saturday Test BOPE as per Hilcorp & AOGCC requirements, Continue milling ahead,12475' KB milling on hard scale. RU CTU & MU Quadco motor & mill BHA. MU Rig Start Date End Date CTU 9/11/20 9/20/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name MGS A23-01LW 50-733-20238-60-00 201-073 09/20/20 - Sunday Bring well online post safe acid soak PJSM & Permits. PT Full body low/high 250/4500. Open well (swab 15.5 t). RIH w/ BHA #1: CTC(1.68" X 0.30'), DFCV(1.70" X 1.29'), Jar(1.70" X 5.14'), Disco(1.70" X 1.43'), Rupture Sub(1.70 X 0.34, 5K), Circ Sub(1.70" X 0.86'), Titan PDM (1.70" x 11.20'), Junk Mill (1.74" x 0.24') OAL = 20.8'. RIH to dry tag @ 12,545' KB. Disco Ball = 1/2", Circ Sub Ball = 0.406". Initial T/IA/OA = 0/80/75, 12,545' KB Fire up pump on FIW @ 1.1 bpm, CTP = 3850, T/IA/OA = 0/80/75. Mill hard scale to 12,559' KB, 12,559' KB mill to 13,580' KB. Broke thru hard milling @ 12590'. FP = 1.0 bpm FIW @ 3850 psi, WHP = 0 w/ 75% returns. TIH @ 54FPM. 13,580' KB cleanout to 13,754' KB tag depth. 38' of rathole below bottom perf @ 13,716' KB. Wiper trip to tubing tail & bottoms up. RBIH to 13716' KB. Load & launch 0.406" ball to shift open circ sub. Circulate 20 bbl OilSafe AR to end of coil displacing w/ FIW. POOH @ 100 FPM, pumping 1.0 bpm FIW, laying in 20 bbl OilSafe AR from 13754' KB - 11463' KB. POOH. Close Swab. Final T/IA/OA = 0/79/75. Bleed all pressures & break off well. LD BHA & lubricator. Set down & secure injector. Secure well, drill & pipe deck. Shipped 316 bbls of FIW returns to MGS Onshore & emailed non-produced fluid transfer form to Onshore. Allow OilSafe AR to soak in hole per procedures. 09/13/20 - Sunday TIH @ 54FPM. 13,580' KB cleanout to 13,754' KB tag depth. 38' of rathole below bottom perf @ 13,716' KB. Circulate 20 bbl OilSafe AR to end of coil displacing w/ FIW. POOH @ 100 FPM, pumping 1.0 bpm FIW, laying in 20 bbl OilSafe AR from 13754' KB - 11463' KB. POOH. Close Swab. Final T/IA/OA = 0/79/75 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): Middle Ground Shoal / MGS Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,842'N/A Casing Collapse Conductor Surface 1,540 psi Intermediate 4,750 psi Production 5,410 psi Liner 10,490 psi Liner slotted Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 9,309' 11,671 - 13,716 9,328'11,738'8,513'3,092 psi 2,312'3-1/2" 8,479'5" 13,775' 9,189 & 11,429 10,140 psi slotted Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 9/3/2020 2-7/8" & 2-3/8" Daniel E. Marlowe Baker DB Packer & Baker T-5 SSSV 11,650' Perforation Depth MD (ft): 9,576' Tubing Size: 2,358' 11,395 (MD) 9,011 (TVD) & 327 (MD) 327 (TVD) Tubing Grade:Tubing MD (ft): 9,249 - 11,011 Perforation Depth TVD (ft): ~370'24" 13-3/8" 9-5/8" 2,393' 7"9,576' 8,080' MD 3,090 psi 6,870 psi 2,214' 6,120' 7,311' 2,393' 8,080' ~370' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018754 201-073 50-733-20238-60-00Anchorage, AK 99503 Hilcorp Alaska, LLC MGS A23-01LW N/A ~370' COMMISSION USE ONLY Authorized Name: 6.5 / L-80 & 4.7 / L-80 TVD Burst Other: CTCO / N2 Operations Oil Safe AR Acid N/A Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 7,240 psi Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:18 pm, Aug 20, 2020 320-346 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.20 14:45:18 -08'00' Dan Marlowe (1267) X *4000 psi BOP test (CTU ) gls 8/24/20 SFD 8/20/2020 CTU DSR-8/20/2020 OIL 10-404 dts 8/24/2020 8/24/2020Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.08.24 11:12:53 -08'00' RBDMS HEW 8/24/2020 Well Work Prognosis Well Name:MGS A23-01LW API Number:50- 733-20238-60 Current Status:Gas Lifted Producer Leg:Leg #4 (West) Estimated Start Date:09/03/2020 Rig:Coil Tubing Reg. Approval Required? 403 Date Reg. Approval Received: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:201-073 First Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Second Call Engineer:Karson Kozub (907) 777-8384 (O) (907) 570-1801(M) Current Bottom Hole Pressure:2,650 psi @ 8,834’ TVD 0.3 psi/ft (7.39 ppg) Maximum Expected BHP:3,975 psi @ 8,834’ TVD 0.45 psi/ft (8.65 ppg) Max Potential Surface Pressure (MPSP): 3,092 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Naming Convention Note: Production is reported to the state under well name MGS A23-01RD (PTD#187-093. API: 50-733-20238-01), the inactive motherbore. But this well was sidetracked and incorrectly permitted and is internally named “A23- 01LW” (PTD 201-073. API: 50-733-20238-60). Brief Well Summary Well MGS A23-01RD is a gas lifted producer completed in Hemlock sands. Recent wireline work has indicated scale formation in the well bore. This procedure will clean-out fill covering the perforations and acidize the perforations. Safety Concerns: x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting methane and Nitrogen during this job) x Ensure all crews are aware of stop job authority (Review Standard Well Procedure – Nitrogen Operations) Procedure: 1.MIRU Coil Tubing. 2.NU BOP and test to 250psi low / 4,500psi High. (Note: Notify AOGCC 48 hours in advance of test) 3.RIH cleaning out fill to ± 13,716’MD using FIW and/or synthetic acid. a. Have milling tool string on hand for contingent scale milling as needed b. Circulate well clean using FIW with N2 assist if needed. 4.Lay ±930 gallons of Oilsafe AR synthetic acid across perforations 5.Displace with CT volume of FIW. RDMO 6.Soak for ±72 hours 7.Turn well over to operations to POP. Notify inspector Well Work Prognosis Attachments: 1. Well Schematic - Current/Proposed (Same) 2. Wellhead Diagram - Current 3. Coil Tubing BOP Drawing 4. Flow Diagrams 5. Oil Safe AR – Technical Data Sheet 6. Standard Well Procedure – Nitrogen Operations 7. Sundry Revision Change Form Updated By: JLL 03/02/18 SCHEMATIC Middle Ground Shoal Well: A23-01LW Last Completed: 08/12/2001 PTD: 201-073 API: 50-733-20238-60 Note: Production reported to State under well name A23-01RD PTD: 187-093 API: 50-733-20238-01 Well currently permitted as Lateral: A23-01LW PTD: 201-073 API: 50-733-20238-60 (technically is a sidetrack not a lateral)A23-01LW is used for internal Production & Petra purposes PBTD: 13,774’ TD: 13,842’ 24” RKB: 116 to MLLW 3-1/2” 3 4 5 6 7 8 13-3/8” 5” 7” 1 2 9-5/8” Wireline tag @ 11,738’ on 1/13/18 X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Surf ~370’ 13-3/8” 61 J-55 BTC 12.515” Surf 2,393’ 9-5/8” 47 N-80 BTC 8.681” Surf 8,080’ (TOW) 7” 26 N-80 LTC 6.276” Surf 9,576’ (TOW) 5” 17.95 N-80 STL 4.276” 9,292’ 11,650’ **3-1/2” 8.81 / 9.2 L-80 STL 2.992” 11,463’ 13,775’ **Liner is a combination of blank and slotted pipe – See Perforation detail for slotted sections TUBING DETAIL 2-7/8” 6.5 L-80 8rd EUE 2.441” Surf 9,189’ 2-3/8” 4.7 L-80 8rd EUE 1.995” 9,189’ 11,429’ PERFORATION DETAIL – INVERTED SECTION Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status HK-2 11,671' 11,916' 9,249' 9,460' 245' 08/06/2001 Slotted Liner HK-2 11,946' 12,191' 9,486' 9,697' 245' 08/06/2001 Slotted Liner HK-2 12,221' 12,680' 9,723' 10,118' 459' 08/06/2001 Slotted Liner HK-1 12,892' 13,143' 10,301' 10,517' 251' 08/06/2001 Slotted Liner HK-1 13,233' 13,495' 10,595' 10,820' 262' 08/06/2001 Slotted Liner HK-1 13,589' 13,716' 10,901' 11,011' 127' 08/06/2001 Slotted Liner JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 36.97’ Tubing Hanger 1 327’ 327’ 2.312” 4.750” Baker T-5 SSSV (19 each ½” SS control line bands) 2,057’ 1,955’ 2.441” 4.625” GLM #1 2 4,143’ 3,355’ 2.441” 4.625” GLM #2 5,778’ 4,500’ 2.441” 4.625” GLM #3 7,058’ 5,407’ 2.441” 4.625” GLM #4 7,946’ 6,018’ 2.441” 4.625” GLM #5 8,579’ 6,534’ 2.441” 4.625” GLM #6 9,145’ 7,028’ 2.441” 4.625” GLM #7 3 9,189’ 7,067’ 1.995” 2.625” X-over 2-7/8” x 2-3/8” 8 round 4 9,649’ 7,474’ 1.995” 2.375” GLM #8 10,087’ 7,864’ 1.995” 2.375” GLM #9 10,751’ 8,451’ 1.995” 2.375” GLM #10 11,317’ 8,944’ 1.995” 2.375” GLM #11 5 11,360’ 8,981’ 1.875” 2.375” Otis X Nipple 6 11,395’ 9,011’ 1.995” 4.625” Baker Locator sub w/ 11’ seal assembly 2.600” 3.960” Baker DB Packer w/ 10’ Sealbore extension 7 11,418’ 9,031’ 1.791” 2.750” XN Nipple 8 11,429’ 9,040’ 2.000” 3.050” WL REG Platform A 23-01RD 08-05-2020 Platform A 23-01RD 13 3/8 x 9 5/8 x 7 x 2 7/8 Tubing hanger, CIW-N-FBB- CL, 7 x 2 7/8 EUE 8rd lift and susp, w/ 2 1/2'’ type H BPV profile, 1- 1/8 npt control line port 13 3/8'’ 9.625'’ BHTA, CIW, External knock-up, 2 9/16 5M FE Valve, Swab, WKM-M, 2 9/16 5M FE, HWO, EE trim Valve, Master, WKM-M, 2 9/16 5M FE, HWO, EE trim Casing head, CIW-WF, 13 5/8 3M FE top x 13 3/8 SOW btm, w/ 2- 2 1/16 5M EFO Tubing head, CIW-N, 11 3M x 7 1/16 5M, w/ 2- 2 1/16 5M SSO, X bottom prep Casing spool, CIW-WF, 13 5/8 3M x 11 3M , w/ 2- 2 1/16 5M EFO, X bottom prep 7'’ 2 7/8'’ Coiled Tubing BOP SWAB VALVE MASTER VALVE Hilcorp Monopod Rig 56 Flow Diagram Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Automatic Choke Manual Choke Pressure Gauge Knife Valve Choke Line P PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLD GAS BUSTER Panic Line C12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: MGS A23-01LW (PTD 201-073)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Imag(" ~roject Well History' File Covert .ge 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. ~..._~J- _~)_~'3 Well History File Identifier Organizing ¢o1,~1 RESCAN Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA J~ Diskettes, No. t [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL~INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Scanning Preparation _r2~.. x 30 =~0 BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,,~ YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES BY: BEVERley,S)VINCENT SHERYL MARIA WINDY DATE.~.~'~S/'["~ (SCANNING IS coMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNEDB~'; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/10/02Rev3NOTScanned.wpd e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFicllc\CvrPgs _lnscrts\Microfihn _ Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 8~25~2003 Permitto Drill 2010730 Well Name/No. MGS A23-01LW Operator XTO ENERGY INC APl No. 50-733-20238-60-00 MD 13842 ~'- TVD 9328 . Completion Dat 8/12/2001 ~' Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Sample N._9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) I nte rval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number ED D Lis Cn See Notes 25 9552 13842 Open Comments Prop, Resistivity, Gamma ED D Lis Dir Directional Survey OTH 0 13842 Open Ray, MWD MD/TVD Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~ N Chips Received? ~ Formation Tops ~/N Analysis -'-Y-t-N'-- R ~.c.~.iv~.d ? Comments: .......................Compliance Reviewed By: -~:~'--': ...... ~ ......................................................................................................................... ~'~'t'~.~-ii.~i'-iii~___. ~~_~ii~ ......................... E & P SERV/OES,/NU. November 5, 2001 Ms. Julie Heusser, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report: Well ~ P&A ,~IOV 0 7 2001 Alaska Oil & Cas Cons. C0mmissi0, Anchorage Dear Commissioner Heusser, XTO Energy, Inc., through Fairweather E&P Services, Inc., hereby submits its Well Completion or Re-completion Report and Log (Form 407) for the work it performed to plug and abandon its well A34-14RD on XTO Platform A in the Middle Ground Shoal Field of Cook INet. After abandonment of the bottom portion of the wellbore, the well was sidetracked as A34-14LW. A separate Form 407 has been submitted for the sidetrack. Please find attached the following information for your review: 1) Form 10-407 Well Completion or Re-completion Report and Log (Please note the Form 407 has been signed by XTO's Drilling Manager for Alaska, Mr. Bobby Smith.) 2) Well Operations Smmnm3, If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, FAIRWEATHER E&P SERVICES, INC. Bill Penrose Senior Project Manager enclosures cc: Mr. Bobby Smith- XTO OR ¢II AL 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 STATE OF ALASKA i ALASKA OIL AND'GAS CONSERVATION( OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Wel OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operato 7. Permit Numbe~ XTO Energy, Inc. 201-073 3. Address 8. APl Numbel 3000 N. Garfield, Suite 175, Midland, Texas 7970 50- 733-20238-60 4. Location of well at surface ~ 9. Unit or Lease Nam( ~-.~.- .~-..:. -..-.. ~.,.j. -~. 1569' FSL, 381' FEL, Sec. 11, T8N, R13W, Seward Meridia~ , ,.. .... :... '.: :.., Middle Ground Shoe '".' ..f ;. 10. Well Numbe~ At Top Producing Interva 2610' FSL, 936' FWL, Sec. 1, T8N, R13W, SM ;~ .._.~ ./'~._z:~._; A23-01LW 5. Elevation in feet (indicate KB, DF, etc. I 6. Lease Designation and Serial N( Middle Ground Shoe 116' DFI ADL 18754 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 5/20/2001 8/05/2001I 8/12/2001I 80 feet MSL! 1 17. Total Depth (MD+TVD) 18. Plug Beck Depth (MD+TVD)I 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 13,842'/9,328' 13,775'/9,312' Yes: X No: IT-SSSSV @ 327 feetMD NA 22. Type Electric or Other Logs Rut Schlumber~ler Cement Evaluation, CBT - GR - CCI 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 61# J-55 0 2,393' 17-1/2" 1940 sx 0 9-5/8" 47# N-80 0 8,080' 12-1/4" ; 1200 sx 0 7' 26# N-80 0 9,989' 8" 0 7" 32# P-110 9,989' 11,538' 8" 980 sx O 5" 18# L-80 STL 9,292' 11,650' 6" 123 sx 0 24. Perforations open to Production (MD+TVD of Top and Bottom ar 25. TUBING RECORD interval, size and number SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 13,775' 11,395' 11,671' / 8,490' Tol: 13,716'/9,295' Botton '26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3-1/2" tubing with 6 intervals of slotted line 27. PRODUCTION TEST Date First Productior I Method of Operation (Flowing, gas lift, etc I Gas Lift Date of Tesl Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD => 0 0 0 NAI NA Flow Tubing Casing. Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 0 0 24-HOUR RATE => 0 0 0 NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chi None RECEIVED,, Alaska Oil & Gas Cons. Commissior} Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVE;RSE SIDE 0RI61N,AL Submit in duplicate -. 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravit~ MEAS. DEPT~ TRUE VERT'. DEPTH GOR, and time of each phase. GN Sand 9,845' 7,405' GR Sand 10,150' 7,621' Top/Hemlock - E. Flank 10,443' 7,799' HC Sand Base/Hemlock- W.Flank 11,720' 8,395' I Top/Hemlock - W.Flank 13,765' 9,193' ,T/HC Sand 31. LiST OF'ATTACHMENTS ........... Wellbore schematics. Summary of Rig Workover Operation,~ .................. 32. I hereby certify that the foregoing is true and correct to the best of my knowledg~ Signed ~ ~~ Title Drilling Manager Date 'D///~///~ I INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log o all types of lands and leases in Alaska Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, sal water disposal, water supply for injection, observation, injection for in-situ combustior Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurement. given in other space on this form and in any attachments Item 16 and 24: If this well is completed for separate production from more than one interval (multipl, completion), so state in item 16, and in item 24 show the productin intervals for only the interval reporte, in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interv~ 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 cemenl lng and the location of the cementing tool Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In. jection, Gas Injection, Shut-in, Other-explain Item 28: If no cores taken, indicate "none". Form 10-407 Alaska Oil & Gas co~. uor~]~l,s~o~, .Ancf~ora§e ~BN~E RGY MGS A23-01 LW Leg 4, Conductor 32 APl No.: 50-733-20238-01 Spud: Surf Csg: 13 3/8", 61 lb, J55. Set @ 2,393'. Cmt'd w/1,940 sx. Intermed Csg: 9 5/8", 47 lb, N80. Set @ 8,080'. Cmt'd w/1,200 sx. 2nd Intermediate Csg: 7", 26 lb, N80 @ 0-9,989'. 7", 32 lb, P110 @ 9,989'-11,538'. Cmt w/980 sx. Drilling Liner: 5" 18~ L80 STL @ 11,650' TOL @ 9,292' Cmt w/123 sx. Production Liner: 3 1/2" 8.8~ L80 STL Slotted Pipe w/Blank Sections Set @ 13,775', TOL @ 11,463' Baker Liner Packer @ 11,463' Baker Hyllo 2 Liner Hangar @ 11,474' PBTD: 13,775' MD, 9,312' TVD TO: Prepared by: PLF 9-26-01 Tbg: 2 7~8" 6.5~ L80 8R EUE 0 - 9,189' 2 3/8" 4.7" L80 8R EUE 9,189 - 11,413' PKR & TBG set 8-12-01 Item MD TVD Pso Psc Port GLM 1 2057 1950 950 909 10 GLM 2 4143 3350 925 892 10 GLM 3 5778 4500 914 875 12 GLM 4 7058 5400 884 857 12 GLM 5 7946 6000 866 844 12 GLM 6 8579 6500 866 827 16 GLM 7 9145 6950 845 810 16 GLM 8 9649 7350 824 794 16 GLM 9 10087 7691 808 777 16 GLM 10 10751 8069 790 760 16 GLM 11 11317 8340 Orifice 24 Baker T-5 SSSV @ 327' (2.312" ID) X-over 2 7/8" x 2 318" 8R @ 9,189' Otis X Nipple 2 3/8" 8R 9Cr (1.87") @ 11,360' Baker Locator sub (40-26) @11,394' Baker Seal Assembly 11' (26) @ 1 t ,395' Baker DB Packer (42-26) 9Ct @ 11,395' 10' Sealbore Ext (40-26) 13Cr X-over 26 Sealbore to 2 3/8 8R @ 11,407' 10' Pup jt 2 3/8" 4.7# 8R EUE 9Cr XN Nipple 2 3/8" 8R 9Cr (1.791" ID) @11,418' 10' Pup jt 2 3/8" 4.7# 8R EUE 9Cr WL REG @ 11,429' Blank 3 1/2" TBG Sections: 11,463 - 11,671' 11,916 - 11,946' 12,191 - 12,221' 12,680 - 12,892' 13,143 - 13,233' 13,495 - 13,589' 13,716 - 13,775' XTO Energy Well No. A23-01LW Well Operations Summary 0600, 05/19/01-0600, 05/20/01 MW: 10.9 ppg Vis: 47 sec Pick up whipstock assembly & bottom hole assembly. Test pulser. Run in hole with whipstock (slow). Circulate and condition mud. Orient & set whipstock 43 degrees left ~ 9,572' - shear release bolt. Start milling window ~ 9,554'. 0600, 05/20/01-0600, 05/21/01 MW: 10.8 ppg Vis: 45 sec Mill window fi.om 9,576' to 9,583' - note: top of whipstock ~ 9,554.73' - bottom of whipstock ~ 9,567.73'. Pmnp dry job. Pull out of hole. Lay down window milling assembly. Pick up bottom hole assembly (drilling assembly) test MWD. Pick up 51 joints 3 ½" drilling pipe. Pull out of hole (scale in pipe). Test MWD - stand back bottom hole assembly. Run in hole with 17 stands, circulate out scale. Pull out of hole. Pick up bottom hole assembly, run in hole 17 Stands, test MWD. Run in hole. Circulate bottoms up. Perform fit test - pressure up on formation to 600 psi with 10.8 mud weight- EMW 12.3 ppg. Wash and ream to bottom (open up 5 %" pilot hole). Drill fi.om 9,583' to 9,585' 0600, 05/21/01- 0600, 05/22/01 Drill from 9,585' to 9,707'. MW: 10.6 ppg Vis: 43 sec 0600, 05/22/01 - 0600, 05/23/01 Drill from 9,707' to 9,847'. MW: 10.7 ppg Vis: 41 sec 0600, 05/23/01 -0600, 05/24/01 MW: 10.5 ppg' Vis: 41 sec Drill from 9,647' to 9,861'. Survey and orient. Drill from 9,861.' to 9,867'. Survey and orient. Drill from 9,867' to 9,887'. Drill from 9,887' to 9,891' (hard time sliding). Drill from 9,891' to 9,900'. Make 5 stand wiper trip to the shoe. Test BOPS (Tom Maunder w/AOGCC waived the witnessing of the BOP test). Run in hole, lay down one washed out joint of 3 ½" drill pipe. Orient tool face, wash to bottom. Drill from 9,900' to 9,904' (tried to slide, could not). Pump dry job, pull out of hole for bit. Break bit, download MWD tool. 0600, 05/24/01 - 0600, 05/25/01 MW: 10.6 ppg Vis: 40 sec Down load Baker MPR tool. Test Baker MWD. Run in hole. Stop ~ the window, change swivel packing & link tilt pins, service top drive. Run in hole fi.om window. Wash and ream to bottom. Drill from 9,904' to 10,020'. 0600, 05/25/01 -0600, 05/26/01 MW: 10.7 ppg Vis: 40 sec Drill from 10,020' to 10,138'. Make connection and survey. Drill from 10,1'38' to 10,172'. Pick up and ream hole. Drill from 10,172' to 10,217'. Survey & make connection, orient. Drill from 10,217' to 10,240'. Reaming, attempting to slide. 0600, 05/26/01- 0600, 05/27/01 MW: 11.3 ppg Vis: 41 sec Drill from 10,240' to 10,269'. Reaming, attempt to slide. Drill from 10269' to 10,283'. Pump pill. Pull out ofhole (lay down bad joint of 3 ½" drill pipe). Change bit, down load MWD, pick up PBL sub. Run in hole to window. Slip and cut drill line. Run in hole. Wash to bottom and orient tool face. Drill from 10,283' to 10,294'. 0600, 05/27/01 -0600, 05/28/01 MW: 11.4 ppg Vis: 40 sec Drill from 10,294' to 10,334'. Make connection and ream coal section. Drill from 10,334' to 10,338'. Orient tool face. Drill from 10,338' to 10,388'. Ream section. Drill from 10,388' to 10,424'. Make connection and survey. Drill from 10,424' to 10,495'. Ream section and change pumps. Drill from 10,495' to 10,516'. Make connection and survey. 0600, 05/28/01 - 0600, 05/29/01 MW: 11.7 ppg Vis: 41 sec Drill from 10,516' to 10,610'. Make connection and survey. Drill from 10,610' to 10,615'. Monitor well, well flowing without ECD. Drill from 10,615' to 10,648' while bringing mud weight from 11.3 to 11.8 ppg. Pump pill, survey, and check flow. Pull out of hole. Change out mud motor, down load MWD, test MWD, lay down stab. Run in hole. Ream to bottom from 10,550'. Circulate out 510 units trip gas, work with Baker Inteq to get MWD signal, prepare to drill. 0600, 05/29/01 - 0600, 05/30/01 MW: 11.8 ppg Vis: 41 sec Work with Baker Inteq to get signal from MWD. Drill from 10,648' to 10,892'. 0600, 05/30/01-0600, 05/31/01 MW: 12.0 ppg Vis: 41 sec Drill from 10,892' to 10,911'. Attempt to slide (not able). Mix and pump dry job, and monitor well. Pull out of hole. Break bit, down load MWD, lay down mud motor. Pull wear ring. Test BOPE 250 / 5000 psi (annulus = 250 / 2500 psi) - witnessed by J. Crisp of AOGCC - Good test. Set wear ring. Make up MWD/MPR, load, orient- surface test MWD and pick up and make up bit #6 and jars. Run in hole, changing out bad boxes while running in. 0600, 05/31/01-0600, 06/01/01 MW: 12.0 ppg Vis: 45 sec Circulate ~ 9,568' (below shoe) 2-drill pipe volumes. Run in hole to 10,334' measure drill pipe, unable to circulate. Pull out of hole to shoe, attempt to circulate again- no go, drop ball to PBL. Wait for ball to seat in PBL and weight up surface volume to 12 ppg. Circulate bottoms up ~ shoe. Pump dry job and pull out of hole. Lay down bit and motor. Fine drill solids packed in bit and motor - packed solid, motor float open. Pick up new mud motor, orient and setup to 1.2 degrees. Program MWD and surface check and setup PBL sub. Run in hole to 9,596' DPM. Circulate and condition mud around. Wash and ream to 10,617' DPM- tried to stall out ~ 10,334' DPM (same spot where drill solids were picked up and plugged bottom hole assembly). 0600, 06/01/01 -0600, 06/02/01 MW: 11.8 ppg Vis: 45 sec Wash and ream from 10,334' to 10,910' DPM. Drill from 10,910' to 10,914' DPM. Drill and orient from 10,914' to 10,947' DPM with tool face of 180L. Drill from 10,927' to 10,957' DPM- losing partial returns. Reduce pump rate and mix and pump LCM. - stage pump rate up to drilling rate - good returns. Drill from 10,957' to 11,080' DPM. Drill and orient from 11,080' to 11,090' DPM with tool face of 70R. 0600, 06/02/01 -0600, 06/03/01 MW: 11.8 ppg Vis: 47 sec Drill and orient from 10090' to 11129' DPM with TF of 180L. Survey, circulate bottoms up, pump Hi-Vis sweep, check for flow and pump dry job. Pull out of hole to window, check for flow and continue to pull out of hole. Break bit, down load MWD, surface check MWD - OK, make up bit #7. Run in hole to 9223' DPM. Slip and cut drill line. Service top drive. Pick up 4 stands drill pipe and run in hole to 10640'. Wash, ream, and drill from 10,640' to 11,084' DPM. 0600, 06/03/01 -0600, 06/04/01 MW: 11.8 ppg Vis: 45 sec Wash, ream and drill from 11,084' to 11,129'. Drill and orient from 11,129' to 11,143' with TF of 85R. Drill from 11,143' to 11,223'. Drill from 11,223' to 11,265'. Drill and orient from 11,265' to 11,273' with TF of 85R. Circulate and change pump swab. Drill and orient fi'om 11,273' to 11,288 with TF of 85R. 0600, 06/04/01 -0600, 06/05/01 MW: 11.8 ppg Vis: 49 sec Attempt to rotate, no go. Circulate bottoms up and sweep hole with Hi-Vis sweep. Pull out of hole. Break bit and down load MWD. Top of MPR packed off with drill pipe scale and rust. Lay down motor, MWD, pick up new motor and MWD. Program MWD - Negative test. Clean out MPR, reprogram MWD - OK. Surface test MWD. Reprogram MWD and surface test- OK. Run in hole 34 stands and rattle drill pipe. Attempt circulation- packed off, unable to circulate. Drop PBL ball - attempt to pump - packed off. Pull out of hole (wet). PBL plugged - no ball. Break bit off- surface test MWD and MPR - OK. Decide to run in hole open ended with 34 stands, fred ball & flush out drill pipe. Run in hole open ended and check for PBL ball. 0600, 06/05/01 -0600, 06/06/01 MW: 11.8 ppg Vis: 45 sec Run in hole open ended, rabbit drill pipe and f'md PBL ball 19 stands up. Continue to nm in hole and rabbit drill pipe for 34 stands (34th stand had visible cement scale - lay down and replaced. Circulate 3 drill pipe volumes ~ Hi rate. Pull out of hole. Make up same bottom hole assembly (#9). Run in hole to 4850'. Fill pipe and check MWD. Run in hole to 8582', fill drill pipe and check MWD. Service rig and top drive. Run in hole to 10,540'. Wash and ream from 10,540' to 10,600', 10,785' to 10,815', 10,860' to 10,908', and 11,095' to 11,288'. Drill from 11,288' to 11,3666'. Got gamma ray marker spike ~ 11,280' for top of HZ zone. Rate of penetration slowed way down ~ 11,355' - clay stone. 0600, 06/06/01 -0600, 06/07/01 MW: 11.8 ppg Vis: 46 sec Drill fi.om 11,366' to 11,465' - look for casing point. Drill and orient fi.om 11,465' to 11,478' with tool face of 45R. Drill from 11,478' to 11,486' - look for CSG PT. 0600, 06/07/01 -0600, 06/08/01 MW: 11.8 ppg Vis: 46 sec Drill fi.om 11,486' to 11,557'. Circulate and build volume. Drill and orient fi.om 11,557' to 11,574' with tool face' s of 60 & 70R. Drill and orient from 11,574' to 11,580' with tool face' s of 50 & 60R. Drill fi.om 11,580' to 11,600'. 0600, 06/08/01 - 0600, 06/09/01 MW: 11.9 ppg Vis: 56 sec Drill fi.om 11,600' to 11,616'. Work on mud pumps. Drill fi.om 11,616' to 11,650' - out of drill pipe. Geologist called casing point. Circulate Hi-Vis sweep. Check for flow and spot soltex/lubetex pill. Wiper trip / short trip to 9,513'. Slip and cut drill line - 200'. Monitor well. Run in hole to 11,650'. Circulate Hi-Vis sweep. Pull out of hole to shoe. Mix and pump dry job. Pull out of hole. Handle bottom hole assembly. 0600, 06/09/01-0600, 06/10/01 MW: 11.9 ppg Vis: 56 sec Finish handling of bottom hole assembly - lay down directional tools. Pull wear ring, make up test assembly, set test plug, test BOPE 250/5000 psi (annulus 250/2500 psi) - good test. Pull test plug, lay down test assembly and set wear ring. Rig up to run 5" liner - safety meeting - discover 5" = mixed load of stainless and series 500 513 Hydrill. Got more stainless on boat and had enough stainless to run till boat arrival. Pick up and run in hole with 5" liner & float equipment & centralizers as per program. Pick up liner hanger equipment and packer. Circulate 5" liner volume and rig down tong equipment. Run in hole with 5" liner on 3 ½" drill pipe (slow). 0600, 06/10/01-0600, 06/11/01 MW: 11.7 ppg Vis: 47 sec Run in hole with 5" liner on 3 ½" drill pipe to window. Circulate string volume. Run in hole and tag bottom ~ 11,650'. Circulate hole and condition mud and circulate out trip gas- unable to move pipe (stuck on bottom). Drop ball, make up cement head, pressure test surface lines to 4000 psi, set Baker hanger and blow seat. Cement liner: pump 30 bbl spacer, 27 bbl lead slurry to 12.5 ppg, 10 bbl tail slurry to 15.8 ppg, drop dart, & displace with mud & pump plug - CIP = 15:48. Set liner packer & unsting fi.om same - bottom shoe at 11,650', top of float collar at 11,603', top of landing collar at 11,525', top of hanger at 9,314', & top of liner packer at 9,292' - detail to follow. Reverse circulate drill string - recovered 23 bbls contaminated spacer with trace of cement. Pump dry job and pull out of hole to 2,141'. Rig up and pull out ofhole and lay down excess 3 ½" drill pipe and bottom hole assembly (including Baker set tool). Make up 6" cement drilling assembly. Run in hole with 6" assembly - tag top of liner at 9,297' (5' low) no cement. 0600, 06/11/01 - 0600, 06/12/01 MW: 11.5 ppg Vis: 49 sec Circulate bottoms up, pump dry job. Pull out of hole. Lay down 6" bottom hole assembly. Rig up and pick up 2 7/8" drill pipe steel measure and rabbit same. Circulate drill pipe. Pick up and make up mud motor and bit. Run in hole and tag top of cement ~ 11,463'. Drill cement from 11,463' to landing collar ~ 11,525' Circulate hole and pump dry job. Pull out of hole. 0600, 06/12/01 - 0600, 06/13/01 MW: 11.6 ppg Vis: 49 sec Finish pulling out of hole. Handle bottom hole assembly. Rig up Schlumberger and hold safety meeting. Run in hole and run bond, LOG/CBT/G-R/CCL - tag top of landing collar ~ 11,437' WLM & tag liner ~ 9,297' WLM - cement bond = good from 11,447' to 9,800', fair from 9,800' to 9,500' & poor from 9,500' to 9,297' - some cement ~ top of liner, but not great bonding. Rig down Schlumberger. Test casing to 3000 psi for 30 min - good test - straight line on chart. Service top drive. Pick up bit and motor & 2 joints 2 7/8" drill pipe. Run in hole to 8,932'. Slip and cut drill line. Run in hole to top of landing collar ~ 11,525'. Drill landing collar ~ 11,525', cement to 11,602', float collar ~ 11,602', & cement to 11,646'. Circulate sweeps and displace hole. 0600, 06/13/01-0600, 06/14/01 MW: 11.6 ppg Vis: 49 sec Clean pits, pipe racks, pollution pan, trip tank, flow lines. Inject & offtwo boats with OBM. Fill pits with OBM. Displace hole with OBM- 8.5 ppg. Drill float shoe ~ 11,650' DPM. Drill rotary FM from 11,650' to 11,670'. Circulate bottoms up. Prep and perform leak off test - obtained 14 ppg estimated mud weight - did not take to leak off. 0600, 06/14/01 - 0600, 06/15/01 MW: 8.5 ppg Vis: 61 sec Finish F.I.T. test. Pull out of hole with 3 ½" drill pipe. Pick up 2 7/8" drilling pipe. Pump 3 drilling pipe volumes. Pull out of hole- stand 2 7/8" drill pipe in derrick. Handle bottom hole assembly - check motor, pick up stab and flex joints. Calibrate MWD probe (spacing problem). Set motor 0.3 degrees (scribe), test MWD. Run in hole to 11,650'. Orient MWD equipment. Rotate from 11,670' to 11,675'. Slide from 11,675' to 11,680'. 0600, 06/15/01 -0600, 06/16/01 MW: 8.4 ppg Vis: 84 sec Drill from 11,675' to 11,808'. Service top drive and rig. Survey and orient. Drill from 11,808' to 11,901' 0600, 06/16/01-0600, 06/17/01 MW: 8.5 ppg Vis: 70 sec Make connection, survey and orient. Drill from 11,901' to 11,993'. Make connection, survey and orient. Drill from 11,993' to 12,081'. Make connection, survey and orient. Drill from 12,081' to 12,163'. 0600, 06/17/01-0600, 06/18/01 MW: 8.4 ppg Vis: 72 sec Drill from 12,163' to 12,180'. Short trip 6 stands to the 5" shoe. Make connection, survey and orient. Drill from 12,180' to 12,209'. Orient and reboot MWD computer. Drill from 12,209' to 12,258'. Work on mud pump #1. Drill fi'om 12,258' to 12,273'. Make connection, survey and orient. Drill fi'om 12,273' to 12,312'. 0600, 06/18/01-0600, 06/19/01 MW: 8.4 ppg Vis: 70 sec Drill from 12,312' to 12,343'- hole started taking 10 barrels per hour. Pump PBL ball- mix and spot 15 bbl of 20# LCM pill. Pull out of hole 14 stands. Pump dry job- blow down stand pipe. Pull out of hole. Break bit down, load MPR, redress and change battery. Pull wear bushing and test BOPs. Change out motor to MWD and initialize MPR - drop dog collar wrench in stack. Fish out wrench. Finish making up bottom hole assembly and bit. Run in hole - flow test motor and check MWD. 0600, 06/19/01 -0600, 06/20/01 MW: 8.3 ppg Vis: 68 sec Trip in hole. Wash and ream 90' to bottom. Drill from 12,343' to 12,367'. Make connection and survey. Drill fi'om 12,367' to 12,417' (drilling break ~ 12,412'). Monitor returns - losing 1 bbl per minute - open PBL sub - spot 20 bbl LCM pill. Pull out of hole to 10,416'. Circulate and monitor well- well lost 15 bbls then leveled off. Run in hole to 11,532'. Circulate with good returns - drop ball, close PBL. Run in hole to bottom. Drill from 12,416' to 12,460' - losing 14 bbls per hour. Make connection and survey. 0600, 06/20/01 -0600, 06/21/01 MW: 8.2 ppg Vis: 59 sec Drill from 12,460' to 12,554' (losing fluid ~ 14 barrels per hour). Survey. Drop ball to open PBL sub- 1St ball didn't work-drop 2nd ball, tool opened- spot LCM pill. Pull out of hole to 10,416'. Circulate-monitor hole (hole not taking any fluid). Run in hole to 11,625' - circulate - no fluid loss - drop ball. Run in hole- close PBL sub- wash 30' to bottom. Make connection, survey and orient tool face. Drill from 12,554' to 12,604'. Working on LWD tool (a short in tool), not able to get tool to work. Drill from 12,604' to 12,610' - hole taking 6 to 10 bbls of fluid per hour- MWD tool not working, 0600, 06/21/01-0600, 06/22/01 MW: 8.1 ppg Vis: 74 sec Drill from 12,610' to 12,631' - MWD tool not working- started losing fluid ~ 30 bph. Drop ball, open PBL sub- spot 20 bbl LCM pill on bottom. Pull out of hole to shoe. Mix and pump dry job. Pull out of hole. Adjust generators. Pull out of hole. Break bit, evaluate motor, attempt to down load MPR, lay down probe and MPR- pick up new MPR and probe - make up bit and test MWD. Run in hole to 11,700'. Slip and cut drill line. Test MWD and circulate and condition mud. 0600, 06/22/01-0600, 06/23/01 MW: 8.0 ppg Vis: 65 sec Test MWD tool. Trip in hole to 12,585'. Make MAD pass with MPR from 12,585' to 12,631'. Drill from 12,631' to 12,743'. Make connection and survey. Drill from 12,743' to 12,812' - continue to lose fluids of 8 to 9 barrels per hour. 0600, 06/23/01-0600, 06/24/01 MW: 8.0 ppg Vis: 71 sec Drill from 12,812' to 12,836'. Drill from 12,836' to 12,849'. Drill from 12,849' to 12,929'. Make connection and survey. Drill from 12,929' to 12,946'. 0600, 06/24/01 - 0600, 06/25/01 MW: 8.0 ppg Vis: 79 sec Drill from 12,946' to 12,954' (hole continues to take 5 to 6 barrels per hour). Drill from 12,954' to 12,979'. Work tight spot - packing off at 12,979'. Drill from 12,979' to 12,982'. Drop ball open PBL sub, pump LCM pill. Short trip 15 stands to shoe. Circulate above LCM pill - squeeze 2 bbls into formation- drop ball, open PBL sub. Run in hole. Wash and ream from 12,391' to 12,982'. Drill from 12,982' to 13,005' (hole taking 1-2 bbl per hour). Hole packing off- work pipe-back off2 7/8" drill pipe-screwed back into it, pulled up hole to 12,841' working thru tight spots- lost fish again- screwed into it 2 more times, pulled off both times (lost ~ 12,000 string weight). Circulate - pump dry job. Blow down top drive - pull out of hole for fishing tools. 0600, 06/25/01 -0600, 06/26/01 MW: 8.0 ppg Vis: 82 sec Pull out of hole for fishing tools- left bottom hole assembly plus 89 joints of 2 7/8" drill pipe (2,941') - top of fish ~ 10,064'. Make up 4 1/8" overshot with 3 1/8" grapples & bumper sub. Run in hole- checking tool joints of 2 7/8" on the' way in hole. Fish ~ 10,063' - unable to get overshot guide over tool joint. Pump dry job. Pull out of hole. Change out cut lip guide with 3 1/8" guide with cut rite. Run in hole. Work through liner top ~ 9,292'. Fish ~ 10,063' - bum over & latch onto fish- work fish. No movement indicated in jars or bumper sub in fish - pull max of 105,000 over string weight. Attempt to back offbelow top offish- backed off above fish, screw back in- release grapples in overshot. Pump dry job. Pull out of hole. Break down fishing tools. Test BOPs (Jane Williamson with AOGCC waived test until today- test due on 25th)(Hole took 50 bbls fluid in last 24 hours). 0600, 06/26/01-0600, 06/27/01 MW: 8.1 ppg Vis: 100 sec Test BOPs. Make up 4 1/8" overshot dressed with 3 1/8" grapples - bumper sub - 3 1/8" Daileyjars- (3) 3 1/8" drill collars. Run in hole to 9,261'. Slip and cut drill line. Service top drive. Run in hole - tag fish. Work onto fish ~ 10,063' & jar on fish. Blind back off. Pull out of hole- left 2 crossovers and overshot on top of fish. Check breaks on fishing assembly. Run in hole with same assembly to screw back in. Screw into fish & work stuck pipe. 0600, 06/27/01 -0600, 06/28/01 MW: 8.2 ppg Vis: 95 sec Release overshot. Mix & pump dry job- blow down top drive. Pull out of hole. Service rig and top drive. Lay down overshot - dress & pick up new 4 1/8" overshot dressed with 3 1/8" grapples. Run in hole. Work over fish, attempt to latch onto fish (couldn't get a firm bite). Mix and pump dry job. Pull out of hole, lay down fishing tools (left all the 3 1/8" grapple in hole). Service rig. Pick up 4 1/8" mill - bit sub - cross over - bumper sub - Dailey jars - cross over - (3) drill collars. Trip in hole - prepare to mill up tool joint, down to 2 7/8" tube - hole taking fluid ~ 2 barrels per hour. 0600, 06/28/01 -0600, 06/29/01 MW: 8.2 ppg Vis: 93 sec Tag top of fish ~ 10,063' and establish parameters. Mill up tool joint on top of fish from 10,063' to 10,066'. Pump sweep and dry job. Pull out of hole with mill assembly. Lay down mill bottom hole assembly & pick up overshot assembly (slick ID with no jars). Run in hole. Repair top drive link tilt ram. Run in hole to 9,224'. Slip and cut drill line - 100'. Run in hole. Work over fish & catch same with overshot assembly. Rig up and run in hole with slick line with 1.25" tools and gauge prong- saw bobble ~ 10,090' WLM and stop ~ 10,178' (junk) & work junk to 10,185' - thick mud causing little or no spang jar action. Pull out of hole with slick line. Rig down slick line and rig up Alaska Pipe Recovery Specialists (APRS) E-line unit. 0600, 06/29/01-0600, 06/30/01 MW: 8.1 ppg Vis: 106 sec Radio silence. Make up APRS string shot - run in hole to 11,400' (got by junk ~ 10,190' WLM). Work (5) rounds leR hand torque into pipe- backed off ~ 9,401' (above grapple). Pull out ofhole with APRS. Rig down APRS. Screw into fish @ 9,401' - release overshot and grapple. Pump dry job and pull out of hole. Redress overshot & new grapple (lost piece in hole). Run in hole and break, clean and re-torque all 2 7/8" tool joints. Space out, work over fish and catch fish ~ 10,063' DPM. Rig up APRS, radio silence, make up string shot and nm in hole - stop at 2na joint below overshot and grapple - unable to pass junk. Locate and work (4) rounds let~ hand torque into string - back offwith string shot - indicates that 1 joint below over shot and grapple was got. Pull out of hole with APRS & rig down same. Pump dry job- lay down space out pups. Pull out of hole. Service rig and top drive. Pull out of hole. Trouble shoot electric pump throttle. Pull out of hole. 0600, 06/30/01 -0600, 07/01/01 MW: 8.2 ppg Vis: 126 sec Pull out of hole. Lay down fish- recovered (1) joint 2 7/8" drill pipe. Trouble shoot electric. Make up, screw in assembly with bump-sub. Run in hole with screw-in assembly. Trouble shoot rig DC electric - repaired OK. Run in hole and tag top of fish (2 3/8" H90 box) ~ 10,095' DPM. Circulate drill string volume. Screw into fish ~ 10,095'. Rig up APRS line-line unit - radio silence - nm in hole with string/shot to top ofjunk ~ 10,038' & attempt to work past - no go - pull out of hole & rig down APRS. Rig up slick line unit - nm in hole with chisel and work junk from 10,038' to 10,300' SLM - unable to break up or work down - pull out of hole rig down slick line. Prep and perform blind back off and attempt to get below junk in drill pipe. 0600, 07/01/01-0600, 07/02/01 MW: 8.2 ppg Vis: 133 sec Attempt blind back off to get by junk - back off above fish. Rig up APRS wire line and nm in hole and locate break ~ 9,300' WLM- screw back into fish- run in hole to 10,147' - pull out ofhole an rig down wire line side-entry sub - pick up string shot and run in hole and back off 1 joint (10,126' WLM) - pull out ofhole and rig down APRS. Pump dry job and blow down top drive. Pull out of hole and recover (1) joint 2 7/8" drill pipe - top of fish = 10,127'. Run in hole slick line and check torque on 2 7/8" drill pipe. Space out and screw into fish ~ 10,127'. Attempt one more blind back off-back offabove fish. Rig up APRS and run in hole and locate break ~ 9,469' - pull out of hole and rig down APRS. Screw back into fish ~ 9,469'. Rig up to unload boat with 1 ½" coil tubing and prep to move coil tubing unit operator to rig. 0600, 07/02/01 -0600, 07/03/01 MW: 8.3 ppg Vis: 140 sec Prep for coil tubing unit rig up - back load boat with 1 ½" coil tubing - assist coil tubing crew rigging down from A34-14RD2 and rigging up for A23-01LW- unable to change out coils with boat due to high winds- will resume ~ 0600 hrs - clean pits and inject and wait for boat. 0600, 07/03/01- 0600, 07/04/01 MW: 8.3 ppg Vis: 115 sec Back load boat and shift equipment around platform- unload 1 ½" coil and spot on rig cat walk- spot INJ HD, power unit, pumps and tanks. Nipple up BOPs. T Stab pipe on INJ HD and pre-bend same, stack lubricator, stab INJ HD. Stab coil, weld on connector, & fill coil with oil based mud- obtain good returns. Pressure test BOPs, install bottom hole assembly and pull test same - OK. Pressure test stack & coil, would not bleed down- inspect reel manifold, lay down bottom hole assembly. Stab on to well and attempt to pump down coil- no go - rig up to reverse - get pressure, but no fluid - tubing plugged somewhere in middle of coil - still rocking it back and forth, but no go. 0600, 07/04/01-0600, 07/05/01 MW: 8.3 ppg Vis: 113 sec Work on clearing 1 ½" coil tubing -change from oil based mud to diesel- finally got circulation. Run in hole with 1.8" mill and 1.68" motor-tag junk ~ 10,190' CTM. Mill intermittent junk 10,190', 10,500', 10,750', 11,561', 11,565', 11,570', & 11,595' - lots of milling & motor stalls - run in hole and tag top of PBL sub ~ 12,848' CTM. Wash PBL profile and pump 8 bbl oil based mud seep around. Drop coil tubing circulation sub ball & open coil tubing circulation sub. Pull out of hole with coil tubing. Rig down coil tubing INJ HD. Lay down mill & motor- pick up 1.75" spray nozzle, drop 1" ball for PBL sub, Rig up coil tubing INJ HD, & pressure test stack. Run in hole with 1.75" spray nozzle and chase 1" PBL. 0600, 07/05/01 -0600, 07/06/01 MW: 8.3 ppg Vis: 120 sec Run in hole, chasing PBL ball with spray nozzle and tag PBL ~ 12,842'. Wash PBL, pick up & pressure up to 4000 psi- hold- bled/quickly from 4000 psi to 2000 psi with pump off- pressure back up and pump0.3 barrels per minute ~ 2600 psi- set down pump and bleed to 333 psi in 20 minutes- attempt pressure up & open PBL again- no circulation. Pressure up drill pipe x 5" annulus with rig and attempt to observe pressure on coil tubing side- no pressure - no circulation- confirm PBL not open. Pull out of hole with coil tubing. Rig down INJ HD and load Schlumberger faring head/perf, hold safety meeting. Pick up perf gun and pressure test stack. Run in hole with perf gun on coil tubing & tag PBL ~ 12,842'. Pick up 6 feet, locate & drop ball - pressure up to 2900 psi & fire gun & perfdrill pipe from 12,834' to 12,836' 4HPF 0.2" holes. Pump down coil tubing and coil tubing x drill pipe annulus and establish circulation in 5" to surface- circulate well. Pull out of hole with coil tubing and make room for APRS wire line unit. Rig up APRS wire line unit and make up free point tools. Run in hole with APRS free point tools. 0600, 07/06/01 - 0600, 07/07/01 MW: 8.1 ppg Vis: 110 sec Run in hole with APRS free point tools - free pipe to 11,800' and sticky pipe from 11,800' to 12,800'. Pull out of hole with free point tools. Safety meeting, radio silence - arm APRS string shot - nm in hole with same - shoot string shot - CCL went bad, pull out of hole. Circulate work pipe, no go - spot diesel pill. Run in hole with wire line and new CCL - pipe not backed off- pull out of hole. Displace drill pipe with diesel and work pipe with right hand torque and attempt break and ream. Safety meeting, radio silence - make up chem. Cutter- well u- tubing - displace diesel with mud. Run in hole with 1 11/16" chem.-cutter, locate 4' below 1 st tool joint above PBL. Fire chem.-cutter and saw - 4,000 decrease on weight indicator - work pipe and move 2 ft - check out with CCL and verify movement - pull out of hole with APRS wire line. 0600, 07/07/01 - 0600, 07/08/01 MW: 7.9 ppg Vis: 69 sec Finish pull out of hole with APRS and rig down. Work pipe and spot diesel around fish. Service top drive and iron roughneck while diesel soaks. Work pipe - unable to work free- acts like wall stuck. Rig up APRS and nm in hole with string shot, work 5 left hand tums in pipe and back off ~ 11,598' (52' above 5" shoe) - verify back offwith CCL, pull out of hole and rig down APRS wire line. Circulate and condition mud. Pump dry job, and pull out of hole - recover 47 joints 2 7/8" drill pipe. Pull wear ring, make up test joint, set test plug, fill stack, and test BOPE 250/5000 psi (250/2500 annulus), retrieve test plug, set wear ring and break down test assembly. Pick up screw in sub, jars, and bump sub- run in hole. 0600, 07/08/01-0600, 07/09/01 MW: 8.0 ppg Vis: 122 sec Run in hole with 2 7/8" drill pipe and clean and dope dry connection. Run in hole with 3 ½" drill pipe. Slip and cut drill line - 100 feet. Run in hole and tag top of fish ~10,598' and jar on same. I no movement. Rig up APRS and nm in hole with .75" CCL and string shot- attempt check cut ~ 12,810' - unable to pass CCL thru cut - pick up, locate and control back off ~ 11,806' (156' below 5" shoe- verify back offwith CCL). Pull out of hole with APRS - stuck in cross over below jars- pulled free- pull out of hole- pulled out of rope socket - left 27'-2" of 3A'' tools in hole, tools likely in down hole fish. Rig down APRS. Circulate while still in box and pick up and wash top of fish ~ 11,806'. Circulate bottom up. 0600, 07/09/01-0600, 07/10/01 MW: 7.9 ppg Vis: 100 sec Blow down top drive, dry job and pull out of hole. Handle bottom hole assembly - (3) 2 3/8" regular crossovers have swelled boxes - send to beach to be re-cut. Recover (7) joints of 2 7/8" drill pipe fish. Service fishing tools. Wait on cross over boxes to be re-cut and ¼" bore out of (2) crossovers. Trouble shooting DC power to rig - rotary table not functioning. Make up screw in sub, bump-sub and jars, and drill collar assembly. Run in hole. Trouble shoot DC power to rotary table. Run in hole. Tag top of fish ~11,806' DPM and screw into same and jar on same - no movement. Trouble shoot DC power to rotary table. 0600, 07/10/01-0600, 07/11/01 MW: 8.1 ppg Vis: 103 sec Trouble shoot D/C power to rotary table and repaired. Rig up APRS wire line unit. Safety meeting and radio silence. Run in hole with string shot. Pick up, locate and back off ~ 11,839' WLM (1)joint down from screw-in sub. Run in hole and verify back offand pull out ofhole and rig down APRS. Circulate bottoms up - pump dry job. Blow down standpipe and pull out of hole. Pull out ofhole and break down fishing tools- recover (1) joint 2 7/8" drill pipe. Pick up 15 joints 2 3/8" tubing and nm in hole on 2 7/8" drill pipe. Run in hole with 3 ½" drill pipe in preparation for cement kickoff plug. 0600, 07/11/01-0600, 07/12/01 MW: 8.1 ppg Vis: 103 sec Run in hole with 15 joints of 2 3/8" tubing on 2/8" and 3 ½" drilling pipe - tag top of fish ~ 11,837' and pick up 3'. Circulate hole and rig up to lay cement kickoffplug. Safety meeting, test surface lines to 3500 psi- OK- mix and pump spacers and 35 sack class 'G' with 0.7% BWOC DC-32 and 0.15% BWOC SM5 and FP6L to a slurry weight of 16.65 ppg and balance kickoffplug-CP = 10:15 hours- calculated top ofcement=l 1,578'. Pull out of hole 10 stands. Circulate long way. Repair hydraulic leaks on top drive and service same. Pull out of hole. Service top drive. Slip and cut drill line. Fill hole and nm in hole and tag top of cement 11,674'. Attempt pump offwith no rotary table & 10k- no pumpoff- drill from 11,674' to 11,679' - drills too easy. Circulate and wait on cement. 0600, 07/12/01-0600, 07/13/01 MW: 8.1 ppg Vis: 90 sec Wait on cement (kick off plug). Attempt to dress off cement - drill cement from 11,679' to 11,691' - cement would hold 10,000 with pump and no rotary, but would drill offwith 1000-2000 ~ 300 FPH with rotary. Circulate bottoms up. Hold 750 psi back pressure on cement. Pull out of hole to 11,550'. Test BOPs (Jack Hartz with AOGCC waived witnessing test). Run in hole. Attempt to dress offcement - drill poor cement and stringers of cement from 11,691' to 11,820' (top of fish 11,837'). Circulate bottoms up. Pull out of hole. Stand back drilling assembly. Pick up 15 joints 2 3/8" tubing. Run in hole with 2 7/8" and 3 ½" drill pipe to lay another cement kick offplug. 0600, 07/13/01-0600, 07/14/01 MW: 8.2 ppg Vis: 94 sec Run in hole with 3 ½" drill pipe to top of fish. Rig up to cement - circulate bottoms up. Safety meeting - BJ pumped 5 bbl water - test lines to 3000 psi - pumped 7.5 bbl water followed by (5 bbl cement) mixed, followed by 5 bbl water - displace with 60 bbl 8.1 ppg drilling mud with rig pump - circulate in pipe. Pull out of hole 10 stands to 10,915'. Circulate long way. Repair top drive - change out saver sub. Pump dry job - pull 1 stand. Work on top drive - change out crownamatic. Pull out of hole. Lay down 15 joints 2 3/8" tubing- make up bit and dressing assembly. Run in hole to dress cement for kick off- string took weight ~ 11,368'. Washing and reaming- looking for cement. 0600, 07/14/01- 0600, 07/15/01 MW: 8.1 ppg Vis: 94 sec Wash to top of fish- seen nothing on weight indicator. Circulate bottoms up (some green cement). Pull out of hole. Service rig, slip and cut line. Run in hole. Perform F.I.T. test and poor results. Circulate and rig up to spot #3 kick off cement plug. Safety meeting, BJ tested lines- pumped cement job. Pull out of hole. Pump dry job. Pull out of hole. Lay down 2 3/8" tubing (cement inside and out on tubing). 0600, 07/15/01-0600, 07/16/01 MW: 8.1 ppg Vis: 94 sec Make up bit and bottom hole assembly. Run in hole w/2 7/8" drill pipe. Cement from inside drill pipe, plugged string above jars. Pull out of hole wet. Break bit, circulate thru bottom hole assembly and make up bit. Run in hole with 2 7/8" drill pipe from derrick that had not been cemented thru. Drill from firm cement at 11,110' to 11,120' - stringers to 11,123' - firm to 11,298' - stringers to 11,480' - mostly firm cement from 11,480' to 11,670' (good firm cement in open hole). Circulate bottoms up, and pull out ofhole for kick off assembly. 0600, 07/16/01-0600, 07/17/01 MW: 8.1 ppg Vis: 94 sec Pull out of hole with dressing assembly. Handle bottom hole assembly. Run in hole and lay down 2 7/8" to be sent in for inspection. Pick up bottom hole assembly and MWD - pick up 5 joints of 2 7/8" drill pipe. Run in hole. Ream from 11,650' to 11,670', orient tool face. Drill, tracking hole from 11,670' to 11,678'. 0600, 07/17/01 - 0600, 07/18/01 MW: 8.1 ppg Vis: 98 sec Drill from 11,678' to 11,768'. Survey. Drill from 11,768' to 11792'. 0600, 07/18/01-0600, 07/19/01 MW: 8.2 ppg Vis: 95 sec Drill from 11,792' to 11,798'. Wash and ream to bottom. Drill from 11,798' to 11,830'. Attempt to unball bit. Drill from 11,830' to 11,861' Make connection, survey and orient. Drill from 11,861'to 11,876'. Orient tool face. Drill from 11,876' to 11,895'. Ream and orient. Drill from 11,895' to 11,955'. Make connection and survey. Drill from 11,955' to 11,990' (lost fluid ~ 12bph from 11,965' to 11,995'). Wash and ream to help slide - fluid loss stopped after adding LCM. Drill from 11,990' to 11,998'. Ream to help slide. Drill from 11,998' to 12,014'. 0600, 07/19/01-0600, 07/20/01 MW: 8.2 ppg Vis: 105 sec Drill from 12,014' to 12,030'. Ream out slide. Drill from 12,030' to 12,048'. Make connection, survey and orient. Drill from 12,048' to 12,052'. Ream hole to continue slide. Drill from 12,052' to 12,060'. Circulate hole and pump dry job. Pull out of hole. Handle bottom hole assembly. Drain stack - pull wear ring. Test BOPs (AOGCC witness of test waived by Jane Williamson). Make up bottom hole assembly- test MWD - make up bit. Pick up 22 joints of 2 7/8" drill pipe. 0600, 07/20/01 -0600, 07/21/01 MW: 8.2 ppg Vis: 94 sec Run in hole to 9,200'. Slip and cut drill line. Fill pipe and replace crownomatic. Run in hole to 11,993'. Wash and ream from 11,993' to 120,060. Reboot MWD and orient tool face. Drill from 12,060' to 12,083'. Make connection and survey. Drill from 12,083' to 12,176'. Wash and ream, survey and make connection. Drill from 12,176' to 12,197'. 0600, 07/21/01-0600, 07/22/01 MW: 8.2 ppg Vis: 91 sec Drill from 12,197' to 12,225'. Monitor well, losing 20 to 25 bbl per hour. Drop ball, open PBL sub - pump 10 bbl LCM pill. Short trip 8 stands. Circulate bottoms up thru PBL sub. Drop ball, close PBL sub. Run in hole. Drill from 12,225 to 12,270' (losing 6 to 8 bph). Make connection and survey. Drill from 12,270' to 12,344'. Ream out slide section. Drill from 12,344' to 12,360' (continue losing fluid at 8 barrels per hour). 0600, 07/22/01 -0600, 07/23/01 MW: 8.2 ppg Vis: 97 sec Drill from 12,360' to 12,373'. Ream trying to slide. Drill from 12,373' to 12,375' (started losing 30 bph fluid). Drop balls to open PBL sub - didn't open. Pump 15 bbl LCM pill thru bit. Pull 10 stands to 11,529'. Monitor well. Shut in well, put 300 psi on back side for 5 minutes- bled off- make sure PBL sub is closed - circulate - hole not taking any fluid. Build mud volume. Run in hole. Wash and ream from 12,270' to 12,375' (hole not taking any fluid). Drill from 12,375' to 12,384' - after 5 feet, hole started taking 4bph- MWD tool worked for awhile then quit. Ream hole, MWD quit working. Drill from 12,384' to 12,400' - MWD not working - hole taking 8-10 bph. Attempt to open PBL sub- no go. Pump LCM pill thru bit. Pull out of hole 10 stands. Pump dry job - blow down top drive. Pull out of hole (hole took total of 250 bbls of fluid last 25 hours. 0600, 07/23/01 -0600, 07/24/01 MW: 8.1 ppg Vis: 97 sec Change out bit, MWD, probe and mud motor- break down PBL sub- surface test MWD and PBL sub. Run in hole- pick up 9 joints of 2 7/8" drill pipe on way in hole- fill pipe and break circulation ~ 4,000' and 9,200'. Break circulation slowly and ream form 12,274' to 12,400'. Drill from 12,400' to 12,421' (losing 15 bph). Drill from 12,421' to 12,457'. Make connection and survey. Drill from 12,547' to 12,551' (losing 8 to 12 bph). Make connection and survey (lost total of 150 bbls last 24 hours). 0600, 07/24/01- 0600, 07/25/01 MW: 8.0 ppg Vis: 104 sec Drill from 12,551' to 12,644' (losing 8 bph). Make connection and survey. Drill from 12,644' to 12,737' (losing 2 to 7 bph). Make connection and survey. Drill from 12,737' to 12,839' (losing 4 bph). Make connection and survey. Drill from 12,839' to 12,852'. Lost 155 bbls in last 24 hours. 0600, 07/25/01 -0600, 07/26/01 MW: 8.1 ppg Vis: 93 sec Reboot MWD and orient tool face. Drill from 12,859' to 12,923'. Circulate high VIS sweep - drop ball to open PBL sub - did not open. Short trip to 5" shoe. Circulate bottoms up ~ 11,651' Run in hole and ream from 12,832' (lost 20 bbls on short trip). Attempt to orient tool face - no signal from MWD. Drill from 12,923' to 13,017' (losing 3 bph). Make connection and survey. Drill from 13,018' to 13,106'. 0600, 07/26/01 -0600, 07/27/01 MW: 8.1 ppg Vis: 95 sec Drill from 13,106 to 13,185'. Ream and survey. Circulate sweep. Short wiper trip to 12,400' DPM. Calculate bottom up, .drop ball and open PBL sub and spot LCM pill. Pull out of hole to 5" shoe. Pump dry job and pull out of hole with 3 ½" drill pipe. Pull out of hole with 2 7/8" drill pipe. 0600, 07/27/01-0600, 07/28/01 MW: 8.2 ppg Vis: 105 sec Pull out of hole with 2 7/8" drill pipe. Handle bottom hole assembly, lay down motor, bit, LC, flex joint with MWD. Clean up floor and pull wear ring. Make up test tools, attempt test BOPs - change out seal on test plug, change out valve on test pump, fill riser, attempt test BOPs with AOGCC rep - VBR inserts leaking - AOGCC rep requested storm packer for ram change out. Wait on storm packer - SWACO/DSR ordered VBR from LA. Borrowed set from UNOCAL - hole taking ½ bph. Run in hole with 18 stands 3 ½" drill pipe and make up storm packer and set ~ 85'. Change out VBR inserts. Attempt test on VBRs on 2 7/8" drill pipe - no test - VBRs cut across face and bent the fingers. Wait on VBRs from SWACO/DSR- from Louisiana. 0600, 07/28/01 -0600, 07/29/01 MW: 8.2 ppg Vis: 105 sec Break down test tools. Decide to bring single gate out and go with stationary pipe rams- nipple down stack and rearrange with single gate and nipple up same install 2 7/8" and 3 ½" rams and carriers. Test BOPE 250/5000 psi (250/2500 annular). 0600, 07/29/01-0600, 07/30/01 MW: 8.1 ppg Vis: 97 sec Finish testing BOPs - good test. Run in hole with pull tool and release storm packer, pull out of hole with same and 18 stands 3 ½" drill pipe. Pick up, make up, and handle bottom hole assembly and test same. Run in hole with 2 7/8" drill pipe. Run in hole with 3 ½" drill pipe to 11,630' DPM. Slip and cut drill line - 100 feet. Calibrate MWD weight and depth. Circulate bottom up. Made pass LWD from 11,630' to 12,387'. 0600, 07/30/01 -0600, 07/31/01 MW: 8.2 ppg Vis: 89 sec Made pass LWD form 12,387' to 13,185' DPM - all smooth, except work thru coal ~ 12,962' to 12,978' DPM. Orient tool face and drill fxom 13,185' to 13,193' - LWD quit working. Drill from 13,193' to 13,248'. 0600, 07/31/01-0600, 08/01/01 MW: 8.2 ppg Vis: 95 sec Drill from 13,248' to 13,395' DPM. Circulate sweep. Short trip to 12,560' - smooth hole. Wash and ream from 13,303' to 13,395'. Drill from 13,395' to 13,485' DPM. 0600, 08/01/01-0600, 08/02/01 MW: 8.2 ppg Vis: 101 sec Drill from 13,485' to 13,635' DPM. Circulate bottoms up and sweep. 0600, 08/02/01 -0600, 08/03/01 MW: 8.3 ppg Vis: 110 sec Open PBL sub and spot LCM pill. Pull out of hole and check flow. Pump dry job and blow down top drive. Pull out of hole with 3 ½" drill pipe. Pull out of hole with 2 7/8" drill pipe. Handle bottom hole assembly - retrieve PBL ball, break bit, download MPR, clean out MWD probe and MPR, program MPR, orient mud motor and make up new bit and surface check MWD. Run in hole with 2 7/8" drill pipe and pick up 8 joints of same. Service rig, top drive and iron rough neck. Run in hole slow to 11,600'. Fill pipe. Run in hole slow to 13,110'. Made pass from 13,110' to 13,246' DPM. 0600, 08/03/01 -0600, 08/04/01 MW: 8.3 ppg Vis: 108 sec Made pass LWD from 13,246' to 13,635' DPM. Drill from 13,635' to 13,735'. Made pass from 13,700' to 13,735' DPM. Drill from 13,735' to 13,756'. 0600, 08/04/01 - 0600, 08/05/01 MW: 8.2 ppg Vis: 110 sec Drill from 13,756' to 13,791' DPM. Circulate sweep. Wiper trip, short trip to 13,550' DPM - smooth hole. Drill from 13,791' to 13,840'. Attempt to regain pulse for MWD-obtain weak pulse. Drill from 13,840' to 13,842' DPM. Attempt to regain pulse for MWD. Circulate sweep and talk to geologist. Geologist - close to TD. 0600, 08/05/01- 0600, 08/06/01 MW: 8.0 ppg Vis: 65 sec Finish circulation sweep, monitor well, confer w/geologist - well is TD. Well flowing, monitor same. Circulate 2nd sweep and monitor well till stable. Short wiper trip to 11,609' - smooth. Slip and cut drill line - 300 feet. Run in hole to 13,842' - slow. Circulate sweep and spot weighted new oil base mud in open hole. Monitor well till static. Pull out of hole to shoe. Open PBL and pump dry job. Pull out of hole with 2 7/8" drill pipe. Pull out of hole with 3 ½" drill pipe. Lay down jars, PBL, (2) MONELS and down load MWD/LWD. 0600, 08/06/01-0600, 08/07/01 MW: 8.2 ppg Vis: 126 sec Finish down load MWD/LWD. Pull wear ring and make up test assembly, set test plug, fill stack and test BOPE 250/5000 psi (250/2500 annular) - OK. Rig up to run 3 ½" slotted liner- pre-job safety meeting. Pick up slotted & blank liner and run in hole. Pick up liner hanger and liner top packer and rig down tong crew. Run in hole slow. Move 27 stands 2 7/8" drill pipe to left side of derrick. Run in hole slow and stop ~ 13,773' DPM. Work liner to 13,780' - 62' high. Drop ball and pump down same- ball never got there. Drop 2nd ball and pump down same ~ faster rate. 0600, 08/07/01 - 0600, 08/08/01 MW: 8.1 ppg Vis: 118 sec Attempt circulate 2nd ball to seat. Attempt set liner hanger - no go. Discuss options with Midland, Kenai, and Anchorage. Drop light weight 1" ball- seated - pressure up and set liner hanger and release from same - set top packer- bottom 3 ½" liner ~ 13,775', top of packer ~ 11,463'. Pump dry job and blow down stand pipe. Pull out of hole. Lay down bottom running tool and pick up 4 1/8" bit and 5" casing scraper. Run in hole with bit and scraper and tag 3 ½" liner at 11,463'. Circulate bottom up. Check for flow and pump dry job. Pull out of hole. Lay down bit and scraper and pick up and make up packer assembly. Run in hole with packer tail pipe assembly. 0600, 08/08/01- 0600, 08/09/01 MW: 8.1 ppg Vis: 115 sec Run in hole with packer tail pipe assembly on drill pipe. Cut and slip 100 feet of drilling line. Service top drive. Run in hole with packer tail pipe assembly slow. Locate, drop ball and pressure up to 1800 psi and set packer, pick up and release from same - top packer ~ 11,378' & EOT ~ 11,413'. Transfer oil based mud surface system volume to ISSO tanks, pump 77 bbl diesel spacer and Hi-Vis cleaning pill. Displace hole with FIW, pumping Hi-Vis cleaning pills, waiting on boat and continue to clean/displace hole. 0600, 08/09/01- 0600, 08/10/01 MW: Vis: Finish displacing well with FIW. Let well stand 30 minutes. Pump Hi-Vis cleaning pill and circulate FIW. Unload ISSO tanks from boat and fill with oil base mud from pits. Clean mud tanks& change boom line on west crane. 0600, 08/10/01 - 0600, 08/11/01 MW: 8.5 ppg Vis: Clean mud tanks. Pull out of hole with 3 ½" drill pipe to 2 7/8" drill pipe (2,260'). Run in hole with 2 7/8" drill pipe from derrick to 4,781'. Inject pits 6 and 7 - fill pit 8 with FIW. Circulate 2 7/8" drill pipe clean ~ 4,781' Lay down 2 7/8" drill pipe. Rig up to run tubing and hold pre-job safety meeting. Running 2 3/8" 4.7//LB0 EUE 8RD tubing (32 joints in hole). 0600, 08/11/01- 0600, 08/12/01 MW: 8.5 ppg Vis: Run 40-26 bonded seal assembly & 40-26 locator-(1)joint 2 3/8" 4.7//L80 EUE 8RD tubing - cross nipple with 1.875" profile - (1) joint 2 3/8" tubing - 2 3/8" pup - # 11 GLM - 2 3/8" pup - (17) joints 2 3/8" tubing - 2 3/8" pup - # 10 GLM - 2 3/8" pup - (20) joints 2 3/8" tubing- 2 3/8" pup - #9 GLM- 2 3/8" pup- (13) joints 2 3/8" tubing - 2 3/8" pup - #8 GLM - 2 3/8" pup - (14) joints 2 3/8" tubing - 2 3/8" x 2 7/8" crossover. Run 2 7/8" tubing - work thru tight spots ~ 9,969' and 10,616'- tubing stopped at 10,733'-tight spots appeared when GLM were going in top of 5" liner. Circulate and work tubing ~ 10,733' - unable to make any hole. Pull out of hole 9,678' and run in hole- went thru tight spot ~ 10,733'. Finish run in hole with 2 7/8" tubing (tight the rest of the way in hole) - pick up SSSV and control line - stab into packer with seals. Space out and spot 10 bbls ofNALCO FC 1348 A BIOCIDE, leaving 3 bbl inside tubing- land tubing hanger- set BPV - 2 7/8 tubing run as follows: (1) joint 2 7/8" 6.5# LB0 EUE 8RD tubing- 2 7/8" pup- #7 GLM- 2 7/8" pup- (17) joints 2 7/8" tubing - 2 7/8" pup- #6 GLM -2 7/8" pup- (19) joints 2 7/8" tubing- 2 7/8" pup - #5 GLM - 2 7/8" pup - (27) joints 2 7/8" tubing - 2 7/8" pup - #4 GLM - 2 7/8" pup - (39) joints 2 7/8" tubing - 2 7/8" pup - #3 GLM - 2 7/8" pup - (50) joints 2 7/8" tubing - 2 7/8" pup - #2 GLM - 2 7/8" pup - (64) joints 2 7/8" tubing - 2 7/8" pup - #1 GLM - 2 7/8" pup - (53) joints 2 7/8" tubing - 2 7/8" pup - TE-5 Safety valve - 2 7/8" pup - (8) joints 2 7/8" tubing - 4', 2', 6', 1 O',pup joints - tubing hanger. Nipple down BOPs. 0600, 08/12/01 -0600, 08/13/01 MW: 8.5 ppg Vis: Nipple down BOPs and pull riser. Land tree - nipple up and test tree to 5k - pull 2-way check. Rig up to pump down tubing - test tubing 1000 psi for 30 minutes (Good) - shear plug ~ 4500 psi. Clear tools from rig floor- blow down lines, clean trip tank and possum belly, clean wellhead room and cellar. Release rig from A23-01LW ~ 1800 hours 8/12/01 - For rig move to A34-14LW. Re: XTOE Well A23-01LW Decompletion Subject: Date: From: To: CC: Re: XTOE Well A23-01LW Decompletion Fri, 18 May 2001 13:54:24 -0700 Tom Maunder <tom_maunder@admin.state.ak.us> Bill Penrose <bill@fairweather.com> "Bobby Smith (E-mail)" <bobby_smith@crosstimbers.com>, "Doug Schultze (E-mail)" <Doug_Schultze@crosstimbers.com>, "Doug Marshall (E-mail)" <marshall@sarcomgs.com>, "XTOC Drlg Platforms (E-mail)" <drilling@sarcomgs.com> Bill, Not a problem with the call. I well know that it usually needs to be nearly dark for anything important to happen, especially if it concerns cement. Very interesting regarding the problems with pumping through the retainer(s). This reply confirms our discussion and my approval for you to cap the retainer with cement due to the difficulties pumping into it. Good luck with the remainder of the project. Tom Maunder, PE Petroleum Engineer AOGCC Bill Penrose wrote: Before I start, please note that Cross Timbers Oil Company has changed their name to XTO Energy and i'11 be referring to them as XTOE or just XTO in the future. Per your request, this is to summarize the modified perforation abandonment procedure for Well A23-OILW and the reasons for it. The original intent was to use the tubing in the well to inject cement below the permanent production packer to abandon the perfs. The tubing could then be pulled and the well sidetracked. Unfortunately, the tubing had holes in it at '-3400' and could not be used for cementing. The well was killed, the tubing pulled and an EZ-Drill retainer run on drill pipe to the production packer and set, the intent being to inject cement through it and the production packer to cover the perfs. For some reason, we could not establish injection at 5,000 psi after the EZ-Drill was set. We pulled out of the hole with the DP, ran back in with a mill and milled up the EZ-DrilI. The well would then take injection at 2000 psi, 2 bpm. We came out of the hole with the mill and went back in with another EZ. Dril/. When we got it to bottom, we attempted to verify injectivity before setting it. The well would not take fluid at 3, 000 psi (but this did give us a good casing test). We set the EZ-Drill just above the production packer and brought the pressure up to 5,000 psi, but the well wouldn't take fluid. / then called you with our request to set a minimum 100' cement plug in the 7" casing with the bottom being at the EZ-Drill setting depth of 9, 679'. The AOGCC regs allow for such a 100' plug above the perforated interval, but this was not how we originally proposed to abandon the peals and the the bottom of the cement plug is more than the requisite 50' above the perforations, For these two reasons, I called for approval of the new plan which you verbally issued last night. I of 2 5/18/01 1:54 PM Re: XTOE Well A23-01LW Decompletion > > The cement plug has been set and we are out of the hole and WOC. Later > today we will RIH to ensure the TOC is no deeper than 9, 579' and that the > cement is competent with a 15, 000# weight test before proceeding to > sidetrack the well. > Thanks for your willingness to work with us on this. If you need additional > information, please let me know. > Bi// Tom Maunder <tom maunder@admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 5t18/01 1:54 PM ALASKA OIL AND GAS CONSERVATION CO~SSION I~VISED Bobby L. Smith Drilling/Operations Manager Cross Timbers Operating Company 3000 North Garfield, Suite 175 Midland Texas 79705 Re: Middle Ground Shoal A23-01LW Cross Timbers Operating Company Permit No' 201-073 Sur Loc: 1569' FSL, 381' FEL, Sec. 11, T8N, R13W, SM Btmhole Loc. 690' FNL, 879' FWL, Sec. 1, T8N, R13W, SM TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dear Mr. Smith: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a new wellbore segment of existing well A23-01R, Permit No. 187-093, API No. 733-20238-01. Production should continue to be reported as a function of the original API number stated above. 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, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this ~/5't~°~ day of May, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA OIL AND GAS CONSERVATION COPlM~SSION Bobby L. Smith Drilling/Operations Manager .Cross Timbers Operating Company 3000 North Garfield, Suite 175 Midland Texas 79705 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Middle Ground Shoal A23-01LW Cross Timbers Operating Company Permit No: 201-073 Sur Loc: 1569' FSL, 381' FEL, SeC. 11, T8N, R13W, SM Btrnhole Loc. 690' FNL, 879' FWL, Sec. 1, T8N, R13W, SM Dear Mr. Smith: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this ~ -~ day of May, 2001 jjc/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. RE: XTO A23-01 RD and sidetrack . Subject: RE: XTO A23-01RD and sidetrack Date: Wed, 25 Apr 2001 09:10:58 -0800 From: "Bill Penrose" <bill@fairweather. com> To: "Tom Maunder $E-mail$" <tom_maunder@admin.state.ak. us> Tom, Below each of your questions is my response: 1--Is the 7" string a long string or a liner?. All the measurements indicate a long string, but on the drawing included with with the 403 and 401, the comment liner is there. The 7" in the drawing is a long string. A: The 7" is a long string. The person who drew up the schematic used an inappropriate term (thought liner and casing are interchangeable terms). 2-It would be helpful to have drawings of the wellbore when the abandonment is accomplished and the ultimate sidetrack. A: The schematics for these wells are generated by the XTOC Production Engineer in OKC after the fact using daily drlg/workover reports. They use Visio which I'm unfamiliar with. I have several times considered obtaining a copy of Visio and training myself on it, but the anticipated results never seemed worth the time and effort. If these schematics are important to you then I can see if the OKC Engineer can gin these up based on proposals I give him. 3--For your decompletion procedure in the 403... .3a--What are the present BHP and SITP? v'~ A: BHP = 4779, SITP = 1200 psi 3b--Isn't it appropriate to kill the well before setting the BPV? A: Yes, I'll modify the program to have the well bullheaded with kill weight ,/~ fluid before setting the BPV to ND/NU. 3c--As I read it, if you load the tubing with mud you will be overbalanced the annulus. If you unsting, the tubing is going to want to U-tube and you will have to have to use the annular and choke to bring the fluid around. Please comment on this portion of the procedure. A: The only way to load the annulus with kill weight fluid is to unsting from the packer and circulate. We can't unsting from the packer without nippling up BOPs. The tubing has to be killed before setting the BPV for nippling down the tree and nipPling up the stack. Therefore, the tubing will have to be full of kill weight fluid when it is unstung from the packer and the annular (or, as a backup, the pipe rams) and choke will be needed to circulate kill weight fluid into the annulus. 3d--I like the method you are using to abandon the existing intervals. Is it possible to perfom the abandonment first? You might be able to accomplish a cement kill prior to ND/NU. This might take some wireline runs to assure the 1 of 3 5/3/01 10:04 AM RE: XTO A23-01RD and sidetrack tubing is clear and there may be other constraints that would prevent this, but it might be worth looking into. You could use some sort of a wiper plug dropped into the tubing. A: Yes, I thought about this, but I want to be able to unsting from the packer immediately after pumping cement in order to circulate out any excess. The only way to ensure the tubing doesn't end up plugged with cement is to overdisplace. However, the top perfs are close enough to the packer that the top of the cement plug needs to be very close to or right at the packer. 4-On the sidetrack in the 401... 4a--You make mention of the leak off at the window for your maximum surface pressure calculation, but you do not have a LOT or FIT planned once you are out of the window. Since you expect higher pressures in the upper part of the Hemlock, it is appropriate to include a LOT or FIT at the window. A: The LOTs we've been running on the wells to date give us confidence that we know the frac gradient quite well at Middle Ground Shoal. However, it's no problem running an FIT after milling out the window and I'll write one into the plan. 4b--You mention of the proximate wells. Is there any expectation of magnetic interfearance? It is appropriate to include some comment about your mitigation plans for any interfearance. A: Based on previous wells where the proximity was even closer, there was no magnetic interference using the same tools we're using now. We plan the well paths in these wells to remain outside the radius of possible magnetic interference from other wellbores. 4c--In your hazards note you specifically note that H2S is not a concern. Is that due to this being an injector? I thought that H2S was a risk drilling the Hemlock. Do other wells produce H2S? Is it in lift gas? Do you have contingency equipment regardless of the risk from the specific .well? A: The producers on Platform A have no H2S in their production stream. The only time H2S is seen is when an injection well is acidized and backflowed (the acid on the iron sulfite scale produces H2S). Nevertheless, we will, as always, maintain H2S scavenger among our on-site mud products and ensure the rig sensors are in working order. 4d--There is a 125' discrepancy between the KOP listed on the Baker Hughes sheet and the KOP entered on the 401. Which is correct? A: It appears you're referring to the KOP of 9675' on the BHI listing and the top of the 5" liner at 9500' on.the 401. The discrepancey between these depths is the liner lap. The KOP will be as close, to as possible to the packer at 9701' - estimated to be approximately 9675'. 4e--The letter notes the intended spud date is May 15, but on the 401 it is noted as June 10. I presume May 15 is correct 2 of 3 5/3/01 10:04 AM RE: XTO A23-01 RD and sidetrack A: May 15 is correct. I don't know where that June 10 came from. 5-You have included the request for exception to the BOP ram requirements as has been granted previously. Looking at your stack diagram I note the blinds are on top. Neither RP 53 nor our regulation proscribe ram positions, but if you have blinds over pipe you cannot use your blinds for protection if you were to encounter a problem with your pipes. I'd like to discuss you philosophy regarding this. I don't know if one order is more correct than the other. A: Me and the guys on the rig have been round and round about this. The ram placements in the stack can be argued either way for drilling vs workover operations, assuming a kick on bottom or off bottom, or how the drilling supervisor intends to use them. It seems that there's a counter-argument for every point made, so I've just left it up to the guys. They think that it's better with the blinds on top of the VBRs. Hope this helps. Give a call or drop a note with any additional questions. Bill 3 of 3 5/3/01 10:04 AM 04/20/01 FR! 08:02 FAX 817 885 2698 CROSS TIMBERS 0IL o01 -078 CROSS TIMBERS OIL COMPANY 810 Houston Street, Suite 2000 Fort Worth, Texas 76102 Phone: (817) 870-2800 Fax: (817) 885-2698 FACSIMILE COVER SHEET To: &~ Cn~, II Comp~ny: ~ogcL FAX #; noT- Z?g-- ?5'y~ From: Subject: Number of pages sent including cover sheet: 7 .__ Urgent Confidential CONFIDENTIALITY NOTE: Thc do;uments accompanying this telsf~x transmission contain information t~longin§ to Cross Timbers Oil Company that is confidential and/or legally privileged. The information is intended only for the use of the individual or entity nttmed above. If you ate not the intended recipient, you arc hereby notified that any examination, disclosure, copying, distribution orthe taking of any action in reliance on, or with respect to, the contents of this telecopied information is strictly prohibited, If you have received this telefax in error, please immediately notify the person identilied as the sending person by a collect person-to-person telephone call at thc number set forth above to arrange for tatum of file original documents to tis at our expense. **Please call Diana/13ng-Ge~ 18t~ Floor (817) 885-2548 if all pages are not receiv~d.~* i / '.~'~;-~-i.'- ............... i:T.:~!~,'?-"-!!.? " ' . " ·: .~". ',, ':",' , . UNri'|~.~!.LO~_~.Ev.,.-._.?:.:~ . . ' I . .. I -.... . .. . , .. .., .'...'....- .,.,......'....'....:., ~.: I ! a~UN~'.:.~?.-:*~?.>.-.~:.':.'-'.".:~ ......'.. ~. ' '... ! .'" ' ' ' . · '," ..', . '.',,. :,',,'.":.:,- ' :~'~-"~:~"~'~"~'~-"~'"~":' ' ' ' .. ', "' ":.'; ,, '." ',' ": ~ :';,' :'i.',,"' ' I,. 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BOUNDARY 120 t I /-IZ NO T .,'PENETRATED ~ 29D," lO0 LOT Cross Timbers Operating Company April 18, 2001 Ms. Julie Heusser, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: A23-01LW Sidetrack APR 1 9 2001 Alaska Oil & Gas Cons. Comm, issio, n Anchorage Dear Commissioner Heusser, Cross Timbers Operating Company hereby applies for a Permit to Drill an offshore development well from Platform A in the Middle Ground Shoal Field of Cook Inlet. The well is planned as a sidetrack of the existing A23-01 wellbore in order to penetrate and develop an un-drained portion of the Hemlock conglomerate in the vicinity of Platform A. Approval of an abandonment plan for the existing wellbore has been requested via a Sundry Notice submitted under separate cover. The anticipated spud date of A23-01LW is approximately Mayl5. This well will be sidetracked in the 7" casing and a 5" intermediate liner set from the kick-off point to the bottom of the East Flank of the Hemlock Fm. After penetrating the West Flank of the Hemlock Fm., a 3-1/2" slotted production liner will be set in place and the well completed as an oil producer with 2-3/8" tubing and gas lift design. Cross Timbers requests continuation of the variance from the BOPE requirements of 20AAC25.035(e) as requested in our letter of January 30, 2001 (copy attached). The rationale is the same as was set out in that letter. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 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 and cementing program is attached as per 20 AAC 25.030. 3000 North Garfield, Suite 175, Midland, Texas 79705 (915) 682-8873 Fax (915) 687-0862 Ms. Julie Heusser Page 2 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. 9) Cross Timbers 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 well is considered to be a development well, basic mud logging will 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) A copy of the January 30, 2001 BOPE variance request is attached. 13) The following are Cross Timbers' designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Bill Penrose, Senior Drilling 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, CROSS TIMBERS OPERATING COMPANY B2ob~bv L. Smith Drilling/Operations Manager enclosures CC: Bill Penrose Doug Marshall Mike Langeler Charles Pope CROSSTIMBERs OPERATING COMPANY 1 650 ]~] MIDLAND OFFICE [~1 ~-~ c^~. ~.~, / / I~ 3000 N. GARFIELD, STE. 175 ' · / /////'~/ , 32-1/1110 TX Iii MID~ND,~ 79705 DATE ~//~/ ~ 0 I~l NafiOnsBank . ~ ~ ~[.. ,,.oo ~ so,,. ,: ~ ~ ~oooo ~ ~,: ~ ~ s o~ ~ ~ ~ ~,,. ' [~ . ~KA 0IL AND GAS CONSERVA~ION C0P~ISSION Bobby L. Smith Drilling/Operations Manager Cross Timbers Operating Company 3000 North Garfield, Suite 175 Midland Texas 79705 Re: Blowout Equipment Variance Request Middle Ground Shoal A23-01LW TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 AN .CHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dear Mr. Smith: We are in receipt of your request for variance to the requirements of 20 AAC 25.035(e)(1)(b). The requirement of that section concerns the number of rams required for a blowout preventer stack when the pressure requirement is 5000 psi or greater. Cross Timbers is seeking this relief due to there being insufficient space available under the rig to install the stack required in the regulations. In addition, information has been supplied that indicates that the BOP equipment used by Shell Oil, the pervious operator, was similar to that being' proposed in the variance request. In the variance request letter, it is indicated that a set of variable bore pipe rams will be employed in the stack. These rams are capable of sealing on the various drill pipe and casing sizes planned for the A23-01LW well. Your request for a variance to the requirements of 20 AAC 25.035(e)(1)(b) is granted for the work planned on well A23-01LW (201-073). For future work planned on Platforms A and C, a specific application for variance will need to be made in the sundry work application (403) or permit to drill application (Form 401). Your request for variance must include a discussion of the planned ram sizes, variable or fixed, to be employed with the various drill pipe and casing sizes planned. JMH:jjc Sincerely, Julie M. Heusser Commissioner cc: W. J. Penrose, Fairweather, Inc. ~KA OIL AND GAS CONSERVATION CO~IPHSSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: ADMINISTRATIVE APPROVAL NO. 44.66 The Application of Cross Timbers Oil Company for the Drilling of the MGS A23-01LW Well in the Middle GroUnd Shoal Field Bobby L. Smith 3000 North Garfield, Suite 175 Midland Texas 79705 Dear Mr. Smith: An application, dated April 18, 2001, requested approval to drill the A23-01LW which would be the fourth'producer in the Northwest ¼, Section 1, T8N'R13W, SM. It is the understanding of the Alaska Oil and Gas Conservation Commission that the drilling and completion of the well will increase recovery of reserves from this structurally complex portion of the Middle Ground Shoal Field. The Alaska Oil and Gas Conservation Commission hereby authorizes drilling and completion of the MGS A23-01LW pursuant to Rule 6(d) of Conservation Order No. 44. DONE at Anchorage, Alaska afeared Apr!l 23, 2~00~1. Daniel T, Seamount, Jr. Chair Commissioner Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION t, :%;~'~'~':" STATE OF ALASKA ALASKA O1[( N D GAS CONSERVATION COMMI~r"-'ION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [ ] Drill [ X] RedrilI lb. Type of well [ ] Service [ ] Development Gas [ X] Single Zone [ ] Multiple Zone [ ] Re-Entry [ ] DeepenI [ ] Exploratory [ ] Stratigraphic Test [ X] Development Oil 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool CROSS TIMBERS OPERATING COMPANY 116' DF 3. Address 6. Property Designation MGS 3000 NORTH GARFIELD, SUITE 175, MIDLAND, TEXAS 79705 ADL 18754 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1569' FSL, 381' FEL, Sec. 11, T8N, R13W, SM Middle Ground Shoal Blanket At top of productive interval 8. Well Number Number 2,380' FSL, 1,096' FWL, Sec 1, T8N, R13W, SM A23-01LW 1363004 At total depth 9. Approximate spu~L,date Amount 690' FNL, 879' FWL, Sec 1, T8N, R13W, SM e'/+elS~ldl(::~ [ $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 700' NorthI At 13,952': 174' from A12-01 3,746 13,960' MD, 9,340' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth ~;'8~MD__~.. Maximum Hole Angle 68 deg Maximum surface 3,856 psig , At total depth (TVD) 8,382 psig 18. Casing Program ~-t~",f~=J¢"~ Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 5" 17.95# L-80 STL 2,068' 9,500' 7,734' 11,568' 8,382' 209 cu. ft. Class G 4-1/8" 3-1/2" 9.2# L-80 STL 2,492' 11,468' 8,340' 13,960' 9,340' Slotted liner - no cement 19. TO be completed for iedrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11,550 feet Plugs (measured) None true vertical 8,821 feet Effective depth: measured 11,440 feet Junk (measured) None Alaska Oil & Gas Cons. Commission true vertical 8,739 feet Anchorage Casing Length Size Cemented M D TVD Structural Conductor Surface 2,393' 13-3/8" 1,940 sx 2,393' 2,215' Intermediate 8,080' 9-5/8" 1,200 sx 8,080' 6,123' Production 11,538' 7" 980 sx 11,538' 8,812' Liner Perforation depth: measured 9,878' - 11,270' (10 intervals) true vertical 7,556' - 8,614' (10 intervals) 20. Attachments [ X] Filing Fee [ ] Property Plat [ ] BOP Sketch [ ] Diverter Sketch [ X] Drilling Program [ X] Drilling Fluid Program [ ] Time vs Depth Pict [ ] Refraction Analysis [ ] Seabed Report [ ] 20AAC25.050 Req. Contact Engineer Name/Number: Bill Penrose (907)258-3446 Prepared By Name/Number: Bill Penrose (907)258-3446 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed/~4~/4¢ Z ~ Title Bobby L. Smith, Drilling / Operations Manager Date ~/1~/~I ! ..... Commission Use Only Permit Number APl Number I A.,~:~,~/..v.~l~a,~e See cover letter ~_<:D/-" O,~.~ ,.5'o-,,~'~,..~.-- .~ C_..22.. :~-~ ~OI _/-L-")/C/'.~/ J for other requirements Conditions of Approval: Samples Required: [ ] Yes ,~ No -/ MOd log Required [ ] Yes ~.~No Hydrogen Sulfide Measures: [ ] Yes tr~No Directional Survey Req'd ,,~ Yes [ ] No Required Working Pressure for BOPE: [ ]2M, [ ]3M, ',~5M, [ ] 10M, [ ] 15M Other: ORIGINAL SIGNED BY by order of Approved By . r., E~ ~,.~.~ Commissioner the commission Date . :3/7/0' I Form 10-401 Rev. 12-01-85 Subrrfl 'riplicate Cross Timbers Operating Company MGS A23-01LW Sidetrack Procedure With the rig over A23-01 and BOPE installed and tested at~er plugging the A23-01RD wellbore: RIH with 7" one-trip whipstock. Orient and set whipstock at 9;Og0'MD and mill a window in 7" casing using a 6" mill. C.~<~K.~ L.c3'V c~- \~' ~,,'5~5~.~.~'t',.c,,o ~t Directionally drill 6" hole from 9,690' to 11,568' MD. Run and cement 5", 17.95//, L-80 STL liner at 11,568' MD with TOL at approximately 9,400' MD (-300' of lap). Clean out liner to float collar and pressure-test casing/liner lap to 3,000 psi for 30 minutes. Drill out liner shoe and displace well to 8.5 ppg oil-base drilling mud. Drill approximately 20' of new hole and conduct leak-off test. Directionally drill 4-1/8" hole from 11,568' to 13,960' MD. Run 3-1/2", 9.2//, L-80, STL slotted liner with liner-top packer at 13,960' MD with TOL at approximately 11,468' (-100' of lap). Displace well to filtered Inlet water. Run 2-3/8", 4.7//, N-80, 8rd EUE completion with gas lift design. Pickle inside of tubing with HCl/xylene and circulate inhibited filtered Inlet water into annulus before setting packer. N/D BOPE, N/U tree. Test tree to 5,000 psi. Release rig. ,CroSS :l'imbers C~ ~.rating Company .. Present Completion MGS A23-01RD WIW Cook Inlet, Alaska Leg 4, Conductor 32 APl No.: Spud: Surf Csg: 13 3/8", 61 lb, J55. Set @ 2393'. Cmt'd w/i940 sx. Prod Csg: 9 5/8", 47 lb, N80. Set @ 8080'. Cmt'd w/1200 sx. Liner Csg: 7", 26 lb, N80. Set @ 0-9989'. 7", 32 lb., Pl10. Set @ 9989'-11538'. Cmt w/980 sx. PBTD: 11440' (WL) (Flagjoints 9904', 10315', 10621 ID: 11550' . KB: Water Depth: Tubing: 3 1/2", 9.3, N80 8rd AB-Mod EUE @'9748'. 10000~ DB WT On Locat0r 90000~ UP WT 62000~ DN WT 3 1/2" Otis "X" Nipple @ 304' . ': 3 1/2" Otis "X" Nipple @ 9667' MD (7381' 'I'VD) .:. Baker Seal Assembly w/11.85' of Seals @ 9700' MD (7408'TVD) . ..=... ,.:..?... Baker FB-1 Permanent Packer'@ 9701' MD (7409' TVD) Baker 9.34' Sealbore Ext. @ 9704' MD (74'11' .TVD) Otis "XN" Nipple @ 9746' MD (744.3' TVD) ,'" :'. . Baker Wireline Re-entry Guide @ 9748' MD {7444T TVD) . " , ; ~ , .,~'; ' GN-GO: 9878'-9899" ' GR-GS:10235'-10251' ' GR-GS: 10261'-10290' ' ' HC-HD: . 10531'-10572' HC-HD: 10593'-10636' HE-HF: ~10651'-10682' HI-HK: Not Perforated HK-HN: 10783'-10914' . H N-H R: 10929'-11072' HR-HZ: ..11096'~111 !9' HR-HZ: 11121'-11270' All Perfs from 987S'-11119' W/Atlas 2 1/8" ~il~' jet 4 SPF~;::'tPerfs from .111.2!'.-11270' WI2 5/8".'~72 1/8" HC/ BG 4 SPF. Perfs from 11240'-11260' were'r~p~n~ed on 6/21/88. · ' .' Cross Timbers Operating Company Drilling Fluid Program, Pressure Calculations, and Drilling Area Risks MGS A23-01LW Sidetrack Drilling Fluid Properties: Tyonek Fm. And East Flank of Hemlock Fm. (9,700' - 11,568'MD) Density 8.8 -11.8 PV 18 - 30 YP 15 - 20 Funnel Vis 55 - 80 Initial Gel 12 -18 10 Minute Gel 18 - 25 APl Filtrate <10 pH 9- 10 % Solids <5 West Flank of Hemlock Fm. 11,568' - 13,960'MD) 8.8 - 9.4 20 - 25 18 - 22 75 - 115 8 - 20 15 - 30 5-Apr Oil Base <5 Drilling Fluid System: ITwo Derrick Shale Shakers Desander' Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio AlarmS) Trip Tank ' Fluid Flow Sensor Fluid Agitators ' Maximum Anticipated, Surface Pressure: The maximum amicipated surface pressure (MASP) for both hole sections in this sidetrack will be the lesser of the formation pore pressure (less a full gas colu ~mn to the surface) or the formation fracture 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 6" hole section is 4,780 psi at the section TD of 8,382' TVD (or 0.570 psi/fi) and the formation fracture pressure at the sidetrack depth of 7,493' TVD is a minimum of 14.4 ppg EMW (0.749 psi/f0. Complete evacuation of the wellbore, except for a 0.11 psi/f~ gas gradient, is assumed. 6" hole section MASP (pore pressure) MASP (fm breakdown) (8,382 ff)(0.570- 0.11)= 3,856 psi (7,493 ff)(0.749- 0.11) =4,788 psi Therefore, MASP in the 6" hole section is 3,856 psi and the BOPE will be routinely tested at their full rated working pressure of 5,000 psi. Again, based on offset well data, the highest formation pressure expected in the 4-1/8" hole section is 3,663 psi at the section TD of 9,340' TVD (or 0.392 psi/ti) in the target Hemlock Formation. The formation fracture pressure at the 5" liner shoe depth of 8,382' TVD is 14.6 ppg EMW (0.759 psi/ii). Complete evacuation of the wellbore, except for a 0.11 psi/fi gas gradient, is assumed. 4-1/8" hole section MASP (pore pressure) = (9,340 fi)(0.392- 0.11) = 2,634 psi MASP (fm breakdown) = (8,382 Ii)(0.759 - 0.11) = 5,440 psi rx~¥ oc\x' xcc,.~c~ ~c~: Therefore, MASP in the 4-1/8" hole section is 2,634 psi and the BOPE will be routinely tested at their full rated working pressure of 5,000 psi. Well Proximit3' Risk: The nearest wellbores to that of A23-01LW are Al3-01 and Al2-01. This well will pass 199' from Well Al3-01 at a depth of 11,713'MD and will pass 174' from Well Al2-01 at a depth of 13,952' MD. Drilling, ~rea Risks: The primary drilling risks in the A23-01LW area are those of stuck pipe in the coals of the Tyonek Formation, waterflo0d-induced over.pressure in the East Flank of the Hemlock Fm. and lost circulation in the Crestal Fault zone between the East and West Flanks of the Hemlock Fm. The risk of stuck pipe in the Tyonek 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 BHA from entering them until the coals can be reamed open. 3.) Casing will be set below the base of the East Flank of the Hemlock Fm., thus isolating the coals before lowering the mud weight and drilling the target Hemlock West Flank. In order to safely drill the over-pressured Hemlock East Flank, the mud weight will be gradually increased near the bottom of the Tyonek Fm. and the mud weight needed to drill the East Flank will be carefully monitored and maintained to avoid approaching the formation fracture gradient at the kickoffpoint. Lost circulation in the Crestal Fault zone will be treated with conventional LCM. While experience has shown that this will be effective, the option will also be maintained of nmning casing at this point, if necessary, in order to allow the lowering of the mud weight to aid in solving a severe lost circulation problem. Disposal of Muds and Cuttings: MGS Platform A 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. A23-01LW Casing Properties and Design Casing Performance Properties Internal Collapse Tensile Strength Size Weight Yield Resistance Joint Body TVD MD Design Safety Factor* (in.) (lb/fi) Grade Cnxn (psi) (psi.) (1,000 tbs) (Ir RKB) (fi RKB) T B C 5 17.95 L-80 STL 10,140 10,490 396 422 8,382 11,568 13.0 2.6 2.1 3-1/2 9.2 L-80 STL Slotted Slotted 207 207 9,340 13,960 11.1 N/A N/A * Tensile design safety factors are calculated using pipe weight less buoyancy. Burst design safety factor for 5" casing is calculated using ASP. Safety factor for 3-1/2" lnr does not apply since lnr is slotted. Collapse design safety factor for 5" casing is calculated assuming complete evacuation of the casing. Safety factor for 3-1/2" lnr does not apply since lnr is slotted. Casing Setting Depth Rationale 99 11,568' RKB, MD 3-1/2" 13,960' RKB, MD Drilling liner to provide sufficient t~acture gradient and well control until TD is reached as well as casing offthe portion of the hole containing troublesome coal beds. Production liner to provide hole stability for production operations. A23-01LW Summary of Drillin Hazards POST THIS NOTICE IN THE DOGHOUSE Elevated formation pressure is present in the East Flank of the Hemlock reservoir. Expected formation pressure in the Tyonek above the Hemlock is 9.0 ppg EMW while mud weight of approximately 11.6 ppg can be expected in the East Flank. There is a potential for lost circulation as the wellbore crosses the Crestal Fault between the East Flank and West Flank of the Hemlock reservoir. Pipe sticking tendency is possibl'e in the coals above the Hemlock reservoir. This wellbore is planned to pass within 199' of Well A13-01 at 11,713'MD and within 174' of Well A12-01 at 13,952'MD. There is no H2S risk anticipated for this well. CONSULT THE A23-01LW WELL PLAN FOR ADDITIONAL INFORMATION Cross Timbers January 3 O, 2001 Ms. Julie Heusser, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7a~ Ave., Suite 100 Anchorage, Alaska 99501 RE: Request for Variance BOP Arrangement Dear Commissioner Heusser, Cross Timbers Operating Company requests a variance from 20AAC25.035(e): Blowout Prevention Equipment and Diverter Requirements for its workover and drilling operations on Platforms A and C in Cook Inlet. This variance is being requested per 20AAC25.035(h). Request Cross Timbers requests authorization to utilize a BOP stack that consists of an annular preventer, one blind ram and one variable bore ram in lieu of the annular preventer and three rams required in the AOGCC's regulations. The approved BOP arrangement currently on file with the Commission is for a 5,000 psi WP annular preventer, one'set of 5,000 psi WP blind rams and 2 each sets of 5,000 psi WP pipe rams. The requested stack arrangement would contain a 5,000 psi WP annular preventer, one set of 5,000 psi WP blind rams and one set of 5,000 psi WP variable-bore rams. The proposed BOP components and arrangement provide an equally effective means of well control as the currently permitted arrangement. Rationale This variance is being requested because the lack of vertical space in the rigs' subbases on these small platforms do not permit the installation of a 3-ram stack. Only a two-ram stack is short enough to fit. Background Cross Timbers began planning to work over wells on Platform C and re-drill others on Platform A shortly after the platforms' purchase from Shell Oil Company in October 1998. Rig work was permitted and commenced in the summer of 2000. The BOP stack arrangement that was submitted to the Commission and approved prior to the start of work was a standard 3-ram stack. Upon attempting to install the stack under the rig on Platform C, it was found to be too tall to fit. The Commission was contacted and it was verbally agreed that a 2-ram stack could be used as long as one ram was a blind ram and the other was a pipe ram that always had rams fitted to the pipe being run into and out of 21 0 Park Avenue, Suite 2350, Oklahoma City, Oklahoma 73102-5605 (405) 232-4011 Fax (405) 232-5538 Ms. Julie Heusser 1/31/01 Page 2 the hole. This worked well as no tapered strings were used during the workovers on Platform C. When the workovers were finished, operations and equipment, including the BOP stack, were moved to Platform A to commence the drilling program there. The same BOP arrangement was used since the same headspace constraints apply as on Platform C and there were initially no tapered strings used. However, on the current well a tapered drilling string is necessary and Commission representatives pointed out that the stack no longer meets requirements. We made inquiries as to how Shell operated when they last drilled on this platform in the mid-90's and found that they used a single set of variable- bore rams in lieu of 2 single pipe rams. Cross Timbers has now installed variable-bore rams with the verbal concurrence of the Commission, but a formal review and approval of this BOP arrangement by the Commission is necessary. Also, we would like to have the new stack arrangement diagram placed on file with the Commission, to replace the one currently on file. Please find enclosed a new BOP diagram, which, if approved, should replace the diagram currently on file with the Commission. If you have any questions or require additional information, please contact me at (405) 319-3213 or Bill Penrose at (907) 258-3446. Sincerely, CROSS TIMBERS OPERATING COMP~ Susan I. Sudduth Sr. Engineering Technician Mid-Continent Division enclosure CC: Bill Penrose Doug Marshall Doug Schultze 'ROSS TIMBERS OIL COMI' qY BOP COMPONENTS MIDDLE GROUND SHOAL FIELD PLATFORMS "A" AND "C" ' , KILL LINE "~[~ 2., 5000 PSI WP MANUAL GATE VALVE 'DSA: 13-5/8",, 5000 PSI WP iX 11", 5000 PSI WP 1 ....... 13-5/8", 5000 PSI WP HYDRIL GK ANNULAR PREVENTER W/ COMPANION FLANGE TO BELL NIP ., I DOUBLE 13-5/8", 5000 PSI ~I ~ SCHAFFER SL BOP W/ -' BLIND RAMS ON TOP AND ,~.....~--2-7/8" X 5" VARIABLE BOR1 RAMS ON BOTTOM L~ . . ~ i CHOKE LINE . 3:', 5000 PSI WP MANUAL GATE VALVE 5000 PSI WP RISER 13-5/8", 5000 PSI WP DRILLING SPOOL W/ TWO 3", 5000 PSI WP OUTLETS I Created by jonesFor: B Penrose{ i Dote plotted: 1J-Apr-2001 Plot Reference {s A23-O1LW Vers}oo i Coordinates ore in feet reference slot ~4-32. True Vertico De tbs ore reference rotary table. I.NTKQ Cross Timbers Operating Company Sfrucfure : A PLATFORIv{ Well : A23-O1LW Field : Middle Ground Shoals Location : Cook Inlef, Alaska PROFILE Point COMMENT KOP - Sidetrack Pt 9675.00 MD Inc Dir TVD EOC #1 10354.31 DATA Begin 2nd Curve 11076.18 North East Final EOC 11307.39 56.88 559.1 5 7593.95 5176.12 2485.52 Tgt - B/HR - CsgPt 11407.57 59.19 302.46 7851.48 5546.11 2227.50 59.19 302.46 8231.46 5888.06 1689.86 65.15 319.50 8339.97 6022.00 1536.93 65.15 319.50 8381.99 6090.99 1478.01 V. Sect Deg/lO0 1710.09 0.00 2149.45 7.00 2775.95 0.00 2979.14 7.00 3069.28 0.00 Tgt-T//HC-TD 1 3951.44 75.63 26.74 9531.99 8500.97 1259.98 4754.91 2.50 CFoss Tin~beFs Operat~n~ Cempan}~ S'Iruci'ure : A PLATFORM Well ; A23-01LW Field : Middle Ground Shoals Locelion : Cook Inlet, Alaskei 5? 08 KOP - Sde~raci< Pt 4105 D~5:700 de9 per SO0 {t , ,%% 4 4 54 ~,~.4827 '~ 5748 EOC #i Dote p¢otted : 13 Apr-2001 Plot Reference is A23 0itW Version //4 Coordinates ore i~ feet reference slot //4 52 irue Vertical .)epths ore reference rotary table 'v"ert'ico %ecfs~r (fa, ct', ~ ~, - z~.:'ir',uih 312.96 with reference 0.00 H, 0.00 E 1~orn s',o~ z4..32 ,, CFoss Tim'beFs OpeFa~ina Company Dot .......... Ar0r ,,: Structure : A PLATFORM WeN : A23-01 LW :cor~,r,o~ .......................... *a ss Field Miaale 3round Shoals Location : Cook Inle]. Alaska V£-rhca D~*nthS ar, reference, rotor ~dO,e 2,¸ Cross Tin~bers Operating Company Omte p,otted 13-Apr-200, Sfrucfure : A PLATFORM Well : A25-01 LW plot NoR-fence is A23-OILW Version ~4 C~a~* ..... ~' ~* '~ ........ ~ ~ S~ Field : Middle Ground Shoals Location : Cook Inlet, Alaska E $ 10000 ~ 8250 ~99oo ,~a~oo 9800 ~ 8000 ] 00~ 8500 · 13: 8400 : ~'~ ¢ 9700 ¢ 7900 ;3 \, ~ 9500 ', ,¢ ~4oo ;77oo j{2 !ilC~ , 9 O0 9100' $ 7500 j ' j iO0~ ~ 7400 ~ 7500 {00 ~7900 7800 ~ ?0 ~ 7700 ~ 7600 ~ 7500 (0 400 · %, 8400 %lgt B/HR fst 'e ,FN, al EOC ~. pSoo 8800 8700 ~ 8600 8500~ ~ 8400 ~ 8300 e 8200 ~ 8100 ~ 8800 ~ 8700 8000 · ' ' ~ 7900~ 8600 ~ ~ 790, EOC ~'~. ~ 8500 . ~ 8400~ 78 '', ~ 8300 7700~, ~ 7 { Cross Tf~nbers Operaiing CompanN For: B Pent ~se ~ ~oo~ S~r~cture : A PLATFORM Wel : A23-01LW ........................ ~'~ '~s Field : Middle Ground Shoals LOCation : Cook n et, Alaska fat r 93L 3~ 9'00 ~ ~ 790U 9506 - 770O . 750E ~ 9500 7500~ .5900 99O0 ~ _ /90C ),7OO~ ~900 ~:~o 8100 ~ _ BTO0 ~ 83o0 ~ 85E 850C 7900 8703~'~ t, _ /700 ~ s/o( 9/oo . 7900 9500~ 9500 9100-~91 _ 7,56';0 'Tx /- Cross Timbers Operating Company A PLATFORM A23-01LW slot #4-32 Middle Ground Shoals Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : A23-01LW Version #4 Our ref : prop4464 License : Date printed : 13-Apr-2001 Date created : 16-Feb-2001 Last revised : il-Apr-2001 Fi.eld 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 47 44.271,w151 29 44.195 Slot Grid coordinates are N 2485785.906, E 232830.984 Slot local coordinates are 6849.00 N 388.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 9675.00 36.88 359.15 7393.93 9700.00 37.08 356.26 7413.90 9800.00 38.58 345.10 7492.98 9900.00 41.05 334.86 7569.86 10000.00 44.34 325.74 7643.42 10100.00 48.27 317.71 7712.54 10200.00 52.69 310.67 7776.21 10300.00 57.48 304.44 7833.47 10334.31 59.19 302.46 7851.48 10500.00 59.19 302.46 7936.34 11000.00 59.19 302.46 8192.44 11076.18 59.19 302.46 8231.46 11100.00 59.70 304.30 8243.57 11200.00 62.12 311.82 8292.24 11300.00 64.93 318.98 8336.86 11307.39 65.15 319.50 8339.97 11407.37 65.15 319.50 8381.99 114Q7.39 65~15 319.50 8382.00 01 11500.00 65~00 322.05 8421.04 11600.00 64.88 324.81 8463.40 PROPOSAL LISTING Page 1 Your ref : A23-01LW Version #4 Last revised : il-Apr-2001 R E C T A N G U L A R Dogleg Vert C O O R D I N A T E S Deg/100ft Sect 5176.12 N 2483.32 E 0.00 1710.09 KOP - Sidetrack Pt 5191.15 N 2482.72 E 7.00 1720.77 5251.44 N 2472.72 E 7.00 1769.17 5311.37 N 2450.73 E 7.00 1826.12 5370.05 N 2417.06 E 7.00 1890.75 5426.61 N 2372.22 E 7.00 1962.11 5480.20 N 2316.88 E 7.00 2039.12 5530.02 N 2251.86 E 7.00 2120.66 5546.11 N 2227.50 E 7.00 2149.45 EOC ~1 5622.48 N 2107.42 E 0.00 2289.38 5852.94 N 1745.06 E 0.00 2711.62 5888.06 N 1689.86 E 0.00 2775.95 Begin 2nd Curve 5899.34 N 1672.73 E 7.00 2796.17 5953.21 N 1604.04 E 7.00 2883.15 6016.93 N 1541.30 E 7.00 2972.49 6022.00 N 1536.93 E 7.00 2979.14 Final EOC 6090.99 N 1478.01 E 0.00 3069.28 Tgt- B/HR - CsgPt 6091.00 N 1478.00 E 0.00 3069.29 A23-01LW TgtEntryPt Rvsd il-Apr- 6156.05 N 1424.89 E 2.50 3152.49 6228.79 N 1370.93 E 2.50 3241.56 11700.00 64.81 327.57 8505.92 6303.99 N 1320.56 E 11800.00 64.80 330.33 8548.49 6381.50 N 1273.89 E 11900.00 64.84 333.09 8591.05 6461.18 N 1231.01 E 12000.00 64.92 335.85 8633.51 6542.87 N 1192.00 E 12100.00 65.06 338.61 8675.79 6626.42 N 1156.94 E 12200.00 65.25 341.36 8717.81 6711.68 N 1125.88 E 12300.00 65.49 344.10 8759.48 6798,47 N 1098.90 E 12400.00 65.78 346.82 8800.74 6886.64 N 1076.03 E 12500.00 66.12 349.54 8841.51 6976.01 N 1057.33 E 12600.00 66.50 352.23 8881.69 7066.41 N 1042.83 E 12700.00 66.93 354.92 8921.23 7157.68 N 1032.56 E 12800.00 67.41 357.58 8960.03 7249.64 N 1026.53 E 12900.00 67.93 0.23 8998.04 7342.11 N 1024.76 E 13000.00 68.49 2.85 9035.17 7434.92 N 1027.26 E 13100.00 69.09 5.45 9071.36 7527.89 N 1034.01 E 13200.00 69.73 8.04 9106.53 7620.84 N 1045.01 E 13300.00 70.41 10.60 9140.63 7713,60 N 1060.23 E 13400.00 71.12 13.13 9173.57 7805.99 N 1079,64 E 13500.00 71.87 15.65 9205.31 7897.83 N 1103.22 E 13600.00 72.65 18.14 9235.79 7988.96 N 1130.90 E 13700.00 73.46 20.62 9264.93 8079.19 N 1162.65 E 13800.00 74.30 23.07 9292.69 8168.35 N 1198.39 E 13900.00 75.17 25.50 9319.02 8256.28 N 1238.07 E 13951.44 75.63 26.74 9331.99 8300.97 N 1259.98 E 13951.48 75.63 26.74 9332.00 8301.00 N 1260.00 E 2.50 3329.66 2.50 3416,64 2.50 3502.32 2.50 3586.54 2.50 3669.].4 2.50 3749.97 2.50 3828.87 2.50 3905.68 2.50 3980.28 2.50 4052.50 2.50 4122.21 2.50 4189.29 2.50 4253.60 2.50 4315.02 2.50 4373.44 2.50 4428.74 2.50 4480.81 2.50 4529.57 2.50 4574.91 2.50 4616.75 2.50 4655.00 2.50 4689.61 2.50 4720.49 2.50 4734.91 Tgt-T/HC-TD 2.50 4734.92 A23-01RD TgtTD (Exit) 16-Feb-01 Ail data is in feet unless otherwise stated. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Bottom hole distance is 8396.08 on azimuth 8.63 degrees from wellhead. Total Dogleg for wellpath is 125~96 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals, Cook Inlet, Alaska MD TVD Rectangular Coords. PROPOSAL LISTING Page 2 Your ref : A23-01LW Version ~4 Last revised : Il-Apr-2001 Comments in wellpath Comment 9675.00 7393.93 5176.12 N 10334.31 7851.48 5546.11 N 11076.18 8231.46 5888.06 N 11307.39 8339.97 6022.00 N 11407.37 8381.99 6090.99 N 11407.39 8382.00 6091.00 N 13951.44 9331.99 8300.97 N 13951.48 9332.00 8301.00 N 2483.32 E KOP - Sidetrack Pt 2227.50 E EOC #1 1689.86 E Begin 2nd Curve 1536.93 E Final EOC 1478.01 E Tgt - B/HR - CsgPt 1478.00 E A23-01LW TgtEntryPt Rvsd Il-Apr-01 1259.98 E Tgt-T/HC-TD 1260.00 E A23-01RD TgtTD (Exit) 16-Feb~01 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 7393.93 5176.12N 2483.32E 9675.00 7393.93 5176.12N 2483.32E 7" Casing n/a 7393.93 5176.12N 2483.32E 11407.39 8382.00 6091.00N 1478.00E 5" Casing n/a 7393.93 5176.12N 2483.32E 13951.48 9332.00 8301.00N 1260.00E ?" Tubing Targets associated with this wellpath ----. Target name Geographic Location T.V.D. Rectangular Coordinates Revised A23-01LW TgtEntryPt 838'2.00 6091.00N 1478.00E 16-Feb-2001 A23-01RD TgtTD (Exit 9332.00 8301~00N 1260.00E 16-Feb-2001 Cross Timbers Operating Company A PLATFORM A23-01LW slot #4-32 Middle Ground Shoals Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : A23-01LW Version #4 Our ref : prop4464 License : Date printed : 13-Apr-2001 Date created : 16-Feb-2001 Last revised : il-Apr-2001 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 47 44.271,w151 29 44.195 Slot Grid coordinates are N 2485785.906, E 232830.984 Slot local coordinates are 6849.00 N 388.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska Measured Depth 9675.00 9700.00 9800.00 9900.00 1000O.00 10100.00 10200.00 10300.00 10334.31 10500.00 11000.00 11076.18 11100.00 11200.00 11300.00 11307.39 11407.37 11407.39 11500.00 11600.00 11700.00 11800.00 11900.00 12000.00 12100.00 12200.00 12300.00 12400.00 12500.00 12600.00 12700.00 12800.00 12900.00 13000.00 13100.00 13200.00 13300.00 13400.00 13500.00 13600.00 13700.00 13800.00 13900.00 13951.44 13951.48 Inclin Azimuth True Vert Degrees Degrees Depth 36.88 359.15 7393.93 37.08 356.26 7413.90 38.58 345.10 7492.98 41.05 334.86 7569.86 44.34 325.74 7643.42 48.27 317.71 7712.54 52.69 310.67 7776.21 57.48 304.44 7833.47 59.19 302.46 7851.48 59.19 302.46 7936.34 59.19 302.46 8192.44 59.19 302.46 8231.46 59.70 304.30 8243.57 62.12 311.82 8292.24 64.93 318.98 8336.86 65.15 319.50 8339.97 65.15 319.50 8381.99 65.15 319.50 8382.00 65.00 322.05 8421.04 64.88 324.81 8463.40 64.81 327.57 8505.92 64.80 330.33 8548.49 64.84 333.09 8591.05 64.92 335.85 8633.51 65.06 338.61 8675.79 65.25 341.36 8717.81 65.49 344.10 8759.48 65.78 346.82 8800.74 66.12 349.54 8841.51 66.50 352.23 8881.69 66.93 354.92 8921.23 67.41 357.58 8960.03 67.93 0.23 8998.04 68.49 2.85 9035.17 69.09 5.45 9071.36 69.73 8.04 9106.53 70.41 10.60 9140.63 71.12 13.13 9173.57 71.87 15.65 9205.31 72.65 18.14 9235.79 73.46 20.62 9264.93 74.30 23.07 9292.69 75.17 25.50 9319.02 75.63 26.74 9331.99 75.63 26.74 9332.00 PROPOSAL LISTING Page 1 Your ref : A23-01LW Version Last revised : il-Apr-2001 R E C T A N G U L A R Dogleg Vert C O O R D I N A T E S Deg/100ft Sect 5176.12N 2483.32E 0.00 1710.09 5191.15N 2482.72E 7.00 1720.77 5251.44N 2472.72E 7.00 1769.17 5311.37N 2450.73E 7.00 1826.12 5370.05N 2417.06E 7.00 1890.75 5426.61N 2372.22E 7.00 1962.11 5480.20N 2316.88E 7.00 2039.12 5530.02N 2251.86E 7.00 2120.66 5546.11N 2227.50E 7.00 2149.45 5622.48N 2107.42E 0.00 2289.38 5852.94N 1745.06E 0.00 2711.62 5888.06N 1689.86E 0.00 2775.95 5899.34N 1672.73E 7.00 2796.17 5953.21N 1604.04E 7.00 2883.15 6016.93N 1541.30E 7.00 2972.49 6022.00N 1536.93E 7.00 2979.14 6090.99N 1478.01E 0.00 3069.28 6091.00N 1478.00E 0.00 3069.29 6156.05N 1424.89E 2.50 3152.49 6228.79N 1370.93E 2.50 3241.56 6303.99N 1320.56E 2.50 3329.66 6381.50N 1273.89E 2.50 3416.64 6461.18N 1231.01E 2.50 3502.32 6542.87N 1192.00E 2.50 3586.54 6626.42N 1156.94E 2.50 3669.14 6711.68N 1125.88E 2.50 3749.97 6798.47N 1098.90E 2.50 3828.87 6886.64N 1076.03E 2.50 3905.68 6976.01N 1057.33E 2.50 3980.28 7066.41N 1042.83E 2.50 4052.50 7157.68N 1032.56E 2.50 4122.21 7249.64N 1026.53E 2.50 4189.29 7342.11N 1024.76E 2.50 4253.60 7434.92N 1027.26E 2.50 4315.02 7527.89N 1034.01E 2.50 4373.44 7620.84N 1045.01E 2.50 4428.74 7713.60N 1060.23E 2.50 4480.81 7805.99N 1079.64E 2.50 4529.57 7897.83N 1103.22E 2.50 4574.91 7988.96N 1130.90E 2.50 4616.75 8079.19N 1162.65E 2.50 4655.00 8168.35N 1198.39E 2.50 4689.61 8256.28N 1238.07E 2.50 4720.49 8300.97N 1259.98E 2.50 4734.91 8301.00N 1260.00E 2.50 4734.92 GRID C OOR D S Easting Northing 235431.36 2490904.10 235431.10 2490919.14 235422.47 2490979.64 235401.85 2491040.06 235369.52 2491099.49 235325.98 2491157.05 235271.88 2491211.88 235208.01 2491263.17 235184.02 2491279.81 235065.71 2491358.89 234708.70 2491597.53 234654.30 2491633.89 234637.44 2491645.56 234570.00 2491700.97 234508.73 2491766.10 234504.47 2491771.27 234447.13 2491841.58 234447.12 2491841.60 234395.51 2491907.84 234343.21 2491981.78 234294.57 2492058.10 234249.68 2492136.66 234208.63 2492217.29 234171.49 2492299.85 234138.33 2492384.17 234109.22 2492470.11 234084.22 2492557.49 234063.36 2492646.16 234046.70 2492735.93 234034.26 2492826.64 234026.07 2492918.11 234022.13 2493010.18 234022.47 2493102.67 234027.08 2493195.39 234035.94 2493288.18 234049.05 2493380.86 234066.38 2493473.25 234087.89 2493565.17 234113.54 2493656.45 234143.29 2493746.92 234177.08 2493836.40 234214.85 2493924.73 234256.51 2494011.73 234279.44 2494055.91 234279.45 2494055.94 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot 94-32 and TVD from rotary table (116.00 Ft above mean sea level). Bottom hole distance is 8396.08 on azimuth 8.63 degrees from wellhead. Total Dogleg for wellpath is 125.96 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska Comments in wellpath PROPOSAL LISTING Page 2 Your ref : A23-01LW Version Last revised : Il-Apr-2001 MD TVD Rectangular Coords. Comment 9675.00 7393.93 5176.12N 2483.32E KOP - Sidetrack Pt 10334.31 7851.48 5546.11N 2227.50E EOC #1 11076.18 8231.46 5888.06N 1689.86E Begin 2nd Curve 11307.39 8339.97 6022.00N 1536.93E Final EOC 11407.37 8381.99 6090.99N 1478.01E Tgt- B/HR - CsgPt 11407.39 8382.00 6091.00N 1478.00E A23-01LW TgtEntryPt Rvsd Il-Apr-01 13951.44 9331.99 8300.97N 1259.98E Tgt-T/HC-TD 13951.48 9332.00 8301.00N 1260.00E A23-01RD TgtTD (Exit) 16-Feb-01 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 7393.93 5176.12N 2483.32E 9675.00 7393.93 5176.12N 2483.32E 7" Casing n/a 7393.93 5176.12N 2483.32E 11407.39 8382.00 6091.00N 1478.00E 5" Casing n/a 7393.93 5176.12N 2483.32E 13951.48 9332.00 8301.00N 1260.00E ?" Tubing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised A23-01LW TgtEntryPt 8382.00 6091.00N 1478.00E 16-Feb-2001 A23-01RD TgtTD (Exit 9332.00 8301.00N 1260.00E 16-Feb-2001 Cross Timbers Operating Company Strucfure : A PLATFORM Well : A23-01LW c,eo~eoby~ .... For:BFenFo,jField : Middle Ground Shoals Loca~rion · Cook Inlet Alaska Dote plotted : 13-Aor-2001 Plot Reference is ~3-01LW Version ~4. Coordlnetes ore in feet reference slot True Vertico' ~pths ar~n .... ,ory tob'~I ,1500 ,1.51(} 520 53O o 4 0 T R U I!{ N 0 R'I" H F~q ~ I5 0 o,_.0 '1 0 2O ,1.50 4O 13400 5O 15600 60 29 C) '70 280 8O 2 '70 9O 260 100 2[}0 24'0 1 20 220 210 2OO t90 t80 150 '1 6(D /' 130 Normcl F:'lclne Tr'-ove[lir'~g Cylinder- - Feet All depths shown are Measured depths on Reference Well Cross Timbers Operating Company A PLATFORM A23-01LW slot #4-32 Middle Ground Shoals Cook Inlet, Alaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E by Baker Hughes INTEQ REPORT Your ref : A23-01LW Version #4 Our ref : prop4464 License : Date printed : il-Apr-2001 Date created : 16-Feb-2001 Last revised : il-Apr-2001 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 47 44.271,w151 29 44.195 Slot Grid coordinates are N 2485785.906, E 232830.984 Slot local coordinates are 6849.00 N 388.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 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. MSS <313-9650'>,,A12-12,A PLATFORM 13-Feb-2001 3947.2 9675.0 9675.0 PMSS <7157 - 10505'>,,A12-12LW, A PLATFORM 12-Mar-2001 4132.5 9675.0 9675. MSS <1787-10200'>,,All-13R2,A PLATFORM 22-May-2000 6819.8 9675.0 9675. MSS <320-10022'>,,All-13,A PLATFORM 22-May-2000 6775.2 9675.0 9675. MSS <714-11820'>,,A22-01,A PLATFORM 1-Jun-2000 1103.0 9675.0 12612. PMSS <8762-11156'>,,A41-11LN,A PLATFORM 16-Feb-2000 3073.8 11223.1 11512. PMSS <7208-10863'>,,A41-11,A PLATFORM 1-Jun-2000 3723.2 11169.2 11169. PMSS <7706-12047'>,,A41AllLN, A PLATFORM 1-Jun-2000 1668.1 11825.0 11862. PGMS <0-7765'>,,A41A-11,A PLATFORM 1-Jun-2000 3543.6 9675.0 10460. MSS <8748-9840'>,,A43-11,A PLATFORM 1-Jun-2000 5732.7 9675.0 9675. MSS <6769-10108'>,,A43-11LW, A PLATFORM 1-Jun-2000 5710.6 9675.0 9675. MSS <0-10960'>,,A23-12,A PLATFORM 8-Feb-2000 4999.3 9675.0 9675. PGMS <0-11997'>,,A44-02,A PLATFORM 16-Feb-2000 1954.1 11625.0 11625. MSS <313-10555'>,,A33-14,A PLATFORM 8-Feb-2000 8274.7 9675.0 9675. MSS <320-9375'>,,All-12,A PLATFORM 1-Jun-2000 2918.5 9675.0 10580. MSS <390-9260'>,,A44-11,A PLATFORM 8-Feb-2000 6083.4 9675.0 9675. "~M$S <383-12586'>,,A33-01,A PLATFORM 8-Feb-2000 814.9 9675.0 9675 MSS <0-9610'>,,A13-12,A PLATFORM 1-Jun-2000 4933.8 9675.0 9675 MSS <6506-9900'>,,A13-12RD,A PLATFORM 1-Jun-2000 5549.1 9675.0 9675 A31-14LW2 Version %3,,A31-14LW,A PLATFORM 18-Jan-2001 8019.0 9675.0 9675 PMSS <9714-11708'>,,A31-14LW, A PLATFORM 1-Jun-2000 6839.5 9675.0 9675 MSS <320-3620'>,,AWS-1,A PLATFORM 1-Jun-2000 6781.5 9675.0 9675 MSS <417-9655'>,,A31-14,A PLATFORM 1-Jun-2000 6839.5 9675.0 9675 PGMS <0-9930'>,,A33-tl,A PLATFORM 1-Jun-2000 6421.9 9675.0 10800 PMSS <8780-11501'>,,A33-11LS,A PLATFORM 1-Jun-2000 6426.5 9675.0 11107 MSS <7259-7750'>,,A14A-1,A PLATFORM 1-Jun-2000 2212.6 9675.0 9675 A24-01LN Version #2,,A24-01LN,A PLATFORM PMSS <9960-11994'>,,A24-01LE,A PLATFORM MSS <0-10900'>,,A24-01,A PLATFORM A42-14A Version 91,,A42-14,A PLATFORM MSS <1250-10800'>,,A42-14,A PLATFORM PGMS <8854-10175'>,,A32-11R, A PLATFORM MSS <9675-12000'>,,A12-01,A PLATFORM MSS <9495-11035'>,,A32-11,A PLATFORM MSS <l1843-12285'>,,A1201LN0,A PLATFORM MSS <t2013-13894'>,,A1201LN1,A PLATFORM MSS <13278-13821'>,,A1201LN2,A PI~TFORM P~S <O-13335'>,,A12A-01,A PLATFOBM PGMS <8100-8800'>,,A1301LN1,A PLATFORM PMSS <8824-13397'>,,A13-01,A PLATFORM PMSS <11540-12641'>,,A13-O1,A PLATFORM MSS <8070-10850'>,,A13-O1,A PLATFORM MSS <10630-13238'>,,All-O1,A PLATFORM MSS <1452-10241'>,,A32-14,A PLATFORM PGMS <O-11530'>,,A22-14,A PLATFORM PMSS <10230-12880'>,,A22-14LS,A PLATFORM PMSS <5650-10750'>,,A3411LS2,A PLATFORM PGMS <O-10330'>,,A34-11,A PLATFORM PMSS <8303-11209'>,,A34-11LS,A PtATFORM MSS <316-10038'>,,A14-01,A PLATFORM PMSS <7943 - 11992'>,,A14-OiLN2,A PI~TFORM A34-14LW Version %9,,A34-14LW,A PLATFORM MSS <5643-12100'>,,A34-14RD, A PLATFORM MSS <1046-11480'>,,A34-14,A PLATFORM MSS <O-11202'>,,A23-O1,A PLATFORM MSS <8177-11550'>,,A23-O1RD,A PLATFORM 20-Sep-2000 31-May-2000 1-Jun-2000 8-Feb-2000 Il-Feb-2000 1-Jun-2000 24-Jan-2001 24-Jan-2001 1-Jun-2000 1-Jun-2000 1-Jun-2000 22-May-2000 1-Jun-2000 1-Jun-2000 1-Jun-2000 22-May-2000 8-Feb-2000 22-May-2000 1-Jun-2000 1-Jun-2000 14-Nov-2000 1-Oct-2000 1-Oct-2000 17-Dec-2000 29-Jan-2001 29-Mar-2001 1-Jun-2000 1-Jun-2000 1-Jun-2000 16-Feb-2001 1659.9 10520.0 1929.3 9675.0 1929.3 9675.0 9149.1 9675.0 7006 8 9675.0 4531 4 9675.0 843 4 12050.0 4933 6 11200.0 598 9 12237.5 391 6 13800.0 391 6 13800.0 173 9 13951.5 1944.1 9675.0 198.6 11712.5 198.6 11712.5 534.6 11284.6 791.2 13951.5 7248.8 9675.0 8341.9 9675.0 8341.9 9675.0 7193.6 9675.0 7193.6 9675.0 7193.6 9675.0 1466.0 10860.0 292.1 12312.5 8129.8 9675.0 8129.9 9675.0 8129.9 9675.0 185.5 9675.0 0.0 9675.0 10520.0 9675.0 9675.0 9675.0 9675.0 13750.0 12050.0 11200.0 12775.0 13800.0 13800.0 13951.5 10680.0 11712.5 11712.5 11284.6 13951.5 9675.0 9675.0 9675.0 9675.0 9675.0 9675.0 10860.0 12312.5 9675.0 9675.0 9675.0 9675.0 9675.0 Cross Timbers Operating Company CLEARANCE LISTING Page 2 A PLATFORM, A23- 01 LW Middle Ground Shoals, Cook Inlet, Alaska Reference wellpath M.D. T.V.D. Your ref : A23-01LW Version #4 Last revised : il-Apr-2001 Object wellpath : MSS <12013-13894'>,,A1201LN1,A PLATFORM Rect Coordinates M.D. 13187.5 9102.2 7609.2N 1043.4E 12753.4 13200.0 9106.5 7620.8N 1045.0E 12764.0 13212.5 9110.9 7632.5N 1046.7E 12779.8 13225.0 9115.2 7644.1N 1048.4E 12790.4 13237.5 9119.4 7655.7N 1050.2E 12806.1 13250.0 9123.7 7667.3N 1052.1E 12816.5 13262.5 9128.0 7678.9N 1054.0E 12830.4 13275.0 9132.2 7690.4N 1056.0E 12840.8 13287.5 9136.4 7702.0N 1058.1E 12851.1 13300.0 9140.6 7713.6N 1060.2E 12861.4 13312.5 9144.8 7725.2N 1062.4E 12871.7 13325.0 9149.0 7736.7N 1064.7E 12882.0 13337.5 9153.1 7748.3N 1067.0E 12892.2 13350.0 9157.2 7759.9N 1069.4E 12902.4 13362.5 9161.4 7771.4N 1071.9E 12912.6 13375.0 9165.4 7782.9N 1074.4E 12922.7 13387.5 9169.5 7794.5N 1077.0E 12932.8 13400.0 9173.6 7806.0N 1079.6E 12942.9 13412.5 9177.6 7817.5N 1082.4E 12954.7 13425.0 9181.6 7829.0N 1085.1E 12964.7 T.V.D. Rect Coordinates 9129.8 7661.6N 1539.6E 9137.8 7668.5N 1538.4E 9149.8 7678.7N 1536.6E 9157.7 7685.5N 1535.3E 9169.5 7695.7N 1533.4E 9177.4 7702.4N 1532.0E 9187.9 7711.3N 1530.2E 9195.7 7718.0N 1528.8E 9203.5 7724.6N 1527.3E 9211.2 7731.3N 1525.9E 9219.0 7737.9N 1524.5E 9226.7 7744.5N 1523.1E 9234.4 7751.1N 1521.7E 9242.1 7757.6N 1520.3E 9249.8 7764.2N 1518.9E 9257.4 7770.7N 1517.4E 9265.0 7777.2N 1516.0E 9272.7 7783.7N 1514.6E 9281.5 7791.3N 1513.0E 9289.1 7797.7N 1511.6E 9296.6 7804.1N 1510.1E 9304.1 7810.5N 1508.7E 9311.6 7816.9N 1507.3E 9319.0 7823.3N 1505.9E 9326.5 7829.6N 1504.5E Horiz Min'm Bearing Dist 84.0 499.7 84.5 496.7* 84.6 493.6* 85.1 490.5* 85.3 487.4* 85.8 484.2* 86.1 481.0' 86.7 477.8* 87.2 474.6* 87.8 471.4' 88.4 468.2* 89.0 465.0* 89.7 461.9' 90.3 458.8* 90.9 455.7* 91.6 452.7* 92.3 449.6* 92.9 446.7* 93.5 443.7* 94.2 440.8* 94.9 438.0* 95.7 435.2* 96.4 432.5* 97.2 429.8* 98.0 427.2* 424.6* 422.1' 419.7' 417.3' 415.1' 412.9' 410.8' 408.7* 406.8* 405.0* 107.8 403.3* 108.8 401.6' 109.9 400.1' 111.0 398.7* 112.1 397.4* 113.2 396.3* 114.4 395.2* 115.5 394.3* 116.7 393.5* 118.0 392.9* 118.9 392.4* 120.2 392.0* 121.5 391.7' 122.8 391.6' 123.7 391.6' 7836.0N 1503.1E 98.8 7842.3N 1501.7E 99.6 7848.5N 1500.3E 100.5 7854.8N 1498.9E 101.3 7861.0N 1497.5E 102.2 13437.5 9185.6 7840.5N 1088.0E 12974.7 13450.0 9189.6 7852.0N 1090.9E 12984.7 13462.5 9193.6 7863.5N 1093.9E 12994.6 13475.0 9197.5 7874.9N 1096.9E 13004.5 13487.5 9201.4 7886.4N ll00.0E 13014.4 13500.0 9205.3 7897.8N 1103.2E 13024.2 9333.9 13512.5 9209.2 7909.3N 1106.5E 13034.0 9341.2 13525.0 9213.1 7920.7N 1109.8E 13043.8 9348.6 13537.5 9216.9 7932.1N ll13.1E 13053.6 9355.9 13550.0 9220.7 7943.5N 1116.5E 13063.3 9363.2 13562.5 9224.5 7954.9N l120.0E 13073.0 9370.5 7867.3N 1496.2E 103.1 13575.0 9228.3 7966.3N 1123.6E 13084.1 9378.9 7874.4N 1494.5E 103.9 13587.5 9232.0 7977.6N 1127.2E 13093.7 9386.1 7880.6N 1493.2E 104.8 13600.0 9235.8 7989.0N 1130.9E 13103.3 9393.3 7886.7N 1491.8E 105.8 13612.5 9239.5 8000.3N 1134.6E 13112.8 9400.5 7892.9N 1490.4E 106.8 13625.0 9243.2 8011.6N 1138.5E 13122.3 9407.7 7899.0N 1489.0E 13637.5 9246.9 8022.9N 1142.3E 13131.8 9414.8 7905.0N 1487.6E 13650.0 9250.5 8034.2N 1146.3E 13141.2 9421.9 7911.1N 1486.3E 13662.5 9254.2 8045.5N 1150.3E 13150.6 9428.9 7917.1N 1484.9E 13675.0 9257.8 8056.7N 1154.3E 13159.9 9436.0 7923.1N 1483.5E 13687.5 9261.4 8068.0N 1158.5E 13169.2 9443.0 7929.1N 1482.2E 13700.0 9264.9 8079.2N 1162.6E 13178.5 9449.9 7935.1N 1480.8E 13712.5 9268.5 8090.4N 1t66.9E 13187.8 9456.9 7941.0N 1479.4E 13725.0 9272.0 8101.6N 1171.2E 13197.0 9463.8 7947.0N 1478.1E 13737.5 9275.5 8112.8N 1175.6E ].3206.2 9470.7 7952.9N 1476.7E 13750.0 9279.0 8123.9N 1180.0E 13218.6 9480.1 7960.9N 1474.9E 13762.5 9282.4 8135.0N 1184.5E 13227.7 9486.9 7966.7N 1473.5E 13775.0 9285.9 8146.2N 1189.1E 13236.8 9493.7 7972.6N 1472.2E 13787.5 9289.3 8157.3N 1193.7E 13245.9 9500.5 7978.5N 1470.8E 13800.0 9292.7 8168.3N 1198.4E 13260.5 9511.4 7988.0N 1468.5E TCyl Dist 512.4 510.1' 507.8* 505.4* 503.0* 500.6* 498.1' 495.5* 493.0* 490.3* 487.5* 484.5* 481.4' 478.3* 475.1' 471.8' 468.5* 465.1' 461.7' 458.3* 454.9* 451.5' 448.1' 444.8* 441.5' 438.2* 435.0* 431.9' 428.8* 425.8* 422.8* 420.0* 417.2' 414.5' 411.9' 409.4* 407.1' 404.8* 402.8* 400.8* 399.0* 397.4* 396.0* 394.7* 393.7* 392.8* 392.2* 391.8' 391.6' 391.6' 13812.5 9296.1 8179.4N 1203.1E 13269.6 9518.1 7993.9N 1467.2E 125.1 391.6 391.7 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company CLEARANCE LISTING Page 3 A PLATFORM, A23-01LW Your ref : A23-01LW Version Middle Ground Shoals,Cook Inlet, Alaska Last revised : il-Apr-2001 Reference wetlpath Object wellpath : MSS <12013-13894'>,,A1201LN1,A PLATFORM Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 13825.0 9299.4 8190.5N 1207.9E 13278.5 9524.7 7999.9N 1465.8E 126.5 391.8 392.0 13837.5 9302.7 8201.5N 1212.8E 13287.5 9531.3 8005.8N 1464.4E 127.9 392.2 392.5 13850.0 9306.0 8212.5N 1217.7E 13302.3 9542.1 8015.6N 1462.0E 128.9 392.6 393.2 13862.5 9309.3 8223.5N 1222.7E 13311.2 9548.6 8021.5N 1460.6E 130.3 393.2 394.1 13875.0 9312.6 8234.4N 1227.8E 13320.1 9555.1 8027.5N 1459.2E 131.8 393.9 395.1 13887.5 9315.8 8245.4N 1232.9E 13329.0 9561.5 8033.4N 1457.8E 133.3 394.7 396.4 13900.0 9319.0 8256.3N 1238.1E 13343.9 9572.2 8043.5N 1455.3E 134.4 395.7 397.9 13910.3 9321.6 8265.2N 1242.4E 13351.2 9577.4 8048.4N 1454.1E 135.7 396.6 399.3 13920.6 9324.3 8274.2N 1246.7E 13358.4 9582.6 8053.3N 1452.9E 137.0 397.6 400.9 13930.9 9326.9 8283.1N 1251.1E 13365.6 9587.7 8058.3N 1451.7E 138.3 398.6 402.5 13941.2 9329.4 8292.1N 1255.5E 13379.1 9597.3 8067.5N 1449.5E 139.2 399.8 404.4 13951.4 9332.0 8301.0N 1260.0E ].3386.3 9602.4 8072.4N 1448.3E 140.5 401.0 406.4 13951.5 9332.0 8301.0N 1260.0E 13386.4 9602.4 8072.4N 1448.3E 140.5 401.0 406.4 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska CLEARANCE LISTING Page 4 Your ref : A23-01LW Version #4 Last revised : Il-Apr-2001 M.D. 13187.5 13200.0 13212.5 13225.0 13237.5 13250.0 13262.5 13275.0 13287.5 13300.0 13312.5 13325.0 13337.5 13350.0 13362.5 13375.0 13387.5 13400.0 13412.5 13425.0 13437.5 13450.0 13462.5 13475.0 13487.5 13500.0 13512.5 13525.0 13537.5 13550.0 13562.5 13575.0 13587.5 13600.0 13612.5 13625.0 13637.5 13650.0 13662.5 13675.0 13687.5 13700.0 13712.5 13725.0 13737.5 13750.0 13762.5 13775.0 13787.5 13800.0 13812.5 Reference wellpath Object wellpath : MSS <13278-13821'>,,A1201LN2,A PLATFORM Horiz Min'm TCyl T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 9102.2 7609.2N 1043.4E 12753.4 9129.8 7661.6N 1539.6E 84.0 499.7 512.4 9106.5 7620.8N 1045.0E 12764.0 9137.8 7668.5N 1538.4E 84.5 496.7* 510.1' 9110.9 7632.5N 1046.7E 12779.8 9149.8 7678.7N 1536.6E 84.6 493.6* 507.8* 9115.2 7644.1N 1048.4E 12790.4 9157.7 7685.5N 1535.3E 85.1 490.5* 505.4* 9119.4 7655.7N 1050.2E 12806.1 9169.5 7695.7N 1533.4E 85.3 487.4* 503.0* 9123.7 7667.3N 1052.1E 12816.5 9177.4 7702.4N 1532.0E 85.8 484.2* 500.6* 9128.0 7678.9N 1054.0E 12830.4 9187.9 7711.3N 1530.2E 86.1 481.0' 498.1' 9132.2 7690.4N 1056.0E 12840.8 9195.7 7718.0N 1528.8E 86.7 477.8* 495.5* 9136.4 7702.0N 1058.1E 12851.1 9203.5 7724.6N 1527.3E 87.2 474.6* 493.0* 9140.6 7713.6N 1060.2E 12861.4 9211.2 7731.3N 1525.9E 87.8 471.4' 490.3* 9144.8 7725.2N 1062.4E 12871.7 9219.0 7737.9N 1524.5E 88.4 468.2* 487.5* 9149.0 7736.7N 1064.7E 12882.0 9226.7 7744.5N 1523.1E 89.0 465.0* 484.5* 9153.1 7748.3N 1067.0E 12892.2 9234.4 7751.1N 1521.7E 89.7 461.9' 481.4' 9157.2 7759.9N 1069.4E 12902.4 9242.1 7757.6N 1520.3E 90.3 458.8* 478.3* 9161.4 7771.4N 1071.9E 12912.6 9249.8 7764.2N 1518.9E 90.9 455.7* 475.1' 9165.4 7782.9N 1074.4E 12922.7 9257.4 7770.7N 1517.4E 91.6 452.7* 471.8' 9169.5 7794.5N 1077.0E 12932.8 9265.0 7777.2N 1516.0E 92.3 449.6* 468.5* 9173.6 7806.0N 1079.6E 12942.9 9272.7 7783.7N 1514.6E 92.9 446.7* 465.1' 9177.6 7817.5N 1082.4E 12954.7 9281.5 7791.3N 1513.0E 93.5 443.7* 461.7' 9181.6 7829.0N 1085.1E 12964.7 9289.1 7797.7N 1511.6E 94.2 440.8* 458.3* 9185.6 7840.5N 1088.0E 12974.7 9296.6 7804.1N 1510.1E 94.9 438.0* 454.9* 9189.6 7852.0N 1090.9E 12984.7 9304.1 7810.5N 1508.7E 95.7 435.2* 451.5' 9193.6 7863.5N 1093.9E 12994.6 9311.6 7816.9N 1507.3E 96.4 432.5* 448.1' 9197.5 7874.9N 1096.9E 13004.5 9319.0 7823.3N 1505.9E 97.2 429.8* 444.8* 9201.4 7886.4N ll00.0E 13014.4 9326.5 7829.6N 1504.5E 98.0 427.2* 441.5' 9205.3 7897.8N 1103.2E 13024.2 9333.9 7836.0N 1503.1E 98.8 424.6* 438.2* 9209.2 7909.3N 1106.5E 13034.0 9341.2 7842.3N 1501.7E 99.6 422.1' 435.0* 9213.1 7920.7N 1109.8E 13043.8 9348.6 7848.5N 1500.3E 100.5 419.7' 431.9' 9216.9 7932.1N ll13.1E 13053.6 9355.9 7854.8N 1498.9E 101.3 417.3' 428.8* 9220.7 7943.5N 1116.5E 13063.3 9363.2 7861.0N 1497.5E 102.2 415.1' 425.8* 9224.5 7954.9N l120.0E 13073.0 9370.5 7867.3N 1496.2E 103.1 412.9' 422.8* 9228.3 7966.3N 1123.6E 13084.1 9378.9 7874.4N 1494.5E 103.9 410.8' 420.0* 9232.0 7977.6N 1127.2E 13093.7 9386.1 7880.6N 1493.2E 104.8 408.7* 417.2' 9235.8 7989.0N 1130.9E 13103.3 9393.3 7886.7N 1491.8E 105.8 406.8* 414.5' 9239.5 8000.3N 1134.6E 13112.8 9400.5 7892.9N 1490.4E 106.8 405.0* 411.9' 9243.2 8011.6N 1138.5E 13122.3 9407.7 7899.0N 1489.0E 107.8 403.3* 409.4* 9246.9 8022.9N 1142.3E 13131.8 9414.8 7905.0N 1487.6E 108.8 401.6' 407.1' 9250.5 8034.2N 1146.3E 13141.2 9421.9 7911.1N 1486.3E 109.9 400.1' 404.8* 9254.2 8045.5N 1150.3E 13150.6 9428.9 7917.1N 1484.9E lll.0 398.7* 402.8* 9257.8 8056.7N 1154.3E 13159.9 9436.0 7923.1N 1483.5E 112.1 397.4* 400.8* 9261.4 8068.0N 1158.5E 13169.2 9443.0 7929.1N 1482.2E 113.2 396.3* 399.0* 9264.9 8079.2N 1162.6E 13178.5 9449.9 7935.1N 1480.8E 114.4 395.2* 397.4* 9268.5 8090.4N 1166.9E 13187.8 9456.9 7941.0N 1479.4E 115.5 394.3* 396.0* 9272.0 8101.6N 1171.2E 13197.0 9463.8 7947.0N 1478.1E 116.7 393.5* 394.7* 9275.5 8112.8N 1175.6E 13206.2 9470.7 7952.9N 1476.7E 118.0 392.9* 393.7* 9279.0 8123.9N l180.0E 13218.0 9479.6 7960.4N 1475.0E 119.0 392.4* 392.8* 9282.4 8135.0N 1184.5E 13227.0 9486.4 7966.3N 1473.6E 120.3 392.0* 392.2* 9285.9 8146.2N 1189.1E 13236.1 9493.2 7972.1N 1472.2E 121.6 391.7' 391.8' 9289.3 8157.3N 1193.7E 13249.2 9503.0 7980.6N 1470.2E 122.6 391.6' 391.6' 9292.7 8168.3N 1198.4E 13258.2 9509.7 7986.4N 1468.8E 123.9 391.6' 391.6' 9296.1 8179.4N 1203.1E 13267.1 9516.3 7992.2N 1467.4E 125.3 391.7 391.7 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska CLEARANCE LISTING Page 5 Your ref : A23-01LW Version #4 Last revised : Il-Apr-2001 Reference wellpath M.D. T.V.D. 13825.0 9299.4 13837.5 9302.7 13850.0 9306.0 13862.5 9309.3 13875.0 9312.6 13887.5 9315.8 13900.0 9319.0 13910.3 9321.6 13920.6 9324.3 13930.9 9326.9 13941.2 9329.4 13951.4 9332.0 13951.5 9332.0 Object wellpath : MSS <13278-13821'>,,A1201LN2,A PLATFORM Rect Coordinates M.D. T.V.D. Rect Coordinates 8190.5N 1207.9E 13279.1 9525.2 8000.0N 8201.5N 1212.8E 13287.9 9531.8 8005.8N 8212.5N 1217.7E 13298.6 9539.7 8012.7N 8223.5N 1222.7E 13307.2 9546.1 8018.3N 8234.4N 1227.8E 13317.5 9553.7 8024.9N 8245.4N 1232.9E 13325.9 9559.9 8030.3N 8256.3N 1238.1E 13336.4 9567.7 8036.9N 8265.2N 1242.4E 13345.6 9574.6 8042.7N 8274.2N 1246.7E 13356.1 9582.4 8049.2N 8283.1N 1251.1E 13373.6 9595.3 8059.9N 8292.1N 1255.5E 13383.0 9602.2 8065.5N 8301.0N 1260.0E 13390.1 9607.4 8069.7N 8301.0N 1260.0E 13390.2 9607.4 8069.8N Horiz Min'm TCyl Bearing Dist Dist 1465.5E 126.5 391.9 392.0 1464.0E 127.9 392.2 392.6 1462.1E 129.3 392.7 393.5 1460.6E 130.8 393.3 394.6 1458.7E 132.2 394.1 395.9 1457.0E 133.8 395.1 397.3 1454.9E 135.3 396.2 398.9 1452.9E 136.6 397.2 400.7 1450.3E 137.9 398.4 402.9 1445.2E 139.0 399.5 405.8 1442.1E 140.5 400.7 410.1 1439.6E 142.2 401.9 415.9 1439.6E 142.2 401.9 416.0 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot %4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska CLEARANCE LISTING Page 6 Your ref : A23-01LW Version %4 Last revised : Il-Apr-2001 Reference wellpath Object wellpath : PGMS <0-13335'>,,A12A-01,A PLATFORM M.D. T.V.D. 12975.0 9026.0 12987.5 9030.6 13000.0 9035.2 13012.5 9039.7 13025.0 9044.3 Rect Coordinates M.D. T.V.D. Rect Coordinates 7411.7N 1026.2E 12105.5 8669.5 7707.7N 1209.2E 7423.3N 1026.7E 12116.7 8677.2 7715.2N 1212.1E 7434.9N 1027.3E 12127.8 8684.9 7722.7N 1214.9E 7446.5N 1027.9E 12139.0 8692.6 7730.3N 1217.8E 7458.2N 1028.5E 12151.5 8701.3 7738.7N 1220.9E 13037.5 9048.9 7469.8N 1029.3E 12162.7 8709.0 7746.3N 1223.8E 13050.0 9053.4 7481.4N 1030.1E 12173.9 8716.8 7753.8N 1226.6E 13062.5 9057.9 7493.0N 1031.0E 12185.1 8724.6 7761.4N 1229.4E 13075.0 9062.4 7504.6N 1031.9E 12196.3 8732.4 7769.0N 1232.1E 13087.5 9066.9 7516.3N 1032.9E 12209.3 8741.3 7777.8N 1235.3E 13100.0 9071.4 7527.9N 1034.0E 12220.5 8749.1 7785.3N 1238.1E 13112.5 9075.8 7539.5N 1035.2E 12233.7 8758.4 7794.2N 1241.4E 13125.0 9080.2 7551.1N 1036.4E 12244.9 8766.2 7801.7N 1244.2E 13137.5 9084.7 7562.8N 1037.6E 12256.1 8774.0 7809.2N 1247.0E 13150.0 9089.1 7574.4N 1039.0E 12269.2 8783.2 7818.0N 1250.3E 13162.5 9093.5 13175.0 9097.8 13187.5 9102.2 13200.0 9106.5 13212.5 9110.9 13225.0 9115.2 13237.5 9119.4 13250.0 9123.7 13262.5 9128.0 13275.0 9132.2 7586.0N 1040.4E 12280.4 8791.0 7825.4N 1253.1E 7597.6N 1041.9E 12291.5 8798.9 7832.8N 1255.9E 7609.2N 1043.4E 12303.1 8807.1 7840.5N 1258.8E 7620.8N 1045.0E 12314.3 8814.9 7847.9N 1261.7E 7632.5N 1046.7E 12325.5 8822.8 7855.3N 1264.5E 7644.1N 1048.4E 12335.8 8830.0 7862.2N 1267.0E 7655.7N 1050.2E 12347.0 8837.9 7869.7N 1269.8E 7667.3N 1052.1E 12358.2 8845.8 7877.3N 1272.5E 7678.9N 1054.0E 12368.7 8853.1 7884.3N 1275.0E 7690.4N 1056.0E 12380.0 8861.0 7891.9N 1277.7E 13287.5 9136.4 7702.0N 1058.1E 12391.3 8868.8 7899.6N 1280.4E 13300.0 9140.6 7713.6N 1060.2E 12403.2 8877.1 7907.6N 1283.2E 13312.5 9144.8 7725.2N 1062.4E 12414.4 8884.9 7915.3N 1285.8E 1.3325.0 9149.0 7736.7N 1064.7E 1.2425.7 8892.8 7923.0N 1288.5E 13337.5 9153.1 7748.3N 1067.0E 12437.0 8900.7 7930.6N 1291.1E 13350.0 9157.2 7759.9N 1069.4E 12450.0 8909.8 7939.4N 1294.2E 13362.5 9161.4 7771.4N 1071.9E 12461.3 8917.6 7947.0N 1296.8E 13375.0 9165.4 7782.9N 1074.4E 12472.5 8925.5 7954.6N 1299.4E 13387.5 9169.5 7794.5N 1077.0E 12483.7 8933.4 7962.2N 1302.0E 13400.0 9173.6 7806.0N 1079.6E 12496.0 8941.9 7970.4N 1304.8E 13412.5 9177.6 13425.0 9181.6 13437.5 9185.6 13450.0 9189.6 13462.5 9193.6 13475.0 9197.5 13487.5 9201.4 13500.0 9205.3 13512.5 9209.2 13525.0 9213.1 7817.5N 1082.4E 12507.2 8949.8 7978.0N 1307.4E 7829.0N 1085.1E 12518.4 8957.7 7985.5N 1310.0E 7840.5N 1088.0E 12529.6 8965.6 7993.0N 1312.6E 7852.0N 1090.9E 12540.8 8973.4 8000.6N 1315.2E 7863.5N 1093.9E 12552.0 8981.3 8008.1N 1317.8E 7874.9N 1096.9E 12563.2 8989.1 8015.6N 1320.4E 7886.4N 1100.0E 12574.3 8997.0 8023.2N 1323.0E 7897.8N 1103.2E 12585.5 9004.9 8030.7N 1325.6E 7909.3N 1106.5E 12596.7 9012.7 8038.2N 1328.2E 7920.7N 1109.8E 12607.4. 9020.2 8045.4N 1330.6E 13537.5 9216.9 7932.1N ll13.1E 12618.5 9028.1 8052.9N 1333.2E 13550.0 9220.7 7943.5N 1116.5E 12629.7 9035.9 8060.4N 1335.8E 13562.5 9224.5 7954.9N 1120.0E 12640.8 9043.7 8067.9N 1338.4E 13575.0 9228.3 7966.3N 1123.6E 12650.9 9050.8 8074.7N 1340.7E 13587.5 9232.0 7977.6N 1127.2E 12662.1 9058.6 8082.3N 1343.3E 13600.0 9235.8 7989.0N 1130.9E 12673.2 9066.4 8089.8N 1345.9E Horiz Min'm TCyl Bearing Dist Dist 31.7 498.2 526.4 32.4 494.4* 522.3* 33.1 490.6* 518.3' 33.8 486.9* 514.2' 34.4 483.1' 510.1' 35.1 479.3* 506.1' 35.8 475.5* 502.0* 36.5 471.7' 498.0* 37.1 467.9* 494.0* 37.7 464.0* 490.0* 38.4 460.2* 486.0* 39.0 456.3* 482.1' 39.7 452.4* 478.1' 40.3 448.4* 474.2* 40.9 444.5* 470.2* 41.6 440.5* 466.3* 42.3 436.5* 462.3* 43.0 432.4* 458.3* 43.7 428.4* 454.3* 44.3 424.4* 450.3* 45.1 420.3* 446.3* 45.7 416.3' 442.3* 46.4 412.2' 438.2* 47.1 408.2* 434.1' 47.7 404.1' 430.0* 48.4 400.1' 425.8* 49.0 396.0* 421.6' 49.6 391.9' 417.4' 50.2 387.8* 413.2' 50.9 383.6* 408.9* 51.4 379.5* 404.6* 52.0 375.3* 400.3* 52.7 371.0' 396.0* 53.3 366.8* 391.7' 53.9 362.5* 387.4* 54.5 358.2* 383.1' 55.2 353.8* 378.7* 55.8 349.5* 374.4* 56.5 345.1' 370.0* 57.1 340.8* 365.6* 57.8 336.4* 361.2' 58.5 331.9' 356.8* 59.1 327.5* 352.3* 59.8 323.1' 347.7* 60.6 318.6' 343.1' 61.2 314.1' 338.5* 61.9 309.7* 333.9* 62.6 305.2* 329.2* 63.5 300.7* 324.5* 64.2 296.2* 319.8' 64.9 291.7' 315.1' Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical sectionis from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska CLEARANCE LISTING Page 7 Your ref : A23-0tLW Version #4 Last revised : il-Apr-2001 Reference wellpath Object wellpath : PGMS <0-13335'>,,A12A-01,A PLATFORM M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates 13612.5 9239.5 8000.3N 1134.6E 12684.4 9074.1 8097.3N 1348.5E 13625.0 9243.2 8011.6N 1138.5E 12695.5 9081.9 8104.9N 1351.1E 13637.5 9246.9 8022.9N 1142.3E 12705.3 9088.7 8111.5N 1353.4E 13650.0 9250.5 8034.2N 1146.3E 12716.4 9096.5 8119.0N 1356.1E 13662.5 9254.2 8045.5N 1150.3E 12725.7 9103.0 8125.3N 1358.3E 13675.0 9257.8 8056.7N 1154.3E 12736.8 9110.7 8132.7N 1361.1E 13687.5 9261.4 8068.0N 1158.5E 12747.9 9118.5 8140.2N 1363.9E 13700.0 9264.9 8079.2N 1162.6E 12757.1 9124.9 8146.3N 1366.3E 13712.5 9268.5 8090.4N 1166.9E 12768.2 9132.7 8153.7N 1369.1E 13725.0 9272.0 8101.6N 1171.2E 12777.4 9139.1 8159.8N 1371.6E 13737.5 9275.5 8112.8N 1175.6E 12788.4 9146.8 8167.1N 1374.6E 13750.0 9279.0 8123.9N 1180.0E 12799.4 9154.5 8174.3N 1377.6E 13762.5 9282.4 8135.0N 1184.5E 12810.3 9162.2 8181.5N 1380.7E 13775.0 9285.9 8146.2N 1189.1E 12821.3 9169.9 8188.6N 1383.7E 13787.5 9289.3 8157.3N 1193.7E 12833.8 9178.7 8196.7N 1387.2E 13800.0 9292.7 8168.3N 1198.4E 12844.6 9186.4 8203.8N 1390.1E 13812.5 9296.1 8179.4N 1203.1E 12855.5 9194.2 8210.8N 1393.1E 13825.0 9299.4 8190.5N 1207.9E 12867.7 9202.9 8218.7N 1396.5E 13837.5 9302.7 8201.5N 1212.8E 12878.5 9210.6 8225.6N 1399.4E 13850.0 9306.0 8212.5N 1217.7E 12889.2 9218.3 8232.5N 1402.3E 13862.5 9309.3 8223.5N 1222.7E 12900.9 9226.7 8239.9N 1405.5E 13875.0 9312.6 8234.4N 1227.8E 12911.6 9234.4 8246.7N 1408.4E 13887.5 9315.8 8245.4N 1232.9E 12922.2 9242.2 8253.5N 1411.3E 13900.0 9319.0 8256.3N 1238.1E 12933.3 9250.2 8260.4N 1414.3E 13910.3 9321.6 8265.2N 1242.4E 12942.0 9256.6 8265.9N 1416.6E 13920.6 9324.3 8274.2N 1246.7E 12950.7 9262.9 8271.3N 1419.0E 13930.9 9326.9 8283.1N 1251.1E 12959.3 9269.3 8276.7N 1421.3E 13941.2 9329.4 8292.1N 1255.5E 12968.2 9275.8 8282.2N 1423.7E 13951.4 9332.0 8301.0N 1260.0E 12976.8 9282.2 8287.5N 1426.1E 13951.5 9332.0 8301.0N 1260..0E 12976.8 9282.2 8287.6N 1426.1E Horiz Min'm TCyl Bearing Dist Dist 65.6 287.2* 310.3' 66.3 282.7* 305.5* 67.2 278.2* 300.7* 68.0 273.8* 295.9* 69.0 269.3* 291.0' 69.8 264.9* 286.2* 70.6 260.4* 281.3' 71.7 256.1' 276.4* 72.6 251.7' 271.6' 73.8 247.4* 266.7* 74.7 243.1' 261.8' 75.7 238.9* 256.9* 76.7 234.7* 252.0* 77.7 230.5* 247.2* 78.5 226.3* 242.4* 79.5 222.1' 237.7* 80.6 217.9' 233.0* 81.5 213.7' 228.4* 82.6 209.5* 223.8* 83.8 205.3* 219.3' 84.8 201.2' 214.8' 86.1 197.2' 210.3' 87.4 193.1' 205.8* 88.6 189.2' 201.3' 89.8 186.0' 197.6' 91.0 182.9' 193.9' 92.2 179.8' 190.3' 93.3 176.8' 186.7' 94.6 173.9' 183.1' 94.6 173.9' ].83.1' All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska CLEARANCE LISTING Page 8 Your ref : A23-01LW Version #4 Last revised : il-Apr-2001 Reference wellpath Object wellpath : PMSS <8824-13397'>,,A13-01,A PLATFORM Horiz Min'm TCyl M.D. 11161.5 11169.2 1117 6.9 11184.6 11192.3 11200.0 11207.7 11215.4 11223.1 11230.8 11238.5 11246.2 11253.8 11261.5 11269.2 11276.9 11284.6 11292.3 11300.0 11303.7 11307.4 11.400.0 11407.4 11407.4 11419.0 11430.5 11442.1 11453.7 11465.3 11476.8 11488.4 11500.0 11512.5 11525.0 11537.5 11550.0 11562.5 11575.0 11587.5 11600.0 11612.5 11.625.0 11637.5 11650.0 11.662.5 11675.0 11687.5 11700.0 11712.5 11725.0 11737.5 T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates 8274.0 5931.3N 1629.8E 10679.2 8274.1 6043.1N 1148.3E 8277.7 5935.5N 1624.6E 10683.9 8278.1 6045.5N 1148.9E 8281.3 5939.9N 1619.4E 10688.6 8282.1 6047.8N 1149.4E 8285.0 5944.3N 1614.2E 10693.3 8286.2 6050.1N 1150.0E 8288.6 5948.7N 1609.1E 10698.1 8290.3 6052.5N 1150.5E 8292.2 5953.2N 1604.0E 10702.8 8294.4 6054.8N 1151.0E 8295.8 5957.8N 1599.0E 10703.8 8295.3 6055.3N l151.1E 8299.4 5962.4N 1594.0E 10708.7 8299.4 6057.7N 1151.7E 8302.9 5967.1N 1589.0E 10713.5 8303.6 6060.1N 1152.2E 8306.4 5971.8N 1584.1E 10718.3 8307.8 6062.5N 1152.7E 8309.9 5976.6N 1579.2E 10723.2 8312.0 6064.8N 1153.2E 8313.4 5981.4N 1574.3E 10728.0 8316.2 6067.2N 1153.7E 8316.8 5986.3N 1569.5E 10732.9 8320.4 6069.5N 1154.2E 8320.2 5991.3N 1564.7E 10737.7 8324.6 6071.9N 1154.7E 8323.6 5996.3N 1559.9E 10742.9 8329.2 6074.4N 1155.2E 8327.0 6001.4N 1555.2E 10742.9 8329.1 6074.4N 1155.2E 8330.3 6006.5N 1550.5E 10747.8 8333.4 6076.8N 1155.7E 8333.6 6011.7N 1545.9E 10752.8 8337.7 6079.1N 1156.2E 8336.9 6016.9N 1541.3E 10757.7 8342.0 6081.5N 1156.6E 8338.4 6019.5N 1539.1E 10760.7 8344.6 6082.9N 1156.8E 8340.0 6022.0N 1536.9E 10763.1 8346.7 6084.1N 1157.0E 8378.9 6085.9N 1482.4E 10808.5 8386.7 6105.4N l160.0E 8382.0 6091.0N 1478.0E 10813.3 8391.0 6107.7N 1160.2E 8382.0 6091.0N 1478.0E 10813.4 8391.0 6107.7N 1160.2E 8386.9 6099.0N 1471.2E 10821.0 8397.8 6111.3N 1160.6E 8391.7 6107.0N 1464.4E 10828.7 8404.6 6114.8N 1160.9E 8396.6 6115.1N 1457.7E 10833.8 8409.1 6117.1N 1161.2E 8401.5 6123.2N 1451.1E 10841.5 8416.0 6120.7N 1161.5E 8406.4 6131.4N 1444.5E 1.0849.3 8422.9 6124.3N 1161.8E 8411.3 6139.6N 1437.9E 10857.2 8429.8 6127.9N 1162.2E 8416.1 6147.8N 1431.4E 10865.0 8436.8 6131.5N 1162.5E 8421..0 6156.1N 1424.9E 10871.3 8442.4 6134.4N 1162.7E 8426.3 6165.0N 1418.0E 10879.8 8450.0 6138.2N 1163.0E 8431.6 6174.0N 1411.1E 10888.3 8457.6 6142.0N 1163.3E 8436.9 6183.0N 1404.2E 10896.8 8465.2 6145.8N 1163.6E 8442.2 6192.1N 1397.5E 10904.5 8472.0 6149.2N 1163.9E 8447.5 6201.2N 1390.7E 10913.0 8479.7 6152.9N 1164.2E 8452.8 6210.4N 1384.1E 10921.5 8487.3 6156.5N 1164.5E 8458.1 6219.6N 1377.5E 10928.8 8493.9 6159.7N 1164.7E 8463.4 6228.8N 1370.9E 10937.2 8501.6 6163.2N 1165.0E 8468.7 6238.1N 1364.4E 10945.7 8509.2 6166.8N 1165.3E 8474.0 6247.4N 1358.0E 10954.1 8517.0 6170.3N 1165.6E 8479.3 6256.7N 1351.6E 10960.8 8523.0 6173.0N 1165.9E 8484.6 6266.1N 1345.3E 10969.2 8530.7 6176.5N 1166.2E 8490.0 6275.5N 1339.0E 10977.7 8538.5 6179.9N 1166.4E 8495.3 6285.0N 1332.8E 10986.2 8546.3 6183.3N 1166.7E 8500.6 6294.5N 1326.7E 10992.6 8552.1 6185.9N 1166.9E 8505.9 6304.0N 1320.6E 11001.2 8559.9 6189.3N 1167.1E 8511.2 6313.6N 1314.5E 11009.7 8567.8 6192.8N 1167.3E 8516.6 6323.2N 1308.5E 11018.3 8575.6 6196.2N 1167.5E 8521.9 Bearing Dist Dist 283.1 494.3 1031.1 283.0 488.2* 1010.6 282.9 482.2* 990.1' 282.8 476.2* 969.6* 282.8 470.2* 949.1' 282.6 464.3* 928.6* 282.3 458.4* 908.0* 282.2 452.5* 887.6* 282.0 446.6* 867.0* 281.9 440.8* 846.5* 281.7 435.0* 826.0* 281.5 429.2* 805.7* 281.3 423.5* 785.3* 281.1 417.8' 765.2* 280.9 412.2' 745.0* 280.3 406.6* 724.9* 280.1 401.0' 705.0* 279.8 395.6* 685.1' 279.5 390.1' 665.3* 279.4 387.6* 655.9* 279.3 385.0* 646.6* 273.5 323.].* 485.6* 273.0 318.4' 474.8* 273.0 318.4' 474.8* 272.3 311.1' 455.6* 271.5 303.9* 437.3* 270.4 296.8* 419.9' 269.5 289.9* 403.4* 268.6 283.2* 387.7* 267.6 276.6* 372.7* 266.5 270.2* 358.3* 265.3 264.0* 344.4* 264.0 257.4* 329.9* 262.6 251.2' 315.9' 261.2 245.1' 302.5* 259.6 239.4* 289.6* 258.0 233.9* 277.5* 256.2 228.7* 266.2* 254.3 223.9* 255.9* 252.3 219.4' 246.2* 250.3 215.3' 237.3* 248.2 21.1.6' 229.2* 245.7 208.4* 221.8' 243.4 205.5* 215.3' 241.0 203.2* 209.7* 238.5 201.3' 205.2* 235.8 199.9' 201.8' 233.2 199.0' 199.6' 230.6 198.6' 198.7' 228.0 198.8 199.0 6332.8N 1302.6E 11025.0 8581.8 6198.8N 1167.6E 225.2 199.4 200.5 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska CLEARANCE LISTING Page 9 Your ref : A23-01LW Version #4 Last revised : il-Apr-2001 Reference wellpath Object wellpath : PMSS <8824-13397'>,,A13-01,A PLATFORM Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 11750.0 11762.5 11775.0 11787.5 11800.0 11812.5 11825.0 11837.5 11850.0 11862.5 11875.0 11887.5 11900.0 11912.5 11925.0 11937.5 11950.0 11962.5 11975.0 11987.5 12000.0 12012.5 12025.0 12037.5 12050.0 12062.5 12075.0 12087.5 12100.0 12112.5 12125.0 12137.5 12150.0 12162.5 12175.0 12187.5 12200.0 12212.5 12225.0 12237.5 12250.0 12262.5 12275.0 12287.5 12300.0 8527.2 8532.5 8537.8 8543.2 8548.5 8553.8 8559.1 8564.5 8569.8 8575.1 8580.4 8585.7 8591.0 8596.4 8601.7 8607.0 8612.3 8617.6 8622.9 8628.2 8633.5 8638.8 8644.1 8649.4 8654.7 8660.0 8665.2 8670.5 8675.8 8681.1 8686.3 8691.6 8696.8 8702.1 8707.3 8712.6 8717.8 8723.0 8728.3 8733.5 8738.7 8743.9 8749.1 8754.3 8759.5 6342.5N 1296.8E 11033.5 8589.6 6202.2N 1167.8E 222.6 200.5 203.2 6352.2N 1291.0E 11042.1 8597.5 6205.5N 1168.0E 220.0 202.1 207.1 6361.9N 1285.2E 11050.7 8605.4 6208.8N 1168.2E 217.4 204.2 212.1 6371.7N 1279.5E 11057.3 8611.6 6211.4N 1168.3E 214.7 206.7 218.1 6381.5N 1273.9E 11065.9 8619.5 6214.6N 1168.5E 212.3 209.7 225.0 6391.3N 1268.3E 11074.4 8627.4 6217.9N 1168.7E 209.9 213.1 232.6 6401.2N 1262.8E 11083.0 8635.3 6221.1N 1168.9E 207.5 217.0 240.8 6411.1N 1257.4E 11089.3 8641.2 6223.4N 1169.0E 205.2 221.2 249.6 6421.1N 1252.0E 11097.8 8649.1 6226.6N 1169.2E 203.0 225.7 258.8 6431.1N 1246.6E 11106.3 8657.0 6229.7N 1169.4E 201.0 230.7 268.3 6441.1N 1241.4E 11113.8 8663.9 6232.5N 1169.6E 199.0 235.9 278.0 6451.1N 1236.2E 11122.3 8671.9 6235.6N 1169.8E 197.1 241.4 287.9 6461.2N 1231.0E 11130.8 8679.8 6238.7N 1170.0E 195.3 247.2 298.0 6471.3N 1225.9E 11139.4 8687.7 6241.8N 1170.1E 193.7 253.2 308.4 6481.4N 1220.9E 11147.9 8695.7 6244.9N 1170.3E 192.1 259.5 319.0 6491.6N 1215.9E 11157.0 8704.2 6248.3N 1t70.5E 190.6 265.9 329.8 6501.8N 1211.0E 11165.6 8712.2 6251.4N 1170.6E 189.2 272.6 340.8 6512.0N 1206.2E 11174.3 8720.2 6254.6N 1170.8E 187.8 279.4 352.0 6522.3N 1201.4E 11182.9 8728.2 6257.8N 1170.9E 186.6 286.3 363.4 6532.6N 1196.7E 11191.5 8736.2 6260.9N l171.1E 185.4 293.4 375.0 6542.9N 1192.0E 11200.2 8744.3 6264.1N 1171.2E 184.3 300.7 386.7 6553.2N 1187.4E 11211.0 8754.3 6268.1N 1171.4E 183.2 308.0 398.6 6563.6N 1182.9E 11219.7 8762.4 6271.4N 1171.5E 182.2 315.5 410.6 6574.0N 1178.4E 11228.4 8770.5 6274.7N 1171.7E 181.3 323.0 422.6 6584.4N 1174.0E 11240.9 8782.0 6279.4N 1171.9E 180.4 330.6 434.6 6594.9N 1169.6E 11249.7 8790.1 6282.8N 1172.1E 179.5 338.2 446.7 6605.4N 1165.3E 11258.5 8798.3 6286.2N 1172.3E 178.8 345.9 458.8 6615.9N l161.1E 11269.9 8808.7 6290.6N 1172.5E 178.0 353.6 471.0 6626.4N 1156.9E 11278.8 8816.9 6294.1N 1172.7E 177.3 361.4 483.1 6637.0N 1152.8E 11287.7 8825.1 6297.6N 1172.9E 176.6 369.3 495.3 6647.6N 1148.8E 11296.6 8833.3 6301.1N 1173.1E 176.0 377.2 507.5 6658.2N 1144.8E 11305.5 8841.5 6304.5N 1173.3E 175.4 385.2 519.6 6668.8N 1140.9E 11315.6 8850.8 6308.5N 1173.5E 174.8 393.2 531.9 6679.5N 1137.1E ].1324.5 8859.0 6312.1N 1173.8E 174.3 401.3 544.1 6690.2N 1133.3E 11333.5 8867.2 6315.6N 1174.0E 173.8 409.4 556.4 6700.9N 1129.5E 11342.4 8875.5 6319.1N 1174.2E 173.3 417.5 568.8 6711.7N 1125.9E 11351.4 8883.7 6322.7N 1174.4E 172.9 425.7 581.2 6722.4N 1122.3E 11359.5 8891.1 6325.9N 1174.7E 172.5 433.9 593.6 6733.2N 1118.8E 11368.5 8899.4 6329.4N 1174.9E 172.1 442.1 606.2 6744.1N 1115.3E 11377.4 8907.6 6333.0N 1175.1E 171.7 450.4 619.0 6754.9N llll.9E 11386.4 8915.8 6336.5N 1175.4E 171.4 458.8 632.0 6765.8N 1108.5E 11395.4 8924.1 6340.0N 1175.6E 171.0 467.2 645.1 6776.6N 1105.3E 11404.3 8932.3 6343.5N 1175.8E 170.7 475.6 658.2 6787.5N l102.0E 1141.0.0 8937.6 6345.7N 1176.0E 170.5 484.0 671.3 6798.5N 1098.9E 11418.9 8945.8 6349.2N 1176.2E 170.2 492.5 684.5 Ail data iS in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals, Cook Inlet, Alaska CLEARANCE LISTING Page 10 Your ref : A23-01LW Version #4 Last revised : il-Apr-2001 Reference wellpath Object wellpath : PMSS <l1540-12641'>,,A13-01,A PLATFORM Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 11161.5 11169.2 11176.9 11184.6 11192.3 11200.0 11207.7 11215.4 11223.1 11230.8 11238.5 11246.2 11253.8 11261.5 11269.2 11276.9 11284.6 11292.3 11300.0 11303.7 11307.4 11400.0 11407.4 11407.4 11419.0 11430.5 11442.1 11453.7 11465.3 11476.8 11488.4 11500.0 11512.5 11525.0 11537.5 11550.0 1.1.56.2.5 11575.0 11587.5 11600.0 11612.5 11625.0 11637.5 11650.0 11662.5 11675.0 11687.5 11700.0 11712.5 11725.0 11737.5 8274.0 8277.7 8281.3 8285.0 8288.6 8292.2 8295.8 8299.4 8302.9 8306.4 8309.9 8313.4 8316.8 8320.2 8323.6 8327.0 8330.3 8333.6 8336.9 8338.4 8340.0 8378.9 8382.0 8382.0 8386.9 8391.7 8396.6 8401.5 8406.4 8411.3 8416.1 8421.0 8426.3 8431.6 8436.9 8442.2 8447.5 8452.8 8458.1 8463.4 8468.7 8474.0 8479.3 8484.6 8490.0 8495.3 8500.6 8505.9 8511.2 8516.6 8521.9 5931.3N 1629.8E 10679.2 5935.5N 1624.6E 10683.9 5939.9N 1619.4E 10688.6 5944.3N 1614.2E 10693.3 5948.7N 1609.1E 10698.1 5953.2N 1604.0E 10702.8 5957.8N 1599.0E 10703.8 5962.4N 1594.0E 10708.7 5967.1N 1589.0E 10713.5 5971.8N 1584.1E 10718.3 5976.6N 1579.2E 10723.2 5981.4N 1574.3E 10728.0 5986.3N 1569.5E 10732.9 5991.3N 1564.7E 10737.7 5996.3N 1559.9E 10742.9 6001.4N 1555.2E 10742.9 6006.5N 1550.5E 10747.8 6011.7N 1545.9E 10752.8 6016.9N 1541.3E 10757.7 6019.5N 1539.1E 10760.7 6022.0N 1536.9E 10763.1 6085.9N 1482.4E 10808.5 6091.0N 1478.0E 10813.3 6091.0N 1478.0E 10813.4 6099.0N 1471.2E 10821.0 6107.0N 1464.4E 10828.7 6115.1N 1457.7E 10833.8 6123.2N 1451.1E 10841.5 6131.4N 1444.5E 10849.3 6139.6N 1437.9E 10857.2 6147.8N 1431.4E 10865.0 6156.1N 1424.9E 10871.3 6165.0N 1418.0E 10879.8 6174.0N 1411.1E 10888.3 6183.0N 1404.2E 10896.8 6192.1N 1397.5E 10904.5 6201,.2N 1390.7E 10913.0 6210.4N 1384.1E 10921.5 6219.6N 1377.5E 10928.8 6228.8N 1370.9E 10937.2 6238.1N 1364.4E 10945.7 6247.4N 1358.0E 10954.1 6256.7N 1351.6E 10960.8 6266.1N 1345.3E 10969.2 6275.5N 1339.0E 10977.7 8274.1 6043.1N 1148.3E 283.1 494.3 1031.1 8278.1 6045.5N 1148.9E 283.0 488.2* 1010.6 8282.1 6047.8N 1149.4E 282.9 482.2* 990.1' 8286.2 6050.1N 1150.0E 282.8 476.2* 969.6* 8290.3 6052.5N 1150.5E 282.8 470.2* 949.1' 8294.4 6054.8N llS1.0E 282.6 464.3* 928.6* 8295.3 6055.3N llSl.lE 282.3 458.4* 908.0* 8299.4 6057.7N 1151.7E 282.2 452.5* 887.6* 8303.6 6060.1N 1152.2E 282.0 446.6* 867.0* 8307.8 6062.5N 1152.7E 281.9 440.8* 846.5* 8312.0 6064.8N 1153.2E 281.7 435.0* 826.0* 8316.2 6067.2N 1153.7E 281.5 429.2* 805.7* 8320.4 6069.5N 1154.2E 281.3 423.5* 785.3* 8324.6 6071.9N 1154.7E 281.1 417.8' 765.2* 8329.2 6074.4N 1155.2E 280.9 412.2' 745.0* 8329.1 6074.4N 1155.2E 280.3 406.6* 724.9* 8333.4 6076.8N 1155.7E 280.1 401.0' 705.0* 8337.7 6079.1N 1156.2E 279.8 395.6* 685.1' 8342.0 6081.5N 1156.6E 279.5 390.1' 665.3* 8344.6 6082.9N 1156.8E 279.4 387.6* 655.9* 8346.7 6084.1N 1157.0E 279.3 385.0* 646.6* 8386.7 6105.4N l160.0E 273.5 323.1' 485.6* 8391.0 6107.7N 1160.2E 273.0 318.4' 474.8* 8391.0 6107.7N 1160.2E 273.0 318.4' 474.8* 8397.8 6111.3N 1160.6E 272.3 311.1' 455.6* 8404.6 6114.8N 1160.9E 271.5 303.9* 437.3* 8409.1 6117.1N 1161.2E 270.4 296.8* 419.9' 8416.0 6120.7N 1161.5E 269.5 289.9* 403.4* 8422.9 6124.3N 1161.8E 268.6 283.2* 387.7* 8429.8 6127.9N 1162.2E 267.6 276.6* 372.7* 8436.8 6131.5N 1162.5E 266.5 270.2* 358.3* 8442.4 6134.4N 1162.7E 265.3 264.0* 344.4* 8450.0 6138.2N 1163.0E 264.0 257.4* 329.9* 8457.6 6142.0N 1163..3E 262.6 251.2' 315.9' 8465.2 6145.8N 1163.6E 261.2 245.1' 302.5* 8472.0 6149.2N 1163.9E 259.6 239.4* 289.6* 8479.7 6152.9N 1.164.2E 258.0 233.9* 277.5* 8487.3 6t56.5N 1164.5E 256.2 228.7* 266.2* 8493.9 6159.7N 1164.7E 254.3 223.9* 255.9* 8501.6 6163.2N 1165.0E 252.3 219.4' 246.2* 8509.2 6166.8N 1165.3E 250.3 215.3' 237.3* 8517.0 6170.3N 1165.6E 248.2 211.6' 229.2* 8523.0 6173.0N 1165.9E 245.7 208.4* 221.8' 8530.7 6176.5N 1166.2E 243.4 205.5* 215.3' 8538.5 6179.9N 1166.4E 241.0 203.2* 209.7* 6285.0N 1332.8E 10986.2 8546.3 6183.3N 1166.7E 238.5 201.3' 205.2* 6294.5N 1326.7E 10992.6 8552.1 6185.9N 1166.9E 235.8 199.9' 201.8' 6304.0N 1320.6E 11001.2 8559.9 6189.3N 1167.1E 233.2 199.0' 199.6' 6313.6N 1314.5E 11009.7 8567.8 6192.8N 1167.3E 230.6 198.6' 198.7' 6323.2N 1308.5E 11018.3 8575.6 6196.2N 1167.5E 228.0 1.98.8 199.0 6332.8N 1302.6E 11025.0 8581.8 6198.8N 1167.6E 225.2 199.4 200.5 Ail data is in feet unless otherwise stated Casing dimensions are not included. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical seCtion is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum' curvature method.. Presented by Baker Hughes INTEQ Cross Timbers Operating Company CLEARANCE LISTING Page 11 A PLATFORM, A23-01LW Your ref : A23-01LW Version Middle Ground Shoals, Cook Inlet, Alaska Last revised : Il-Apr-2001 Reference wellpath Object wellpath : PMSS <l1540-12641'>,,A13-01,A PLATFORM Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 11750.0 8527.2 6342.5N 1296.8E 11033.5 8589.6 6202.2N 1167.8E 222.6 200.5 203.2 11762.5 11775.0 11787.5 11800.0 11812.5 11825.0 11837.5 11850.0 11862.5 11875.0 11887.5 11900.0 11912.5 11925.0 11937.5 11950.0 11962.5 11975.0 11987.5 12000.0 12012.5 12025.0 12037.5 12050.0 12062.5 12075.0 12087.5 12100.0 12112.5 12125.0 12137.5 12150.0 12162.5 12175.0 12187.5 12200.0 12212.5 12225.0 12237.5 12250.0 12262.5 12275.0 12287.5 12300.0 8532.5 8537.8 8543.2 8548.5 8553.8 8559.1 8564.5 8569.8 8575.1 8580.4 8585.7 8591.0 8596.4 8601.7 8607.0 8612.3 8617.6 8622.9 8628.2 8633.5 8638.8 8644.1 8649.4 8654.7 8660.0 8665.2 8670.5 8675.8 8681.1 8686.3 8691.6 8696.8 8702.1 8707.3 8712.6 8717.8 8723.0 8728.3 8733.5 8738.7 8743.9 8749.1 8754.3 8759.5 6352.2N 1291.0E 11042.1 8597.5 6205.5N 1168.0E 220.0 202.1 207.1 6361.9N 1285.2E 11050.7 8605.4 6208.8N 1168.2E 217.4 204.2 212.1 6371.7N 1279.5E 11057.3 8611.6 6211.4N 1168.3E 214.7 206.7 218.1 6381.5N 1273.9E 11065.9 8619.5 6214.6N 1168.5E 212.3 209.7 225.0 6391.3N 1268.3E 11074.4 8627.4 6217.9N 1168.7E 209.9 213.1 232.6 6401.2N 1262.8E 11083.0 8635.3 6221.1N 1168.9E 207.5 217.0 240.8 6411.1N 1257.4E 11089.3 8641.2 6223.4N 1169.0E 205.2 221.2 249.6 6421.1N 1252.0E 11097.8 8649.1 6226.6N 1169.2E 203.0 225.7 258.8 6431.1N 1246.6E 11106.3 8657.0 6229.7N 1169.4E 201.0 230.7 268.3 6441.1N 1241.4E 11113.8 8663.9 6232.5N 1169.6E 199.0 235.9 278.0 6451.1N 1236.2E 11122.3 8671.9 6235.6N 1169.8E 197.1 241.4 287.9 6461.2N 1231.0E 11130.8 8679.8 6238.7N l170.0E 195.3 247.2 298.0 6471.3N 1225.9E 11139.4 8687.7 6241.8N l170.1E 193.7 253.2 308.4 6481.4N 1220.9E 11147.9 8695.7 6244.9N 1170.3E 192.1 259.5 319.0 6491.6N 1215.9E 11157.0 8704.2 6248.3N 1170.5E 190.6 265.9 329.8 6501.8N 1211.0E 11165.6 8712.2 6251.4N 1170.6E 189.2 272.6 340.8 6512.0N 1206.2E 11174.3 8720.2 6254.6N 1170.8E 187.8 279.4 352.0 6522.3N 1201.4E 11182.9 8728.2 6257.8N 1170.9E 186.6 286.3 363.4 6532.6N 1196.7E 11191.5 8736.2 6260.9N l171.1E 185.4 293.4 375.0 6542.9N 1192.0E 11200.2 8744.3 6264.1N 1171.2E 184.3 300.7 386.7 6553.2N 1187.4E 11211.0 8754.3 6268.1N 1171.4E 183.2 308.0 398.6 6563.6N 1182.9E 11219.7 8762.4 6271.4N 1171.5E 182.2 315.5 410.4 6574.0N 1178.4E 11228.4 8770.5 6274.7N 1171.7E 181,3 323.0 422.3 6584.4N 1174.0E 11240.9 8782.0 6279.4N tt7t.9E 180.4 330.6 434.1 6594.9N 1169.6E 11249.7 8790.1 6282.8N 1172.1E 179.5 338.2 445.9 6605.4N 1165.3E 11258.5 8798.3 6286.2N 1172.3E 178.8 345.9 457.5 6615.9N l161.1E 11269.9 8808.7 6290.6N 1172.5E 178.0 353.6 469.1 6626.4N 1156.9E 11278.8 8816.9 6294.1N 1172.7E 177.3 361.4 480.4 6637.0N 1152.8E 11287.7 8825.1 6297.6N 1172.9E 176.6 369.3 491.5 6647.6N 1148.8E 11296.6 8833.3 6301.1N 1173.1E 176.0 377.2 502.4 6658.2N 1144.8E 11305.5 8841.5 6304.5N 1173.3E 175.4 385.2 513.2 6668.8N 1140.9E 11315.6 8850.8 6308.5N 1173.5E 174.8 393.2 523.7 6679.5N 1137.1E 11324.5 8859.0 6312.1N 1173.8E 174.3 401.3 534.2 6690.2N 1133.3E 11333.5 8867.2 6315.6N 1174.0E 173.8 409.4 544.4 6700.9N 1129.5E 11342.4 8875.5 6319.1N 1174.2E 173.3 417.5 554.4 6711.7N 1125.9E 11351.4 8883.7 6322.7N 1174.4E 172.9 425.7 564.3 6722.4N 1122.3E 11359.5 8891.1 6325.9N 1174.7E 172.5 433.9 573.7 6733..2N 1118.8E 1.1368.5 8899.4 6329.4.N 1174.9E 172.1 442.1. 583.0 6744.1N 1115.3E 11377.4 8907.6 6333.0N 1175.1E 171.7 450.4 592.0 6754.9N llll.9E 11386.4 8915.8 6336.5N 1175.4E 171.4 458.8 600.8 6765.8N 1108.5E 11395.4 8924.1 6340.0N 1175.6E 171.0 467.2 609.4 6776.6N 1105.3E 11404.3 8932.3 6343.5N 1175.8E 170.7 475.6 617.8 6787.5N 1102.0E 11410.0 8937.6 6345.7N 1176.0E 170.5 484.0 626.2 6798.5N 1098.9E 11418.9 8945.8 6349.2N 1176.2E 170.2 492.5 634.3 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PIJ~TFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska CLEARANCE LISTING Page 12 Your ref : A23-01LW Version #4 Last revised : il-Apr-2001 Reference wellpath Object wellpath : PMSS <7943 - l1992'>,,A14-01LN2,A PLATFORM M.D. T.V.D. Horiz Min'm TCyl Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 11725.0 8516.6 6323.2N 1308.5E 11512.1 8701.5 6241.3N 855.1E 259.8 496.5 570.0 11737.5 8521.9 6332.8N 1302.6E 11523.2 8705.1 6251.8N 854.7E 259.7 490.7* 560.3* 11750.0 11762.5 11775.0 11787.5 11800.0 11812.5 11825.0 11837.5 11850.0 11862.5 11875.0 11887.5 11900.0 11912.5 11925.0 11937.5 11950.0 11962.5 11975.0 11987.5 12000.0 12012.5 12025.0 12037.5 12050.0 12062.5 12075.0 12087.5 12100.0 12112.5 12125.0 12137.5 12150.0 12162.5 12175.0 12187.5 12200.0 12212.5 12225.0 12237.5 12250.0 12262.5 12275.0 12287.5 12300.0 12312.5 12325.0 12337.5 12350.0 8527.2 8532.5 8537.8 8543.2 8548.5 8553.8 8559.1 8564.5 8569.8 8575.1 8580.4 8585.7 8591.0 8596.4 8601.7 8607.0 8612.3 8617.6 8622.9 8628.2 8633.5 8638.8 8644.1 6342.5N 1296.8E 11534.3 8708.6 6262.3N 854.2E 259.7 485.0* 550.8* 6352.2N 1291.0E 11545.4 8712.2 6272.8N 853.8E 259.7 479.3* 541.6' 6361.9N 1285.2E 11557.7 8716.2 6284.5N 853.3E 259.8 473.6* 532.7* 6371.7N 1279.5E 11568.9 8719.8 6295.0N 852.9E 259.8 468.1' 524.0* 6381.5N 1273.9E 11580.1 8723.4 6305.6N 852.5E 259.8 462.5* 515.6' 6391.3N 1268.3E 11591.3 8727.1 6316.2N 852.1E 259.8 457.1' 507.6* 6401.2N 1262.8E 11602.6 8730.8 6326.8N 851.8E 259.7 451.6' 500.0* 6411.1N 1257.4E 11612.6 8734.1 6336.3N 851.4E 259.6 446.3* 492.6* 6421.1N 1252.0E 11624.0 8737.9 6347.0N 851.0E 259.5 441.0' 485.6* 6431.1N 1246.6E 11635.3 8741.6 6357.7N 850.6E 259.5 435.8* 478.7* 6441.1N 1241.4E 11643.2 8744.1 6365.2N 850.2E 259.0 430.8* 472.0* 6451.1N 1236.2E 11654.7 8747.8 6376.1N 849.7E 259.0 425.8* 465.4* 6461.2N 1231.0E 11666.2 8751.5 6386.9N 849.1E 259.0 420.9* 458.8* 6471.3N 1225.9E 11674.4 8754.1 6394.7N 848.6E 258.5 416.1' 452.4* 6481.4N 1220.9E 11686.0 8757.8 6405.6N 847.9E 258.5 411.3' 446.1' 6491.6N 1215.9E 11698.1 8761.6 6417.2N 847.2E 258.6 406.7* 439.8* 6501.8N 1211.0E 11709.7 8765.2 6428.2N 846.4E 258.6 402.2* 433.7* 6512.0N 1206.2E 11721.4 8768.9 6439.2N 845.7E 258.6 397.6* 427.7* 6522.3N 1201.4E 11737.3 8773.9 6454.2N 844.9E 259.2 393.1' 421.7' 6532.6N 1196.7E 11748.9 8777.6 6465.3N 844.4E 259.2 388.5* 415.9' 6542.9N 1192.0E 11764.7 8782.7 6480.2N 843.7E 259.8 384.0* 410.1' 6553.2N 1187.4E 11776.3 8786.4 6491.2N 843.3E 259.8 379.5* 404.5* 6563.6N 1182.9E 11792.0 8791.5 6506.0N 842.9E 260.4 375.0* 399.1' 8649.4 6574.0N 1178.4E 11803.6 8795.3 6517.0N 842.6E 260.4 370.5* 393.8* 8654.7 6584.4N 1174.0E 11815.3 8799.1 6528.0N 842.4E 260.3 366.0* 388.7* 8660.0 6594.9N 1169.6E 11830.8 8804.1 6542.7N 842.2E 260.9 361.6' 383.7* 8665.2 6605.4N 1165.3E 11842.4 8807.9 6553.7N 842.1E 260.9 357.1' 378.9* 8670.5 6615.9N l161.1E 11857.8 8812.9 6568.2N 842.1E 261.5 352.6* 374.2* 8675.8 6626.4N 1156.9E 11869.5 8816.7 6579.3N 842.1E 261.5 348.2* 369.4* 8681.1 6637.0N 1152.8E 11881.2 8820.5 6590.3N 842.1E 261.5 343.8* 364.6* 8686.3 6647.6N 1148.8E 11894.6 8824.9 6603.0N 842.3E 261.7 339.3* 359.9* 8691.6 6658.2N 1144.8E 11906.3 8828.7 6614.1N 842.4E 261.7 335.0* 355.1' 8696.8 6668.8N 1140.9E 11917.9 8832.4. 6625.1N 842.5E 261.7 330.7* 350.4* 8702.1 6679.5N 1137.1E 11929.7 8836.2 6636.2N 842.5E 261.6 326.5* 345.6* 8707.3 6690.2N 1133.3E 11941.4 8839.9 6647.4N 842.6E 261.6 322.3* 340.9* 8712.6 6700.9N 1129.5E 11953.2 8843.7 6658.6N 842.7E 261.6 318.3' 336.2* 8717.8 6711.7N 1125.9E 11965.1 8847.4 6669.8N 842.7E 261.6 314.2' 331.5' 8723.0 6722.4N 1122.3E 11976.9 8851.2 6681.0N 842.8E 261.6 310.3' 326.9* 8728.3 8733.5 8738.7 8743.9 8749.1 8754.3 8759.5 8764.7 8769.8 8775.0 8780.2 6733.2N 1118.8E 11988.8 8855.0 6692.3N 842.8E 261.6 306.4* 322.2* 6744.1N 1115.3E 11992.0 8856.0 6695.3N 842.9E 259.9 302.7* 317.6' 6754.9N llll.9E 11992.0 8856.0 6695.3N 842.9E 257.5 299.5* 313.1' 6765.8N 1108.5E 11992.0 8856.0 6695.3N 842.9E 255.2 296.8* 308.7* 6776.6N 1t05.3E 11992.0 8856.0 6695.3N 842.9E 252.8 294.8* 304.4* 6787.5N 1102.0E 11992.0 8856.0 6695.3N 842.9E 250.4 293.3* 300.2* 6798.5N 1098.9E 11992.0 8856.0 6695.3N 842,9E 248.1 292.4* 296.1' 6809.4N 1095.8E 11992.0 8856.0 6695.3N 842.9E 245.7 292.1' - 6820.4N 1092.8E 11992..0 8856.0 6695.3N 842.9E 243.4 292.5 - 6831.4N 1089.8E 11992.0 8856.0 6695.3N 842.9E 241.2 293.4 - 6842.4N 1086.9E 11992.0 8856.0 6695.3N 842.9E 238.9 294.9 - Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska M.D. 12362.5 12375.0 12387.5 CLEARANCE LISTING Page 13 Your ref : A23-01LW Version #4 Last revised : il-Apr-2001 Reference wellpath Object wellpath : PMSS <7943 - l1992'>,,A14-01LN2,A PLATFORM T.V.D. Horiz Min'm TCyl Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 8785.3 6853.4N 1084.1E 11992.0 8856.0 6695.3N 842.9E 236.8 297.0 8790.5 6864.5N 1081.4E 11992.0 8856.0 6695.3N 842.9E 234.7 299.6 8795.6 6875.5N 1078.7E 11992.0 8856.0 6695.3N 842.9E 232.6 302.9 12400.0 12412.5 12425.0 12437.5 12450.0 12462.5 12475.0 12487.5 12500.0 12512.5 12525.0 12537.5 12550.0 12562.5 12575.0 12587.5 12600.0 12612.5 12625.0 12637.5 12650.0 12662.5 12675.0 12687.5 8800.7 8805.9 8811.0 8816.1 8821.2 8826.3 8831.4 8836.4 8841.5 8846.6 8851.6 8856.6 8861.7 8866.7 8871.7 8876.7 8881.7 8886.7 8891.6 8896.6 8901.5 8906.5 8911.4 8916.3 6886.6N 1076.0E 11992.0 8856.0 6695.3N 842.9E 230.6 306.6 6897.7N 1073.5E 11992.0 8856.0 6695.3N 842.9E 228.7 310.9 6908.9N 1071.0E 11992.0 8856.0 6695.3N 842.9E 226.9 315.7 6920.0N 1068.5E 11992.0 8856.0 6695.3N 842.9E 225.1 320.9 6931.2N 1066.2E 11992.0 8856.0 6695.3N 842.9E 223.4 326.7 6942.4N 1063.9E 11992.0 8856.0 6695.3N 842.9E 221.8 332.8 6953.6N 1061.6E 11992.0 8856.0 6695.3N 842.9E 220.3 339.3 6964.8N 1059.4E 11992.0 8856.0 6695.3N 842.9E 218.8 346.3 6976.0N 1057.3E 11992.0 8856.0 6695.3N 842.9E 217.4 353.5 6987.3N 1055.3E 11992.0 8856.0 6695.3N 842.9E 216.0 361.2 6998.5N 1053.3E 11992.0 8856.0 6695.3N 842.9E 214.8 369.1 7009.8N 1051.4E 11992.0 8856.0 6695.3N 842.9E 213.6 377.3 7021.1N 1049.6E 11992.0 8856.0 6695.3N 842.9E 212.4 385.8 7032.4N 1047.8E 11992.0 8856.0 6695.3N 842.9E 211.3 394.6 7043.7N 1046.1E 11992.0 8856.0 6695.3N 842.9E 210.3 403.6 7055.1N 1044.4E 11992.0 8856.0 6695.3N 842.9E 209.3 412.9 7066.4N 1042.8E 11992.0 8856.0 6695.3N 842.9E 208.3 422.3 7077.8N 1041.3E 11992.0 8856.0 6695.3N 842.9E 207.4 432.0 7089.2N 1039.9E 11992.0 8856.0 6695.3N 842.9E 206.6 441.8 7100.5N 1038.5E 11992.0 8856.0 6695.3N 842.9E 205.8 451.8 7112.0N 1037.2E 11992.0 8856.0 6695.3N 842.9E 205.0 462.0 7123.4N 1035.9E 11992.0 8856.0 6695.3N 842.9E 204.3 472.3 7134.8N 1034.7E 11992.0 8856.0 6695.3N 842.9E 203.6 482.7 7146.2N 1033.6E ].1992.0 8856.0 6695.3N 842.9E 202.9 493.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot %4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska Reference wellpath M.D. T.V.D. Rect Coordinates 9675.0 7393.9 5176.1N 2483.3E 9681.3 7398.9 5179.9N 2483.2E 9687.5 7403.9 5183.6N 2483.1E 9693.8 7408.9 5187.4N 2482.9E CLEARANCE LISTING Page 14 Your ref : A23-01LW Version 94 Last revised : il-Apr-2001 Object wellpath : MSS <0-11202'>,,A23-01,A PLATFORM Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates Bearing Dist Dist 9646.4 7475.9 5014.7N 2443.0E 194.0 185.5 188.3 9651.5 7480.5 5016.9N 2443.1E 193.8 186.6 189.4 9657.7 7486.0 5019.7N 2443.3E 193.7 187.6 190.4 9663.8 7491.5 5022.4N 2443.4E 193.5 188.7 191.5 9700.0 7413.9 519t.lN 2482.7E 9670.0 7497.0 5025.1N 2443.5E 193.3 189.7 192.6 9707.7 7420.0 5195.8N 2482.4E 9677.5 7503.7 5028.5N 2443.7E 193.0 191.0 193.9 9715.4 7426.2 5200.4N 2482.0E 9685.0 7510.5 5031.8N 2443.8E 192.7 192.3 195.2 9723.1 7432.3 5205.0N 2481.5E 9692.6 7517.2 5035.1N 2444.0E 192.5 193.6 196.6 9730.8 7438.4 5209.7N 2480.9E 9699.0 7523.0 5038.0N 2444.1E 192.1 194.9 197.9 9738.5 7444.5 5214.3N 2480.3E 9706.5 7529.8 5041.3N 2444.2E 191.8 196.2 199.2 9746.2 7450.6 5219.0N 2479.6E 9714.0 7536.5 5044.6N 2444.3E 191.5 197.5 200.6 9753.8 7456.7 5223.6N 2478.8E 9721.5 7543.2 5047.9N 2444.4E 191.1 198.9 201.9 9761.5 7462.8 5228.2N 2478.0E 9729.0 7550.0 5051.2N 2444.5E 190.7 200.2 203.3 9769.2 7468.8 5232.9N 2477.1E 9736.5 7556.7 5054.5N 2444.5E 190.3 201.5 204.6 9776.9 7474.9 5237.5N 2476.1E 9744.0 7563.4 5057.8N 2444.6E 189.9 202.8 206.0 9784.6 7480.9 5242.2N 2475.0E 9751.2 7569.9 5061.0N 2444.7E 189.5 204.1 207.3 9792.3 7487.0 5246.8N 2473.9E 9758.7 7576.6 5064.2N 2444.7E 189.1 205.5 208.7 9800.0 7493.0 5251.4N 2472.7E 9766.1 7583.3 5067.5N 2444.8E 188.6 206.8 210.1 9807.7 7499.0 5256.1N 2471.5E 9773.5 7589.9 5070.8N 2444.8E 188.2 208.1 211.5 9815.4 7505.0 5260.7N 2470.1E 9781.0 7596.6 5074.0N 2444.8E 187.7 209.5 212.8 9823.1 7511.0 5265.3N 2468.7E 9788.4 7603.2 5077.3N 2444.9E 187.2 210.8 214.2 9830.8 7516.9 5270.0N 2467.2E 9795.8 7609.9 5080.5N 2444.9E 186.7 212.2 215.6 9838.5 7522.9 5274.6N 2465.7E 9803.9 7617.2 5084.1N 2444.9E 186.2 213.5 217.0 9846.2 7528.8 5279.2N 2464.0E 9811.2 7623.8 5087.4N 2444.9E 185.7 214.9 218.5 9853.8 7534.7 5283.8N 2462.4E 9818.6 7630.4 5090.7N 2444.8E 185.2 216.2 219.9 9861.5 7540.6 5288.4N 2460.6E 9825.9 7636.9 5093.9N 2444.8E 184.6 217.6 221.4 9869.2 7546.5 5293.0N 2458.8E 9833.3 7643.5 5097.2N 2444.8E 184.1 219.0 222.9 9876.9 7552.4 5297.6N 2456.9E 9840.6 7650.0 5100.4N 2444.7E 183.5 220.4 224.4 9884.6 7558.2 5302.2N 2454.9E 9847.8 7656.6 5103.7N 2444.7E 182.9 221.8 225.9 9892.3 7564.1 5306.8N 2452.8E 9856.0 7663.9 5107.3N 2444.6E 182.4 223.2 227.4 9900.0 7569.9 5311.4N 2450.7E 9863.3 7670.4 5110.5N 2444.6E 181.8 224.7 229.0 9907.7 7575.7 5315.9N 2448.5E 9870.5 7676.9 5113.8N 2444.5E 181.1 226.1 230.6 9915.4 7581.4 5320.5N 2446.3E 9877.7 7683.3 5117.0N 2444.4E 180.5 227.6 232.2 9923.1 7587.2 5325.1N 2444.0E 9885.0 7689.8 5120.2N 2444.3E 179.9 229.1 233.9 9930.8 7592.9 5329.6N 2441.6E 9892.1 7696.2 5123.4N 2444.2E 179.3 230.6 235.6 9938.5 7598.6 5334.1N 2439.1E 9899.3 7702.6 5126.7N 2444.1E 178.6 232.1 237.3 9946.2 7604.3 5338.7N 2436.6E 9907.5 7709.9 5130.3N 2444.0E 178.0 233.7 239.1 9953.8 7610.0 5343.2N 2434.0E 9914.6 7716.3 5133.6N 2443.9E 177.3 235.3 240.9 9961.5 7615.6 5347.7N 2431.4E 9921.7 7722.6 5136.8N 2443.8E 176.6 236.9 242.7 9969.2 7621.2 5352.2N 2428.6E 9928.8 7729.0 5140.0N 2443.6E 176.0 238.5 244.6 9976.9 7626.8 5356.7N 2425.8E 9935.9 7735.3 5143.2N 2443.5E 175.3 240.1 246.5 9984.6 7632.4 5361.1N 2423.0E 9942.9 7741.5 5146.3N 2443.4E 174.6 241.8 248.5 9992.3 7637.9 5365.6N 2420.1E 9950.0 7747.8 5149.5N 2443.2E 173.9 243.5 250.5 10000.0 7643.4 5370.1N 2417.1E 9958.7 7755.5 5153.4N 2443.0E 173.2 245.3 252.5 10007.7 7648.9 5374.5N 2414.0E 9965.7 7761.8 5156.6N 2442.8E 172.5 247.1 254.6 10015.4 7654.4 5378.9N 2410.9E 9972.6 7768.0 5159.8N 2442.6E 171.7 248.9 256.7 10023.1 7659.8 5383.3N 2407.7E 9979.6 7774.1 5163.0N 2442.5E 171.0 250.7 258.9 10030.8 7665.2 5387.7N 2404.4E 9986.5 7780.3 5166.1N 2442.2E 170.3 252.6 261.2 10038.5 7670.6 5392.1N 2401.1E 9993.3 7786.4 5169.3N 2442.0E 169.6 254.5 263.4 10046.2 7675.9 5396.5N 2397.7E 10002.6 7794.6 5173.5N 2441.7E 168.8 256.4 265.8 10053.8 7681.3 5400.8N 2394.3E 10009.5 7800.7 5176.7N 2441.5E 168.1 258.3 268.2 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska CLEARANCE LISTING Page 15 Your ref : A23-01LW Version Last revised : il-Apr-2001 Reference wellpath Object wellpath : MSS <0-11202'>,,A23-01,A PLATFORM M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm TCyl Rect Coordinates Bearing Dist Dist 10061.5 7686.5 5405.2N 2390.7E 1001.6.3 7806.8 5179.9N 2441.2E 1.67.4 260.3 270.7 10069.2 7691.8 5409.5N 2387.2E 10023.1 7812.8 5183.0N 2441.0E 166.6 262.4 273.2 10076.9 7697.0 5413.8N 2383.5E 10029.9 7818.8 5186.1N 2440.7E 165.9 264.4 275.8 10084.6 7702.2 5418.1N 2379.8E 10036.6 7824.8 5189.3N 2440.4E 165.2 266.5 278.5 10092.3 7707.4 5422.4N 2376.0E 10046.1 7833.]. 5193.7N 2440.0E 164.4 268.7 281.2 10100.0 10107.7 10115.4 10123.1 10130.8 10138.5 10146.2 10153.8 10161.5 10169.2 10176.9 10184.6 10192.3 10200.0 10207.7 10215.4 10223.1 10230.8 10238.5 10246.2 10253.8 10261.5 10269.2 10276.9 10284.6 10292.3 10300.0 10306.9 10313.7 10320.6 10327.4 10334.3 10400.0 10500.0 7712.5 5426.6N 2372.2E 10052.8 7839.0 5196.8N 7717.6 5430.8N 2368.3E 10059.5 7844.9 5199.9N 7722.7 5435.1N 2364.4E 10066.1 7850.8 5203.1N 7727.8 5439.3N 2360.4E 10072.7 7856.6 5206.2N 7732.8 5443.5N 2356.3E 10079.3 7862.4 5209.3N 7737.7 7742.7 7747.6 7752.4 7757.3 7762.1 7766.8 7771.5 7776.2 7780.9 7785.5 7790.0 7794.6 7799.0 7803.5 7807.9 7812.3 7816.6 7820.9 7825.1 7829.3 7833.5 7837.1 7840.8 7844.4 7847.9 7851.5 7885.1 7936.3 5447.6N 5451.8N 5455.9N 5460.0N 5464.1N 5468.1N 5472.2N 5476.2N 5480.2N 5484.2N 5488.1N 5492.1N 5496.0N 5499.8N 5503.7N 5507.5N 5511.4N 5515.1N 5518.9N 5522.6N 5526.3N 5530.0N 5533.3N 5536.5N 5539.7N 2352.1E 10088.9 7870.8 5213.8N 2347.9E 10095.4 7876.6 5216.9N 2343.7E 10101.9 7882.3 5220.0N 2339.4E 10108.4 7888.0 5223.1N 2335.0E 10114.9 7893.6 5226.2N 2330.5E 10121.3 7899.3 5229.2N 2326.0E 10131.0 7907.7 5233.9N 2321.5E 10137.4 7913.3 5236.9N 2316.9E 10143.7 7918.9 5240.0N 23t2.2E 10150.0 7924.4 5243.0N 2307.5E 10156.3 7929.8 5246.1N 2302.7E 10162.5 7935.3 5249.1N 2297.9E 10168.7 7940.7 5252.1N 2293.0E 10176.3 7947.3 5255.8N 2288.0E 10182.4 7952.6 5258.7N 2283.0E 10188.6 7957.9 5261.7N 2278.0E 10194.6 7963.2 5264.6N 2272.8E 10200.6 7968.5 5267.5N 2267.7E 10206.6 7973.7 5270.4N 2262.5E 10212.5 7978.9 5273.3N 2439.7E 163.6 270.8 284.0 2439.4E 162.9 273.1 286.9 2439.0E 162.2 275.3 289.9 2438.7E 161.4 277.6 292.9 2438.3E 160.7 280.0 296.1 2437.8E 159.9 282.4 299.3 2437.5E 159.1 284.8 302.7 2437.1E 158.4 287.3 306.2 2436.7E 157.7 289.8 309.8 2436.3E 156.9 292.3 313.6 2435.9E 156.2 295.0 317.5 2435.3E 155.4 297.6 321.6 2434.8E 154.7 300.3 325.8 2434.4E 153.9 303.1 330.1 2434.0E 153.2 305.9 334.6 2433.5E 152.5 308.7 339.2 2433.0E 151.8 311.7 344.0 2432.6E 151.1 314.6 349.0 2432.0E 150.3 317.6 354.1 2431.5E 149.6 320.7 359.4 2431.0E 148.9 323.8 364.8 2430.5E 148.3 327.0 370.4 2430.0E 147.6 330.3 376.2 2429.5E 146.9 333.6 382.2 2429.0E 146.3 337.0 388.3 2257.2E 10217.9 7983.6 5275.8N 2428.6E 145.6 340.5 394.7 2251.9E 10223.8 7988.7 5278.6N 2428.0E 145.0 34.4.0 401.2 2247.1E 10229.0 7993.3 5281.1N 2427.6E 144,4 347.2 407.2 2242.2E 10234.2 7997.8 5283.6N 2427.1E 143.8 350.4 413.4 2237.4E 10239.3 8002.3 5286.0N 2426.6E 143.3 353.7 419.7 5542.9N 2232.5E 10244.4 8006.7 5288.4N 2426.1E 142.7 357.1 426.2 5546.1N 2227.5E 10249.5 8011.2 5290.8N 2425.6E 142.2 360.4 432.9 5576.4N 2179.9E 10297.8 8053.6 5313.5N 2420.7E 137.5 394.3 482.3 5622.5N 2107.4E 10373.3 8120.1 5347.9N 2411.7E 132.1 449.1 561.1 M.D. 9675.0 9681.3 9687.5 9693.8 9700.0 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals,Cook Inlet, Alaska CLEARANCE LISTING Page 16 Your ref : A23-01LW Version #4 Last revised : Il-Apr-2001 Reference wellpath Object wellpath : MSS <8177-11550'>,,A23-01RD,A PLATFORM T .V.D. Horiz Min'm TCyl Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 7393.9 7398.9 7403.9 7408.9 7413.9 5176.1N 2483.3E 9675.0 7393.9 5176.1N 2483.3E 270.0 0.0 0.0 5179.9N 2483.2E 9681.2 7398.9 5179.9N 2483.3E 93.7 0.0 0.0 5183.6N 2483.1E 9687.5 7403.9 5183.6N 2483.2E 93.7 0.1 0.1 5187.4N 2482.9E 9693.7 7408.9 5187.4N 2483.1E 93.7 0.2 0.2 5191.1N 2482.7E 9700.0 7413.9 5191.1N 2483.1E 93.7 0.3 0.3 9707.7 7420.0 9715.4 7426.2 9723.1 7432.3 9730.8 7438.4 9738.5 7444.5 9746.2 7450.6 9753.8 7456.7 9761.5 7462.8 9769.2 7468.8 9776.9 7474.9 9784.6 7480.9 9792.3 7487.0 9800.0 7493.0 9807.7 7499.0 9815.4 7505.0 9823.1 7511.0 9830.8 7516.9 9838.5 7522.9 9846.2 7528.8 9853.8 7534.7 9861.5 7540.6 9869.2 7546.5 9876.9 7552.4 9884.6 7558.2 9892.3 7564.1 9900.0 7569.9 9907.7 7575.7 9915.4 7581.4 9923.1 7587.2 9930.8 7592.9 9938.5 7598.6 9946.2 7604.3 9953.8 7610.0 9961.5 7615.6 9969.2 7621.2 9976.9 7626.8 9984.6 7632.4 9992.3 7637.9 10000.0 7643.4 10007.7 7648.9 10015.4 7654.4 10023.1 7659.8 10030.8 7665.2 10038.5 7670.6 10046.2 7675.9 10053.8 7681.3 5195.8N 2482.4E 9707.7 7420.1 5195.7N 2483.0E 93.4 0.6 0.6 5200.4N 2482.0E 9715.4 7426.2 5200.4N 2482.8E 93.4 0.9 0.9 5205.0N 2481.5E 9723.1 7432.4 5205.0N 2482.7E 93.4 1.2 1.2 5209.7N 2480.9E 9730.7 7438.5 5209.6N 2482.6E 93.4 1.7 1.7 5214.3N 2480.3E 9738.4 7444.6 5214.2N 2482.5E 93.4 2.2 2.2 5219.0N 2479.6E 9746.1 7450.8 5218.8N 2482.3E 93.4 2.7 2.7 5223.6N 2478.8E 9753.8 7456.9 5223.4N 2482.1E 93.4 3.3 3.3 5228.2N 2478.0E 9761.5 7463.1 5228.0N 2482.0E 93.1 4.0 4.0 5232.9N 2477.1E 9769.1 7469.2 5232.6N 2481.8E 93.1 4.7 4.8 5237.5N 2476.1E 9776.8 7475.3 5237.2N 2481.6E 93.1 5.5 5.6 5242.2N 2475.0E 9784.4 7481.4 5241.8N 2481.4E 93.1 6.4 6.5 5246.8N 2473.9E 9792.0 7487.5 5246.4N 2481.2E 93.1 7.3 7.4 5251.4N 2472.7E 9799.7 7493.6 5251.0N 2481.0E 93.1 8.3 8.4 5256.1N 2471.5E 9807.3 7499.7 5255.6N 2480.8E 93.1 9.4 9.5 5260.7N 2470.1E 9814.9 7505.8 5260.1N 2480.6E 93.1 10.5 10.6 5265.3N 2468.7E 9822.6 7511.9 5264.8N 2480.3E 92.7 11.7 11.8 5270.0N 2467.2E 9830.2 7518.0 5269.3N 2480.1E 92.7 12.9 13.1 5274.6N 2465.7E 9837.8 7524.0 5273.9N 2479.8E 92.7 14.2 14.5 5279.2N 2464.0E 9845.4 7530.1 5278.5N 2479.6E 92.7 15.6 15.8 5283.8N 2462.4E 9852.9 7536.1 5283.0N 2479.3E 92.6 17.0 17.3 5288.4N 2460.6E 9860.5 7542.1 5287.6N 2479.0E 92.6 18.5 18.8 5293.0N 2458.8E 9868.0 7548.1 5292.1N 2478.7E 92.6 20.0 20.4 5297.6N 2456.9E 9875.8 7554.3 5296.8N 2478.3E 92.1 21.6 22.1 5302.2N 2454.9E 9883.3 7560.3 5301.4N 2478.0E 92.0 23.2 23.8 5306.8N 2452.8E 9890.9 7566.3 5305.9N 2477.6E 92.0 24.9 25.6 5311.4N 2450.7E 9898.4 7572.2 5310.5N 2477.3E 91.9 26.7 27.4 5315.9N 2448.5E 9905.8 7578.2 5315.0N 2476.9E 91.9 28.5 29.3 5320.5N 2446.3E 9913.3 7584.1 5319.5N 2476.5E 91.9 30.3 31.3 5325.1N 2444.0E 9920.7 7590.0 5324.0N 2476.1E 91.8 32.3 33.3 5329.6N 2441.6E 9928.6 7596.2 5328.8N 2475.7E 91.3 34.2 35.5 5334.1N 2439.1E 9936.0 7602.1 5333.3N 2475.2E 91.3 36.3 37.6 5338.7N 2436.6E 9943.4 7608.0 5337.8N 2474.8E 91.2 38.4 39.9 5343.2N 2434.0E 9950.8 7613.8 5342.3N 2474.3E 91.2 40.5 42.2 5347.7N 2431.4E 9958.2 7619.7 5346.8N 2473.9E 91.2 42.7 44.6 5352.2N 2428.6E 9965.5 7625.5 5351.3N 2473.4E 91.1 45.0 47.1 5356.7N 2425.8E 9972.9 7631.2 5355.8N 2472.9E 91.1 47.3 49.6 5361.1N 2423.0E 9980.8 7637.5 5360.6N 2472.3E 90.6 49.6 52.2 5365.6N 2420.1E 9988.1 7643.3 5365.1N 2471.8E 90.6 52.1 54.9 5370.1N 2417.1E 9995.4 7649.0 5369.5N 2471.3E 90.5 54.5 57.6 5374.5N 2414.0E 10002.7 7654.8 5374.0N 2470.8E 90.5 57.1 60.5 5378.9N 2410.9E 10009.9 7660.5 5378.4N 2470.2E 90.5 59.7 63.4 5383.3N 2407.7E 10017.1 7666.1 5382.8N 2469.7E 90.5 62.3 66.4 5387.7N 2404.4E 10024.3 7671.8 5387.2N 2469.1E 90.4 65.0 69.4 5392.1N 2401.1E 10032.4 7678.1 5392.2N 2468.4E 89.9 67.8 72.6 5396.5N 2397.7E 10039.6 7683.7 5396.6N 2467.8E 89.9 70.6 75.8 5400.8N 2394.3E 10046.7 7689.4 5401.0N 2467.2E 89.9 73.4 79.1 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Cross Timbers Operating Company A PLATFORM, A23-01LW Middle Ground Shoals, Cook Inlet, Alaska CLEARANCE LISTING Page 17 Your ref : A23-01LW Version #4 Last revised : il-Apr-2001 Reference wellpath Object wellpath : MSS <8177-11550'>,,A23-01RD,A PLATFORM M.D. T.V.D. Horiz Min'm TCyl Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 10061.5 7686.5 5405.2N 2390.7E 10053.8 7694.9 5405.3N 2466.6E 89.9 76.3 82.5 10069.2 7691.8 5409.5N 2387.2E 10060.9 7700.5 5409.7N 2466.0E 89.8 79.3 85.9 10076.9 7697.0 5413.8N 2383.5E 10068.0 7706.0 5414.1N 2465.4E 89.8 82.3 89.5 10084.6 7702.2 5418.1N 2379.8E 10075.0 7711.6 5418.4N 2464.7E 89.8 85.4 93.1 10092.3 7707.4 5422.4N 2376.0E 10083.2 7717.9 5423.4N 2463.9E 89.3 88.5 96.9 10100.0 7712.5 5426.6N 2372.2E 10090.2 7723.4 5427.7N 2463.3E 89.3 91.7 100.7 10107.7 7717.6 10115.4 7722.7 10123.1 7727.8 10130.8 7732.8 10138.5 7737.7 10146.2 7742.7 10153.8 7747.6 10161.5 7752.4 10169.2 7757.3 10176.9 7762.1 10184.6 7766.8 10192.3 7771.5 10200.0 7776.2 10207.7 7780.9 10215.4 7785.5 10223.1 7790.0 10230.8 7794.6 10238.5 7799.0 10246.2 7803.5 10253.8 7807.9 10261.5 7812.3 10269.2 7816.6 10276.9 7820.9 10284.6 7825.1 10292.3 7829.3 10300.0 7833.5 10306.9 7837.1 10313.7 7840.8 10320.6 7844.4 10327.4 7847.9 10334.3 7851.5 10400.0 7885.1 10500.0 7936.3 10600.0 7987.6 10700.0 8038.8 10800.0 8090.0 5430.8N 2368.3E 10097.2 7728.9 5432.0N 2462.6E 89.3 95.0 104.6 5435.1N 2364.4E 10104.2 7734.3 5436.3N 2461.9E 89.3 98.2 108.6 5439.3N 2360.4E 10111.1 7739.7 5440.6N 2461.2E 89.2 101.6 112.7 5443.5N 2356.3E 10118.0 7745.1 5444.9N 2460.5E 89.2 105.0 116.8 5447.6N 2352.1E 10124.9 7750.4 5449.1N 2459.8E 89.2 108.4 121.1 5451.8N 2347.9E 10133.1 7756.9 5454.2N 2458.9E 88.7 111.9 125.5 5455.9N 2343.7E 10140.0 7762.2 5458.5N 2458.2E 88.7 115.5 130.0 5460.0N 2339.4E 10146.8 7767.5 5462.7N 2457.5E 88.7 119.1 134.5 5464.1N 2335.0E 10153.6 7772.8 5466.9N 2456.7E 88.7 122.7 139.2 5468.1N 2330.5E 10160.3 7778.0 5471.1N 2456.0E 88.7 126.5 144.0 5472.2N 2326.0E 10167.0 7783.2 5475.2N 2455.2E 88.6 130.2 148.8 5476.2N 2321.5E 10173.7 7788.4 5479.4N 2454.4E 88.6 134.0 153.8 5480.2N 2316.9E 10180.3 7793.5 5483.5N 2453.6E 88.6 137.9 158.9 5484.2N 2312.2E 10188.7 7800.1 5488.7N 2452.6E 88.1 141.8 164.1 5488.1N 2307.5E 10195.4 7805.2 5492.8N 2451.8E 88.1 145.8 169.4 5492.1N 2302.7E 10201.9 7810.3 5496.9N 2451.0E 88.1 149.8 174.8 5496.0N 2297.9E 10208.5 7815.3 5501.0N 2450.2E 88.1 153.9 180.4 5499.8N 2293.0E 10215.0 7820.3 5505.0N 2449.4E 88.1 158.0 186.0 5503.7N 2288.0E 10221.4 7825.3 5509.1N 2448.6E 88.1 162.1 191.8 5507.5N 2283.0E 10227.9 7830.3 5513.1N 2447.8E 88.1 166.4 197.7 5511.4N 2278.0E 10234.2 7835.2 5517.1N 2446.9E 88.1 170.6 203.7 5515.1N 2272.8E 10242.8 7841.8 5522.4N 2445.8E 87.6 175.0 209.9 5518.9N 2267.7E 10249.2 7846.7 5526.4N 2445.0E 87.6 179.3 216.2 5522.6N 2262.5E 10255.5 7851.6 5530.3N 2444.1E 87.6 183.7 222.6 5526.3N 2257.2E 10261.8 7856.4 5534.2N 2443.3E 87.6 188.2 229.2 5530.0N 2251.9E 10268.0 7861.2 5538.1N 2442.4E 87.6 192.7 235.9 5533.3N 2247.1E 10273.5 7865.4 5541.6N 2441.6E 87.6 196.8 242.0 5536.5N 2242.2E 10279.0 7869.6 5545.0N 2440.8E 87.5 200.9 248.2 5539.7N 2237.4E 10284.5 7873.8 5548.4N 2440.1E 87.5 205.0 254.5 5542.9N 2232.5E 10292.2 7879.7 5553.3N 2439.0E 87.1 209.2 261.0 5546.1N 2227.5E 10297.6 7883.9 5556.7N 2438.2E 87.1 213.4 267.6 5576.4N 2179.9E 10351.7 7925.5 5590.3N 2429.9E 86.8 253.7 314.6 5622.5N 2107.4E 10436.9 7991.5 5642.3N 2415.7E 86.3 313.8 383.0 5668.6N 2034.9E 10524.2 8059.6 5694.3N 2399.3E 86.0 372.3 448.5 5714.7N 1962.5E 10613.3 8129.6 5746.2N 2381.0E 85.7 429.4 511.1 5760.8N 1890.0E 10703.4 8199.6 5799~5N 2361.0E 85.3 485.1 571.0 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~4-32 and TVD from rotary table (116.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 312.96 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ WELL PERMIT' CHECKLIST t COMPANY FIELD & POOL_5'.~ ~//'. ,)"/'~.~ ~,'//~ INIT CLAS~. WELL NAME 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 ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in drilling unit ............ 8. If deviated, is wellbore 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 ........... ENGINEERING GEOLOGY 14. Conductor stdng 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 pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed. ' 23. If diverter required, does it meet regulations .......... 24~ Ddlling .fluid program schematic & equip list adequate .... . 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .~{~ osig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. 29. 30. 31. 32. 33. 34. PROGRAM: exp dev ~ redrll serv. wellbore seg ann. disposal para req ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... APPR DATE (B) will not contaminate freshwater; or cause ddlling waste... to surface; ' (C) will not impair mechaniCal integrity of the well used for diSposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20AAC 25..252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UIC/Annular ON/OFF SHORE GEOL AREA ~- :~.__~ UNIT# ..-----...___-..~--'---" >U ? WOrkls presence of H2S gas probableWill occur without operation ................. shutdown ........... Y,,;,,&;~'5 ~ ' ' Permit can be issued wlo hydrogen sulfide measures ...... Y N ,,,-' Data presented on Potential overpressure zones ..... ' · Y Seismic analysis of shallow gas zones... ....... seabed condition survey (if off-shore) ............. ,//Y N ' "' Contact name/phone for weekly progress reports [exploratory_ptily] Y N Y N YY'NY NN' Y N COMMISSION: Comments/Instructions: O Z O -.I z -4 -r- c:Vnsoffice\wordian~diana\checklist (rev. 11101//00)