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Home My WebLink About204-1821. 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 15,305 feet N/A feet true vertical 9,967 feet N/A feet Effective Depth measured 13,990 feet 10,540 & 10,598 feet true vertical 9,983 feet 8,880 & 8,927 feet Perforation depth Measured depth 11,316 - 15,257 feet True Vertical depth 9,431 - 9,970 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / L-80 & 9.2 / L-80 10,567 MD 8,902 TVD Baker FB-1 10,540 (MD) 8,880 (TVD) Packers and SSSV (type, measured and true vertical depth)TIW HHP Pkr 10,598 (MD) 8,927 (TVD) Baker TE5 SSSV 322 (MD) 322 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer Other: CTCO / N2 Operations OilSafe AR Acid 7" 5" 10,883 MD 370 1,155 15,300 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 75 Representative Daily Average Production or Injection Data 86100 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-182 50-733-20415-01-00 Plugs ADL0018756 MGS C22A-26RD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-326 83 Authorized Signature with date: Authorized Name: 127 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 19 Gas-Mcf 597 Pumped 95 bbl OilSafe AR displaced with 25 bbl FIW. Final Pressure: T/IA/OA = 680/665/120 Oil-Bbl 1 Water-Bbl Production 11,316 - 12,300 Junk 5. Permit to Drill Number: 1 Middle Ground Shoal / MGS Oil PoolN/A measured 9,797 1,894 Size 833 Liner Casing Structural Liner 4,702 Length 370 1,155 Conductor Surface slotted 5,410psi 24" 13-3/8" 9-5/8" 9,797 6,330psi 907 777-8376 7,240psi 370 1,149 8,215 9,148 9,967 Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,130psi 3,810psi 2,730psi 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 9:47 am, Oct 20, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.10.19 11:12:52 -08'00' Dan Marlowe (1267) CTCO / N2 Operations OilSafe AR Acid RBDMS HEW 11/13/2020 Other Stimulate gls 12/9/20 SFD 10/20/2020 DSR-10/20/2020 _____________________________________________________________________________________ Updated By: JLL 10/16/20 SCHEMATIC Middle Ground Shoal Well: MGS C22A-26RD Last Completed: 12-20-2004 PTD: 204-182 API: 50-733-20415-01 PBTD: 15,300‘ TD: 15,305’ 24” KB: 35’ MSL = 73’ 5” 3-12 17 16 13-3/8” 7” 1 2 9-5/8” 13 14 15 CTCO to 13,990 CTM 9/18/20 X XN XO CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Conductor Surf 370’ 13-3/8” 54.5 K-55 BTC 12.615” Surf 1,155’ 9-5/8” 43.5 L-80 LTC 8.755” Surf 4,123’ 9-5/8” 47 L-80 LTC 8.681” 4,123’ 9,797’ 7” 26 L-80 LTC 6.276” 8,989’ 10,280’ 7” 29 L-80 LTC 6.184” 10,280’ 10,691’ 7” 32 P-110 LTC 6.094” 10,691’ 10,883’ (TOW) 5” 18 L-80 Hydril 513 4.276” 10,598’ 15,300’ TUBING DETAIL 3-1/2” 9.3 L-80 8 rd EUE 2.992” Surf 991’ 3-1/2” 9.2 L-80 IBT 2.992” 991’ 10,567’ Note: Tbg tally was 22’ deeper than DPM. All depths based on Tbg. (Pkr was set on DP) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status H1 – H2 11,316’ 11,586’ 9,431’ 9,597’ 270’ 12/17/2004 Slotted Liner H2 – H3 – H2 11,629’ 12,773’ 9,622’ 10,007’ 1,144’ 12/17/2004 Slotted Liner H2 12,905’ 14,093’ 10,014’ 9,983’ 1,188’ 12/17/2004 Slotted Liner H1 14,226’ 14,672’ 9,986’ 9,994’ 446’ 12/17/2004 Slotted Liner H1 14,843’ 15,074’ 9,988’ 9,981’ 231’ 12/17/2004 Slotted Liner H1 15,117’ 15,257’ 9,979’ 9,970’ 140’ 12/17/2004 Slotted Liner JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 322’ 322’ 2.812” 5.375” Baker TE5 SSSV 2 991’ 988’ 2.992” 4.500” X-over 8rd Box X BTC Pin 3 1,918’ 1,870’ 2.992” 4.800” GLM #1 4 3,207’ 2,963’ 2.992” 4.800” GLM #2 5 4,617’ 4,008’ 2.992” 4.800” GLM #3 6 5,882’ 4,956’ 2.992” 4.800” GLM #4 7 7,144’ 5,810’ 2.992” 4.800” GLM #5 8 8,169’ 6,619’ 2.992” 4.800” GLM #6 9 8,894’ 7,326’ 2.992” 4.800” GLM #7 10 9,505’ 7,931’ 2.992” 4.800” GLM #8 11 10,028’ 8,430’ 2.992” 4.800” GLM #9 12 10,467’ 8,820’ 2.992” 4.800” GLM #10 (Orifice) 13 10,533’ 8,874’ 2.813” 4.500” HES X Nipple 14 10,539’ 8,879’ 3.000” 3.990” GBH-22 Locator & Seal Assembly 10,551’ 8,889’ 3.000” 3.990” Muleshoe 10,540’ 8,880’ 4.000” 5.875” Baker 85-40 FB-1 Perm Packer w/10’ seal bore extension 15 10,559’ 8,896’ 2.625” 3.500” HES XN Nipple 2.750” w/ 2.625” no-go 16 10,567’ 8,902’ 3.000” 3.500” WLEG 17 10,598’ 8,927’ TIW HHP Packer Fish Date Depth Item 03/10/2006 GLV Rig Start Date End Date CTU 9/16/20 9/20/20 PJSM & Permits. Continue letting well unload. Come online with pump down coil @ 1.2 bpm, CTP 4140, WHP 77, IA 750, OA 150. RIH to 13200', PU OOH. Pull past 12700' clean. POOH,Tagged up, swab closed, bleed down, pop off well. Cut 100' coil. Do general maintenance, housekeeping and clean up around coil set up. Shut down for the day, send the guys in to get some rest. Transferred 160 bbl FIW to Platform C & shipped same to MGS Onshore. Emailed non-produced fluid form to MGS Onshore. 09/19/20 - Saturday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name MGS C22A-26RD 50-733-20415-01-00 204-182 09/16/20 - Wednesday Hold Platform C PJSM with crew and Crane op. Begin offloading Coil package from the MV Sovereign onto Platform C spotting CTU package on pipe deck. MV Titan backloaded and away to Platform C for equipment transfer. Fly 3 personnel from Platform A to Platform C. Safety & operational meeting w/ crane operator & SLB CT personnel. Continue offloading MV Sovereign while spotting CTU package on pipe deck. MV Sovereign offloaded & away. Working MV Titan offloading remainder of CTU package spotting equipment on pipe & drill decks. Titan away from platform waiting on tide change. Resume working MV Titan offloading CTU equipment. All equipment on deck. SDFN. Job in Progress. PJSM & Permits. Continue MIRU Coil Package. Run hyd. lines from power pack to hose reel, ops cab, CT reel & injector. Run FIW supply line from platform manifold to mixing tank & pump. Run supply line from OilSafe AR ISO to pump. Run pump iron from N2 & fluid pump to CT reel. Run kill line iron to drill deck. MU riser and BOP to WHA. Tie in kill line to flow cross. Run flowback iron from choke manifold to flow cross. Turn over crane for use by production electrician to repair deck lights. Set gas baster on flowback tank & run flowback iron from choke manifold to gas buster. Rig up drain lines from flowback tank to C- pump & from C-pump to platform day tank. Test BOPE as per Hilcorp & AOGCC requirements, witnessed waived 9/17/2020 @ 1127 AM by AOGCC Inspections Supervisor Jim Regg, 250/4500. Emailed BOPE Test Report to AOGCC. Stab pipe in injector. Secure well room, drill & pipe decks. SDFN. Job in progress. 09/18/20 - Friday PJSM & permit. RU CTU. MU lubricator & BHA1: CTC(2.13" X 1.27'), DFCV(2.13" X 1.70'), BI-DI Jar(2.25" X 4.30'), DISCO(@.13" X 1.58'). Circ Sub(2.13"" X 1.17', 5K Rupture Disc), XRV(2.13" X 1.40'), Motor(2.13"" X 11.60'), Mill (2.60" X 0.95') OAL = 23.97'. PT CTC = 25K Press Test BHA to Disco = 3500 Disco ball = 9/16" Circ sub ball = 1/2". Pressure test lubricator & WHA, break off to replace leaking lubricator o-ring. Back to well, PT = 4500 to WHA. Close valves @ CT reel, PT pump iron =5500. Open swab (18.5T). Initial T/IA/OA = 0/550/120. RIH w/ motor & 2.60" 3-blade junk mill for dry tag @ 11,492'. Roll pump & slide by. Stop pump & continue TIH for dry tag @ 12,632'. 5000' wt chk = 3K , 10,500' wt chk = 17.5 k, 11,300' wt chk = 21k, 11,492' PUW = 22K, 12,300' wt chk = 26K,12,632' roll pump & slide by. Stop pump & continue TIH for dry tag @ 12,979'. PUH to 9900' bring pump online @ 1.25 bpm to establish circulation CTP = 4800, WHP 0, IA 550. OA 120. Mill ahead to 13990' started hitting lock up. PU hole making wiper trip. Got hung up at 12700'. Try pumping down coil, bringing well online to production, surging coil, surging the pump. Working coil with no love. Fire watch coil for the night. Transferred 565 bbl FIW & 15 bbl of FloVis L gel to Platform C & shipped same to MGS Onshore. Emailed non-produced fluid form to MGS Onshore. 09/17/20 - Thursday Rig Start Date End Date CTU 9/16/20 9/20/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name MGS C22A-26RD 50-733-20415-01-00 204-182 PJSM & Permits. Get tied into IA for a fluid pack. Open IA, Start pumping FIW into IA @ 2bpm taking returns to production flow line. Initial T/IA/OA = 68/783/120. Make up CC, pull test 25k. Make up rest of tool string. PT low/high 250/3500. Stab on well. Continue pumping down IA. ( CTC 1.68" x .30') ( DFCV 1.70" X 1.29') ( WT BAR 1.70" X 4.93') ( TTS DISCONNECT 1.70" X 1.43') ( XO 1.5" X .42') ( DJN 1.5" X .50') TOL= 8.87'. Disconnect ball=.5". Open well, Swab 18.5, WHP 70, IA 600, OA 120. RIH while continuing to fluid pack IA. Taking returns to production flow line,12,300'. Pumped 602 bbl to IA, stop pump. SI production flow line. T/IA/OA = 230/424/120. Pump 10 bbl FIW @ 1.0 bpm, CTP =2820, WHP = 911, IA =572. Swap to OilSafe AR & continuing pumping for bullhead injection @ 1.0 BPM. 12,300' Pumped 95 bbl OilSafe AR, WHP = 1400, IA = 1357. Displace OilSafe AR from coil w/ 25 bbl FIW @ 0.75 BPM. Stop pump. WHP = 1470, IA = 1365. Let OilSafe AR soak per procedures. POOH. Close swab. Final T/IA/OA = 680/665/120. Purge coil w/ N2 to flowback tank. Bleed all pressures. Break off well & LD BHA & Lubricator. Start RD CTU package prepping for backload to boats & move to Steelhead. Transfered 75 bbls from flowback tank to Platform C and shipped same to MGS Onshore. Emailed non-produced fluid form to MGS Onshore. SDFN. 09/20/20 - Sunday 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): 15,305'N/A Casing Collapse Structural Conductor Surface 1,130 psi Production 3,810 psi Liner 5,410 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018756 Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length MGS C22A-26RD COMMISSION USE ONLY Authorized Name: Size 6,330 psi N/A TVD Burst 10,567' 7,240 psi slotted Tubing Size: MD 2,730 psi 370' 1,149' 8,215' 370' 1,155' 24" 13-3/8" 370' 9-5/8"9,797' 1,155' Perforation Depth MD (ft): 9,797' 11,316 - 15,257 1,894' 10,540 (MD) 8,880 (TVD) 10,598 (MD) 8,927 (TVD) & 322 (MD) 322 (TVD) Tubing Grade:Tubing MD (ft): 9,431 - 9,970 Perforation Depth TVD (ft): 9.3 / L-80 & 9.2 / L-80 Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 8/21/2020 3-1/2" Daniel E. Marlowe Baker FB-1 Perm Packer & TIW HHP Packer / Baker TE5 SSSV 4,702' 5" 9,148'7" 15,300' 9,967' 10,883' Other: CTCO / N2 Operations/ Oil Safe AR Acid N/A 9,967' 15,300' 9,967' 3,240 psi 204-182 50-733-20415-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 6:48 pm, Aug 06, 2020 320-326 Digitally signed by Daniel Marlowe DN: cn=Daniel Marlowe, ou=Users Date: 2020.08.06 14:39:47 -08'00' Daniel Marlowe *4000 psi BOP test (min) acid soak gls 8/24/20 DLB 08/07/2020 X CTU X SDR-8/7/2020 10-404 dts 8/24/2020 8/24/2020 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.08.24 11:14:22 -08'00' RBDMS HEW 8/24/2020 Well Work Prognosis Well Name: MGS C22A-26RD API Number: 50- 733-20415-01 Current Status: Gas Lifted Producer Leg: Leg #4 (West) Estimated Start Date: 8/21/2020 Rig: Coil Tubing Reg. Approval Required? 403 Date Reg. Approval Received: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 204-182 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: 3,648 psi @ 9,886’ TVD 0.369 psi/ft (7.1 ppg) Maximum Expected BHP: 4,229 psi @ 9,886’ TVD 0.45 psi/ft (8.7 ppg) Max Potential Surface Pressure (MPSP): 3,240 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Well C22A-26RD is a gas lifted producer completed in Hemlock sands. This well has a history of scaling over and SL drifts confirm scale in TBG and liner. 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 bottom of the perf interval using FIW/synthetic acid. a. Have milling tool string on hand for contingent scale milling as needed b. Circulate well clean using FIW w/ N2 assist as needed. 4. Lay ±3880 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. Attachments: 1. Well Schematic - Current/Proposed (Same) 2. Wellhead Diagram - Current 3. Coil Tubing BOP Drawing 4. Flow Diagrams Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. Well Work Prognosis 5. Oil Safe AR – Technical Data Sheet 6. Standard Well Procedure – Nitrogen Operations 7. Sundry Revision Change Form _____________________________________________________________________________________ Updated By: JLL 11/01/16 SCHEMATIC Middle Ground Shoal Well: MGS C22A-26RD Last Completed: 12-20-2004 PTD: 204-182 API: 50-733-20415-01 PBTD: 15,300‘ TD: 15,305’ 24” KB: 35’ MSL = 73’ 5” 3-12 17 16 13-3/8” 7” 1 2 9-5/8” 13 14 15 X XN XO CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Conductor Surf 370’ 13-3/8” 54.5 K-55 BTC 12.615” Surf 1,155’ 9-5/8” 43.5 L-80 LTC 8.755” Surf 4,123’ 9-5/8” 47 L-80 LTC 8.681” 4,123’ 9,797’ 7” 26 L-80 LTC 6.276” 8,989’ 10,280’ 7” 29 L-80 LTC 6.184” 10,280’ 10,691’ 7” 32 P-110 LTC 6.094” 10,691’ 10,883’ (TOW) 5” 18 L-80 Hydril 513 4.276” 10,598’ 15,300’ TUBING DETAIL 3-1/2” 9.3 L-80 8 rd EUE 2.992” Surf 991’ 3-1/2” 9.2 L-80 IBT 2.992” 991’ 10,567’ Note: Tbg tally was 22’ deeper than DPM. All depths based on Tbg. (Pkr was set on DP) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status H1 – H2 11,316’ 11,586’ 9,431’ 9,597’ 270’ 12/17/2004 Slotted Liner H2 – H3 – H2 11,629’ 12,773’ 9,622’ 10,007’ 1,144’ 12/17/2004 Slotted Liner H2 12,905’ 14,093’ 10,014’ 9,983’ 1,188’ 12/17/2004 Slotted Liner H1 14,226’ 14,672’ 9,986’ 9,994’ 446’ 12/17/2004 Slotted Liner H1 14,843’ 15,074’ 9,988’ 9,981’ 231’ 12/17/2004 Slotted Liner H1 15,117’ 15,257’ 9,979’ 9,970’ 140’ 12/17/2004 Slotted Liner JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 322’ 322’ 2.812” 5.375” Baker TE5 SSSV 2 991’ 988’ 2.992” 4.500” X-over 8rd Box X BTC Pin 3 1,918’ 1,870’ 2.992” 4.800” GLM #1 4 3,207’ 2,963’ 2.992” 4.800” GLM #2 5 4,617’ 4,008’ 2.992” 4.800” GLM #3 6 5,882’ 4,956’ 2.992” 4.800” GLM #4 7 7,144’ 5,810’ 2.992” 4.800” GLM #5 8 8,169’ 6,619’ 2.992” 4.800” GLM #6 9 8,894’ 7,326’ 2.992” 4.800” GLM #7 10 9,505’ 7,931’ 2.992” 4.800” GLM #8 11 10,028’ 8,430’ 2.992” 4.800” GLM #9 12 10,467’ 8,820’ 2.992” 4.800” GLM #10 (Orifice) 13 10,533’ 8,874’ 2.813” 4.500” HES X Nipple 14 10,539’ 8,879’ 3.000” 3.990” GBH-22 Locator & Seal Assembly 10,551’ 8,889’ 3.000” 3.990” Muleshoe 10,540’ 8,880’ 4.000” 5.875” Baker 85-40 FB-1 Perm Packer w/10’ seal bore extension 15 10,559’ 8,896’ 2.625” 3.500” HES XN Nipple 2.750” w/ 2.625” no-go 16 10,567’ 8,902’ 3.000” 3.500” WLEG 17 10,598’ 8,927’ TIW HHP Packer Fish Date Depth Item 03/10/2006 GLV Platform C Well #22A-26RD 08/05/2020 Platform C 22A-26RD 13 3/8 x 9 5/8 x 3 ½ Tubing hanger, CIW-AP-FBB- CL, 11 x 3 1/2 EUE 8rd lift and susp, w/ 3'’ type H BPV profile, 1- 1/8 npt control line port 13 3/8'’ 9.625'’ BHTA, CIW, External knock-up, 3 1/8 5M FE Valve, Swab, CIW-FL, 3 1/8 5M FE, HWO, EE trim Valve, Master, CIW-FL, 3 1/8 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 SSO Tubing head, CIW-AP, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, X bottom prep 3 ½’’ Coiled Tubing BOP SWAB VALVE MASTER VALVE HilcorpMonopod Rig 56Flow Diagram Fluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveAutomatic Choke Manual ChokePressure Gauge Knife ValveChoke LineP PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLDGAS BUSTER Panic LineC12 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 C22A-26RD (PTD 204-182)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 • • From: Patricia Bettis To: Well History File: PTD 204-182 Date: January 13, 2017 Re: Well Name Change At the request of Hilcorp, the well name for MGS C22A-26LN was changed to MGS C22A-26RD, effective January 13, 2017. SCANNED JAN 2 6 2017, Image p:ect Well History File co!r Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ OIJ - 115 ~ Well History File Identifier Organizing (done) ~wo-sided 1111111111111111111 D Rescan Needed 1111111111111111111 RES CAN vz{color Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) ~aps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Date I/a oj 07 D Other:: ~ 111111111111111111/ /5/ V\1 P BY:' ~ /5/ Project Proofing BY: ~ Date 1/30/0 7 , I ~ + 3 = TOTAL PAGES~ (Count does not include cover sheet) 1M ,p' /5/ r f t Scanning Preparation BY: Date: Production Scanning Stage 1 Page Count from Scanned File: _~ Lt 11111111I1111' "III (Count does include cover sheet) BY: Page Count Matches Number in Scanning Preparation: V YES ~ Date: l/aoJ 07 NO /5/ mp NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: /5/ IIIIIII111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 ,,11/ BY: Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc of T r �� _ts THE STATE T. le r / � Alaska: C f G a 333 West Seventh Avenue itert GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 Main: 907 279 1433 ,e LAe"' Fox: 907.2'76.7542 SCANNED J U L 2 9 2014 Sandra Haggard Regulatory Analyst aod _/ 9""XTO Energy 4' 9127 South Jamaica Street Englewood, CO 80112 Re: Middle Ground Shoal Field, E, F, & G Oil Pools, Middle Ground Shoal C22A-26LN Sundry Number: 314-142 Dear Ms. Haggard: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this 171%, of March, 2014. Encl. MAR 0 7,201' STATE OF ALASKA 0 7 /1— ALASKA OIL AND GAS CONSERVATION COMMISSION AOGC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pod❑ Repair Well O• Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate Q . Pull Tubing❑ Tune Extension❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other 'Col tubing cleanout/AC 1.0e ❑✓ 2.Operator Name: 4.Current Wel Class: 5.Permit to Drill Number. 56k ic— XTO Energy , Exploratory 0 Development [(• 204-182 . 3.Address: Stratigraphic ❑ Service i 1 6.API Number. 9127 South Jamaica Street,Englewood,CO 80112 50-733-20415-01-00- 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Petting existing zone, Will planned perforations require a spacing exception? Yes ❑ No ❑, . Middle Ground Shoal C22A-26LN 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 18756 . MGS E,F,G Oil pols 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 15,305' ' 9,967' , 15,305' 9,967' NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,155' 13-3/8" 1,155' 1,148' 2,730 psi 1,130 psi Intermediate 9,797' 9-5/8" 9,797' 8,210' 6,330 psi 3,810 psi Liner 3,050' 7" 12,039' 9,953' 9,060 psi 5,410 psi Liner 4,702' 5" 15,300' 12,703' 10,140 psi 10,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slotted liner, 10,614'-15255'♦ 8,940' - 12,688' 3-1/2" L80 10,567' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 7"Baker FB-1 Perm packer/Baker TE5 SSSV Packer @ 10,540'MD,8,881'ND;SSSV @ 322'MD,322'ND 12.Attachments: Description Summary of Proposal ❑' . 13.Well Class after proposed work: V. Detailed Operations Program Q , BOP Sketch Q . Exploratory ❑ Stratigraphic❑ Development d Service [1 14.Estimated Date for April 2014 15.Well Status after proposed work: Commencing Operations: Oil ❑✓ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sandra Haggard ISandra Haggard(a)xtoenergy.com Printed Name Sandra Haggard Title47,,efiy# 4421‘ Signature Phone 303-397-3672 Date 14-Feb-14 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Li Mechanical Integrity Test ❑ Location Clearance p Other: S'0/) /95.4. ia'e CSS— RBDMS MAY 1 0 2014 Spacing Exception Required? Yes ❑ No Id Subsequent Form Required: `a —VOL( APPROVED BY /C /i" Approved by: 1 COMMISSIONER THE COMMISSION Date: 3 -/7 - /6-(z- e.„? -if-8 1 it G4 SubiForm ane rForm 10-403(Revised 10/2012) Ap I I' ve-ivr nths from the date of approval. Attachmentss in Duplicate • E7D. �„/n`Frr / 2014 /1ny jfro ENERGY AOGCC Maith3,2014 Alaska Oil and Gas Conservation Commission Attn: John Norman,Commissioner 333 W. 7th Ave., Suite 100 Anchorage,Alaska 99501 Re: Form 10-403,Request for Sundry approval Objective: Coil Tubing Cleanout,Perforating and Acidize to Remove Scale Middle Ground Shoal#C22A-26LN MGS Field Cook Inlet,Alaska API: 50-733-20145-01 PTD#: 204-182 XTO Energy Inc. hereby submits its Application for Sundry Approval for coil tubing cleanout, perforating and acidizing to remove scale deposits in the well. Attached is the following information for your files: 1. Form 10-403 Application for Sundry Approval 2. Proposed job procedure 3. Present wellbore schematics and deviation survey If you require additional information,please contact me at 303-397-3672 Sincerely, Sandra Haggard,Regulatory Analyst Copy to: Bola Adeyeye,Operations Engineer • )(TO ENERGY To: John Norman Guy Schwartz Victoria Ferguson CC: Romeo Perez Scott Griffith From: Ajibola Adeyeye Re: MGS C22A-26LN(204-182) Cook Inlet,Platform C Coil Tubing Cleanout and Acidize to Remove Scale OBJECTIVE: The objective of XTO Energy's proposed workover for MGS C22A-26LN producer well is to clean-out and acidize scale deposit in the tubing, liner and across the production interval;the well has a history of scale deposit,requiring periodic cleanout. The plan includes mechanical cleanout of the tubing and liner via coil tubing,jet nozzle/mill.Afterwards,acid will be applied to remove additional solids in the wellbore and across the production interval. WELL HISTORY: The original well was drilled by Shell in the 1960's and plugged in 1990,then sidetracked for another well(C22A-26),which was plugged in 2004.A new sidetrack and well(C22A-26LN) was drilled out of the recently plugged well. The well scheduled for workvoer, C22A-26LN was drilled in 2004 and completed with 3.5" slotted liner; gas lift mandrels were included in the completion set-up to enable artificial lift support via gas injection. Initial production was measured at 991 BOPD, 189 BWPD and 297 MCF. Routine maintenance on this well is mainly scratcher attempts on slickline to remove scale and optimization of gas lift valves,check-ups for leaks and debris. ,,bv 0)1- MISCELLANEOUS: N" The AOGCC has granted XTO a waiver since 1999 concerning the BOPE stack since the rig's sub structure can only fit a double ram configuration and not a triple ram configuration. XTO was grandfathered a variance due to extensive knowledge of the mature Middle Ground Shoal Field and due to depleted reservoir pressure. XTO Energy is requesting the same variance for this workover. N6 The anticipated start date for this workover is April 2014. Please contact me at 301-397-3606 ArrV 60 -`with any questions or concerns. eSincerely, Bola Adeyeye Operations Engineer Aro ENERGY MGS C22A-26LN Workover Package for Coil Tubing Cleanout and Acidizing Operations Engineer: Bola Adeyeye Office: (303)3973606 Cell: (720)5391660 Well Identifier Well Name: MGS C22A-26LN Permit to Drill Number: 204-182 API #: 50-733-20415-01-00 Objective Perform coil tubing cleanout to remove scale and other debris in the well.Acidize the producing zone and perform scale inhibitor squeeze. Background The C22A-26LN well was side tracked and drilled from C22A-26 well in October 2004. A 5" slotted liner was set in the open hole without cement barrier.This well was also completed with 3-1/2" 9.3#tubing and ten gas lift mandrels.There is no history of intensive workover(rig/coil tubing) on this well, however, scratcher have periodically been deployed on slickline to remove paraffin and scale identified in the tubing as early as 2006.The most recent scratcher run was made in 2014 to cleanout the deposits in the tubing but hasn't been successful due to the heavy solids build-up in the well.This well has experienced a steep decline in its production; steady production of 220BOPD from February 2013 has fallen drastically to 7BOPD in 2014—see production chart on next page.The reason for this sudden reduction in production is mainly attributed to the scale in the tubing, restricting fluid flow. Bailer trip was made via slickline with 1.75" bailer tagging at 10,553'and grabbing scale samples.The scale samples were sent onshore for further testing; analysis of bailed scale collected at 10,583' indicated 23 wt%Calcium and 20 wt% Barium. Due to the large amount of barium sulfate scale present in the sample, mechanical cleanout of the solids is deemed necessary. Workover History Workover Date Comment Initial Completion 12-12-2004 Gas lift survey August 2005 No obstruction in tubing Gas lift survey Dec 2005 Change out GLV Feb 2006 Change out GLV#2 and 5 Change out OV on # 10 March 2006 Hard running through 2200' -3600', possibly paraffin Change plugged OV#10 Jan 2007 Possibly plugged due to paraffin Scale removal via SL July 2013 Hit scale with scratcher at 10,449', hard scale Scratch and bail scale on SL Jan 2014 Bailed out scale at 10,522', hard scale below 10,528' Scale bailer run Jan — Feb 2014 Bailed scale at 10,553' MGS C22A-26LN: Coil Tubing Cleanout and Acidizing Procedure 1 Current Well Status Well is currently producing @7 bopd, 16 bwpd, 6mcfd gas. Lift gas is continuously injected at 1025 mcfd. Wellbore Construction Detail ID Drift Cap. Annular 100% 1.25 SF 100% 1.33 SF Bbl/Ft Bbl/Ft Burst Burst Collapse Collapse Prd Tbg—3.5", 9.3#, L80 @ 10,567' 2.992 2.867 0.00914 0.0685 9520 7616 10040 7548 Prd Liner-5', 18#, L80 @15,305' 4.276 4.151 0.0177 0.0107 10140 8112 10500 7894 Drilling Liner—7" 26#, 29#& 32#, L80,P110 and Intermediate Csg—9-5/8", 43.5#&47#, L80 Surf Csg—13-3/8",54.5#,K55 @ 1,155' 12.615 12.459 0.1545 2730 2184 1130 849 Well Data Surface Casing: 13-3/8", 54.5#, K55, BTC. Set at 1155'. Cmt with 441 sx Intermediate Casing: 9-5/8", 43.5#& 47# L80, LTC. Set at 9797', cmt with 560 sx Drilling Liner: 7", 26#, 29# & 32# L80 & P110. Set at 10,883' (window) Production Liner: 5", 18# L80, hydril 513. Set at 15,300' (slotted liner) Top of liner @ 10598' PBTD: —15300' Tubing: 3-1/2" 9.3#, 8rd & 8.8# BTC. Set at 10,567' Packer: 7" Baker 'FB-1' permanent packer at 10,540' BHST: 240 F BHP: 3500 psi Smallest ID: 3-1/2" 'XN' Nipple: 2.625" ID @ 10,559' Max Deviation: 95.52 deg at 13,112' Max DLS: 10deg/100ft at 12,735' Other: Fish in hole, at bottom of liner. GLV fell 3-10-06 MGS C22A-26LN: Coil Tubing Cleanout and Acidizing Procedure 2 Vendor Contacts Coil Tubing unit— Baker/BJ Services Josh Herald 907-398-8303 Chemical Supply— Baker Petrolite Clyde Willis 907-229-0052 Bits, Motors, BHA Josh Herald 907-398-8303 Crane Operator—All American Pete Dickinson 907-230-6541 Rousterbout & Drill Supv—All American Pete Dickinson 907-230-6541 GR—CCL Memory logging tool Steve Barow or Barry Milazzo Materials Required ■ 15000 gal 10% HCI Acid (25%Xylene will be added if necessary) ■ 10 bbl Gel pill (supplied by Baker Petrolite) ■ 50 bbl 3% KCI — Fresh Water (mixed out of fresh water) ■ 600 bbl 3% KCI — FIW (fixed out of filtered inlet/sea water) ■ Nitrogen will be used when necessary for flowback assist ■ 990 gal Baker's mutual solvent (WLC 603) pumped ahead of the scale inhibitor ■ 990 gal of Baker Scale Inhibitor (SCW 4004), this will be flushed with 3% KCI FIW Equipment Required ■ 1.5" Coil Tubing Unit ■ 1.5" Pipe and blind rams, BOPE ■ 50 ft Lubricator ■ Crane; provided by the platform ■ 2 PTS tanks (250 bbl each) Acid Additives and Other Chemicals ■ 10% HCI — Inorganic acid used to acidize the formation ■ 250 gpt Xylene (25%) —To dissolve and disperse solid petroleum residue ■ 28 gal US-40— mutual solvent. Formation water wetting agent & reduce surface tension ■ 63 lb Ferrotrol 300—acid treatment fluid to prevent precipitation of ferric hydroxide ■ 10 gal Corossion Inhibitor—corrosion protection of tubular, casing & BHA ■ 50 gal Ferrotrol 280L- acid treatment fluid to prevent precipitation of ferric hydroxide ■ 7 gal FRW-16A— Friction reduction agent ■ 3 gal Clay Master-5C—to prevent formation damage due to scale swelling MGS C22A 26LN: Coil tubing Cleanout and Acidizin,g Procedure 3 Well Schematic: C22A-26LN �O PLF 4-11-06 ENERGY Current(Completion KB: 35' MGS C22A-26LN ` J Water Depth: 73'MSL Cook Inlet, Alaska Leg 4,Conductor 30 TBG:3-Y2"9.3#8rd&8.8#BTC @ 10,567' API No.:50-733-20415 / Set: 12-20-04 Sidetracked: 11-1-04 Replaced C-line well P&A'd June'90 Spud C22A-26 on 7-18-90 ' Item MD TVD Psc Pso Port P&A'd C22A-26 on 10-28-04 / GLM 1 1918 1881 905 951 12 GLM 2 3207 2967 895 939 12 Conductor Csg: 24"@ 370'. / J / GLM 3 4617 4021 885 923 12 GLM 5 5882 4961875 908 12 Surf Csg: 13 3/8", 54.5 Ib, K55, BTC. GLM 5 7144 5815 865 895 12 GLM 6 8169 6623 855 881 12 Set @ 1,155'. Cmt'd w/441 sx. / GLM 7 8894 7328 845 866 12 GLM 8 9505 7934 835 867 16 GLM 9 10028 8434 825 849 16 Intermediate Csg: 9 5/8", L80 LTC. J GLM 10 10467 8821 ORIFICE 24 Set @ 9,797'. Cmt'd w/560 sx. Surf-4,123' : 43.5# 4,123-9,797' :47# Jr SQZ'd TOL w/160 sk on 12-29-90. J 6'Pup Jt 3-1/2"9.3#L80 8rd @ 315' Baker TE5 SSSV(2.81"ID)@ 322' Drilling Liner: 7" Window Milled @ 10,883'. 6'Pup Jt 3-1/2"9.3#L80 8rd @ 327' 8,989'. Cmt'd w/1500 sk. / 21 Jts 3-1/2"9.3#L80 8rd EUE TOL @ X-over 3-''/2'9.3#8rd Box X BTC Pin @ 991° (Original Depth @ 12,039') 316 Jts 3-1/2"8.8#L80 BTC 8,989 10,280' : 26#L80 X-over 3.5"9.3#BTC Bx X 8rd Bx @ 10,532' 10,280- 10,691' : 29#L80 3-W X Nipple(2.81"ID)8rd 9Cr @ 10,533' 10,691 - 10,883' : 32#P110 ' ■ 6'Pup Jt 3-1/2"9.3#L80 8rd @ 10,539' ► -4111 12'Loc w/2 Seals b/w spacer @10,540' 7"Baker FB-1 Perm Pkr(85-40)@ 10,540'* 10'Baker SBE(80-40)@ 10,542' X-over SBE to 3-W 8rd Pin @ 10,552' 6'Pup Jt 3-1/2"9.3#L80 8rd @ 10,553' XN Nipple(2.625"ID)8rd 9Cr @ 10,559' 6'Pup Jt 3-1/2"9.3#L80 8rd @ 10,560' WLREG @ 10,567' *Tbg tally was 22'deeper than DPM.All Prod Liner: 5" 18#L80 Hydril 513. depths based on Tbg.(Pkr was set on DP.) Slotted Csg w/Blank sections. Set @ 15,300'. TOL @ 10,598' 5"TIW HHP Pkr @ 10,598'. Blank Csg Sections: 10,614- 11,316' 11,586-11,629' Liner Across: HC, HE, HI, HK, HN &back 12,773-12,905' thru HK, HI, HE&HC. 14,093-14,226' 14,672-14,843' 15,074-15,117' 15,256-15,300' Fish: GLV fell DH 3-10-06. TD: 15,305' MD(9,967'TVD) / \ MGS C22A-26LN: Coil Tubing Cleanout and Acidizing Procedure 4 Production Trend MCF BBL HEMLOCK BBL 1.700. .340 1.600. .320 1.500. .300 1.400. .280 1.300. I 11` fI�'. JI .260 1.zao. l " .240 , ,� '� 1 M 220 1.000. , ! 200 900. ,180 800. .160 700. ,140 600. .120 500. - .100 400. — y r , 80 300. .80 200. _40 100 - . illill*Ili101 .20 0 I - 0 10118/08 2/1 5/1 811 11/1 211 5/1 8/1 11/1 2/1 5/1 8/1 1111 2/1 511 8/1 11/1 2/1 5/1 811 10/17/13 —Gas —Oil —Water —Wafer elf —Gas Injection CO2 Prod —CO2 Infection —Gas Treat —Oil Target .-4neP.esse e Carte Production Chart (1 year) MCF 2,500- C22A-26LN HEMLOCK 2,000- 200 1,500- Op 150 1 11,000 .•,,,.,,r1,11 4me ` 100 '''11. priiiiirin 500. ) .1 .50 II e... 0 4 0 2/15/13 411 511 6/1 711 8/1 9/1 10/1 11/1 12/1 1/1 2/14114 —D Gas —I Oil —I Water —!Water Inj —I Gas Injection ❑CO2 Prod -R®CO2 Injection —I Gas Target —I Oil Target •-I LinePressure Clear Selections MGS C22A-26LN: Coil Tubing Cleanout and Acidizing Procedure Carte Lift Gas Injection and Production Pressure Chart PSI Dn 1 aoo- Cl2A-26LN HEMLOCK Hr 26 800• .20 600 .,.r 15 400• .10 200• ■ -6 ■ ■ 0', ■ 0 2/16/13 4/1 5/1 6/1 711 8/1 9/1 10/1 11/1 12/1 1/1 2/14/14 —I Casing Pressure —"Tubing Pressure —(Annulus Pressure —1 SurfaceCasingPressure InterCasingPressure ■I Down Hours ■I SoapStick Clear selections Summary Procedure: 1. Conduct safety meeting to review the daily work program and communicated associated risk with the entire crew. 2. Test BOPE, NU injection head and lubricator with the holding support of the crane 3. Pickle the coil tubing with acid and flush with 3% brine water, dispose appropriately 4. Trip into well with retrieving tool to pull the Baker TE5 SSSV, lay down and inspect the safety valve. 5. Pick up the roto-jet nozzle,CCL, GR memory tool (placed in a carrier) on 1-1/2" coil tubing and run into the well. Cleanout the tubing and flag a depth for correlation. Download the log data. 6. Continue cleaning the production tubing, reduce speed upon approach of the end of tubing. Cleanout through the liner and proceed until arriving at tagged depth. 7. Perform an extra bottom to top of liner cleanout and continue downhole to tag the well. Record tagged depth and pull coil tubing out of the well 8. Pick up the bit and motor, if tagged high. Run into well and cleanout additional fill in the liner MGS C22A-26LN: Coil Tubing Cleanout and Acidizing Procedure 6 9. Lay down the bit and motor. Pick up the roto-jet tool with GR and CCL in the BHA, run into well while cleaning the tubing. Pump down acid across the slotted liner and make multiple bottom to top passes. 10. Shut in the coil tubing annulus and squeeze acid into the perf, pull coil tubing out of well and allow acid to soak for 24 hours. Download the log data and compare gamma ray data for successful cleanout of barium scale behind the liner. 11. Zones will have to be perforated if it is determined that significant amount of scale still exist behind the slotted liner. 12. Nipple down lubricator, BOPE and move the coil tubing over to the next well. 13. Resume the injection of lift gas on the well. Flow back well to the PTS tank, monitor flow and take periodic pH level of the fluid 14. Once the fluid pH is at recommended value, prepare scale inhibitor mixture and bullhead into the well to enable squeeze into the producing zones. 15. Resume lift gas injection and collect fluid samples periodically to measure the residuals Risks and Safety Considerations 1. All PPE's(FRC's, hard hat, safety glasses, steel toe boots) must be worn at all times, no exception.Additional PPE's might be required for personnel involved in other specific roles. 2. Pressure test will be required on the BOPE, surface lines and manifolds; refrain from the vicinity of the equipment during these tests. 3. Lubricator and injection head will be held with crane during the coil tubing work, personnel should stay clear of the lifting area as much as necessary. 4. Acid and other hazardous chemicals will be mixed in tanks and used during the cleanout process.All required PPE must be used when handling and mixing these chemicals; MSDS sheets must also be available within close proximity of these chemicals 5. Perforating guns will be used on the wells; manufacturer recommended precautions should be exercised for the handling and storage of these guns. Pre-Mobilization Plan for Production Operators ***Approximately 1 week prior to resuming coil tubing cleanout, shut off the lift gas supply into the annulus. Open the well to flow up the tubing to bleed-off effluent gas in the well. If well stop flowing, shut-in the well and periodically open to flow to bleed off head gas in the tubing. MGS C22A-261N: Coil 1 ubing Cleanout and Acidizing Procedure 7 DETAILED PROCEDURE ***Anticipated shut in pressure on this well is 4000psi. Production tree and wellhead are rated to 5000 psi (see diagram on page....). *** Do not add bleach to the treated FIW ***** Note: 3% brine water mixed from fresh water must be used as spacer fluid whenever acid is pumped. Refrain from allowing FIW to get in contact with the acid. ***** Mobilize, Set-up Equipment, Riq-Up 1. Move in All American Service crew to prepare the platform for the cleanout program, prep work will include insuring space for equipment location are cleared and measured for spotting ahead of time. Ensure crew is on-site at least 3 days prior to coil tubing mobilization. 2. Prior to staging equipment,conduct safety meeting to review the work program; potential hazards should be identified and communicated to the entire crew involved in the program 3. Stage the PTS tanks, move in the 1.5" Coil Tubing unit, lubricator, injector head, acid/other chemical vessels and all associated equipment required for the workover. Set-up the site, lay down and connect pipes to flowback/PTS tank and manifolds. Prepare fresh water mixed adequately with KCI to create 3% brine solution in the mud/PIT tank. - Two PTS tanks will be used on each platform during this program;this will enable adequate flowback of dirty fluid from multiple workover wells before sending offshore. Substantial cleanout of dirty fluid to the disposal well will help in minimizing the amount of sludge transported offshore. - Debris catcher/filter should be installed on the flowback line before the PTS tank to capture solids returns. Filter should be monitored and periodically emptied. - Ensure there are accessible valves on the flowback line to collect and monitor cleanout fluid on the upstream and downstream of the PTS tanks. Test BOPE, Pull SSSV 4. Ensure the master and wing valves are closed, re-check to insure the lift gas line is tagged and closed. Nipple up pipe rams, blind rams, lubricator and injector head, hoist the lubricator and injection with,the support of the crane. MGS C22A-26LN: Coil Tubing Cleanout and Acidizing Procedure 8 5. Contact AOGCC 24 hours prior to BOP test,test BOPE to 250 psi and 5000 psi, low and high pressure for both shell and pipe tests. 6. Pump pipe volume of acid down the coil tubing to pickle and flush with 3% brine water that is conditioned from fresh water. Send the used acid and flush fluid to the PTS tank and be disposed appropriately. 7. Pick up the SSSV retrieving tool, make up to the coil tubing connector and perform the required pull test to ensure the connection is intact. 8. Run the coil tubing into well and pull the Baker TE5 subsurface safety valve (located at^ 322'). Lay down and inspect the safety valve, send the SSSV to Baker shop for inspection and re-dress Cleanout with Roto Jet Nozzle,Acid Soak and Mill Scale 9. Pick up the roto-jet tool,gamma ray and CCL memory tool and put together the BHA. Memory tool will be installed in the carrier to enable flow across it. 10. Make-up BHA to the coil tubing connector and run into the well. Continue tripping into the well at 100fpm while washing out solids and other debris in the tubing with slick 3% KCI FIW and circulating at 1—2 BPM 11. Continue cleanout and monitor the annulus pressure and returns for difficulty in lifting fluid. Engage the nitrogen and foaming agent to enhance the fluid flowback. Periodically collect samples on the flowback line to assess cleanout effectiveness. • 12. Continue cleaning the tubing while proceeding with caution through the restrictions (2.81" 'X' & 2.625" XN-nipple). 13. Reduce the speed while approaching the end of tubing. Continue cleanout through the liner and proceed slowly until tagged. Flag a depth in the liner for correlation. - Pull up every 300 ft to ensure the coil tubing is not getting stuck, pump slugs of gel sweeps to improve the clean-ups. - If tagged high or unable to get to the bottom of the well, pump down 500 gal of acid and spot on top of the scale. Mill will be necessary for further cleanout 14. Make an extra up-down pass from the liner top to the tagged depth.This additional pass enable assessment of the effectiveness of scale cleanout behind the liner,from the GR log - Scale testing indicated —20 wt% barium in the sample, if such amount of barium exists behind the slotted liner, GR log will be able to identify the success of the scale cleanout after each pass. MGS C22A-261M: Coil Tubing Cleanout and Acidizing Procedure 9 15. Pull the roto-jet and logging tools out of the well. Download the log data and send to the production engineer. 16. If unable to get to bottom of the well with the roto-jet tool, pick up 1-11/16" motor 2.5" bit. Run into well at 80 fpm and mill out additional scale deposit in the liner Perforating Via TCP(only if deemed necessary) Perforating via TCP will conducted if considered necess ry by the production engineer. Determination will be based on the effectiveness of the scale cleanout behind the slotted liner. Perf gun will be put together at the vendor workshop into transportable sections and delivered to the platform; each run will consist of 40 ft gun and firing head. This will provide adequate space to trip and pull through the 50 ft lubricator A disconnecting/shear piece must be included on the BHA to release of the guns; in situation of last resort. The flagged depth on the CCL/GR log from earlier run will be used for depth correlation. 17. Hold pre-job safety meeting before picking up the perforating guns and designate the essential personnel allowed on location while assembling the gun. 18. Assemble to 40 ft gun and the firing head, run the coil tubing with connector through the lubricator to make-up to the gun assembly.Gradually pull out with the coil tubing to pull the gun while pulling up the lubricator with the crane. 19. Position the lubricator over the well;flange back the lubricator onto the BOP. Open the master valves and trip the perforating gun into the well. 20. Correlate and ascertain the depth to be perforated (refer to table 1), drop the ball and pump down to seat. Pressure up to 3000 psi to engage the firing head,watch for signals that indicated the gun is fired; for example sudden vibration on the lubricator/wellhead, surge of fluid in the annulus. Table 1: Perforating gun data Run 4* Perforating Interval Gun length Gun Size/Other Comments 1 TBD 40 ft 2 TBD 40 ft 3 TBD 40 ft MGS C22A-26LN: Coil Tubing Cleanout and Acidizing Procedure 10 • 21. Once confirmed, gradually trip out with the gun while exercising some caution across the constricted depths (end of tubing, 'X' and 'XN' profiles). 22. Pull out of the wellhead, close the master valve and laydown the perforating gun. 23. Repeat steps 18-22 for the second and third run of the 40 ft gun. Acid Squeeze 24. Pick up the roto-jet tool and run in at 100 fpm. Pump down slick 3% KCI FIW while cleaning down to the top of the perforated depth (or top of slotted liner if well wasn't perforated). 25. While at this depth, pump down 10bbI 3% KCI—fresh water spacer and 10 bbl of HCI acid and 10 bbl of 3% KCI-fresh water as'tail'spacer. Reduce the pumping rate to 0.25 bpm as the acid approach the end of the coil tubing. Gradually trip down the production interval while washing the perforations at this reduced rate.Wash down to the tagged depth. 26. Pull coil tubing back up to 12900 ft,this is the mid-section of the production interval 27. Pump fluid down the tubing while following the tabled sequence below. When 15 bbl of the 3% KCI-fresh water in step 1 have exited the coil tubing, close the coil tubing annulus. Continue pumping the fluid as recommended to squeeze the acid into the formation. Note: Benzoic acid flakes will be used as diverting agent during acid job. This will be applied between each acid stage (refer to table below). Table 2: Fluid Sequence for Acid Squeeze Step Fluid Volume Comment/Purpose 1 3% KCI —Fresh Water 25 bbl Displacement of 3% KCI—FIW from bottom 2 Benzoic acid flakes Diverting agent to against flow into opened zones 3 10% HCI acid 3000 gal Acid stage 1 - squeeze into formation 4 Benzoic acid flakes Diverting agent 5 10% HCI acid 2500 gal Acid stage 2—squeeze into formation 6 Benzoic acid flakes Diverting agent 7 10% HCI acid 2500 gal Acid Stage 3—squeeze into formation 8 Benzoic acid flakes Diverting agent 9 10 % HCI acid 2500 gal Acid Stage 4—Squeeze into formation 10 Benzoic acid flakes Diverting agent 11 10% HCI acid 2500 gal Acid Stage 5—squeeze into formation 12 3% KCI—Fresh Water 15 bbl Spacer MGS C22A-26LN: Coil Tubing Cleanout and Acidizing Procedure 11 • 28. Pull the coil tubing out of the well, lay down the roto-jet nozzle, and re-dress as required. Shut in the well, nipple down the coil tubing lubricator and BOPE. Move coil tubing over to the next well. 29. Allow acid to soak for 24 hours. Monitor and chart the tubing pressure. 30. After 24 hours and upon consultation with the production engineer, open well to flowback to the PTS tank and resume injection of lift gas to aid liquid unloading. Monitor returns and send flowback fluid into the disposal well. - pH of the flowback fluid must be measured and recorded, send record of the data to production engineer and Baker Hughes chemical contact before proceeding to the next step 31. Once the fluid PH is at recommended level, shut off lift gas supply. Scale Inhibitor Squeeze 32. Prepare scale inhibitor mixture. Engage the mud pump and bullhead the scale inhibitor as recommended in table 3. Flush with 3% KCI—FIW and shut in the well for 24 hours. Table 3: Scale Inhibitor Squeeze—Fluid Sequence Fluid Type Volume (gal) Comment Mutual Solvent (WLC603) 990 gal Scale Inhibitor(SCW4004) 990 gal 3%KCI - FIW 180 bbl Over displace SI 33. After 24 hours and upon the approval of the production engineer, handover well to production team and resume injection of the lift gas. 34. Sent the well to test separator. Collect daily, labelled bottle sample of the produced fluid, send sample Baker Hughes lab for further testing for scale inhibitor residuals. MGS C22A-26LN: Coil Tubing Cleanout and Acidizing Procedure 12 , Well Directional Survey C22A-26LN Measured Angle Azimuth TVD-RKB TVD DLS Vert.Sec SVY# Depth deg deg ft Subsea deg/100 ft ft Tie-In 0 0 0 0 -105 0.00 0.00 1 110 0 9 110 5 0.34 0.33 2 210 0 222 210 105 0.48 0.57 3 310 1 242 310 205 0.51 0.36 4 410 1 196 410 305 1.00 -0.83 5 510 2 193 510 405 0.77 -3.53 6 610 3 206 610 505 1.32 -7.48 7 710 5 217 710 605 1.63 -12.50 8 810 6 218 809 704 1.32 -18.68 9 910 8 212 908 803 1.73 -26.95 10 1010 10 208 1007 902 2.06 -38.24 11 1110 12 204 1106 1001 2.40 -53.10 12 1210 13 202 1203 1098 1.65 -71.24 13 1310 15 204 1300 1195 1.64 -91.56 14 1410 17 206 1396 1291 1.63 -113.50 15 1510 18 207 1492 1387 1.39 -136.92 16 1610 19 208 1586 1481 1.53 -161.88 17 1710 21 210 1680 1575 1.70 -188.21 18 1810 23 210 1773 1668 1.85 -216.25 19 1910 25 212 1865 1760 2.30 -246.20 20 2010 27 214 1954 1849 2.09 -277.48 21 2110 28 214 2043 1938 0.69 -309.67 22 2210 28 215 2132 2027 0.56 -342.11 23 2310 29 216 2220 2115 0.99 -374.59 24 2410 30 216 2307 2202 1.37 -407.93 25 2510 31 216 2393 2288 1.21 -442.58 26 2610 32 217 2478 2373 1.06 -477.98 27 2710 33 216 2562 2457 0.84 -514.16 28 2810 34 216 2646 2541 1.12 -551.56 29 2910 35 217 2728 2623 1.05 -589.58 30 3010 36 218 2810 2705 1.13 -627.73 31 3110 37 219 2890 2785 1.28 -666.07 32 3210 38 219 2969 2864 1.18 -705.05 33 3310 40 220 3047 2942 1.58 -744.75 34 3410 41 220 3123 3018 1.25 -785.16 35 3510 42 220 3198 3093 1.35 -826.65 36 3610 43 221 3272 3167 0.88 -868.46 37 3710 43 221 3346 3241 0.23 -909.94 38 3810 43 221 3419 3314 0.01 -951.33 39 3910 42 221 3493 3388 0.26 -992.62 40 4010 42 220 3567 3462 0.68 -1034.31 41 4110 42 221 3641 3536 0.74 -1075.92 MGS C22A-26LN: Coil Tubing Cleanout and Acidizing Procedure 13 , 42 4210 42 221 3715 3610 0.21 -1117.03 43 4310 43 222 3788 3683 1.16 -1158.12 44 4410 42 221 3862 3757 1.05 -1199.27 45 4510 43 223 3935 3830 1.43 -1239.80 46 4610 43 223 4008 3903 0.27 -1279.46 47 4710 43 224 4082 3977 0.73 -1318.63 48 4810 42 225 4156 4051 1.21 -1356.57 49 4910 43 225 4230 4125 0.79 -1393.95 50 5010 41 220 4304 4199 3.83 -1433.24 51 5110 40 215 4380 4275 3.28 -1476.10 52 5210 41 215 4456 4351 0.15 -1520.98 53 5310 41 213 4532 4427 1.30 -1566.74 54 5410 41 213 4608 4503 0.65 -1613.62 55 5510 41 213 4683 4578 0.14 -1660.87 56 5610 41 212 4758 4653 0.69 -1708.49 57 5710 41 212 4833 4728 0.12 -1756.48 58 5810 42 213 4908 4803 1.31 -1804.66 59 5910 44 214 4981 4876 1.60 -1853.20 60 6010 45 214 5052 4947 0.75 -1902.30 61 6110 45 215 5123 5018 1.08 -1951.64 62 6210 47 215 5192 5087 1.12 -2001.37 63 6310 48 216 5260 5155 1.68 -2051.70 64 6410 49 218 5326 5221 1.72 -2101.54 65 6510 49 218 5392 5287 0.02 -2150.72 66 6610 48 218 5458 5353 0.85 -2199.60 67 6710 48 218 5525 5420 0.35 -2248.29 68 6810 48 218 5591 5486 0.03 -2297.09 69 6910 48 218 5658 5553 0.65 -2345.64 70 7010 48 218 5725 5620 0.30 -2394.06 71 7110 48 219 5792 5687 0.93 -2441.88 72 7210 47 219 5860 5755 0.72 -2488.72 73 7310 46 219 5929 5824 0.81 -2534.98 74 7410 45 219 5999 5894 1.10 -2580.49 75 7510 42 219 6072 5967 2.49 -2624.58 76 7610 40 221 6147 6042 2.74 -2665.78 77 7710 37 221 6225 6120 3.16 -2703.77 78 7810 33 222 6307 6202 3.86 -2738.40 79 7910 31 223 6392 6287 2.04 -2769.73 80 8010 28 223 6479 6374 3.11 -2798.45 81 8110 25 222 6569 6464 2.64 -2824.91 82 8210 22 226 6660 6555 3.75 -2847.80 83 8310 18 229 6754 6649 4.27 -2865.47 84 8410 14 227 6850 6745 3.79 -2879.41 85 8510 11 222 6948 6843 3.10 -2891.55 86 8610 9 223 7046 6941 1.95 -2901.98 87 8710 7 235 7145 7040 2.43 -2909.25 88 8810 6 233 7245 7140 1.86 -2913.99 89 8910 3 222 7344 7239 2.67 -2917.72 MGS C22A--26LN: Coil Tubing Cleanout and Acidizing Procedure .14 P ` 90 9010 2 252 7444 7339 1.54 -2919.57 91 9110 5 296 7544 7439 3.81 -2917.09 92 9210 8 313 7643 7538 3.16 -2908.89 93 9310 9 326 7742 7637 2.56 -2895.88 94 9410 11 338 7841 7736 2.42 -2879.25 95 9510 12 351 7939 7834 3.08 -2859.50 96 9610 15 357 8036 7931 2.58 -2836.44 97 9710 17 1 8132 8027 2.71 -2809.77 98 9810 18 6 8228 8123 1.69 -2780.93 99 9910 18 23 8323 8218 5.20 -2753.62 100 10010 23 42 8417 8312 7.96 -2729.42 101 10110 24 45 8509 8404 1.72 -2706.78 102 10210 26 43 8600 8495 2.40 -2682.78 103 10310 29 46 8688 8583 3.13 -2656.94 104 10410 33 49 8774 8669 4.05 -2630.55 105 10510 37 49 8856 8751 4.37 -2602.29 106 10610 36 56 8937 8832 4.32 -2576.09 107 10710 38 64 9017 8912 5.18 -2557.03 108 10810 41 66 9094 8989 3.77 -2541.99 109 10883 43 65 9148 9043 3.07 -2530.84 110 11047 48 62 9263 9158 3.12 -2500.61 111 11142 50 54 9325 9220 7.21 -2475.31 112 11234 52 46 9383 9278 7.26 -2440.56 113 11326 53 38 9439 9334 6.88 -2396.61 114 11421 52 33 9497 9392 4.24 -2344.57 115 11512 52 27 9553 9448 4.57 -2290.54 116 11604 52 20 9609 9504 6.11 -2231.19 117 11699 56 15 9665 9560 5.88 -2163.83 118 11774 58 11 9706 9601 4.75 -2106.69 119 11831 61 11 9735 9630 5.03 -2061.40 120 11933 65 3 9782 9677 8.23 -1975.13 121 12026 72 357 9816 9711 8.93 -1890.38 122 12117 76 353 9842 9737 6.16 -1803.65 123 12212 76 348 9865 9760 5.45 -1711.62 124 12304 75 346 9888 9783 2.03 -1622.51 125 12398 75 341 9912 9807 5.15 -1532.03 126 12445 74 339 9924 9819 3.62 -1487.21 127 12546 70 336 9955 9850 4.96 -1392.77 128 12643 74 340 9984 9879 5.64 -1301.98 129 12735 81 347 10004 9899 10.01 -1212.61 130 12831 88 351 10014 9909 8.22 -1117.15 131 12921 90 349 10016 9911 3.23 -1027.20 132 13019 94 350 10013 9908 4.33 -929.27 133 13112 96 351 10006 9901 2.28 -836.62 134 13205 95 352 9997 9892 2.00 -744.09 135 13299 95 352 9989 9884 0.69 -650.60 136 13395 93 351 9983 9878 2.61 -554.98 137 13488 91 347 9979 9874 4.59 -462.06 MGS C22A-26LN: Coil Tubing Cleanout and Acidizing Procedure 15 138 13583 89 347 9979 9874 2.61 -367.12 139 13682 92 345 9979 9874 3.69 -268.25 140 13777 90 348 9977 9872 3.36 -173.34 141 13874 87 351 9979 9874 4.60 -76.41 142 13967 88 351 9983 9878 1.08 16.43 143 14061 89 348 9984 9879 3.34 110.39 144 14154 89 346 9985 9880 2.54 203.34 145 14250 87 342 9988 9883 4.31 298.97 146 14346 88 342 9992 9887 0.72 394.24 147 14441 89 344 9994 9889 2.68 488.70 148 14536 89 346 9995 9890 1.95 583.46 149 14634 90 344 9996 9891 1.96 681.23 150 14729 92 343 9994 9889 2.85 775.78 151 14823 92 338 9990 9885 4.69 868.71 152 14921 91 331 9987 9882 7.68 963.63 153 15013 92 332 9985 9880 1.42 1051.37 154 15108 93 331 9981 9876 1.35 1141.90 155 15207 94 332 9975 9870 1.69 1236.09 156 15250 95 332 9972 9867 0.98 1277.04 157 15305 95 332 9967 9862 1.24 1329.38 MGS C22A-•26LN:° Coil Tubing Cleanout and Acidizing Procedure 16 r_ OFFSHORE Well Head Rig Up BAKER a j � HUGHES y iJ 96"Gooseneck rI .F- ! I '—_ C r• 4 S&S 800L Injector Head rl .1 ,• L' Hydraulic Stripper 4 1/6" 10K FE 4 Crossover 4 1/16"10K x 5 1/16"10K 5 1/16"10K Lubricator -10 ft 5 1/16" 10K Flow Cross-2 ft 1 Crossover 5 1/16" 10K x 4 1/16" 10K 4 1/16"15K Combi BOPs Blind/Shear Ram (I. .) 4 Pipe/Slip Ram "' I `� `� 4 4 1/16" 10K Flow Cross 4— 4 1/16" 15K Blind/Shear Ram I . • ~,< -~.. • .~•"" ~.,~ ~' ~ , _ =' LL ,, ~_, MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicheK;vrPgs_InsertsuViicrofilm Marker.doc ;¿I J~~"1 DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Permit to Drill 2041820 Well Name/No. MGS C22A-26LN Operator XTO ENERGY INC API No. 50-733-20415-01-00 MD 15305 TVD 9967 Completion Date 12/21/2004 Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes --~- _.~._-~- ._-~~ ._-~'._----".._- DATA INFORMATION Types Electric or Other Logs Run: LWD: Gamma Ray & Resistivity Well Log Information: Electr Digital Dataset d/Frmt Number Name C TIF 12933 Induction/Resistivity (data taken from Logs Portion of Master Well Data Maint Log Log Scale Media Run Interval No Start Stop 1 0886 15305 OH/ CH Received Comments RWD-MPR/GR-GRAPHIC l IMAGES A Directional Survey Log is II required to be submitted. This record automatically [ created from Permit to Drill I Module on: 10/6/2004. . --~----- L__ Well Cores/Samples Information: ~~~. ~~- ~ Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORM~N Well Cored? y~ Daily History Received? ~ . Chips Received? )rT'r;¡- Analysis ~. Received? Formation Tops -----,-_._.._--------_._-~--~_._~_._- -----~ --~-~~---_._,~- ---~.~ Comments: Compliance Reviewed By: Jk -_._~.._-----_.._._-_._-----,_._.__.~---~.__. 3 )j. '-. ~------- . ~----'- Ò tT--..- ~ ? ~--"-' _.~~ _.~-_.-.....__.__._.__.,---~---~- Date: . ... I cC¡{!-/ '15' d . FRANK H. MURKOWSK/, GOVERNOR ALASKA OIL AlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 20, 2006 Mr. Bob Tisserand Alaska Department of Environmental Conservation 555 Cordova Street Anchorage, AK 99501 Dear Mr. Tisserand: On July 17, 2006, you emailed Mr. Tom Maunder of my staff requesting that the Commission review production data for XTO Energy's ("XTO") operations. During calendar year 2005 the peak individual well production volume for an XTO operated well in the Middle Ground Shoal Field was 130,429 barrels of oil from well MGS C22A- 26LN. This results in an annual average daily production rate for the well of 357 barrels of oil per day. If you have any further questions on this matter please feel free to contact Mr. Dave Roby of my staff at 793-1232. Sincerely, f21£~ Com~issioner 4 ,'...... "a. A ....., ............--'-b,¡J ... I . Thanks, T oml Dave, this is for you. If you've never done one of these, j ane can likely help you. Thomas Maunder wrote: Cathy, This gentleman from DEC called this morning and I asked him to send an email with his request I am forwarding it to you for proper assignment within the West Team. Tom -------- Original Message -------- Subject:XTO Energy Date:Mon, 17 Jul2006 10:38: 18 -0800 From:Tisserand, Robert <Robert Tisserand(~dec.state.ak.us> To:tom maunder(Zi;'admin.state.ak.us Good morning Tom. As I mentioned on the telephone I am the C-Plan reviewer for XTO Energy. XTO's C-Plan is up for review and I have a question regarding XTO's blowout scenario. The "Response Planning Standard" (RPS) for a production facility is three times the annual average oil production volume for the maximum producing well at the facility. 18 AAC 75.434(e)(1). I know that XTO has a high water cut but that doesn't matter when calculating the maximum volume from a producing well. Can you check XTO's well data and let me know what that figure is so I can compare it with what XTO submitted? Thank you, Bob Tisserand Alaska Department of Environmental Conservation Exploration, Production & Refineries Section 555 Cordova Street Anchorage, AK 99501 Phone: (907) 269-3060 Fax: (907) 269-7687 Emai1: Robert_Tisserand@dec.state.ak.us Cathy Foerster lof2 7/20/20063:06 PM .I.'\...\ ~ nu. /'\. .1 V LU\".lðJ J '-' to, · I . Commissioner Alaska Oil and Gas Conservation Commission 20f2 7/20/20063:06 PM J . . /Lv 'i - {1~ ;[tg XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) January 7, 2005 R12Cf:! J4N f . IIF:D A/RSke Oi! &,( 8 2005 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report: Well C22A-26LN Dear Mr. Norman, XTO Energy, Inc. hereby submits its Well Completion Report (Form 10-407) for the sidetrack drilled for the C22A-26LN on Platform C, in the Middle Ground Shoal Field of Cook Inlet, AK. The well was completed in the Hemlock with a double penetration in the HC, HE, HI, HK & HN zones. A 5" slotted liner was set across the Hemlock and being produced with gas lift. Please find attached the following information for your files: 1. Form 10-407 Well Completion 2. Daily Drilling Reports 3. Present Wellbore Schematic 4. Well Surveys 5. LWD Logs: GR & Resistivity (CD format) If you have any questions or require additional information, please contact me at (432) 620-6743. ". Sincerely, n f' ~ ~J'/ +-;¡; Paul L. Figel Engineering Manager Cc: Scott Griffith Tim Smith , . STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMW.N WELL COMPLETION OR RECOMPLETION REPORT AND LOG Other 5. Date Comp., Susp., or " Aband.: 12/21/2004 6. Date Spudded: October 31, 2004 7. Date TD Reached: December 14, 2004 8. KB Elevation (ft): 105' 9. Plug Back Depth(MD+TVD): 15256' + 9971' 10. Total Depth (MD + TVD): 16. Property Designation: Zone- AK4 I 15305' + 9967' "' ADL 18756ðJl>o". Zone- HC 111. Depth Where SSSV Set: 17. Land Use PenfrtC::L~/r, I..... Zone- HC2 322' N/A Cd V J..........I'" 19. Water Depth, if Offshore: 20. Th,iFj<ness of Pé1tI¥f1sÌ£ï -- &...0 73 feet MSL ÑI/ilS/(e n;/ .. . ð 200t:¡ "r/tJ~ /0 B8 '3' m£> v:r¡¡¡¡ C ,{ It./Ø I TVt:> I'~Ò> Af!f:h,,~ (JIIS. CO/rJ,...". CASING, LINER AND CEMENTING RECORD . "ye 'VU/ '11 SETTING DEPTH MD SETTING DEPTH TVD AMOUNT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED Surf 1155' Surf 1150' 17-1/2" 441 sxs 0 Surf 9797' Surf 8216' 12-1/4" 560 sxs 0 8989' 10883' 7324' 9148' 8-1/2" 1500 sxs 0 FALSE Oil~ Gas 0 Plugged 0 Abandoned 0 20AAC 25.105 GINJD WINJD WDSPLD 2. Operator Name: XTO Energy Inc. 3. Address: 200 North Loraine, Suite 800, Midland, Texas 79701 4a. Location of Well (Governmental Section): Platform C, Leg 4 Surface: Cond 30, 500' FSL, 1538' FEL, See 23, T8N, R13W, S.M. Top of Productive Horizon: 2372' FNL, 1622' FWL, See 26, T8N, R13W, S.M. No. of Completions 1 Total Depth: 1294' FSL, 929' FWL, See 23, T8N, R13W, S.M. 4b. Location of Well (State Base Plane Coordinates): Surface: '( ¡'- 2474186 j( ~- 231417 TPI: 'f - 2471364 I( - 229232 Total Depth: '.., - 2475045/ ,... - 228623 " 18. Directional Survey: Yes ~ No U 21. Logs Run: LWD: Gamma Ray & Resistivity 22. CASING WT. PER GRADE FT. 13-3/8" 54.5 K55 9-5/8" 43.5,47 L80 7" 26,29,32 L80, P110 5" 18 L80 15300' 8927' 10598' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): Slotted Liner: 11316' - 11586' 11629' - 12773' 12905' - 14093' 14226' - 14672' 14843' - 15074' 15117' - 15256' WAGD 1b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic Test 0 12. Permit to Drill Number: 204-182 13. API Number: 50-733-20415-01 14. Well Name and Number: C22A-26LN 15. Field/Pool(s): Middle Ground Shoal Field Suspended 0 20AAC 25.110 9967' 6" - I N/A-slotted csg o 24. SIZE 3-1/2" TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 10567' 10540' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): December 23, 2004 Gas lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: 1/4/2005 12 Test Period ... 312 95 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Press. 24-Hour Rate ..... 624 190 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Water-Bbl: 51 Water-Bbl: 102 RBDMS BFl .IAN ? (¡ 7005 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE Choke Size: TGas-Oil Ratio: 2" 1305 Oil Gravity - API (corr): 28.5 . ·.L2 , 7 ;. ~~~/ ORIGINA[ Gr-- G NAME GEOLOGIC MARKERS M TVD 29. Include and briefly su detailed supporting dat "None". FORMATION TESTS e test results. List intervals tested, and attach s necessary. If no tests were conducted, state 28. Top Hemlock HC 11040' Top Hemlock HN 11610' Top Hemlock HN2 12780' Top Hemlock HC2 (est) 15305' 9258' NONE 9613' 10009' 9967' 30. List of Attachments: Daily Drilling Reports, Wellbore Schematic, Well Survey, CD w/GR & Resistivity 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Paul Figel Printed Name: Paul Fiael Signature: Title: Engineer Manager Phone: 432-620-6743 Date: 1/12/2005 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 . . 1 XTO Energy Inc. C22A-26LN Daily Well Report Objective: Drill Horizontal Sidetrack First 09/16/2004 Report: 10/24/04 NU BOP's. Circ 10 hrs, Build Mud Vol/Wt 6 hrs, Monitor Well 4 hrs, NU/ND Tree 3 hrs, Pressure/lnject/Lot/Fit 1/2 hr, NU/ND BOP/Diverter 1/2 hr. RU to kill well. Filled pits w/FIW. Prep for boat (boat unable to load @ dock due to wind & wave action). Allowed well to bleed off fr tbg & tbg annulus. Press tstd mud lines to 1,000 psi. Circ well to prod w/FIW. Circ well thru choke to pits. Set BPV. Std to ND tree, 2-7/8" x 9-5/8" annulus built to 70 psi. Bled the 500 psi fr the 9-5/8" x 13-3/8" annulus, which stopped the tbg annulus fr bldg press. ND & pulled tree. Prep to PU & install riser. 10/25/04 Prep To LD 2-7/8" Tbg. MW 8.5, NU/ND BOP/Diverter 14 hrs, Test BOPS/Diverter 7-1/2 hrs, LDIPU Drill Pipe/Tbg 2 hrs, Circ 1/2 hr. NU BOPS. Chg out BPV for 2 way check. Attempted to tst BOPS. ND riser flange above tbg spoo. PU BOPS. Put plug in control line port. Landed BOPS & retightened flange. Tstd BOPS 250-5,000 psi. NU drlg nipple. Worked tbg free. Pulled hanger to rig floor. RU & circ tbg. 10/26/04 PU 3.5" DP WIPBR Spear. MW 8.5, LDIPU Drill Pipe/Tbg 21 hrs, PU/LD BHA & Tools 3 hrs. LD 340 jts 2-7/8", 6.5#, EVE, 8rd tbg, SSSV, 10 GLM's, Otis sliding sleeve, PBR seals. MU PBR spear & BHA. PU 3-1/2",15.50, S-135 drill pipe. 10/27/04 Rll-I To Lay Cmt Plug. MW 8.5, LDIPU Drill Pipe/Tbg 10 hrs, Trip 4-1/2 hrs, Circ 4 hrs, PU/LD BHA & Tools 3-1/2 hrs, Slip & Cut Drill Line 2 hrs. PU 3-1/2", 15.50, S-135 DP. Speared PBR @ 10,954'. Pulled & reI pkr. Dropped bar. Opened pmp out sub. Circ well. POOH w/pkr. Stood back DC's. LD BPR, pkr & tail pipe. PU cmt stinger. 10/28/04 Dress Off Cmt Plug. MW 8.5, Trip 14 hrs, Circ 4 hrs, LDIPU Drill Pipe Tbg 3 hrs, PU/LD BHA & Tools 1-1/2 hr, Cmt Plug 1 hr, W & R 1/2 hr. TIH w/3-1/2" DP & 3-1/2" muleshoe & tagged btm @ 11,890'. Spotted high vis 10.3 ppg pill @ 11,890'. Mixed & pmpd 190sx CI "G" w/3% CD-32, .28% R-3, .5% FL-63, 1 gps FP-6L. Disp cmt w/68 BFW. POOH. PU used 6" bit & 7" scraper. TIH & tagged cmt @ 10,700'. Dress of cmt plug 10,700'-10,760'. 10/29/04 Circ. Circ 12 hrs, Trip 7-1/2 hrs, W & R 4 hrs, Tst Csg 1/2 hr. Drld cmt fr 10,760'-10,960'. Weight tst, set 15K dwn on cmt plug, OK. Tstd csg to 3,000 psi for 30 min, OK. TOOH. PU window mill (top mill full 6"). TIH to 10,960', unable to rotate. Top drive stalling. MU 200 bbls gel & lubricant & pmpd around. 10/30/04 PU Whipstock Assembly. MW 8.7, Vis 36, PV 5, YP 14, Gel 5/5, pH 8.7, WL 20.0, Alk 0.1, CI13,OOO, Ca 150, Sd tr, Solids 2.0, Oil 0.1, Added 300sx Barite, 40sx Bicarbonate Soda, 3sx Biozan, 60sx Durogel, lOsx Flo- Vis, 5sx Lubricant EP & 250sx MI Gel. Circ 8- . . 2 1/2 hrs, Other 5-1/2 hrs, Trip 6-1/2 hrs, PU/LD BRA & Tools 3-1/2 hrs. Circ adding gel & lubricant. Est rot. TOOH & LD mill assembly & jars. PU & RIH w/bridge plug. Corelated & set plug @ 10,902'. POOH & RD WL. PU whipstock assembly. Attempted to tst MWD (would not tst). Changed out MWD collar. 10/31/04 Milling Window & Formation. MW 8.7, Vis 40, PV 5, YP 14, Gel 5/5, pH 8.5, WL 20.0, Alk 0.1, CI13,OOO, Ca 150, Sd tr, Solids 2.0, Oil 0.1, Added 8sx Flo-Vis, 1sx Lubricant EP & 5sx Soda Ash. Trip 8-1/2 hrs, Mill/Cut Sect Or Window 8 hrs, Rig Repair 5 hrs, PU/LD BHA & Tools 1-1/2 hr, Orient Tool Face 1 hr. Surf tstd MWD, tstd OK. Orient w/whipstock. TIH slowly w/whipstock assembly to 10,683'. Washed dwn fr 10,683', oriented tool face. Tagged bridge plug @ 10,902'. Set whipstock & oriented @ 52 deg left of high side. Milled window 10,883'-10,886'. Mill window & formation 10,886'-10,908'. 11/1/04 Prep For Using OBM, Filling Pits. MW 8.7, Vis 55, PV 7, YP 23, Gel 10/10, pH 8.7, WL 20.0, Alk 0.1, CI13,OOO, Ca 100, Sd tr, Solids 2.0, Oil 0.1, MBT 5.0, Added 200sx Barite & 7sx Biozan. Cleaned Mud Tanks 9 hrs, Circ 7 hrs, Build Mud Vol 4 hrs, Mill/Cut Sect Or Window 1-1/2 hr, Trip 1-1/2 hr, Displace 1 hr. Milled & dressed window 10,908'-10,915'. Top of window 10,883 '-btm 10,896'. Circ high vis sweep. Displ milling fluid wlFW. Cleaned pits. Prep for oil based mud. Filled pits w/oil based mud. 11/2/04 Prep For OBM. MW 8.5, Vis 60, PV 13, YP 6, Gel 3/6, CI13,OOO, Added 615sx Versadrill. Build Mud Vol 24 hrs. Filled pits w/OBM. Cont'd to prep platform for using OBM. RU slop tnk for rig drains in wellhead room #4. Installed pancake blanks in drains for pits & pmp room. Plugged wellhead room drains, installed new channel rubbers & float mounts on shaker #1. RU IDA solids plant, repaired DP press gauge. Slipped & cut 100' drlg line. Boat @ dock filling tnks @ 05:00 for displacement. 11/3/04 LD Milling Assembly @ 10,915', MW 8.6, Vis 130, PV 13, YP 6, Gel 3/6, CI26,000, Added 1sx Versawet, 1sx Flo-Vis, 4sx Versacoat, 6sx Durogel, 50sx Barite & 17,822 gals Mapco 200 Oil. Other 8 hrs, Trip 7-1/2 hrs, Displace 5-1/2 hrs, Build Mud Vol 3 hrs. Prep to disp w/OBM. Disp FW w/OBM. Injected FW dwn disposal well. TOOH w/mill assembly. Milled @ 3,711'. SD due to high winds (30-40 knots). Fin TOOH w/mill assembly. LD DC's & mills (top mill full gauge). 11/4/04 Drlg @ 11,105' (190'/24 hrs), Survey: 48.17 deg @ 11,047' (62.48 deg Azimuth, 9,263' TVD), MW 8.5, Vis 90, PV 15, YP 8, Gels 3/10, Cake 2.0, Cl 28,000, Solids 5.0, Oil 80.0, Added 40sx IMG-400, 35sx Lm & 2sx Versa-HRP, Bit #2,6", SEC FM2643, SN# 377969R, Bit/Nozzles 12/12/12, In @ 10,915' (190ì'14 hrs), ROP 13.57, WOB 5K, RPM 276, PP 2,600#, SPM 70, GPM 209, Liner Size 5-1/2" x 10". Slide Drld 8-1/2 hrs, Rot Drlg 5-1/2 hrs, Trip 4-1/5 hrs, PU/LD BRA & Tools 3 hrs, Orient Tool Face 1 hr, W & R 1 hr, Test BOPS/Diverter 1/2 hr. Function tstd BOPS, OK. PU bit & BHA. Surf tstd MWD. TIH to window. Oriented TF to 60 deg left. Worked through window & W & R fr 10,903'- 10,915'. Oriented TF. Slide drld fr 10,915'-10,946' (35 deg left). Rot drld fr 10,946'-11,017'. Oriented & slide drld fr 11,017'-11,035' (70-90 deg left). Rot drld fr 11,035'-11,061'. Oriented & slide drld fr 11,061 '-11,105' (90 deg left). . . 3 11/5/04 Sliding @ 11,320' (215:124 hrs), Survey: 50.10 deg @ 11,142' (53.78 deg Azimuth, 9,325' TVD), MW 8.5, Vis 94, PV 17, YP 12, Gels 9/20, Cake 2.0, CI29,000, Solids 5.0, Oil 80.0, Added Isx Versawet, Isx Versa-HRP, Isx Versacoat, 20sx IMG-400 & 20sx Lm, Bit #2, In @ 10,915' (405'l35-3/4 hrs), ROP 11.33, WOB 5K, RPM 291, PP 3,100#, SPM 75, GPM 224, Liner Size 5-1/2" x 10". Slide Drld 19-1/2 hrs, Drlg 2-1/4 hrs, Survey 1-3/4 hr, W & R 1/2 hI. Rot & slide drld fr 11,105'-11,320'. 11/6/04 TIH W/Bit #2 @ 11,365' (45124 hrs), Surveys: 51.99 deg @ 11,234' (45.54 deg Azimuth, 9,383' TVD), 52.72 deg @ 11,326' (37.60 deg Azimuth, 9,439'TVD), MW 8.5, Vis 93, PV 20, YP 11, Gels 11/24, Cake 2.0, CI 28,000, Sd 0.1, Solids 6.0, Oil 79.0, Added 80sx Barite, Bit #2, In @ 10,915', Out @ 11,365' (450'l43-3/4 hrs), ROP 10.29, WOB 5K, RPM 291, PP 3,100#, SPM 75, GPM 224, Liner Size 5-1/2" x 10", Bit 3, 6", Smith FM2643, SN# 377969R, Bit/Nozzles 12/12/12/12, In @ 11,365', ROP 11.75, WOB 5K, RPM 291, PP 3,100#, SPM 75, GPM 224, Liner Size 5-1/2" x 10". Trip 8-1/2 hrs, Slide Drld 8 hrs, Test BOPS/Diverter 4 hrs, PU/LD BHA & Tools 2-1/2 hrs, Circ 1 hI. Slide drld fr 11,320'- 11,365' (105 deg left). TOOH w/Bit #2. Tstd BOP's. MU bit & BHA. TIH w/Bit #3. 11/7/04 Sliding @ 11,600' (235:124 hrs), Surveys: 52.45 deg @ 11,421' (32-54 deg Azimuth, 9,497' TVD), 51.89 deg @ 11,512' (27.32 deg Azimuth, 9,553' TVD), MW 8.6, Vis 90, PV 18, YP 11, Gels 9/18, Cake 2.0, CI25,000, Sd 0.5, Solids 6.5, Oil 79.5, Added 15sx Lm, 20sx Versatrol & 840 gals Mapco 200 Oil, Bit 3, In @ 11,320' (235120 hrs), ROP 11.75, WOB 5K, RPM 290, PP 3,100#, SPM 75, GPM 224, Liner Size 5-1/2" x 10". Slide Drlg 15-1/4 hrs, Drlg 4-3/4 hrs, Trip 2 hrs, Service Rig 1 hr, Orient Tool Face 1/2 hr, W & R 1/2 hr. TIH to 11,240'. W & R 11,240'-11,365' (125). Rot 11,365'-11,391'. Orient & slide 11,391'- 11,448'. Rot 11,448'-11,483'. Orient & slide 11,483'-11,554'. Rot 11,554'-11,566'. Slide 11,566'-11,600'. 11/8/04 Sliding @ 11,735' (135:124 hrs), Survey: 52.26 deg @ 11,604' (20.21 deg Azimuth, 9,609' TVD), MW 8.7, Vis 90, PV 19, YP 11, Gels 9/22, Cake 2.0, CI26,000, Sd 0.5, Solids 6.5, Oil 78.5, Added lOsx Citric Acid, 15sx Durogel & 20sx Versatrol, Bit #3, In @ 11,365' (370'/37-3/4 hrs), ROP 9.80, WOB 8K, RPM 291, PP 3,100#, SPM 75, GPM 224, Liner Size 5-1/2" x 10". Slide Drld 16-1/4 hrs, W & R 3-3/4 hrs, Trip 2 hrs, Drlg 1-1/2 hr, Service Rig 1/2 hI. Slide & rot 11,600'-11,735' (70 deg left 9,688' TVD). 11/9/04 Sliding @ 11,882' (147'/24 hrs), Surveys: 55.85 deg @ 11,699' (14.92 deg Azimuth, 9,665' TVD) & 57.76 deg @ 11,774' (11.33 deg Azimuth, 9,706' TVD), MW 8.6, PV 20, Vis 93, YP 11, Gels 11/22, Cake 2.0, CI28,000, Sd 0.5, Solids 6.0, Oil 79.0, Added 2sx DeFoamex, 5sx IMG-400, 5sx Desco Chrome Free, 20sx Calcium Chloride & 420 gals mapco 200 Oil, Bit #3, In @ 11,365' (517'l56-1/4 hrs), ROP 9.19, WOB 8K, RPM 291, PP 3,100#, SPM 75, GPM 224, Liner Size 5-1/2" x 10". Slide Drld 17 hrs, W & R 4-1/2 hrs, Drlg 1-1/2 hr, Survey 1 hr. Slide 11,735'-11,742' (60 deg left). Rot & reamed 11,742'-11,763'. Slide & reamed 11,763'-11,845' (70 deg left). Rot 11,845'-11,848'. Orient & slide 11,848'-11,882' (70 deg left, 9,762' TVD). . . 4 11/10/04 Ream To Btm @ 11,888' (6'/24 hrs), Survey: 60.56 deg @ 11,831' (10.62 deg Azimuth, 9,735.17' TVD), MW 8.0, PV 20, Vis 92, YP 10, Gels 10/22, Cake 2.0, CI28,000, Sd 0.5, Solids 6.0, Oil 79.0, Added lOsx IMG-400, 19sx Durogel & 100sx Barite, Bit #3, In @ 11,365', Out @ 11,888' (523'/59-3/4 hrs), Rap 8.75, WOB lOK, RPM 291, PP 3,100#, SPM 75, GPM 224, Liner Size 5-1/2" x 10", Bit #4,6", SEC FM2643, SN# 10670751, Bit/Nozzles 12/12/12, In @ 11,888', WOB lOK, RPM 291, PP 3,100#, SPM 75, GPM 224, Liner Size 5-1/2" x 10". Trip 9-1/2 hrs, PU/LD BHA & Tools 7 hrs, Slide Drld 3-1/2 hrs, Slip & Cut Drill Line 2 hrs, W & R 1-1/2 hr, Circ 1/2 hr. Slide 11,882'-11,888'. TOOH w/Bit #3. TIH w/Bit #4. W & R 11,600'-11,888'. 11/11/04 Rig Repair, Top Drive @ 11,997' (109'/24 hrs), Survey: 65.17 deg @ 11,933' (2.73 deg Azimuth, 9,781.74' TVD), MW 8.7, PV 16, Vis 90, YP 10, Gels 10/22, Cake 2.0, CI27,500, Sd 0.5, Solids 6.0, Oil 80.0, Added 5sx IMG-400 & lOsx Gel, Bit #4,6", SEC FM2643, SN# 10670751, Bit/Nozzles 12/12/12, In @ 11,888' (109'/9-3/4 hrs), ROP 15.57, WOB lOK, RPM 291, PP 3,100#, SPM 75, GPM 224, Liner Size 5-1/2" x 10". Rig Repair 11-1/2 hrs, Slide Drld 5-1/4 hrs, Drlg 4-1/4 hrs, Trip 1-1/2 hr, Orient Tool Face 3/4 hr, Survey 1/2 hr, W & R 1/4 hr. Rot 11,888'-11,895'. Slide & reamed 11,895'-11,975' (75 deg left), Rot 11,975'-11,997' (TVD 9,808). TOOH to window. WO mechanic, top drive losing oil press. Mechanic to arrive on first chopper. 11/12/04 Drlg @ 12,097' (100'/24 hrs), MW 8.7, PV 21, Vis 110, YP 11, Gels 11/22, Cake 2.0, CI 28,000, Sd 0.5, Solids 6.5, Oil 79.0, Added Isx Versacoat, 5sx IMG-400, lOsx Calcium Chloride, 15sx Durogel & 13,780 gals Mapco 200 Oil, Bit #4,6", In @ 11,888' (209'/24-1/4 hrs), ROP 9.72, WOB lOK, RPM 70, PP 3,000#, SPM 75, GPM 224, Liner Size 5-1/2" x 10". Slide Drld 12 hrs, Rig Repair 6 hrs, Drlg 2-1/2 hrs, W & R 1-1/2 hr, Survey 1 hr. Repr'd top drive mtr & tstd. Till. Rot 11,997'-12,002'. Slide 12,002'-12,068'. Rot 12,068'- 12,081'. Reamed hole, survey & made connection. Rot 12,081 '-12,090'. Slide 12,090'- 12,097'. 11/13/04 Drlg @ 12,255' (158'/24 hrs), Surveys: 75.55 deg @ 12,117' (352.92 deg Azimuth, 9,841.74' TVD) & 76.08 deg @ 12,212' (347.61 deg Azimuth, 9,865.04' TVD), MW 8.7, PV 22, Vis 103, YP 11, Gels 11/25, Cake 2.0, CI27,000, Sd 0.5, Solids 6.5, Oil 78.5, Added 5sx Citric Acid, 6sx IMG-400, lOsx Durogel, lOsx Calcium Chloride & 50sx Barite, Bit #4,6", In @ 11,888' (367'/45-1/4 hrs), ROP 7.5, WOB lOK, RPM 60, PP 3,000#, SPM 75, GPM 224, Liner Size 5-1/2" x 10". Slide Drld 15-3/4 hrs, Drlg 5-1/4 hrs, W & R 1-3/4 hr, Survey 1-1/4 hr. Slide 12,097'-12,134' (110 deg left). Rot 12,134'-12,139'. Slide 12,139'-12,151' (110 deg left). Rot 12,151 '-12,164'. Reamed hole. Rot 12,164'-12,200'. Slide 12,200'-12,255' (140 deg left). 11/14/04 TIH w/Bit #5 @ 12,315' (60'/24 hrs), MW 8.7, PV 22, Vis 100, YP 12, Gels 10/25, Cake 2.0, CI 28,000, Sd 0.8, Solids 6.5, Oil 78.5, Added lOsx Calcium Chloride, lOsx Lm & 80sx Barite, Bit #4,6", In @ 11,888', Out @ 12,315' (427/53-3/4 hrs), ROP 7.1, WOB lOK, RPM 60, PP 3,000#, SPM 75, GPM 224, Liner Size 5-1/2" x 10", Bit #5,6", FM2643R, SN# 11530RW, Bit/Nozzles 12/13/17/16, In @ 12,315', WOB lOK, RPM 60, PP 3,000#, SPM 75, GPM 224, Liner Size 5-1/2" x 10". Trip 7-1/2 hrs, Drlg 7 hrs, Rig Repair 3-1/2 hrs, PU/LD BRA & Tools 2 hrs, Wiper Trip/Short Trip 1-1/2 hr, Slide Drld 1-1/2 hr, Survey 1/2 hr, Circ 1/2 hr. Slide 12,255'-12,268'. Rot 12,268'-12,315'. TOOH for Bit #5. TIH w/Bit #5. . . 5 11/15/04 TOH & LD DP @ 12,501' (186'/24 hrs), Surveys: 75.40 deg @ 12,304' (345.82 deg Azimuth, 9,887.70' TCD) & 75.15 deg @ 12,398' (340.82 deg Azimuth, 9,911.61 , TVD), MW 8.7, PV 23, Vis 100, YP 12, Gels 10/25, Cake 2.0, CI28,000, Sd 0.8, Solids 6.5, Oil 79.5, Added lOsx Calcium Chloride & 15sx Lm, Bit #5,6", FM2643R, SN# 11530RW, Bit/Nozzles 12/13/17/16, In @ 12,315' (186ï15-1/2 hrs), ROP 12.0, WOB lOK, RPM 60, PP 3,000#, SPM 75, GPM 224, Liner Size 5-1/2" x 10". Slide Drld 8 hrs, Drlg 7-1/2 hrs, Trip 3-1/2 hrs, LD/PU Drill Pipe Tbg 2-1/2 hrs, W & R 1-1/2 hr, Survey 1 hI. TIH w/Bit #5. Rot 12,315'-12,359'. Slide 12,359'-12,407' (140 deg left). Rot 12,407'-12,452'. Slide 12,452'- 12,494' (180 deg left). Rot 12,494'-12,501'. TOOH to window, pmpd sweep. TOOH LD 3- 1/2" DP. 11/16/04 Prep To Tst BOP's @ 12,501' (0'/24 hrs). LD 3-1/2" DP. Chg'd out pipe rams & prep to PU 4" HT38 DP. Prep to tst BOP's, TIH w/4" DP & drill ahead. 11/17/04 PU 4" HT38 DP @ 12,501' (0'/24 hrs). Test BOP's - OK. PU 10,883' of 4" HT38 DP. Prep to Till & drill ahead. 11/18/04 Drilling @ 12,502' (1 '/24 hrs). Fin PU 4" DP. PU Bit #6, BHA & TIH. Reamed 81' to btm. Rot 12,501 '-12,502'. Prep to drill ahead. 11/19/04 PU 6" BRA @ 12,511' (9'/24 hrs). Rot 12,502'-12,511'. Pmpd sweep. TOOH. PU 6" BRA. Prep to TIH w/6" BHA & drill ahead. 11/20/04 Till @ 12,515' (/24 hrs). MU 6" mill, 2 junk baskets & BHA. Till & mill 12,511'-12,515'. TOH, LD mill assembly. MU 6" drlg assembly & TIH. Prep to drill ahead. 11/21/04 Sliding @ 12,655' (140'/24 hrs). TIH w/bit #8. Slid & rotated fr/12,515'-12,655'. Prep to drill ahead. 11/22/04 Sliding @ 12,828' (173'/24 hrs). Slid & rotated fr/12,655'-12,828'. Prep to drill ahead. 11/23/04 Drilling @ 13,014' (186'/24 hrs). Slid & rotated fr/12,828'-13,014'. Prep to drill ahead. 11/24/04 Drilling @ 13,166' (152'/24 hrs). Slid & rotated fr/13,014'-13,166'. Prep to drill ahead. 11/25/04 Drlg @ 13,228' (62'/24 hrs). Rot 13,166'-13,169'. TOOH for bit. Chg'd out bit & BHA. Till. Slide & rot 13,169'-13,228'. Drlg ahead. 11/26/04 TOOH For BHA @ 13,358' (130'/24 hrs). Slide & rot 13,228'-13,358'. Cire btms up & TOOH for BHA. Prep to ehg out BHA & TIH. 11/27/04 Sliding @ 13,472' (114'/24 hrs). TOOH w/Bit #9. MU Bit #10 & Till. Slide & rot 13,358'- 13,472'. Drlg ahead. . . 6 11/28/04 Circ Btms Up For Trip @ 13,580' (108'/24 hrs). Slide & rot 13,472'-13,580'. Circ btms up for trip. Prep to TOOH for bit. 11/29/04 Circ & Cond Mud @ 13,583' (3'/24 hrs). TOOH, tstg BOP's, OK. MU new bit & BHA. TIH & rot 13,580'-13,183'. C & C mud. Drlg ahead. 11/30/04 Drlg @ 13,663' (80'/24 hrs). Repaired plugged flowline. TIH to btm. Rot 13,583'-13,663' (9,981' TVD). Drlg ahead. 12/1/04 Drlg @ 13,782' (119'/24 hrs). Slide & rot 13,663'-13,782' (9,972' TVD). Drlg ahead. 12/2/04 PU New Bit & BRA @ 13,832' (50'/24 hrs). Slide & rot 13,782'-13,832'. TOOH for bit. Prep to TIH w/Bit #2. 12/3/04 Drlg @ 13,870' (138'/24 hrs). TIH w/Bit #12. Reamed 94' to btm. Slide & rot 13,832'- 13,970'. Drlg ahead. 12/4/04 Drlg @ 14,102' (132'/24 hrs). Slide & rot 13,970'-14,102' (9,987'TVD). Drlg ahead. 12/5/04 Drlg @ 14,214' (112'/24 hrs). Slide & rot 14,102'-14,214' (9,987'TVD). Drlg ahead. 12/6/04 LD Bit #12 @ 14,315' (101 '/24 hrs). Slide & rot 14,214'-14,315'. TIH for bit. LD Bit #12. Prep to PU new bit & TIH. 12/7/04 Drlg @ 14,442' (127'/24 hrs). Chg'd out bit & BHA. TIH & washed to btm. Rot 14,315'- 14,442' (9,995' TVD). Drlg ahead. 12/8/04 Drlg @ 14,498' (56'/24 hrs). Rot 14,442'-14,443'. TOOH, chg out bits & TIH. Rot 14,443'- 14,498' (9,997' TVD). Drlg ahead. 12/9/04 Drlg @ 14,682' (184'/24 hrs). Slide & rot 14,498'-14,682' (9,995' TVD). Drlg ahead. 12/10/04 Drlg @ 14,791' (109'/24 hrs). Slide & rot 14,682'-14,791'. Prep to TOOH for bit. 12/11/04 Washed & reamed to btm @ 14,791' (0'/24 hrs). TOH, tstd BOP's. MU new bit & BHA. TIH. Drlg ahead. 12/12/04 Drilling @ 15,000' (209'/24 hrs). Slide & rot fr 14,791 '-15,000'. Drlg ahead. 12/13/04 Drilling @ 15,228' (228'/24 hrs). Rot fr 15,000'-15,228'. Drlg to TD. 12/14/04 Running 7" Scraper @ 15,305' (77'/24 hrs). Rot fr 15,228'-15,305'. Circ btms up. TOOH. v MU 6" bit & 7" scraper & TIH. Prep to clean out & log. . . 7 12/15/04 C & C Hole @ 15,305' (0'/24 hrs). TIH w/bit & scraper to window. Circ btms up. TOOH. TIH to TD & C & C hole. Prep to displace hole to #4 diesel. 12/16/04 Running 5" Liner @ 15,305' (0'/24 hrs). Displaced hole to #4 diesel & 5#/bbl Solotex. TOOH. PU 5" slotted liner & TIH. Prep to set 5" slotted liner. 12/17/04 RIH w/Clean Out Assembly @ 15,305' (0'/24 hrs). TIH & set 5" slotted liner @ 15,300' (liner hanger pkr @ 10,598). TOOH. PU Baker FB-l production pkr. TIH & set @ 10,517'. TOOH & PU 2-3/8" clean out assembly. Prep to clean out. 12/18/04 Cleaning Mud Pits @ 15,305' (0'/24 hrs). TIH w/clean out assembly. Rev circ hole. Displaced well w/FW. Prep to tst pkr & LD DP. 12/19/04 LD DP @ 15,305' (0'/24 hrs). Stung into pkr & tstd to 1,000 psi. TOOH & LD DP. Prep to RIH w/3-1/2" tbg. 12/20/04 Locate Tbg Lk @ 15,305' (0'/24 hrs). TIH w/316 jts 3-1/2",9.3#, L-80, BTC tbg & 31 jts 3- 1/2",9.3#, L-80, 8rd tbg wi 10 GLM's, SSSV & 11.1' of seals. (Tagged pkr 22.09' deeper with tbg measurements. New recorded depths: pkr @ 10,540',3-1/2" XN nipple (2.625" ID) @ 10,559' & WLREG @ 10,567'.) Stabbed into seal assbly & tstd, would not tst. RU SL & attempted to locate lk. Prep to locate tbg lk. 12/21/04 Rig Released @ 15,305'. RIH w/slickline to locate tbg lk (check valve seated), tbg holding pressure. Spaced out tbg, circ pkr fluid & landed tbg hanger. Tstd tbg to 1,400 psi, tstd OK. RD tst equipment & released rig 12/21/04 @ 06:00 hrs. Moved to MGS C41-23LN. ,/ 12/22/04 RU test lines to tst tnk & flow tstd well. Prep to flow test well. 12/23/04 Started up gas lift @ 2100 hrs. Producing load into flowback tank. Recovered 466 load. 12/24/04 P: 600 BPD gross, 48% oil & 52% OBM & water.Csg press = 900 psi. Total load = 1000 bbl. 12/25/04 P: 814 BO, 110 BW & 176 bbl OBM. Csg press = 900 psi. Started transfer prod from flowback tank to prod facility. Put well in test. 12/26/04 P: 991 BO, 189 BW, 263 MCF. Csg Press = 890 psi. WHP = 120 psi. Lifting off GL V 2-3. 12/27/04 P: 896 BO, 134 BW, 410 MCF. Csg Press = 890 psi. WHP = 120 psi. Lifting off GLV 2-3. 12/28/04 P: 839 BO, 104 BW, 297 MCF. Csg Press = 885 psi. WHP = 100 psi. Lifting off GL V 3. 12/29/04 P: 814 BO, 81 BW, 236 MCF. Csg Press = 885 psi. WHP = 80 psi. Lifting offGLV 3. . . 8 12/30/04 P: 804 BO, 60 BW, 278 MCF. Inj 1019 MCF lift gas w/Csg Press = 885 psi. WHP = 100 psi. Lifting off GL V 3. 12/31/04 P: 744 BO, 74 BW, 235 MCF. Inj 1034 MCF lift gas w/Csg Press = 885 psi. WHP = 80 psi. Lifting off GL V #4. 1/1/05 P: 701 BO, 69 BW, 289 MCF. Inj 846 MCF lift gas w/Csg Press = 875 psi. WHP = 85 psi. Lifting off GL V #5. 1/3/05 P: 670 BO, 70 BW, 225 MCF. Inj 888 MCF lift gas w/Csg Press = 880 psi. WHP = 80 psi. Lifting off GL V #4. 1/5/05 P: 624 BO, 102 BW, 190 MCF. Inj 989 MCF lift gas w/Csg Press = 890 psi. WHP = 80 psi. . MGS C22A-26LN Cook Inlet, Alaska Leg 4, Conductor 30 API No.: 50-733-20415 Sidetracked: 11-1-04 Replaced C-line well P&A'd June '90 Spud C22A-26 on 7-18-90 P&A'd C22A-26 on 10-28-04 Conductor Csg: 24" @ 370'. Surf Csg: 13 3/8", 54.5 Ib, K55, BTC. Set@ 1,155'. Cmt'dw/441 sx. Intermediate Csg: 95/8", L80 LTC. Set @ 9,797'. Cmt'd wI 560 sx. Surf - 4,123' : 43.5# 4,123 -9,797' : 47# SQZ'd TOL wI 160 sk on 12-29-90. Drilling Liner: 7" Window Milled @ 10,883'. TOL @ 8,989'. Cmt'd w/1500 sk. (Original Depth @ 12,039') 8,989 - 10,280' : 26# L80 10,280 - 10,691' : 29# L80 10,691 -10,883': 32# P110 Prod Liner: 5" 18# L80 Hydril 513. Slotted Csg wI Blank sections. Set @ 15,300'. TOL @ 10,598' 5" TIW HHP Pkr @ 10,598'. Blank Csg Sections: 10,614 -11,316' 11,586 - 11,629' 12,773 - 12,905' 14,093 - 14,226' 14,672 - 14,843' 15,074 -15,117' 15,256 - 15,300' TO: 15,305' MD (9,967' TVD) . Item GLM 1 GLM 2 GLM3 GLM4 GLM5 GLM6 GLM7 GLM8 GLM9 GLM 10 PLF 1-7-05 KB: 35' Water Depth: 73' MSL TBG: 3-%" 9.3# 8rd & 8.8# BTC @ 10,567' Set: 12-20-04 MD 1918 3207 4617 5882 7144 8169 8894 9505 10028 10467 TVD 1881 2967 4021 4961 5815 6623 7328 7934 8434 8821 Psc Pso 905 951 895 939 885 923 875 908 865 895 855 881 845 866 835 867 825 849 ORIFICE Port 12 12 12 12 12 12 12 16 16 24 6' Pup Jt 3-1/2" 9.3# L80 8rd @ 315' Baker TE5 SSSV (2.81" ID) @ 322' 6' Pup Jt 3-1/2" 9.3# L80 8rd @ 327' 21 Jts 3-1/2" 9.3# L80 8rd EUE X-over 3-%" 9.3# 8rd Box X BTC Pin @ 991' 316 Jts 3-1/2" 8.8# L80 BTC X-over 3.5" 9.3# BTC Bx X 8rd Bx @ 10,532' 3-%" X Nipple (2.81" ID) 8rd 9Cr @ 10,533' 6' Pup Jt 3-1/2" 9.3# L80 8rd @ 10,539' Baker 12' Lac w/2 Seals b/w spacer @10,540' 7" Baker FB-1 Perm Pkr (85-40) @ 10,540' * 10' Baker SBE (80-40) @ 10,542' X-over SBE to 3-%" 8rd Pin @ 10,552' 6' Pup Jt 3-1/2" 9.3# L80 8rd @ 10,553' 3-%" XN Nipple (2.625" ID) 8rd 9Cr @ 10,559' 6' Pup Jt 3-1/2" 9.3# L80 8rd @ 10,560' WLREG @ 10,567' * Tbg tally was 22' deeper than DPM. All depths based on Tbg. (Pkr was set on DP.) Liner Across: HC, HE, HI, HK, HN & back thru HK, HI, HE & HC. 0/ ;[tg XTO Energyt.,Slot #4-30 Platform C, Middle Ground Shoal, Cook Inlet, Alaska SURVEv4tTING Page 1 Wellbore: C22A-26LN Wellpath: MWD wI Sag <11047 -15305'> Date Printed: 7-Jan-2005 r&ií. BAKER HUGHES INTEQ Wellbore Name C22A-26LN I Created I 5-Nov-2004 I Last Revised 117 -Oec-2004 -- Well Name I Government 10 I Last Revised C22A-26 150-733-20415 117 -Oec-2004 Slot Name slot #4-30 Installation Name Platform C Field Name Middle Ground Shoal Cf CC I I L__ Latitude Lon itude North, East N60 45 49.7542 W151 307.3364 4780.00S 1538.00W Eastin 233063.0833 Coord S stem Name AK-4 on NORTH AMERICAN DATUM 1927 datu Eastin 234754.5480 s All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Actual Datum 1 05.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 348.72 degrees Bottom hole distance is 2923.24 Feet on azimuth 285.77 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ;[~ . XTO Energy, Inc.,slot #4-30 Platform C, Middle Ground Shoal,Cook Inlet, Alaska SURVEVITING Page 2 Wellbore: C22A-26LN Wellpath: MWD wI Sag <11047 -15305'> Date Printed: 7-Jan-2005 ,&¡. BAKER HUGHES INTEQ Well path Report MD[ft] Inc[deg] I Azi[deg] rvD[ft] Vertical North[ft] East[ft] Station Station Dogie Vertical Station Comment I Depth S8 Position(Grid Position(Grid g Section[ft] North) East) [deg/1 00ft1 10883.00 43.46 65.26 9148.28 9043.28 3056.358 2384.25V\ 2471185.35 228963.30 0.00 -2530.84 I Tie-In Point from Original Hole _J1047.00 48.17 62.48 9262.56 9157.56 ' 3004.48S 2278.76V\ 2471234.80 229069.94 3.12 -2500.61 i 11142.00 50.10 53.78 9324.78 9219.78 2966.54S 2217.90V\ 2471271.33 229131.65 7.21 -2475.31 11234.00 51.99 45.54 9382.68 9277.68 2920.25S 2163.50~ 2471316.36 229187.09 7.26 -2440.56 Ilntercolated Azimuth --l 11316.00 52.62 ¡ 38.45 9432.86 9327.86 2872.085 2120.15 2471363.53 229231.53 6.88 -2401.80 11326.00 52.72 37.60 9438.93 9333.93 2865.828 2115.25V\ 2471369.68 229236.57 6.88 -2396.61 Î 11421.00 52.45 I 32.54 9496.67 9391.67 2804.10S 2071.92V\ 2471430.39 229281.31 4.24 -2344.57 11512.00 51.89 , 27.32 9552.51 9447.51 2741.858 2036.07V\ 2471491.80 229318.57 4.57 -2290.54 11604.00 52.26 20.21 9609.10 9504.10 ,2675.51S 2006.87V\ 2471557.46 229349.28 6.11 -2231.19 11699.00 55.85 i 14.92 9664.88 9559.88 2602.218 1983.75V\ 2471630.20 229374.07 5.88 -2163.83 11774.00 57.76 11.33 9705.95 9600.95 2541.11S 1969.52V\ 2471690.97 229389.69 4.75 -2106.69 11831.00 60.56 10.62 9735.17 9630.17 2493.06S 1960.21V\ 2471738.78 229400.10 5.03 -2061.40 11933.00 65.17 2.73 9781.74 9676.74 2403.028 1949.80V\ 2471828.56 229412.56 8.23 -1975.13 12026.00 71.60 357.07 9816.00 9711.00 2316.658 1950.05V\ 2471914.92 229414.29 8.93 -1890.38 12039.00 72.16 356.4 7 9820.04 9715.04 2304.318 1950.74V\ 2471927.26 229413.88 6.16 -1878.14 7" Liner 12117.00 75.55 352.92 9841.74 9736.74 2229.74S 1957.69V\ 2472001.98 229408.64 6.16 -1803.65 12212.00 76.08 347.61 9865.03 9760.03 2139.008 1973.26V\ 2472093.05 229395.15 5.45 -1711.62 12304.00 75.40 345.82 9887.69 9782.70 , 2052.22S 1993.75V\ 2472180.27 229376.65 2.03 -1622.51 12398.00 75.15 340.82 9911.60 9806.60 1965.168 2019.83V\ 2472267.90 229352.57 5.15 -1532.03 12445.00 74.36 339.26 9923.96 9818.96 1922.548 2035.31 V\ 2472310.86 229338.07 3.62 -1487.21 ] 12546.00 70.17 336.37 9954.73 9849.73 1833.48S 2071.60V\ 2472400.72 229303.83 4.96 -1392.77 12643.00 74.14 340.32 9984.46 9879.46 1747.698 2105.62V\ 2472487.27 229271.78 5.64 -1301.98 ' 12735.00 81.03 346.58 10004.24 9899.24 1661.65S 2131.12111i 2472573.87 229248.25 10.01 -1212.61 " 12831.00 87.65 350.89 10013.71 9908.71 1568.038 2149.75111i 2472667.89 229231.77 8.22 -1117.15 12921.00 89.58 348.71 10015.89 9910.89 1479.48S 2165.68VIA 2472756.78 229217.87 3.23 -1027.20 13019.00 93.61 350.03 10013.16 9908.16 1383.228 2183.75111i 2472853.42 229202.01 4.33 -929.27 1 13112.00 95.62 350.71 10005.6 9900.68 1291.848 2199.26111i 2472945.14 229188.60 2.28 -836.62 13205.00 94.53 352.22 9997.45 9892.45 1200.23S 2213.00111i 2473037.03 229176.95 2.00 -744.09 13299.00 95.18 352.23 9989.49 9884.49 1107.438 2225.68111i 2473130.10 229166.40 0.69 -650.60 13395.00 93.12 350.80 9982.55 9877.55 1012.748 2239.80111i 2473225.08 ! 229154.45 2.61 -554.98 13488.00 91.06 347.06 9979.15 9874.15 921.558 2257.65111i 2473316.65 229138.69 4.59 -462.06 13583.00 88.63 346.59 9979.41 9874.41 829.068 2279.30111i 2473409.62 229119.16 2.61 -367.12 13682.00 92.08 345.39 9978.80 9873.80 733.028 2303.26111i 2473506.17 229097.41 3.69 -268.25 13777.00 90.02 347.83 9977.06 9872.06 ' 640.638 2325.25W 2473599.04 229077.53 3.36 -173.34 13874.00 87.44 351.4 7 9979.21 9874.21 545.268 2342.67111i 2473694.79 229062.30 4.60 -76.41 13967.00 88.42 351.27 9982.57 9877.57 ' 453.378 2356.62111i 2473786"~ _.229050.46 1.08 16.43 14061.00 89.43 348.30 9984.33 9879.33 360.898 2373.28111i 2473879.80 229035.91 3.34 110.39 14154.00 89.31 345.94 9985.35 9880.35 270.248 2394.01111i 2473970.90 229017.26 2.54 203.34 I 14250.00 87.40 342.27 9988.11 9883.11 177.978 2420.28VIA 2474063.75 228993.11 4.31 298.97 14346.00 87.92 341.82 9992.03 9887.03 86.728 2449.86111i 2474155.65 228965.64 0.72 394.24 \ 14441.00 89.49 343.82 9994.17 9889.18 4.01N 2477.9111\i 2474246.99 228939.67 2.68 488.70 ~ 14536.00 88.97 345.60 9995.45 9890.45 I 95.63N 2502.9511\i 2474339.16 228916.72 1.95 583.46 I l 14634.00 90.17 344.10 9996.19 9891.19 , 190.22N 2528.56VIA 2474434.311 228893.28 1.96 681.23 14729.00 92.48 342.68 9993.99 9888.99 281.22N 2555.71111i 2474525.91. 2~8868.23 2.85 775.78 I 14823.00 92.32 338.27 9990.05 9885.05 369.72N 2587.0911\i 2474615.10 228838.88 4.69 868.71 I 14921.00 90.88 330.88 9987.31 9882.31 458.13N 2629.12111i 2474704.44 228798.88 7.68 963.63 15013.00 91.92 331.67 9985.07 9880.06 538.78N 2673.3211\i 2474786.08 228756.54 1.42 1051.37· 15108.00 92.84 330.77 9981.12 9876.12 621.97N 2719.0211\i 2474870.30 228712.76 1.35 1141.90 15207.00 94.33 331.54 9974.93 9869.93 708.51 N 2766.69W 2474957.91 228667.08 1.69 1236.09 i I All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TV D's are from Rig ( Actual Datum 1 05.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 348.72 degrees Bottom hole distance is 2923.24 Feet on azimuth 285.77 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ;[!~ XTO Energyt.,Slot #4-30 Platform C, Middle Ground Shoal, Cook Inlet, Alaska SURVEVITING Page 3 Well bore: C22A-26LN Well path: MWD wI Sag <11047 -15305'> Date Printed: 7-Jan-2005 ,&¡. BAKER HUGHES INTEQ Wellpath Report MD[ft) Inc[deg) Azi[deg) TVD[ft) Vertical North[ft) East[ft) I ration Station Dogie Vertical Station Comment Depth SS Position(Grid Position(Grid g Section[ft) i North) East) [deg/1 OOftl 15250.00 94.75 331.52 9971.53 9866.53 ' 746.20N 2787.12W 2474996.04U28647.52 0.98 1277.04 .---- 15305.00 95.43 331.52 9966.65 9861.65 1 794.35N 2813.24wi 2475044.78 i 228622.50 1.24 1329.38 Projected Data - NO SURVEY, 13 i ! i 3/8" Casino. 9 5/8" Casino Top of the Producing Interval: 11316 MD 2372.08' FNL, 1621.85' FWL Sec. 26, T8N, R13W TD: 15305 MD 1294.35' FSL, 928.76' FWL Sec. 23, T8N, R13W All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 1 05.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 348.72 degrees Bottom hole distance is 2923.24 Feet on azimuth 285.77 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated · XTO Energyt.,Slot#4-30 Platform C, Middle Ground Shoal, Cook Inlet, Alaska SURVEVITING Page 4 Wellbore: C22A-26LN Well path: MWD wI Sag <11047 -15305'> Date Printed: 7-Jan-2005 "~i. BAKER HUGHES INTEQ ;[tg Comments MDlftl TVDrftl Northrftl Eastlftl Comment 10883.00 9148.28 3056.35S 2384.25W Tie-In Point from Oriainal Hole 11234.00 9~82.68 2920.25S 2163.50W Interoolated Azimuth 15305.00 9966.65 794.35N 2813.24W Proiected Data - NO SURVEY -- -~-~ Hole Sections Diameter Start Start Start Start End I~nd End Start Wellbore finl MDlftl TVDlftl Northrftl Eastlftl MDfftl TVDfftl Northrftl Eastlftl 171/2 0.00 0.00 O.OON O.OOE 1155.00 , 1149.51 69.97S 39.27W C22A-26 12 1/4 1155.00 1149.51 69.97S 39.27W 9797.00 '-1- 8215.39 3394.48S 2781.54W C22A-26 81/2 9797.00 8215.39 3394.48S 2781.54W 12140.00 I 10036.53 2207.66S 1960.69W C22A-26 Casin s Name Shoe Wellbore East ft 39.27W C22A-26 2781.54W I C22A-26 1604.61W I C22A-26 13 3/8" Casin 9 5/8" Casin 7" Liner Surve Reference 712100 8496 : TVD ft J.5305.00 10883.0 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 1 05.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 348.72 degrees Bottom hole distance is 2923.24 Feet on azimuth 285.77 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated \-' ~1r~1fŒ (ID~ ~~~~æ~ AI,A.SHA. OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. -¡rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bobby Smith Drilling Manager XTO Energy, Inc. 3000 North Garfield, Suite 175 Midland, Texas 79705 Re: Middle Ground Shoal C22A-26LN XTO Energy, Inc. Pennit No: 204-182 (Revised) Surface Location: 500' FSL, 1538' FEL, SEC. 23, T8N, R13W, SM Bottomhole Location: 1216' FSL, 855' FWL, SEC. 23, T8N, R13W, SM Dear Mr. Smith: Enclosed is the approved revised application for pennit to redrill the above development well. This revision was necessary due to the bottomhole location changing in excess of 500' laterally. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to _. ness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 (p ger). DATED this Dday of December, 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~TO ~bRGY '-/ "-"" RECEIVED DEC 15 2004 December 14,2004 Alaska Oil & Gas Cons. Coronia.ion Anchorage Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: Supplemental Application for Permit to Drill: C22A-26LN Sidetrack Dear Mr. Norman, XTO Energy, Inc. hereby submits a supplemental application for a Permit to Drill its Well C22A -26LN from Platform C in the Middle Ground Shoal Field of Cook Inlet. The well was previously permitted and is nearing completion of the drilling phase. However, directional drilling challenges and differences between predicted geological tops and those actually encountered have resulted in a predicted bottomhole location./ approximately 575' laterally distant from the one originally permitted. As such, 20 AAC 25.015 applies, which requires the submittal of a new application and filing fee. Consequently, please find attached a revised Form 10-401 and an accompanying check Vi for $100.00 payable to the State of Alaska. If you have any questions or require additional information, please contact me at (432) 620-6718 or Bill Penrose at (907) 258-3446. Sincerely, XTO ENERGY, INC. fdlr ¡ ~ Bobby L. Smith Drilling Manager enclosures cc: Bill Penrose ORIGINAL XTO Energy Inc. · 200 North Loraine, Suite 800 · Midland, Texas 79701 (432) 682-8873 · Fax (432) 687-0862 A ""&.AI 1 a. Type of Work: Drill D Redrill 0 1 b. Current Well Class: Exploratory D Development Oil [21' u Zone 0 Re-entry 0 Stratigraphic Test 0 Service 0 Development Gas o Single Zone 0 2. Operator Name: 5. Bond: Blanket 0 Single Well 0 11. Well Name and Number: XTO Enerav. Inc. Bond No. 103652600 C22A-26LN 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3000 North Gañield. Suite 175. Midland. TX 79705 MD: 15.300' TVD: 9.981' Middle Ground Shoal 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 500'FSL,1538'FEL,See.23,T8N,R13VV,SM ADL 18756 Top of Productive Horizon: 8. Land Use Permit: 13. APproXima1~pud Datet. 1170' FNL, 1619' FVVL, See 26, T8N, R13VV, 8M N/A 10/J.812004 ,( Total Depth: 9. Acres in Property: 14. Distance to Nearest 1216' FSL, 855' PNL, See 23, T8N, R13VV, 8M 5120 Property: 1,619' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well SUrface~:; 2474186 ~231417 )1¡2.../¿¡.bf Zone- AK-4 (Height above GL): 105 feet ASL Within Pool: 157' from C21-26 16. Deviated wells: Kickoff depth: 10,950 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3,200 psi Surface: 2,101 psi 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c.f.orsacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 6" 5" 18# L-80 STL 4,650' 10,650' 9.665' 15,300' 9.981' N/A - slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 12,140' 10,020' None 11,819' 9,786' Bit/BHA @ 12039' Casing Length Size Cement Volume MD TVD Structural Conductor 370' 24" 370' 370' Surface 1.155' 13-3/8" 441 sx 1.155' 1,150' Intermediate 9.797' 9-5/8" 560 sx 9.797' 8.215' Production Liner 3.050' 7" 1.500 sx 12.039' 10.019' Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch 'U Drilling programU Time v. Depth Plot U Shallow Hazard Analysis U Property Plat 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 MC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bill Penrose 258-3446 Printed Name BObby Smith Title Drillina Manaaer Signature ~ ( C-/ Phone 432-620-6718 Date /.?p~ 0 V , 7 Commission Use Only / Permit to Drill </ . B IAPI Number: , Permit APproval,~ ~¡¿' See cover letter for other Number: 2C>" -I 2- 50- ')33-ZDt//S"-O/ Date: l;,t~ /!J. requirements. Condftions of approval : ~ , S equired Yes 0 No ~ Mud log required Yes 0 No ~ ø. ydro sulfide measures Yes 0 No ~ Directional survey required Yes ~ No 0 Other: ~l-~ ""u-.\$cPk,,\. ~Q~\c.,,~''''''~~\'=:. \~~'t~ J'VJ /Þcf . ~ BY ORDER OF .. Approv b.....--11 . ~ 1H}: ÇO.,M¿SSION Date: \../ V '--- OR\\S\1\lAL , , Form 10-401 Revised 12/2003 Submit inDuplicate STATE OF ALASKA ALAS~L AND GAS CONSERVATION COMMIS~~ PERMIT TO DRILL 20 MC 25 005 · '" -- ......, .... II V .... LJ . DEC 1 5 2004 ~I(" Alaska Oil & Gas Cons. Commission '~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER c2z'z/1- Zb '-4 WELL NAME PTD# mcß :5 2.oÝ-IB2- J,,'- v' Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If APJ Dumber last two. (2) digits are between 60-69) Explorati on Stratigraphic ~'CLUE"· The permit is for a new weJlbore 'segment of existing wen ~ Permit No, API No. . Production. sbould continue to be reponed as a fUDction' of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(f), an records, data and Jogs acquired for the pilot bole must be dearly differentiated In botb Dame (name on permit plus PH) and API Dum ber (SO - 70/80) from records, data and Jogs acquired for wen (name on permit). paOT (PH) SPACING EXCEPT10N DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25..0SS~ Approval to perforate and produce is contingent UpOD issuanee of ~ conservation order approving a spacing e:J ceptioD. (CompaDY Name) assumes tbe liability of auy protest to tbe spacing .e:JceptioD that may occur. AU dry ditch sample sets submitted to tbe Commission must be in no greater ·tbaD 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample iIiter:va)s tbrougb target 7.0Des. 575/ Clc~ -h ~ ~~ ¿$IlL · k /2. . /0 ·0;/ L!t) ?n1 l ~ J 1,_ .-~ '-{ ( ( . - ield & Pool MIDDLE GROUND SHOAL, E,F.G OIL - 524114 Well Name: MGS C22A-26LN Program DEV Well bore seg 0 PTD#: 2041820 Company XTO ENERGY INC Initial Classrrype DEV /1-0IL GeoArea 820 Unit 00000 On/Off Shore Off Annular Disposal 0 Administration 1 Permitfeeattaçhe.d_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ Yes.. _ _ _. _feeJs(eguir.edfoJthjs.5}5'.changeto_an_apprpve.d.bpttQmOQlel.ocaJionaflerdrilltng.operattooshayebe9-uo._ 2 tease_number _app-rORriate_ _ _ _ . _ _ _ . _ . _ _ _ . _ _ _ _ _ _ . _ _ . _ . _ _ _ . Yes. . . . . . . Entire wellJn ADL 18]56 . _ . . . . . _ _ _ . _ . . . . . . . . II'~ _Unique welt name _aod oumb_er _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ _ Yes. _ _ . _ . _ . _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ . _ . . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ . . . _ _ . _ . _ _ _ . _ . . . . . _ _ .WellJQcated in.a.d.efine.dppoL . . . . . . . . . . . . . . _ . . . . . . . . . . . _ . . . . Yes. _ . Mi.ddle Ground $ho_al E. f._and G. (524t14). _ _ . . . . . . . . _ . . . . . . . . _ _ _ _ _ _ . . i5 .WelUQcated prpper .dtstance. from driJling unitb.ounda'Y_ . _ . . . . . . . . . . . . . . . . . . . Y.es . _ _ . . . . PeLG.Q 44; .>500~ trQm lease. line where owneJs.hip.changes.. . . _ . . . . . . . . . . . . . . . . . . _ . . . . . . . . i6 .Well .located prpper _distance. from other wells_ . _ . . . . . . _ _ _ . . . . . . . . _ Yes. . . . . . . CO 44- doe_s _not specify a minimlJm .otfs_et distance between. weJls. _ . . . . . _ . . . . . . . . . . . . . . . . . . . . . . 1~~:~:::~::;~:i:I:~~~~~:g unjt . . . . . . . . . . . . . . . . . . . . . . . . . . . ~:~ . . . . . :;~:~ s~~:;:~~~~UJRE[) will be 3rd well open !opoolin ~W!4 Seç26 Md 5th well OPen . . . . . . . 19 .Ope(ator onl~ affected party. . . . . . . _ . . . . . . . . . . . . . _ _ _ _ _ . _ . _ . _ . . . Yes. . _ . . . . . . . . . . . . _ _ _ _ . _ _ . . . . . . . . . . . . . . . . _ . . . . . . . _ _ . _ _ . . . _ . . . . _ . . . _ 10 _Oper:.ator bas_apprppriateJ~.ood inJorce . _ . _ . . . . _ _ . . . . _ . _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ . _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ 11 Permit G.aO be issued wjtoout co.nservaJion order. . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . _ . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . _ _ . . . . . . Appr Date 12 Permit G.aO be issued wjtoout administ(ati\le.apprpvaJ . . _ . . . . . . . . . . . . . . . . . . . . . . No - . - . . . . . . . .. ...... _ . . . . . _ . . . _ . _ . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ....... SFD 12/16/2004 13 Can permit be approved before 15-day wait Yes 14 .WelUocated within area and.strata .authorized byJojecti.oo Orde( # (PutlO# in.cpmmeots).{For. .NA . . . . . . . . . . . . . . . . . . . .. . _ . . . . . . . . . _ . . . . . . . . . . . . . . . _ . _ _ . . . . . . . _ . . . _ . . _ . . . ( 15 _AJI welJs_ wittltn .1l4JlJite_area_of reyiew jdeotified (Fpr:. s.ervj~ well onl~L _ _ _ _ _ _ _ . _ _ _ _ _ _ _NA _ _ _ . _ . _ . _ . _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . . _ . . . _ . . . . . _ _ _ . _ _ _ _ _ _ _ . _ _ _ . . _ . _ _ _ . _ _ _ _ . _ . _ . . . _ 16 PJe-produ.çed injector; .duration.of pre-pro.ductioo I~Ss. tnan.:3 months. (For.ser::vtce well QnJy) . . NA . . . _ _ _ . . . . _ _ . . . . . _ . . . . . . . . . . . . . _ . _ . . . . _ . . . _ . . . . . . . _ . . . . . . . _ _ _ . _ _ _ 17 .AÇMP.FJndjng.of Con$i$teocy_h.as bee.nJs.sued. for.tbis pr.oleçt . . . . _ _ _ _ _ . . . . _ . . . . NA . . . . . . . Sidetr:.açk welt. . . . _ .... _ . _ . _ . . . . . . . . . . . . . . . _ _ . _ . . . . . . . _ . . . . . . . . . . . . . . . .C.oodu.ctor str:.irlg.PJQvided . . . . . _. .................. _ . . . . _ . . . . . . . . . Yes _ . . .. . Con.ductor .set io orginaLweUbore.. . . . . . . . . . . . . . . .. .......................... _ . .Sur:.face.casing.PJQtectsaILknownUSDWs.............. _... _ _. _ _.. . _.. NA. _.... .Allaq.uifersexempted,AØ.C_FRg7.102.(2)(iii)........................... _........... _CMTv.oladequate.to circulate.o.n.cond.uctor.& SUJtC$g _ . . . _ . . . . . . . . . . . . . . . . . . . NA _ _ _ . _ . . Surfaçe ca.stng cemente.dJn orgioal wellb.or:.e, . _ . . . . . _ . . . . . . . . . _ . . . . . . . . . _ _ . _ . . . . . . . _ . .. .CMT. v.ol adequ.ate.to tie-tnJQng .string to_sur:.f Ç$.g_ _ . . _ . . . . _ . . . . . . . . . . . . . . . . . . No. . . . _ . _ _ . . . _ _ . . _ . . . . . . . . . _ . . . . . _ _ . _ _ . . _ . . . . . . . . . . . . . . . _ _ _ _ . _ _ _ _ _ _ . . . . . . . .CMT.will coYer_aJll<oow.n.pro.ductiYe bQri~on.s. . . . . . . . . . . . . . . . _ _ No. . . . . . . . Slotte.dJioer.completion plaoned.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .C.asiog de.signs adegua.te f.o( C..T.. B .&_ Rermafr.ost . . . . . . . . . . . . . . . . . . _ . . . . . _ _ _Yes. _ _ . _ . . _ . . . . _ . . _ . _ . . . . . . . _ . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . .. _ _ _ _ . . . . . . . .A.dequateJan.kage.oJre.sel'Yepit.... _. _ _.. _......................... Y~s...... . Rigjs.e.uipped.with.steelRits.oooffstloreplatfQrm, NpJeser:vepitpossible..AlJwastetp.di$PQsaLweJI......... Ra.re-dr:.ilL bas.a. 10:-403 for abandon.me.nt beeo apPJQved . . . . . . . . . . . . . . . Yes. . . . . . . 3Q4~3~7 . . . . . . . . . . . . . . . _. . _ _ _ . . . . . . . . . . . . _ _ _ _ _ _ _ . _ . . . _ . . . . . . . . . _ _A.dequatewellbore s.eparatjo_n_propos.ed _ _ _ _ _ . _ _ _ _ _ . . . . . . . . _ . _ _ _ . . . _ . . . _ . Yes _ _ _ _ . _ _ prp,-<imiJY- analysis perf.orme.d. Çlo$e aP-Pfoache.s jdefltjfi~d,_aJI withio tlemloGk, _ _ _ _ _ . . . _ _ _ _ _ _ . . . _ _ . _ Kdjvßr:ter Jeq.uiJed. does jt meßt reguJatioos. . . . . . . . . . _ . . . . . . . . .. . _ . . . NA . . . . . . . BOP wlJ alread~ be. io place, _ _ _ . . . . . . . . . . . . . . _ .. . _ _ _ _ . _ _ _ _ . . . . . . . . . . .DJilliog flujd.Rr09-ram sGhematic.& eQ.uipJistadequate. . . . . . . . . . . . _ . _ . _ _ . _ . . . . . Yes _ _ _ _ . _ _ MaxJmum expected f.or:.mation pres.sur~.6, tEMW.. MW plannßd._9,5.-JO..5.ppg.. . . . . .. _ _ _ . . . . . . . _B.oPEs,.d.oJhey meßt.rßguJatiol1 . . . _ . _ .... _ . . . . _ _ . . _ . _ . _ _ _ . . .Yes . _ . Waiyer.h.as been .9LVen t.o.operatß wjtb 1 seLof pipe rams (VBRs} du_eJQ Ijmited $yb.structu.re beighL _ . . . . . . . .B.oPE.press ratiog appropr:.iate;.test t.o.(pu.t psig in.commeots). . . . . . . . . . . . - . . . . . . . .Yes. . . . . . . MAS!? calculate.d_at 21.0.1 psi, 35QO.p$LBQ~ testapproprLate, . . 1:n·?)'V{· l'ðt· . . . - . eJ ....... .C.hoke.manjfold cQmpJies. w/APt R.~-5:3 (May 84 L _ _ . . . . . . . . . . . . . . . . . . . _ . . . _ _ Yes _ . . . . _ . _ _ _ . . _ . _ _ . _ _ . . . _ . . . . . . . . . . . _. ... _ _ . . . hJ.k. . . . . . . l t ~ _~ q .-=\. . . . . . .Work will PGc.ur:.with.oytoperation .sbutdown. . _ _. _... _ . _ . . . . . . . . . . . . . . . . . . Yes . ~ . Revjsßd permit dye tp .cbange in.dept!:1/lengt!:1._ Prjor aoaly-sis.applies.. _~_ . . . . . . . . . . . . . . . Jsp-resence_QfH2Sgas.Rrob.able...... _ _.. _. _......... _..... _........ No_ _... _ _ .1:i2Sisnotexpe_cted._ Mud$h.ouldmitigate.an~1:i2Son.rig, Rigeq.uipped.with.sens.o(s.andalarms,... _.. Mecba.nicaLc.oodJUon p{ wells wLthin AOR yerified (For.s.ervicß wßIJ onJ~). . . . . . . . . . . . . . NA . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . _ . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . _ 18 19 20 21 22 23 24 25 26 27 Date 28 12/16/2004 29 30 31 32 33 34 Engineering Appr TEM Appr SFD 35 36 Date 37 12/16/2004 38 39 Geology ( Per:.mitc.ao be i.ssued w!o hyd(ogen.s.ulfide measur:.es. . . . . . . . . . . . . . . _ . . . . . . . . . Yes _ . . . . . . . . . . . _ . . . . _ . . . . . . . . . . . . . _ _ . . . _ . . _ . . . . _ . . _ _ _ _ _ _ _ . . . . . . . . . . . . _ _D.ata.PJesßotedon.Rote_ntial.oveJpres.surß.zone$. _ ......................... yes..... _ . Offs.etwell.d.ataJndjcate.HemJock is.underpres.sur_eçi{6..2 ppg.EMW);wiJlbeçirjlledwith.9.5-::10..5.p-pg.mu_d, _... .Setsmic_analysjs. of sbaJlow gas.z.ooes. . . . . . . _ . . . . . . . . . NA . . . . . .. .................. . . . . . . . . . . . . . . . _ _ _ . . . . . . . . . . . . . _ _ . . . . . . . . _ .Seabed .condjti.oo survey.(if off-~h.o(e) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .NA . . . . _ . . . . _ . . . . . . _ . . . . . . . . . . . . . . . _ . _ _ _ _ . . . . . . . . . . . _ . . . . . . . . . Conta.ct l1amelptlone.for.weekly prpgres.s.reRorts [exploratp'Y .only]. . . . . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . .. _.. _ . . _. ........ _ . _ _ _ . . . . . . . . . _. _. _ . . . . . . Geologic Commissioner: Date DTS Engineering Ji:'tLf-- Commissioner: I PUbl~'C Commis n r Date J K 0/6/2004 Dec. 15, 2004: Application received to revise bottom hole location from 780' FSL, 1230' FWL, S. 23, T8N, R13W, SM to 1216' FSL, 855' FWL, S. 23, T8N, R13W, SM (a total change of 575') after drilling operations began. TO of well lies within SW/4 of S. 23. Spacing exception approved in AA 44.73 remains in effect without change. SFD ~ - '~ ~TO ~~RGY October 8, 2004 ~1\ ~~n'~ \O{ \~-a~ FEDERAL EXPRESS: Mr. Steve Davies State of Alaska Alaska Oil & Gas Conservation Commission 333 W. ih Ave. #100 Anchorage, Alaska 99501-3539 RE: Request for administration approval for spacing exception for the Middle Ground Shoal No.C22A-26LN well in the Middle Ground Shoal Field. ~~4-\.~ð q/~"'\-o'-\ Dear Mr. Davies: ~ ~ o'-\. - '3 "-\,\ ~ I. \ø - 0,-\ XTO Energy Inc. (XTO) plans to plug back from the productive Hemlock fonnation in the MGS C22A-26 well and side track the well to the North as a horizontal producer in the Hemlock fonnation. XTO, as operator, hereby respectfully requests administrative approval for spacing exception for SW/4 of Section 23 and NW/4 of Section 26 all in 8N-13W, Kenai County, Alaska. This well will be the 3Td producer in the West Flank and quarter section ofSW/4 section 23. It will be the 2nd producer in the West Flank and 3rd in the quarter section for the NW/4 of section 26. There are no other landowners or operators within 1,000 feet of the well to notify. Enclosed please find in duplicate an affidavit stating that the facts are true and correct as well as a plat of the captioned well. Sincerely, XTO ENERGY INC. ~¿~ Landman Enclosure RECEIVED OCT 11 2004 cc: Mike Langler Kyle Hammond Paul Figel ( Alaska Oil & Gas Cons. Commission Anchorage o p y XTO Energy Inc. · 810 Houston Street · Fort Worth, Texas 76102-6298 · (817) 870-2800 · Fax: (817) 870-1671 ~ '"-"' AFFIDA VIT I, George A. Cox, Landman for XTO Energy Inc. do hereby swear that all of the facts described in my October 8, 2004 request for administration approval for spacing exception and accompanying map pertaining to the requested spacing exception for Middle Ground Shoal No. C22A-26LN Well are true and correct to my knowledge. .,¿/~ George . Cox C31-23 C11-23- C11-23ST C21-23' ' C12-23- -- IIIIIIIIIIIIIIIIIIII \ ¡}NIT ( I ( , , 004 9;03032 AM wetL Middle Ground Shoal ~---~,-~--~ POSTED WELL DATA It -9- D<yHole 111Je<;!1OI\_ SoM"" wen "", Plugged end!lb_ <ß$ TM'd or Sllnje"'", SI1u! In on and G"" PM Waler 1,*,"'01" REMARKS 1:1000 ----_...~----~-- By: M. lMge!er ---- ~-----~ 001_ 8. 2004 . «Lì ~ @; Œ (ill AI,ASIi& OILAlQ) GAS CONSERVATION COMMISSION . I FRANK H. MURKOWSKI, GOVERNOR / ¡ 333 W. P" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bobby Smith Drilling Operations Manager XTO Energy, Inc. 3000 North Garfield, Ste 175 Midland, TX 79705 Re: Middle Ground Shoal C22A-26LN XTO Energy, Inc. Pennit No: 204-182 Surface Location: 500' FSL, 1538' FEL, SEC. 12, T8N, R13W, SM Bottomhole Location: 780' FSL, 1230' FWL, SEC. 23, T8N, R13W, SM Dear Mr. Smith: Enclosed is the approved application for pennit to redrill the above development well. The pennit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. XTO Energy. Inc. assumes the liability of any protest to the spacing exception that may occur. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to itness any required test. Contact the Commission's petroleum field inspector at (907) 659- 0 ager). BY ORDER OJ' THE COMMISSION DATED this~day of October, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~TO )Á.kRGY . . September 1Q, 2004 RECE f\/i:: SEP 1 :1 ?004 Alaska Oil & Anchural:i~ '~"I '<;~. " " Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: C22A-26LN Sidetrack Dear Mr. Norman, XTO Energy, Inc. hereby applies for a Permit to Drill an offshore development well from Platform C in the Middle Ground Shoal Field of Cook Inlet. The well is planned as a / sIdetrack of the existing C22A-26 wellbore in order to penetrate and develop an un- drained portion of the Hemlock conglomeraté in the vicinity of Platform C. Approval of the associated pre-drilling work plan for the existmg weHbore has been requested via a Sundry Notice submitted under separate cover. The anticipated spud date of C22A-26LN is approxìmately October 10, 2004. The well will be sidetracked at 10,950' from the existing 7" production liner. A 6" hole will be directionally drilled to the base of the Hemlock Reservoir, a 5" slotted production liner will be set in place and a 3-112" gas lift completion instaHed. 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 weIrs proposed surface and bottomhole loca.tions per 20 AAC 25.050 (c) (2). 4) Directional plots and proximity calculatton8 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) and a request for waiver of one of the provisions of those regulations have been previously submitted and approved. 6) A complete proposed casing program is attached as per 20 AAC 25.030. 7) The drilling fluid program, in addition to the requirements of 20 AAC 25.033 is attached. 8) A copy of the proposed drilling program is attached. 9) XTO Energy does not anticipate the presence of H2S in the formation to be encountered in this well. However, H2S monitoring equipment will be v XTO Energy Inc. . 3000 N. Garfield . Suite 175 . Midland, Texas 79705 . (915) 682-8873 · Fax: (915) 687-0862 . . Mr. John Norman Page 2 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) The following are XTO Energy's 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 (432) 620-6718 or Bill Penrose at (907) 258-3446. Sincerely, XTO ENERGY, INe. I~J~ Bobby L. Smith Drilling/Operations Manager enclosures cc: Bill Penrose 1 a. Type of Work: 2. Operator Name: XTO Energy, Inc. 3. Address: . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Drill 0 Redrill [] Re-entry 0 A/~ 1 b. Current Well Class: Stratigraphic Test 0 5. Bond: Bond No. 6. Proposed Depth: ,/ MD: 14,678' 7. Property Designation: ADL 18756 Exploratory 0 Development Oil [] Multiple Zone 0 Service 0 Development Gas 0 Single Zone [] Blanket [] Single Well 0 11. Well Name and Number: 103652600 ,/ C22A-26LN , 12. Field/Pool(s): TVD: 10.005' Middle Ground Shoal 3000 North Garfield, Suite 175, Midland TX 79705 4a. Location of Well (Governmental Section): Surface: 500' FSL, 1538' FEL, Sec. 23, T8N, R13W, SM .I Top of Productive Horizon: 1170' FNL, 1619' FWL, See 26, TaN, R13W, SM Total Depth: 780' FSL, 1230' FWL, See 23, T8N, R13W, SM 4b. Location of Well (State Base Plane Coordinates): Surface:x-f'"2474186 7231417 I>Rf¿,'¡;;.f Zone- AK-4 16. Deviated wells: Kickoff depth: 10,950 feet .; Maximum Hole Angle: 90 degrees 18. Casing Program: Size Hole Casing 6" 5" 19. Total Depth MD (ft): 12,140' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Specifications Weight 18# Grade Coupling L-80 STL Length 4.028' 8. Land Use Permit: 13. Approximate Spud Date: 10/10/2004 14. Distance to Nearest N/A 9. Acres in Property: 5120 Property: 1,619' 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 105 feet ASL Within Pool: 157' from C21-26 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3,200 psi .... Surface: 2,101 psi I Setting Depth Quantity of Cement Top Bottom c.f. or sacks MD 10.650' TVD 9.665' MD TVD 14.678' 10 005' (including stage data) N/ A - slotted liner PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): 10,020' None 11,819' 9,786' Bobby Smith 0-u æJL L I Permit to Drill., 'F J Number: 2D 'f- /'32- Conditions of approval: Length Size 370' 24" 1.155' 13-3/8" 9.797' 9-5/8" 3,050' 7" Junk (measured): Bit/BHA @ 12039' Cement Volume MD TVD 441 sx 560 sx 370' 1155' 9 797' 370' 1,150' 8215' 1.500 sx 12.039' 10.019' Perforation Depth TVD (ft): Filing Fee L:J BOP Sketch .j Property Plat 0 Diverter Sketch 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. 20. Attachments: Printed Name Signature Drilling Program L::J Seabed Report 0 Time v. Depth Plot U Shallow Hazard Analysis U Drilling Fluid Program [] 20 AAC 25.050 requirements 0 Date Contact Bill Penrose 258-3446 Title Drilling/Operations Manager 5:;L~r Phone 432-620-6718 Commission Use Only API Number: Permit Approval See cover letter for other 50- 733- 2D L/ 1:5- ð I Date: /¿? Ii ~ ItU::: r~ ~"CJ, ..... I' '. "'--- ..-- Date Samples required Yes 0 No ~ Mud log required ~EP 1 3Y~rtAJ No ~ ti3Ydr sulfide measures Yes 0 No ~ Directional survey require<Y YésuW No 0 Other: ?:.So ~zo ~<'';\ ~'~' ......hM. w'? ~s\-. ß(ì'V-\~~\'\ ~ \(:\~~~ ;D~ ~F~Qj & ;aSh;~;gS~ Co",:,i~O~. " / Approved by{ ~ /' J THE COMMISSION Date: nc ID/'6/ ð Y ¡,/ Form ~I~ed 12/2003"'-- U RIG I N A L SUb~itin~UPlicat~ . . XTO Energy, Inc. MGS C22A-26LN Summary Sidetrack Procedure · With the rig over C22A-26, the BOPE installed and tested, the wellbore plugged with cement and the hole loaded with oil-base mud, drill the C22A-26LN sidetrack as follows: · RJU e-line and RIH with 7" bridge plug. Log casing collars and set bridge plug 5' above first collar below 10,950' MD. · RIH with 7" one-trip whipstock. Orient and set whipstock on the bridge plug at ±10,950' MD and mill window in 7" casing using a 6" mill. · Directionally drill 6" hole from 10,950' to 14,678' MD. ,¡ tI · Run 5", 17.95#, L-80, 513 Rydril slotted liner to 14,678' MD with TOL at approximately 10,650' (~300' oflap). · Set liner hanger and liner top packer. · Displace well to filtered Inlet water. · Run 2-7/8" completion with gas lift design. · Pickle inside oftubing with RCI/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. . . XTO Energy, Inc. Drilling Fluid Program, Pressure Calculations, and Drilling Area Risks MGS C22A-26LN Sidetrack Drillinl! Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate Oil:Water Ratio % Solids 6" Hole Section (10,950' - 14,678'MD 9.5 - 10.5 / 18 - 30 15 - 20 55 - 80 8 - 12 15 - 30 <8 75:25 <5 Drillinl! Fluid System: Two Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifu e De asser Pit Level Indicator Visual and Audio Alarms Tri Tank Fluid Flow Sensor Fluid A itators Maximum Anticipated Surface Pressure: The maximum anticipated surface pressure (MASP) for the 6" hole section in this sidetrack will be the lesser of the formation pore pressure (less a full gas column to the surface) at the 5" casing point or the formation fracture pressure at the kick-off point in the existing 7" liner (less a full gas column to the surface). Based on offset well data, the highest formation pressure expected in this 6" hole section is 3,200 psi at the section TD .... of 10,005' TVD (or ,9.320 psi/ft). Well-documented fracture gradient data for this area indicates that the ftacture gradient at 9,196' TVD (the kick-off point in the existing 7" liner) is 0.735 psi/ft. Complete evacuation of the wellbore, except for a 0.11 psi/ft gas gradient, is assumed. 6" hole section MASP (pore pressure) MASP (fin breakdown) / (10,005 ft)(0.320 - 0.11) =2,101 psi (9,196 ft)(0.735 - 0.11) = 5,748 psi . . / Therefore, MASP in the 6" open hole section is 2,101 psi and the 5,000 psi BOPE system to be used will be adequate. Well Proximity Risk: The nearest wellbore to that of C22A-26LN is that of C21-26. C22A-26LN will pass 157' from the C21-26 wellbore at a depth of 12,901'. Drillin2 Area Risks: The primary drilling risks in the C22A-26LN area are those of stuck pipe in the coals of the T yonek and Hemlock Formations and p otentia11 oss 0 f circulation in the Hemlock Formation. The risk of stuck pipe in the Tyonek and Hemlock coals will be countered in two 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. The pore pressure in the Hemlock interval has dropped to approximately 3,200 psi (or .I' 0.308 psi/ft) over the years as a result of production from the reservoir. The potential for lost circulation will be countered with appropriate mud weight and, when necessary, lost circulation additives in the mud. LCM will be kept to a minimum to avoid plugging the slots in the production liner after it is run. Disposal of Muds and Cuttin2s: MGS Platform C has a dedicated Class II disposal well. All oil-base or sheening waste wellbore fluids will be injected down the disposal well as will cuttings after they are ground. Non-sheening water-base fluids and cuttings will be discharged overboard. C22A-26LN Casin2 Properties and Desi2n Verification Casing Performance Properties Internal Collapse Tensile Strength . Size Weight Yield Resistance Joint Body TVD MD Design Safety Factor* (in.) (lb/ft) Grade Cnxn fu.ill fu.ill O,OOOlbs) (ft RKB) (ft RKB) T B C 7 26 L-80 LTC 6,340 N/A 3.02 N/A 5 18 L-80 H-513 N/A N/A 319 422 10,005 14,678 4.98 N/A N/A * Tensile design safety factor for the existing 7" casing is not calculated since it is already cemented in place. For the 5" liner, it is calculated using pipe weight less buoyancy. Burst design safety factor for the existing 7" casing is calculated using MASP. For the 5" liner, it is not calculated since the liner is slotted. Collapse design safety factor for t he existing 7" casing is not calculated since it is already in place and will be exposed to no . different differential pressures than it currently experiences. For the 5" liner, it is not calculated because the liner is slotted. Casing Setting Depth Rationale 5" 14,678' RKB, MD Production liner to provide hole stability for production operations. . . C22A-26LN Summary of Drillinq Hazards POST THIS NOTICE IN THE DOGHOUSE "'-I The target Hemlock reservoir contains a production-depleted pressure of approximately 3,200 psi. There is a potential for lost circulation and consequent difficulty in keeping the hole full. "'-I Pipe sticking tendency is possible in the coals above and in the Hemlock reservoir. / "'-I This well bore is planned to pass approximately 157' from the C21- 26 well bore at a depth of 12,902' MD. "'-I There is no H2S risk anticipated for this well. v' CONSULT THE C22A·26LN WELL PLAN FOR ADDITIONAL INFORMATION XTO Energy, Inc.. Field: Installation: Seale 1 em = 200 It -3200 -2800 -2400 is C22A-26LN Ver2. Coordinates are in feet reference slot #4-30. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Pianned Datum Rig Datum to mean sea level: 105,OO!t. Plot North is to TRUE North. C22A-26LN Vers2 WELL PROFILE DATA Poínt MD Ine Azi TVD North KOP 65.41 9196.14 -3036.67 End of Build/Tum 66.03 9221.34 End of Hold 10988.05 47.43 66.03 9222,38 -3025.35 Target False Target 11920.80 65.00 0.25 9780,07 End of Build/Turn 12156,51 70.21 346.02 9870,24 End of Hold 12386,39 70.21 346.02 9948,08 Target C22A-26LN - Hrd 12719,19 90,00 348,72 10005.00 -2123.00 6.00 1924.93 T,O. & Target C22A-26LN 14707,62 90.00 280.00 -2512.00 0.00 2527,56 ¢: 0 <.D 9000 II E ü (J) 9120 ro ü (j) 9240 - - (I) .æ 9360 - .c - Q. 9480 (I) C 'ii 9600 (,) 1:: (I) > 9720 (I) :s I.. ¡.... 9840 . V 9960 10080 10200 KOP EOG Build/Turn 6/100 47.30 47.81 DLS: 6.00 deg/1 OOft 50.45 52.50 54.97 57.79 60.91 64.27 66.61 EOG Begin Final Bid/Turn -EOG 1440 1560 1680 Scale 1 ern = 60 ft Azimuth Slot: Well: C22A-26 Well bore: C22A-26LN East (feet) -> -2000 -1600 -1200 -800 TO Target - EOG Begin EOG TO C22A-26LN Vers2 1800 1920 2040 2160 2280 2400 2520 2640 Vertical Section (feet) -> 276.36 with reference 0.00 N, 0.00 E from slot #4-30 -400 400 o Surface 0.00 N 0.00 E Bid/Turn 2760 800 400 0 -400 -800 -1200 -1600 -2000 -2400 -2800 (Jj C"> OJ W -3600 ~ C"> 3 II -4000 I\.) 0 0 ;::> . . XTO Energy, Inc.,slot #4-30 Platform C, Middle Ground Shoals,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Wellbore: C22A-26LN Vers2 Wellpath: C22A-26LN Ver2 Date Printed: 7-Sep-2004 '&i. ..,. INTEQ Well bore N",,",,, C22A-26LN Vers2 I 7 -Seo-2004 II I 7 -Sep-2004 Iwell ~1-26 I Govemment 10 I ~q~~~~;~~~d Easl Installation Platform C 233063.0833 AK-4 on NORTH AMERICAN DATUM 1927 datum True I ;'dGroomd Shoo', I Eastin~ 34754 5480 INorth~ 000165290 I~~~ I~OtJbðl.D_ I R ERICAN DATUM 1927 datum True Comments . ~;i All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Planned Oatum 105.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 276.36 degrees Bottom hole distance is 2527.56 Feet on azimuth 276.36 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . XTO Energy, Inc.,slot #4-30 Platform C, Middle Ground Shoals, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Well bore: C22A-26LN Vers2 Well path: C22A-26LN Ver2 Date Printed: 7-Sep-2004 '&1. BfII.s INTEQ WellDath ReDort MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[ 1 N"rth\ ¡::",..t\ loftl Itl 11100;11 1111 452R R541 ¡¡1¡¡R 14 ¡¡0¡¡114 .,,,.,,, 70\11 OR 000 1 ¡¡¡¡ORP KOP ::In~ Tip. On /I, Kir:k off P"int 10986.51 47.43 66.03 9221.34 9116.34 3025.80S 2317.61\1\ 2471214.37 229030.61 6.00 1968.15 EOC End of BuildlTurn 1110AA 110; 474::1 RR n::\ O??? ':IA Q117 ::\R "n"" <:AI, Z4f 1[14.80 ??011':11 "'''' 000 1QR717 R/100 ¡::nrl "f 1-I"lrl 1100000 47::1R R50R "..,.,,, A7 ¡¡1?547 ::IO?1 o;71^ ?R ROO 1¡¡5¡¡ R? 11100.00 47.30 56.90 9298.29 9193.29 2986.09S 2244.36\1\ 2471252.39 229104.74 6.00 1899.76 11?00 00 47 R1 4R 7Q 0':1"'<: AA ¡¡?RO R4 ?¡¡41 <=;<=; ,,"'n." A" ROO 1R4R::\A 11::10000 4RR7 40R¡¡ ¡¡4::1?::IR ¡¡::I?7::1R "000 ?R RnO 17¡¡¡¡¡¡F 11400.00 50.45 33.29 9497.16 9392.16 2827.90S 2087.24\11 2471406.94 229265.45 6.00 1761.12 1150000 5? 50 ?R OR n""n An ¡¡4<=;44¡¡ n~~n ¡¡R ROO 17::10 ?i" 11ROO.00 54¡¡7 1¡¡2¡¡ ¡¡R1RRR ¡¡51::1BR "'''0'' 57 ROO 1707RP 11700.00 57.79 12.93 9674.09 9569.09 2605.69S 1994.59\11 2471626.97 229363.15 6.00 1693.66 11ROOOO RO¡¡1 R¡¡7 ¡¡7?5 10 ¡¡R?O 10 ?<=;?1 O?~ . n7n 0.,. ?¡¡ ROO 1RRR ::Ii" 1101111 1111 64.27 1.37 ¡¡77UR ¡¡RRR 1 R ?A':I? o;o:¡e:: 107., A.", 5¡¡ ROO 1R¡¡1R1 11920.80 65.00 0.25 9780.07 9675.07 2413.74S 1973.16\11 2471818.38 229388.97 6.00 1693.62 False Taraet 3DS Kick off Point 1 ?111111 1111 RRR1 ::155::15 ¡¡R1? 5i" ¡¡707 55 ?::\41 5¡¡~ <=;R ROO 1704 ::Iq 1?11111 1111 68.R5 34¡¡::I::I ¡¡R5047 ¡¡74547 ??AO OAe:: AO ROO 172RR4 12156.51 70.21 346.02 9870.24 9765.24 2198.23S 1999.62\1\ 2472034.43 229367.44 6.00 1743.80 EOC End of BuildlTum 1 ??1111 1111 70?1 ::\4R O? ¡¡RR4 ¡¡7 ¡¡77¡¡¡¡7 ?1O;A ~A' O:¡", nnnn~n An 000 175R m 1 ?::\1111 1111 70.21 ::\4R 02 ¡¡¡¡1RR~ ¡¡RBR::I ?11"'7 15 000 17¡¡074 12386.39 70.21 346.02 9948.08 9843.08 1988.34S 2051.89\11 2472245.46 229319.99 0.00 1819.00 Benin Final Bld/Tum End of Hold 1 ?AI1I1 1111 7102 ::I4R14 ¡¡¡¡5?BC ¡¡R47 RO 1070; ¡¡R ??¡¡::I17 1R ROO 1 R?::I 44 1 ?<=;1111 1111 76.96 34R 9R ¡¡¡¡R017 ¡¡R75 17 1AA? ?47?::151¡¡1 ROO 1 R55¡¡A 12600.00 82.91 347.78 9997.63 9892.63 1786.40S 2098.80\11 2472448.42 229277.72 6.00 1887.98 1 ?71111 1111 RRRR ::I4R57 110004 R ¡¡R¡¡¡¡ R 1 1"'AA A, ROO 1¡¡1¡¡ Oq 12719.19 90.00 348.72 10005.0 9900.00 1670.005 2123.00\1\ 2472565.34 229256.18 6.00 1924.93 Target - EOC,C22A-26LN - HrdPt1 - 12/14/03 SIC Kick off Point 1?RI1I1 1111 ¡¡OOO ::I4R7? 110005nl ¡¡¡¡OOOO 10;011 nA' n.~nn A O? 000 1¡¡4¡¡ 4? 1 ?01111 1111 QO 00 ::\4R 7? 11000501 9900.00 140? 41 ')')O')')A 00 000 197973 13000.00 90.00 348.72 10005.0 9900.00 1394.62S 2177.931/\ 2472841.90 229207.56 0.00 2010.04 1::\11111 1111 ¡¡OOO ::I4R7? 110005.01 ¡¡¡¡OO 00 1?O'" o:¡A 000 ?040 ::14 1':1?11111111 90.00 348.72 110005.01 9900.00 110R .LJhl/\ A7 000 2070Rfi 13300.00 90.00 348.72 10005.0 9900.00 1100.42S 2236.631/\ 2473137.36 229155.62 0.00 2100.96 1 '<41111 1111 ¡¡OOO ::I4R7? 11000501 ¡¡¡¡OOOO 11111? 1O\^ Ao; 000 ?1::11 ?fì 1 ':1<:11111111 90.00 348.72 11000501 9900.00 904.2RS ZZfh 'hV' o:¡o:¡ 000 21 R1.57 13600.00 90.00 348.72 10005.0 9900.00 806.21S 2295.311/\ 2473432.82 229103.67 0.00 2191.88 1 ::\71111 1111 90.00 34R.72 11000501 ¡¡¡¡OOOO 70R14~ ').,1 001, ?47::\5::11::11 000 222211' 1O:¡AI1111111 ¡¡O 00 ::\4R 7? 11000<=; 01 9900.00 610.08S """ A AI, 0" 0.00 2252.49 13900.00 90.00 348.72 10005.0 9900.00 512.01S 2354.001/\ 2473728.29 229051.73 0.00 2282.80 14000 00 0111111 348.72 11000501 990000 41::1¡¡4~ ..,')O".,A A') 000 2::11::110 1410000 ¡¡O 00 ::\4R 7? 11000<=; 01 QQOO 00 ::\1<=; R7e:: ?::\O::\ 1::\\11 ZZ!oILJ"I f III 0.00 ?::\4::\ 41 14200.00 90.00 348.72 10005.0 9900.00 217.81S 2412.691/\ 2474023.75 228999.79 0.00 2373.72 1A':I11111111 QO 00 ::\4R 7? 11111111<=; 111 9900.00 119.74S Z4 000 2404.02 1AAI1111111 ¡¡O 00 ::\4R 7? 11000<=; 01 QQOO 00 ?1 R7e:: ?A<:1 A?I, ??ROR<=; 1 R 000 ?4::\4 ::\1 14500.00 90.00 348.72 10005.0 9900.00 76.40N 2471.38\1\ 2474319.21 228947.84 0.00 2464.64 1A"'11111111 QO 00 ::\4R 7? 11111111<=; 111 001111 1111 174. Z4f44' {[: 000 2494.94 1A71111 1111 ¡¡O 00 ::\4R 7? 11000<=; 01 ¡¡¡¡OOOO ?7? 1Q ??RQ1::\ ?1 000 ?<=;?<=; ?'i 14707.62 90.00 348.72 10005.0 9900.00 280.00N 2512.00\1\ 2474523.69 228911.90 0.00 2527.56 TD, C22A-26LN - TD Pt - 12/15/03, End of Hold All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 276.36 degrees Bottom hole distance is 2527.56 Feet on azimuth 276.36 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . XTO Energy, Inc.,slot #4-30 Platform C, Middle Ground Shoals, Cook Inlet, Alaska PROPOSAL LISTING Page 3 Wellbore: C22A-26LN Vers2 Wellpath: C22A-26LN Ver2 Date Printed: 7-Sep-2004 '&1. BAKlR ....HIS INTEQ 14707.62 10005.00 2512.00W 280.00N TO C22A-26LN - HrdPt1 1670.00S 2123.00W 10005.00 N60 45 33.3070 W151 30 50.0653 229256.18 2472565.34 C22A-26LN - TO Pt - 280.00N 2512.00W 10005.00 N60 45 52.5088 W151 30 57.9030 228911.90 2474523.69 12/15/03 Isurve~ Tool Pr~ram I MOrftl ITVDlft~ I ~~:~~¿~~I Gvro I ~~~d~~el ::~~renc I~~e <O~~~~O'> 10950 00 19614 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Planned Datum 105.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 276.36 degrees Bottom hole distance is 2527.56 Feet on azimuth 276.36 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated XTO Energy, Inc.. Alaska Field: Middle Ground Shoals Installation: Platform C Scale 1 em == 60 ft Well: CZZA-Z6 Wellbore: CZZA-Z6LN VersZ East (feet) -> is Coordinates are in feet reference slot #4-30. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to Plot North is -3240 -3120 -3000 -2880 -2760 -2640 -2520 -2400 -2280 -2160 -2040 -1920 -1800 -1680 -1560 -1440 -1320 -1200 9300 9100 8900 9500 8300 8900 9100 '. 6700 7500 7~0071å&6900 9300 8100 7700 9700 9900 10100 10300 10500 10700 10900 9500 9700 5700 9100 7900 8100 9900 6300 9900 5300 5500 9500 9500 5900 6100 5100 9700 9900 4700 -1080 -1200 -1560 -1680 -1800 -2760 -2880 (J) -3000 £ æ- C) -3120 :3 II en o Scale 1 em = 60 ft -3360 -3240 -3120 XTO Energy,lnc.. Inlet. Alaska Middle Ground Shoals Platform C 5300 5100 5100 -2760 -2640 East (feet) -> -2520 -~400 -2280 -1920 -2160 -2040 -3000 -2880 5500' 4900 4700 4500 4900 4300 4700 4500 9300 9300 9100 9100 8900 Ref wellpath Ver2. Coordinates are in feet reference slot #4-30. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to -1800 -1560 -1440 -1680 9500 8700 8500 7900 7300 6500 61Ô0s90057Ò65500 5300 5100 4900 4700 7100 7300 7500 7700 720 600 360 240 120 o -120 -240 Z o ;:¡ ::T - -360 at Ci) - - 480 -600 -720 -840 -960 -1080 C/) (") Q) ro -1200 ...... (") 3 II -1320 0) o ~ True Vertical Measured Depths ar<3 r<3fer¡¡nce Rig Rig Datum: Plann<3d Datum Rig Datum to mean sea I<3V<3I: 105.00 ft. Plot North is North. XTO Energy, Ine.. Inlet, Alaska Middle Ground Shoals Platform C TRUE NORTH 350 o 10 340 20 330 30 300 210 150 290 280 270 260 250 240 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well · e XTO Energy, Inc. C22A-26LN Ver2, C22A-26LN Vers2 slot #4-30, Platform C CLEARANCE LISTING Page 1 Date Printed: 9-Sep-2004 Middle Ground Shoals, Cook Inlet, Alaska r'ii. ..,. INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Onlv Depth and Maqnetic Reference Field error terms are correlated across tie points Proximities beyond ft with expansion rate of ft/1 OOOft are not reported Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/Casinqs are NOT included Hole size/Casinqs are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.00standard deviations. Closinq Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation I~J'::effi2 Iwell ~~-26 I ~~a~~~2004 I L8~~e':~;~;4d I Govemment 10 I Last Revised 9-Jul-2004 North East lnstallatiOn ~=rm C I Eastina I No,,";oo I r~~ ~ I~orth At.om... I >33063011.' 2478929982 ---. R _EBICAN [)AruM 19:>7 '...,mIlt..: . Field N"""", Middle Ground Shoals I ¡::",c:tinn I 234754.5481 I I.L 2500016.5291 AK-4 on NORTH AMERICAN DATUM 1927 datumT True Clearance Summarv Offset Offset Offset Offset Minimum MD[ft] Diverging Ellipse Ellipse Clearance Clearance WellName Wellbore Slot Structure Distance From[ft] Separation MD[ft] Factor MD[ft] I rftl I rftl C22A-26 C22A-26 slot #4-30 Platform C 0.00 10956.4 1 0956.4 C21-26 C21-26 slot #9 Platform C 156.8· 12931.3 12931.3 IIAWR\ C22-26 C22-26 slot #11 Platform C 615.2 12024.5 12024.5 IAWR\ C11-26 C11-26 slot #4-17 Platform C 619.31 12570.8 12570.8 AWB) C24A-23LN C24A-23LN slot #2-15 Platform C 635.1 14414.0 14414.0 IAWR\ C22-26RD C22-26RD slot #11 Platform C 734.2~ 11942.2 11942.2 IAWR\ C24-23 C24-23 slot #2-15 Platform C 747.01 14350.2 14350.2 AWB\ C13-23 C13-23 slot #7 Platform C 921.4 14707.6 14707.6 IAWS\ C23-26 C23-26 slot #13 Platform C 970.5 11171.2 11171.2 IAWR\ All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . XTO Energy, Inc. C22A-26LN Ver2, C22A-26LN Vers2 slot #4-30, Platform C CLEARANCE LISTING Page 2 Date Printed: 9-Sep-2004 Middle Ground Shoals, Cook Inlet, Alaska All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated J&I. --.-,. INTEQ · e XTO Energy, Inc. C22A-26LN Ver2, C22A-26LN Vers2 slot #4-30, Platform C CLEARANCE LISTING Page 3 Date Printed: 9-Sep-2004 Middle Ground Shoals, Cook Inlet, Alaska '&i. ..,. INTEQ Clearance Data Reference Reference Reference MD[ft] TVD[ft] North[ft] Reference East[ft] Offset Well Offset MD[ft] Offset TVD[ft] Offset North[ft] Offset East[ft] Angle From Highside Closest Ellipse Approach Separation Distance [ft] All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . XTO Energy, Inc. C22A-26LN Ver2, C22A-26LN Vers2 slot #4-30, Platform C CLEARANCE LISTING Page 4 Date Printed: 9-Sep-2004 Middle Ground Shoals, Cook Inlet, Alaska ,,¡¡. BAKER ....... INTEQ Clearance Data Reference Reference Reference MD[ft] TVD[ft] North[ft] Reference Offset Well East[ft] Offset MD[ft] Offset TVD[ft] Offset North[ft] Offset East[ft] Angle Closest Ellipse From Approach Separation Highside Distance [ft] 13700.0 14000.0 14500.0 14707.6 Error Model All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 1 05.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Saker Hughes Incorporated . . XTO Energy, Inc. C22A-26LN Ver2, C22A-26LN Vers2 slot #4-30, Platform C CLEARANCE LISTING Page 5 Date Printed: 9-Sep-2004 Middle Ground Shoals, Cook Inlet, Alaska r&ií. BfII.s INTEQ Clearance Data Reference Reference Reference MD[ft] TVD[ft] North[ft] Reference Offset Well East[ft] Offset MD[ft] Offset TVD[ft] Offset North[ft] Offset East[ft] Angle Closest Ellipse From Approach Separation Highside Distance [ft] 11920.8 12100.0 12500.0 MDft Error Model v All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Saker Hughes Incorporated . . XTO Energy, Inc. C22A-26LN Ver2, C22A-26LN Vers2 slot #4-30, Platform C CLEARANCE LISTING Page 6 Date Printed: 9-Sep-2004 Middle Ground Shoals, Cook Inlet, Alaska J&I. BAKER HUGHIS INTEQ Clearance Data Reference Reference Reference MD[ft] TVD[ft] North[ft] Reference Offset Well East[ft] Offset MD[ft] Offset TVD[ft] Offset North[ft] Offset East[ft] Angle Closest Ellipse From Approach Separation Highside Distance [ft] 11920.8 12100.0 12500.0 12719.1 Error Model All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . e XTO Energy, Inc. C22A-26LN Ver2, C22A-26LN Vers2 slot #4-30, Platform C CLEARANCE LISTING Page 7 Date Printed: 9-Sep-2004 Middle Ground Shoals, Cook Inlet, Alaska J&ií. .... INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Closest Ellipse MO[ft] TVO[ft] North[ft] East[ft] MO[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Oistance [ft] [deal rftl 11700.0 9674.m 2605.69~ 1994.59V C11-26 10310.2 9680.1 1877.77 2632.27V -69. 967.7' 11ROOo, q7?!i 1 C ?<;?1 n?e 1q7q R1V 1r.11-?R qRqR !i~ ?R:l7 R7V -RR q171, 11qOOo, q7711 f ?LI "I? <;"Ie 1 qn4:1V 1r.11-?R ."""" '"~ q710 1! ?¡:;LI? <;<;11 -67. R6S.4f 11920.8 9780.0 2413.74~ 1973.16V C11-26 10346.0 9712.6 1887.80 2643.41 V -67. 854.6 1 ?OOO 0, qR1? !if ?"ILl1 <;oe 107<; 0<;11 1!"'11_?R 10:l!iR 1! q7?1 q{ 1 RqO R!i! ?¡:;LI¡:; <;¡:;II -6!i,F R1:1 1Ç 121000, qRS04, ??LlO OLle 10AA "I?II 1('11-?6 ."""00' qn:l:lf 1AOLl1A' ?¡:;<;n LlOII -64.f 760.7f 12156.5 9870.2 2198.23~ 1999.62V C11-26 10375.7 9739.7 1896.14 2652.66V -63.E 731.2 1 ??OO n qRR4 q, ?1!iR !i?~ ?OOq !i1V 1r.11_?R 10:lR1 1: q744 !i, ?¡:;<;LI "I?II -R4 70q R~ 12:100 0, qq1RR: ?OR7??~ ?n"l? ?<;II 1('11_?R 10:\q:l:ll q7!i!i Rf 1 q010R! ?RSR 1 :IV -RS.4 667RC 12386.3 9948.m 1988.34~ 2051.89V C11-26 10403.4 9764.8 1903.89 2661.27V -66. 641.9 1?400 0, qq!i? RC 107<; Aoe ?n<;LI OAII 1!"'11_?R q7RR ?' . "". "'" ?¡:;¡:;17<;11 -6F; R:lR 7, 12S000, qqRO 1 , Annn ?077:10V 1r.11-?R ,n n n, q771 :I{ ?¡:;¡:;"I <;ml -6R4 6227~ 12570.8 9993.5 1814.61~ 2092.63V C11-26 10408.3 9769.3 1905.29 2662.81V -68.' 619,3~ 1?6000, qqq7 6~ ."70" ."e ?nOA AmI 1!"'11_?R ,n 'n^ n, q7R7 1 ~ ?¡:;¡:;? nAIl -6R 61q qf 12700.0, 10004.R" 1¡:;AA A?e 2110??11 1('11-26 10:lq?SI q7!i4RI A nnn nn, ?¡:;<;7 A¡:;II -66.f 630.S1 12719.1 10005.0( 1670.00~ 2123.00V C11-26 10388.5 9751.3 1899.72 2656.64V -65.£ 633.9E 12ROOn 1000S OC 1<;on 7¡:;e ?nR.R1V 1r.11-?R 10:\71 :II q7:1!i R~ AnnA nn, ?¡:;<;1 ?¡:;II -R44 RS3qf 12900.0 10005.0C 1 Lla? ¡:;a~ 215R.37V IC11-26 q71R2{ A nnn on, 2644.61V -62.E 690.51 13000.0 10005.0 1394.62~ 2177.93V C11-26 10328.5 9696.7 1882.90 2637.96V -60.E 738.2 131000, 10005 OC 1?qR.!i!i~ ?107 <;ml 1('11-?R 10:107 1. qR77 :If ?¡:;"I1 "Iml -5R 7q52C 1:1?00 0, 10005.0C AAn"A", ??17 n¡:;11 1('11-26 llJLKh.f! Q657Q, ?¡:;?LI ¡:;<;II -56.E 859.5C 13300.0 10005.0( 11 00.42~ 2236.63V C11-26 10264.3 9638.5 1864.92 2618.00V -55.( 929.~ Error Model All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig ( Planned Datum 105.0ft above mean sea level) Reference MO's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (10) Prepared by Baker Hughes Incorporated · e XTO Energy, Inc. C22A-26LN Ver2, C22A-26LN Vers2 slot #4-30, Platform C CLEARANCE LISTING Page 8 Date Printed: 9-Sep-2004 Middle Ground Shoals, Cook Inlet, Alaska '&1. .... INTEQ Clearance Data Reference Reference Reference MD[ft] TVD[ft] North[ft] Reference Offset Well East[ft] Offset MO[ft] Offset TVD[ft] Offset North[ft] Offset East[ft] Angle Closest Ellipse From Approach Separation Highside Distance [ft] All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Planned Datum 105.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (10) Prepared by Baker Hughes Incorporated · e XTO Energy, Inc. C22A-26LN Ver2, C22A-26LN Vers2 slot #4-30, Platform C CLEARANCE LISTING Page 9 Date Printed: 9-Sep-2004 Middle Ground Shoals, Cook Inlet, Alaska '&i. .... INTEQ Clearance Data Reference Reference Reference MD[ft] TVD[ft] North[ft] Reference East[ft] Offset Well Offset MD[ft] Offset TVO[ft] Offset North[ft] Offset East[ft] Angle Closest From Approach Highside Distance Ellipse Separation [ft] 14700.0 IOffset Well bore Survey Tool P1rams ~1e~_23 1~1e~~2O;~AWB\ I ~~e~o~~ ~9'> I MDfftl 11299 oj ~~:~~:~~I Gvro I ~~~d~~el All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Reference MD's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (10) Prepared by Baker Hughes Incorporated . . XTO Energy, Inc. C22A-26LN Ver2, C22A-26LN Vers2 slot #4-30, Platform C CLEARANCE LISTING Page 10 Date Printed: 9-Sep-2004 Middle Ground Shoals, Cook Inlet, Alaska J&ií. ~ INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Distance [ft] IrciAnl I rftl 11900.0 9771.11 2432.53 1973.431/1 C21-26 10723.3 9697.0 1521.92c 2265.211/1 -34. 959.0! 11Q20 RI Q7RO 0, ?A 1'1 7 A trY7" "". "'''·_2R 107'\d Q. Q70<; RI 1<;1R QH ""CO n.,. _'\'\ r Qd2 O~ 1200001 QR12fi! ?'A1 <;QC '^~~ ^~.. '^A -2R 1077R 0: Q7'\fidl 1 fiOR 1 '\~ 2?'\1 RRI/\ -2df R7fi 2, 12100.0 9850.4 2249.94 1988.321/1 C21-26 10817.9 9764.7 1496.89~ 2204.151/1 -1U 788.0 121 fiR fi' QR70 2, 21 QR 2'\~ _2R 10835.8. 9776.91 1491.96~ 21Q1 Q71/\ -2 7'\7 Q' 1220001 QRRdQ, 21 fiR fi2~ -2R 10Rd77' Q7Rd Q' 1AAA AAC ?1 A'I 7AI^ -1 :1 RQQ '\! 12300.0 9918.8 2067.22 2032.251/1 C21-26 10877.5 9804.5 1480.26~ 2163.011/1 2.8 612.1( 12'\RR '\. QQdRm 1 QAA 'A ?O<; 1 ACI. 11"'?1_26 10900.01 9819.0' 1473.81 ~ ?1d70dl/\ R <;'\R Q, 12dOO 01 QQfi2 R( 1 Q7<; AQC "nc, _?R 10QO'\ O. QR?O Q: 1A7? Q?C ?1AA AAI. R~ <;?7 R~ 12500.0 9980.1 1882.44 2077.301/1 C21-26 10927.2 9835.9 1465.78~ 2127.33\1\ 10.~ 443.7 12ROO 01 QQQ7 R' 17AA Anc "nno O^'^ 1"'''·-26 1 0946.8! 9847.9: 1.4<;QR<;~ 2112.921/\ 1R, ,\<;Q <;. 1 nnnA A' 1 AAA A?C _?R 10QR? l' QR<;7 Of 1.4<;<; 1<;~ ?101 <;QI/\ 22' ?77m 12719.1 10005.0 1670.00 2123.00\1\ C21-26 10965.3 9858.9 1454.15~ 2099.21V 24. 261.7 1 nnn<; nl 1 <;Qn 7AC ". "0 0." I"'''·_?R 1 OQ7R '\' QRRR <;. 1A<;n nAC ?R ?O'\d 1nnn<; nl 1AQ? AQC 'H co "7" 1"'''·_2R 10QQ1S QR7 d 0- 1AA<; A7C 207Q fi1V '\'\f 1fiQ Rf 12931.3 10005.0 1461.95c 2164.50\1\ C21-26 10996.7 9877.0 1444.21 C 2075.58V 35. 156,8 1nnn<; nl 1 'QA A?C ?177 _?R 1100<; RI QRR? 1~ 1AA 1 ?7C ?nAA AAII '\R f 170 Q~ 1 nnn<; nl 1?QA <;<;c -2R 11022 R' QRQ1 fi~ · A"C onc ?n<;<; 7AII ddf ??R R~ 13200.0 10005.0 1198.48c 2217.06\1\ C21-26 11037.7 9899.7 1430.87 2044.16V 49. 308.H '^^^^ ^ 1nnn<; nl 1100 d?~ """" _?R 110<;'\ O' QQOR OJ · A"C 0", ?O'\? ?7V fid ,\QR ?~ 1nnn<; nl 1nn? '<;c '>'>c" 1 0\, 11"''>1_?R 11070 ?! QQ17 ?: 1d?n 1d' ?n1R RRII fiQf dRRd, 13500.0 10005.0 904.281= 2275.751/\ C21-26 11086.1 9925.5 1414.87 2006.45V 64. 582.7( '^^^^ ^ 1nnn<; nl ROR ?1 ~ ""nc _?R 1110001 QQ,\? 7, 1QQ<; <;<;11 R7' R7R 1f 1nnn<; nl 70R 1d!' ?'1<1. RRI^ Ir?1_?R 1111R'\: QQd1 l' · AnA OA, 1 QA? A?II 71 77dfi1 13800.0 10005.0 610.08~ 2334.441/\ C21-26 11133.2 9949.7 1399.23 1969.19V 74.f 871.3 '^^^^ ^ 1 nnn<; nl <;1? 01!' ?'<;1I _?R 111dO ,\, QQ<;'\dl 1QA'I <;AII 7R ~ QRRR' Offset Well bore Survey Tool pro;!"ms ~;~1-26 I~;~I~C;;~AWB) I ~~e~~~ ~5'> IMDfftl 11485 oJ ~~:~~:~~I Gvro I ~~~d~~ddel All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 105.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated . . XTO Energy, Inc. C22A-26LN Ver2, C22A-26LN Vers2 slot #4-30, Platform C CLEARANCE LISTING Page 11 Date Printed: 9-Sep-2004 Middle Ground Shoals, Cook Inlet, Alaska r&i. BfBI.s INTEQ Clearance Data Reference Reference Reference MD[ft] TVD[ft] North[ft] Reference East[ft] Offset Well Offset MD[ft] Offset TVD[ft] Offset North[ft] Offset East[ft] Angle From Highside Closest Ellipse Approach Separation Distance [ft] All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 1 05. Oft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Prepared by Baker Hughes Incorporated I C22A...26LN Cook Inlet Sidetrack Name Signature Date Originator: Pat Young Reviewed by: Mark Dick Customer Approval: Sill Penrose Version: 1.0 SeptemberS, 2004 9/8/2004 . . XTO C22A-26LN I Production Interval - 6.0" Drilling Fluid System VERSADRIL Key Products Mapco-200 base oil, Versa-Mod, Versa-HRP, VersaCoat HF, VersaWet, SAFE-CARB, Lime, VG Supreme Solids Control Shakers, Mud cleaner, Centrifuge Potential Problems Torque and drag. Hole cleaninQ. Depth MD MudWt. Yield Point High Oil:Water Electric (ft) (Ib/gal) (lbI100tr) Temp.{âl250 Ratio Stability ., 10,950 -14,678 9.5 - 10.5 15-20 <8cc 75 :25 >500 Production Interval VERSAPRO Formulation Product Mapco 200 (.825 SpG) IMG-400 Lime VERSACOAT HF VERSAWET Brine (10.4 CaCI2) VERSA-MOD VERSA HRP Barite 0.7 Bbl 6.0 Lbs 4.5 Lbs 5.0 Lbs 2.0 Lbs 0.19 Bbls 0.5 Lbs 0.75 Lbs 75.0 Lbs Location North Slope Alaska 9/8/2004 Confidential 5 MGS C22A-.26LN will be the fifth well to the in SW/4 of 23. MGS C22A-26LN wi/t be the third well to the pool in NW/4 of 26. T8N, R13W, SM MGS C22A..26LN Producer 2041820 . . TO THE ORDER STATE OF ALASKA AOGCC (OIL & G OF 333 WEST 7TH AVE SUITE 100 ANCHORAGE AK 99501 USA III 0 ~ :l ~ HJ III I: ~ 2 5 20 0 0 b 0 I: o. ¡. 2 8 2 j 0 III ~ -"-_.-;--~----_._....__.-;-:-------------------------------~--..,........~-~- M' . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER /?/L7S (!¿zA-z&¿¢ 2-DÝ.- /~2 WELL NAME PTD# ~velopment Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE ". APPLIES (OPTIONS) MULTI The permit is for a new weUbore segment of LATERAL existing weD . Permit No, API No. . (If API Dum ber Production. should continue to be reponed as last two. (2) digits a function' of the original API number. stated are between 60-69) above. Pn,OT HOLE In accordance with· 20 AAC 25.005(f), aI] (PH) records, data and logs acquired ,for the pUot bole must be dearly differentiated In botb name (name on permit plus PH) .' and API Dumber (50 - 70/80) from records, data and logs acquired for we]] (name on permit). SPACING Tbe permit is approved subject ·to fun ( EXCEPTION .' compliance with 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation or,;:: appro~g ~ spa dng' e:JCeption. I J iÚ' tc-vI;rù -v (Company Name) assumes the liability of any protest to tbe spacing exception that mey occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater 1han 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample iIi1er:vals through target zones. .' ~/- ,tÞ tJ¡./7·Dý Well Name: MGS C22A-26LN Program DEV Well bore seg PTD#: 2041820 Company XTO ENERGY INC Initial ClasslType DEV / PEND GeoArea 820 Unit 00000 On/Off Shore Off Annular Disposal 1 Permittee attache.!:L . . . . . . . . . . . . . .Y~s. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 .leas~.number .appropriat.e . . . . . . . . . . . . . . . . . . . . .Y~s . . . . Entire well in ADL 18756 . . . . . . . . . . . . . . . . . . .' ....... 3 _U.nique well.n.am~_aod oumb.er . . . . _ _ _ . . . . _ . . . . _ _ _ . . . _ . . . . . . . . . . . . . . _ .Y~s . . . _ . . . . _ . . . . . . _ . . . . . _ . . . . _ . . . . . _ . . . . . _ . . . . . . . _ . . . . . _ _ _ . . . . _ _ . . . . . . . . . . . . . . 4 WellJQcat~d in.aclefinedppol . . . . . . . . . . . . . . . . . . . . . .Y~s . . . Middle GrQuod ShQal E, f,.and G (524114) . . . . . . . . . . . . . . . . . 5 WellJQcat~d pr.oper .distance. from driJling unitb.ound.ary. . . . . . . . . .Y~s . . . . . . . PerCQ 44; >500' from lease. line wbere pwners.hip.changes. .............. 6 WeJIJQcat~d prpper .distance. from otber welJs . . . . . . . . . . .Y~s . . CO M does.npt.specify a minimum pffs.et distance .between weJls.. . . . . . . . . . . . . . . . 7Suffjcientacreag.eayailable indrilJiog unjt . . . . . . No. . . SpACING EXÇ¡;:PTION.REQUJREQ:will be.3.rd well open toppoUn NW145ec.26 aodsecon.dwell ppe.n. 8 Jf.d~viated, js. weJlbore platincJu.ded . . . . . . . . . . . . . . . . . . . .Y~s . . . . . t.o ppol jn SW/"-.of Section 23, . . . . . . . . . . . . . . . 9 Operator onl}! affected party. . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 .Operator bas.apprppriate.bond inJorce . . . . . _ . . . . . . . . . . _ . . . . _ . . . . . . . . . . . .Y~s . . _ . . . . _ . . . . . . . . . . . . . . . . . _ . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 P~rmit.canbeissuedwitbQutco.nservationorder .. .Y~s. ...... .............. ....... ....... Appr Date 12 P~rmit.can be issued witbQut administratille.apprpvaJ . . . . . . . . . . . . . No. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . SFD 9/17/2004 13 Can permit be approved before 15-daywait Yes 14 WellJQcat~d within area and.strataauthorized by.lojectipn Ord~r# (puUOtJ in.cpmmeots) (For. NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15 .AJI welJs.withtn.114.mile.are.a.of reyiew id~ntified (Fpr sefVj~well pnl}!). . _ . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . '. ................... _ . . . . 16 Pre-produced injector; durat.ionof pre-production less than. 3. montbs. (For.servtce well only) . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17 ACMP.Fïnding.ofConstst.eocyh.as beenissued.fortbis project. . . . NA . . . Sidetrack well, . . . . . . . . . . . . . . . . . . . . . Administration Engineering Appr Date TEM 9/29/2004 'I/¡V¡ Geology Appr SFD Date 9/16/2004 Geologic Commissioner: o'iS Field & Pool MIDDLE GROUND SHOAL, E,F,G OIL - 524114 D D - - - - - - 18Coodu.ct.or string. provided . . . . . . . . . . . . . . . . . . . . . . . .Y~s 19 .s.uúa~ .casing. protects alLknown USQWs . . . . . . . . .NA . . 20 .CMTvoladequ.ateto circulate.o!lcpnductor.8c surfC$g . . NA 21CMT vpl adequateto tie-tnJong .string to surf csg . . . . . . No 22CMTwiIJ coyeraJlknow!lpro.ductiye bori;¡:on.s . . . . . . . . . . . . No. . . . SlotledJioer.completloo plaoned.. . . . . . . . . . . . . . . . 23 .C.asiog desigos ad.eç¡ua.te fpr C.T. B&. permafrost . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . 24 Adequatetan.k<lge. or re.seIYe pit . . . . .Y.es . . . . Rig js. euipped. withste.el pits On offshore platform, No reserve pit possible.. ,i\1J waste to dtsposal. well.. 25 Jfa.re-drilt basa to,403 for abandonment be~o approved. . . . . . . . . . . . . . .Y~s . 30"-:3"-7. . . . . . . . . . . . . . . . . . . . . 26 .Adequat.eweJlbore. sep<lratio.n.proppsed. . . . . . . . . . . . . . . . . . . _ . . . . _ . . . . . . . . .Y~s _ . . . . . . prp¡çimity- analysis pertorrT)e.d, Close <lpproacbe.s .id.entjfi~d,.all within Hemlpck, . . . . . . . . . . . . . . . . . . . . . 27 Jf.diverter required, does it meet. reguJations . . . . . . . . . . . . . NA . . . eop wlJ <llreadY- be.in pl<lce, .. ....... . . . . . . . . . . . . . . 28 .DriUingfJuid.programschem<ltic&equipJistadequat.e. ............ .... .Yes .. .M<lximumexpectedfprmationpressuœ.6JEMW.. MWpl<lnned,.9,5.-.10..5.ppg. 29 .BOPEs..dp they meetreguJation. ............. . . . . . Y.es . . Waiyerhas been.glven t.o .operate witb 1 seLof pipe rams (\IBRs) du.e.to limit.ed substructure beight.. 30 .B.OPEpressratingappropriate;testto(putpsigtn.comments) ......... .Y~s. . . M,i\SP calcu!ated.at2tOJ psi, 35QOpst6QF'tesLapproprtate,.......... 31C.hokemanifold compJies w/,i\PI. RP-53(May 84) . . . . 'yes . . . . . . . . . . . . . . . . . . . . . . . . . 32 Work will occ.ur withouLoperatjo!lsbutdoW!l. . . . . . . . . . .Y~s. . . . . . . . . . . . . . . . 33 .Is presence. of H2S gas. probable. . . . . . . . . . . . No. . . . 1-125 is notexpected.. Mud should mitigat.e .an}!1-I25 on rig, Rjg equipped with .sensors .and <llarm.s, . 34 Mecba.nlcaLcond.iUon pf wells wlthin AOR yerified (Fpr.s.ervjce welJ onJy). . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Conductor.setin orgtn<llwelJbore. . . . . . All aq.uifers exempt.ed.A.o.CFR1.47.10212)(iii).. . . . Surtace castng cemente.din orgioal welJbpre, . . - - - - - - ~ - - - - - ~ - - - - - - - ~ - - - - - - ~ - - - - - - - - - - - - ~ - 35 P~rmit. cao be lssued wfo. hydrogen. s.ulfide measures. . . 36 .Data.presented on pote.ntial overpressur~ .zones. 37 .S~tsmic.an<llys.is of shaJlow gas.zpoes. . 38 .S~<lbed .condition survey .(if off-sh.ore) . . . . . . . . 39 . Contact nam.elphoneforweelsly prpgressreports [explor<ltpryonly] .. Y~s. . . . .Y~s. .NA NA. NA. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- . . . Offs.et well d.ataindjcate HemJock isu!lderpressuœd (6.2 pp.gEMW); wiJl be drjlled with 9.5 - to.Q ppgmud, - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - Date: Engineering Commissioner: P blic sioner Date 7/3cJ/1- D-7 G POOL 1/68 1263 BOPD /180 BWPD HC-HR 9169 255 BOPD 117 BWPD, C.T.I. .105/.019 T 0-7 12/69 1824 BWIPD HC-HR 12/84 P&A 8.528 D-5 E,F,G 3 / 68 1645 BOPD / 51 BWPD POOLS 11/76 928 BWPD, P&A 3.639 /1.282 7 D-12 G POOL 11168 881 BOPD / 377 BWPD HC-HR 4/70 509 BOPD /76 BWPD, C.T.I. .285/.067 D-12 G POOL 4170 1824 BWIPD HC-HR 2187 P&A 17 .728 N ÎÕ ~ ~~~ yV/A-P S.eº. r:¡-~ F~J.vv MIDDLE GROUND SHOAL FIELD Kenai County Offshore Cook Inlet, Alaska DEVELOPMENT MAP HEMLOCK HC HORIZON (HC-HD) STRUCTURAL CONTOURS CONTOUR INTERVAL: 200' ALL WELLS POSTED GEOLOGIST: M. LANGELER DATE: JUNE 21, 2001 MHJ: MGSFIELD.CDR e Cross Timbers Oil Company- . .