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Home My WebLink About189-0491. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,450 feet 1,800 feet true vertical 6,543 feet N/A feet Effective Depth measured 1,800 feet See schematic feet true vertical 1,753 feet See schematic feet Perforation depth Measured depth 1,497 - 1,781 feet True Vertical depth 1,480 - 1,737 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / N-80 1,788 MD 1,743 TVD Packers and SSSV (type, measured and true vertical depth)See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer 10-3/4" 9-5/8" 504 MD 951 1,462 7,460 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 1217 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 189-049 50-733-20407-00-00 Plugs ADL0017594 Trading Bay Unit M-13 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-195 420 Authorized Signature with date: Authorized Name: 0 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 141 N/A Oil-Bbl 290 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 0 McArthur River Field / Middle Kenai Gas PoolN/A measured 2,923 504 Size 50 Production Casing Structural Production 6,946 Length 951 1,462 Conductor Surface 3,810psi 4,020psi 20" 16" 13-3/8" 2,923 3,090psi 907 777-8387 6,450psi 950 1,447 2,601 504 6,643 Collapse Mark McKinley mmckinley@hilcorp.com Tubing Pressure 1,020psi 1,540psi 2,630psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 6,330psi Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:41 am, Jun 18, 2020 Daniel Marlowe I am approving this document 2020.06.17 15:29:37 -08'00' Daniel Marlowe gls 6/22/20 DSR06/18/2020 RBDMS HEW 6/18/2020 Perforate Updated by: JLL 06/17/20 SCHEMATIC Steelhead M-13 Completed: 10/18/12 PTD: 189-049 API: 50-733-20407-00 JEWELRY DETAIL No. Depth ID Description 1 469' 2.992 BX Nipple 2 471' 2.82 SCSSV, Baker TE5 3 1,267' 2.992 Gas lift mandrel 4 1,375' 6 9-5/8" 47# Model 'D' Isolation Packer 5 1,483' 4.892 Top of 5-1/2" .012 304SS Screen (109' overall) 6 1,578' 2.813 3-1/2" CS Hydril Benoit5 Sliding Sleve w/ 2.813 X nipple 7 1,596' 6 9-5/8" 47# Model 'D' Isolation Packer 8 1,612' 2.813 3-1/2" 8rd x 2.813 "X" Nipple 9 1,625' 4 Overshot is 4.71' over the Hook-up Nipple 10 1,723' 4.982 Top of 5-1/2" .012 304SS Screen (64' overall) 11 1,788' 4.75 9-5/8" 47# Model 'D' Sump Packer 12 2,090' CIBP 13 2,099' 3.25" S-22B Snap Latch Seal Assembly 14 2,103' 4.75" SC-1 GP Packer 15 2,109' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV 16 2,135' 4.00" 4 1/2 " , 11.6#, H-503, L-80 Blank Pipe 17 2,189' 3.548" Excluder Screen 4" SLHT (74.6') 18 2,255' 3.25" S-22B Snap Latch Seal Assembly 19 2,256' 4.75" SC-1 GP Packer 20 2,262' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV 21 2,288' 4.00" 4 1/2 " , 9.5#, H-503, L-80 Blank Pipe 22 2,423' 3.548" Excluder Screen 4" SLHT (447.6') 23 2,872' 4.75" Baker Model D Sump Packer SZ-19 SZ-20 SZ-21 SZ-22 SZ-23 TD = 7,450’(MD) PBTD = 1,800’ (MD) Max Hole Angle=44.8° @ 2,400’(MD) RKB to Tbg Hanger = 73.4’ A6 13 18&19 20 TOC 1,800’ B-1,2 & 21 22 D6 D16A D16B & C 20” 16” 13-3/8” 9-5/8” 10-3/4” SZ-11 SZ-13 SZ-17 23 13&14 15,16 &17 SZ-12 1 2 BX 3 4 5 6 7 8 9 10 11 12 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Status Date SZ-11 1,497' 1,578' 1,480' 1,555' 81' 12 Open 10/16/2012 SZ-12 1,645’ 1,652’ 1,616’ 1,623’ 7’ Open 05/25/2020 SZ-13 1,737' 1,749' 1,698' 1,709' 12' 12 Open 10/14/2012 1,759' 1,767' 1,717' 1,724' 8' 12 Open 10/14/2012 1,773' 1,781' 1,730' 1,737' 8' 12 Open 10/14/2012 CASING DETAIL Size Type WT Grade ID Top BTM 20” Conductor 94 X-56 19 Surf 951’ 16” Intermediate 75 K55 15.124 Surf 1,462’ 13-д” Surf Csg 61 K-55 12.515 Surf 2,923’ 10- 3/4" Prod Csg 55.5 N-80 9.76 Surf 504' 9 5/8" Prod Csg 43.5 N80 8.755 504' 2,010' 9-5/8 Prod Csg 47 N80 8.681 2,010' 7,450' TUBING DETAIL 3-1/2" 9.3 N-80 2.992 Surf 1,788’ Isolated perforations are listed on the next page. SZ-12 7’ Open 05/25/2020SZ-12 1,645’ 1,652’ 1,616’ 1,623’ Updated by: JLL 06/17/20 SCHEMATIC Steelhead M-13 Completed: 10/18/12 PTD: 189-049 API: 50-733-20407-00 Isolated-Perforation Data Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Status Date SZ-11 1,479’ 1,484’ 1,463’ 1,468’ 5’ 2 Squeezed 10/03/12 SZ-11 1,602’ 1,607’ 1,577’ 1,582’ 5’ 4 Squeezed 10/02/12 SZ-13 1,727’ 1,732’ 1,689’ 1,694’ 5’ 4 Squeezed 10/01/12 SZ-14 1,820’ 1,823’ 1,770’ 1,773’ 3’ 1 Isolated 9/30/12 SZ-14 1,846.5’ 1,850.5 1,793’ 1,796’ 4’ 6 Isolated 10/07/12 SZ-15 1,870’ 1,875’ 1,812’ 1,817’ 5’ 5 Isolated 9/30/12 SZ-16 2,082’ 2,084’ 1,984’ 1,985’ 2’ 10 Isolated 09/29/12 SZ-16 2,085’ 2,088’ 1,986’ 1,988’ 3’ 10 Isolated 09/30/12 SZ-17 2,190' 2,234' 2,065' 2,097' 44' 12 Isolated 11/8/08 SZ-19 2,461' 2,470' 2,259' 2,265' 9' 12 Isolated 11/6/08 2,470' 2,479' 2,265' 2,272' 9' 6 Isolated 10/15/04 2,492' 2,497' 2,281' 2,285' 5' 12 Isolated 11/6/08 Stray 2,518' 2,522' 2,300' 2,303' 4' 12 Isolated 11/6/08 SZ-20 2,538' 2,550' 2,314' 2,323' 12' 6 Isolated 11/2/03 2,538' 2,550' 2,314' 2,323' 12' 12 Isolated 11/6/08 2,569' 2,583' 2,336' 2,347' 14' 12 Isolated 11/6/08 2,576' 2,590' 2,341' 2,352' 14' 6 Isolated 10/15/04 2,598' 2,602' 2,357' 2,360' 4' 12 Isolated 11/6/08 SZ-21 2,641' 2,653' 2,389' 2,398' 12' 12 Isolated 11/6/08 2,650' 2,662' 2,395' 2,404' 12' 6 Isolated 10/15/04 2,690' 2,712' 2,425' 2,441' 22' 12 Isolated 11/6/08 2,698' 2,718' 2,431' 2,446' 20' 6 Isolated 10/15/04 2,719' 2,734' 2,446' 2,458' 15' 12 Isolated 11/6/08 2,733' 2,742' 2,457' 2,464' 9' 6 Isolated 10/14/04 SZ-22 2,780' 2,789' 2,492' 2,499' 9' 12 Isolated 11/6/08 2,789' 2,798' 2,499' 2,506' 9' 6 Isolated 11/19/03 SZ-23 2,846' 2,852' 2,542' 2,547' 6' 4 Isolated 11/6/08 SZ Coal 2,850' 2,862' 2,554' 2,554' 12' 6 Isolated 10/14/04 A-6 3,570' 3,610' 3,103' 3,134' 60' 12 Isolated B-1 3,754' 3,778' 3,245' 3,264' 24' 12 Isolated B-2 3,790' 3,809' 3,273' 3,288' 19' 12 Isolated B-3 3,948' 4,006' 3,396' 3,442' 58' 12 Isolated D-6 5,950' 5,978' 5,140' 5,166' 28' 12 Isolated 10/19/89 D-16A 7,035' 7,042' 6,150' 6,157' 7' 12 Isolated 10/19/89 D- 16B,C 7,106' 7,134' 6,217' 6,243' 28' 12 Isolated 10/19/89 Rig Start Date End Date Eline 5/25/20 5/25/20 Daily Operations: Hilcorp Alaska, LLC Weekly Operations Summary API Number Well Permit NumberWell Name M-13 50-733-20407-00 189-049 Arrive @ Platform. PJSM & permit. RU ELU. PU GR/CCL tool suite. Surface test CCL. PT = 250/1500. RIH to 1783' CCL. Log up to 1000' CCL. Send for log correlation. Correct -8'. Resend corrected log. Correction verified & approved. POOH. Surface test CCL & FH. PU Perf Gun#1: 2-1/2" x 7' Spiral Strip carrier, 4 spf, 60* phase, 25 gm Shogun charge. CCL-to Top Shot = 13.8'. CCL to Bottom Shot = 20.8'. BIH w/ Perf Gun#2 to 1702' CCL. Pull log pass to 1575' CCL, correct -0.5'. RBIH to 1700', log up to 1631.2' CCL to place shots on depth (1631.2' + 13.8' = 1645' Top Shot). Fire Perf Gun#1 to perf Zone SZ-12 1645' - 1652'. Log up 200' & POOH. OOH all shots fired. RD ELU, turnover well to Prod Ops & prep for ELine kit for backload to boat. Fly crew to beach. Job Complete. 05/25/2020 - Monday . PU Perf Gun#1: 2-1/2" x 7' Spiral Strip carrier, Fire Perf Gun#1 to perf Zone SZ-12 1645' - 1652'. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7,450'N/A Casing Collapse Structural Conductor Surface 1,020 psi Intermediate 1,540 psi Production 4,020 psi Production 3,810 psi 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:mmckinley@hilcorp.com Contact Phone: (907) 777-8387 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Operations Manager Mark McKinley PRESENT WELL CONDITION SUMMARY Length Size 3,090 psi 1,800' COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017594 189-049 50-733-20407-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-13 CO 228A 9.3 / N-80 TVD Burst 1,788 6,450 psi 6,330 psi Tubing Size: MD 2,630 psi 950' 1,447' 2,601' 951' 1,462' 20" 16" 951' 13-3/8"2,923' 1,462' 504' Perforation Depth MD (ft): 2,923' 1,497 - 1,781 504' See schematic Tubing Grade:Tubing MD (ft): 1,480 - 1,737 Perforation Depth TVD (ft): Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 5/21/2020 3-1/2" Daniel E. Marlowe See schematic 6,543' 1,800' 1,753' 542 psi 6,946' 9-5/8" 504'10-3/4" 7,460' 6,643' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Daniel Marlowe I am approving this document 2020.05.07 07:51:25 -08'00' Daniel Marlowe By Samantha Carlisle at 8:43 am, May 07, 2020 320-195 Perforate X DSR-5/7/2020 10-404 GAS DLB 05/07/2020 gls 5/14/20 Comm. q Yes 5/18/2020 dts 5/14/2020 JLC 5/18/2020 RBDMS HEW 5/22/2020 Well Work Prognosis Well Name:Trading Bay Unit M-13 API Number: 50-733-20407-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:5/21/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (907) 777-8332 Permit to Drill Number:189-049 First Call Engineer:Mark McKinley Office: 907-777-8387 Cell: 907-953-2685 Second Call Engineer:Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Current Bottom Hole Pressure:173 psi @ 1,615 TVD 0.1 psi/ft Gas Gradient to surface Maximum Expected BHP:706 psi @ 1,632’ TVD 0.433 psi/ft water gradient to surface Maximum Potential Surface Pressure:542 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) **Well to be perforated while flowing Brief Well Summary: Well M-13 is a gas well completed in the “SZ” Sands. This project will add additional perforations in the SZ-12 sand. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Well M-13 is a gas well completed in the “SZ” Sands. This project will add additional perforations in the SZ-12 sand. (perf through tubing and casing) As Completed 10/18/12 As Perfed: 10/16/12 REVISED by JLL: 12/06/12 Steelhead M-13 JEWELRY DETAIL No. Depth ID Description 1 469' 2.992 BX Nipple 2 471' 2.82 SCSSV, Baker TE5 3 1,267' 2.992 Gas lift mandrel 4 1,375' 6 9-5/8" 47# Model 'D' Isolation Packer 5 1,483' 4.892 Top of 5-1/2" .012 304SS Screen (109' overall) 6 1,578' 2.813 3-1/2" CS Hydril Benoit5 Sliding Sleve w/ 2.813 X nipple 7 1,596' 6 9-5/8" 47# Model 'D' Isolation Packer 8 1,612' 2.813 3-1/2" 8rd x 2.813 "X" Nipple 9 1,625' 4 Overshot is 4.71' over the Hook-up Nipple 10 1,723' 4.982 Top of 5-1/2" .012 304SS Screen (64' overall) 11 1,788' 4.75 9-5/8" 47# Model 'D' Sump Packer 12 2,090' CIBP 13 2,099' 3.25" S-22B Snap Latch Seal Assembly 14 2,103' 4.75" SC-1 GP Packer 15 2,109' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV 16 2,135' 4.00" 4 1/2 " , 11.6#, H-503, L-80 Blank Pipe 17 2,189' 3.548" Excluder Screen 4" SLHT (74.6') 18 2,255' 3.25" S-22B Snap Latch Seal Assembly 19 2,256' 4.75" SC-1 GP Packer 20 2,262' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV 21 2,288' 4.00" 4 1/2 " , 9.5#, H-503, L-80 Blank Pipe 22 2,423' 3.548" Excluder Screen 4" SLHT (447.6') 23 2,872' 4.75" Baker Model D Sump Packer SZ-19 SZ-20 SZ-21 SZ-22 SZ-23 TD = 7,450’(MD) PBTD = 1,800’(MD) Max Hole Angle=44.8° @ 2,400’(MD) RKB to Tbg Hanger = 73.4’ A6 13 18&19 20 TOC 1,800’ B-1,2 & 21 22 D6 D16A D16B & C 20” 16” 13-3/8” 9-5/8” 10-3/4” SZ-11 SZ-13 SZ-17 23 13&14 15,16 &17 1 2 BX 3 4 5 6 7 8 9 10 11 12 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Status Date SZ-11 1,497' 1,578' 1,480' 1,555' 81' 12 Open 10/16/2012 SZ-13 1,737' 1,749' 1,698' 1,709' 12' 12 Open 10/14/2012 1,759' 1,767' 1,717' 1,724' 8' 12 Open 10/14/2012 1,773' 1,781' 1,730' 1,737' 8' 12 Open 10/14/2012 CASING DETAIL Size Type WT Grade ID Top BTM 20” Conductor 94 X-56 19 Surf 951’ 16” Intermediate 75 K55 15.124 Surf 1,462’ 13-д” Surf Csg 61 K-55 12.515 Surf 2,923’ 10- 3/4" Prod Csg 55.5 N-80 9.76 Surf 504' 9 5/8" Prod Csg 43.5 N80 8.755 504' 2,010' 9-5/8 Prod Csg 47 N80 8.681 2,010' 7,450' TUBING DETAIL 3-1/2" 9.3 N-80 2.992 Surf 1,788’ Isolated perforations are listed on the next page. As Completed 10/18/12 As Perfed: 10/16/12 REVISED by JLL: 12/06/12 Steelhead M-13 Isolated-Perforation Data Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Status Date SZ-11 1,479’ 1,484’ 1,463’ 1,468’ 5’ 2 Squeezed 10/03/12 SZ-11 1,602’ 1,607’ 1,577’ 1,582’ 5’ 4 Squeezed 10/02/12 SZ-13 1,727’ 1,732’ 1,689’ 1,694’ 5’ 4 Squeezed 10/01/12 SZ-14 1,820’ 1,823’ 1,770’ 1,773’ 3’ 1 Isolated 9/30/12 SZ-14 1,846.5’ 1,850.5 1,793’ 1,796’ 4’ 6 Isolated 10/07/12 SZ-15 1,870’ 1,875’ 1,812’ 1,817’ 5’ 5 Isolated 9/30/12 SZ-16 2,082’ 2,084’ 1,984’ 1,985’ 2’ 10 Isolated 09/29/12 SZ-16 2,085’ 2,088’ 1,986’ 1,988’ 3’ 10 Isolated 09/30/12 SZ-17 2,190' 2,234' 2,065' 2,097' 44' 12 Isolated 11/8/08 SZ-19 2,461' 2,470' 2,259' 2,265' 9' 12 Isolated 11/6/08 2,470' 2,479' 2,265' 2,272' 9' 6 Isolated 10/15/04 2,492' 2,497' 2,281' 2,285' 5' 12 Isolated 11/6/08 Stray 2,518' 2,522' 2,300' 2,303' 4' 12 Isolated 11/6/08 SZ-20 2,538' 2,550' 2,314' 2,323' 12' 6 Isolated 11/2/03 2,538' 2,550' 2,314' 2,323' 12' 12 Isolated 11/6/08 2,569' 2,583' 2,336' 2,347' 14' 12 Isolated 11/6/08 2,576' 2,590' 2,341' 2,352' 14' 6 Isolated 10/15/04 2,598' 2,602' 2,357' 2,360' 4' 12 Isolated 11/6/08 SZ-21 2,641' 2,653' 2,389' 2,398' 12' 12 Isolated 11/6/08 2,650' 2,662' 2,395' 2,404' 12' 6 Isolated 10/15/04 2,690' 2,712' 2,425' 2,441' 22' 12 Isolated 11/6/08 2,698' 2,718' 2,431' 2,446' 20' 6 Isolated 10/15/04 2,719' 2,734' 2,446' 2,458' 15' 12 Isolated 11/6/08 2,733' 2,742' 2,457' 2,464' 9' 6 Isolated 10/14/04 SZ-22 2,780' 2,789' 2,492' 2,499' 9' 12 Isolated 11/6/08 2,789' 2,798' 2,499' 2,506' 9' 6 Isolated 11/19/03 SZ-23 2,846' 2,852' 2,542' 2,547' 6' 4 Isolated 11/6/08 SZ Coal 2,850' 2,862' 2,554' 2,554' 12' 6 Isolated 10/14/04 A-6 3,570' 3,610' 3,103' 3,134' 60' 12 Isolated B-1 3,754' 3,778' 3,245' 3,264' 24' 12 Isolated B-2 3,790' 3,809' 3,273' 3,288' 19' 12 Isolated B-3 3,948' 4,006' 3,396' 3,442' 58' 12 Isolated D-6 5,950' 5,978' 5,140' 5,166' 28' 12 Isolated 10/19/89 D-16A 7,035' 7,042' 6,150' 6,157' 7' 12 Isolated 10/19/89 D- 16B,C 7,106' 7,134' 6,217' 6,243' 28' 12 Isolated 10/19/89 Updated by: JLL 05/05/20 PROPOSED Steelhead M-13 Completed: 10/18/12 PTD: 189-049 API: 50-733-20407-00 JEWELRY DETAIL No. Depth ID Description 1 469' 2.992 BX Nipple 2 471' 2.82 SCSSV, Baker TE5 3 1,267' 2.992 Gas lift mandrel 4 1,375' 6 9-5/8" 47# Model 'D' Isolation Packer 5 1,483' 4.892 Top of 5-1/2" .012 304SS Screen (109' overall) 6 1,578' 2.813 3-1/2" CS Hydril Benoit5 Sliding Sleve w/ 2.813 X nipple 7 1,596' 6 9-5/8" 47# Model 'D' Isolation Packer 8 1,612' 2.813 3-1/2" 8rd x 2.813 "X" Nipple 9 1,625' 4 Overshot is 4.71' over the Hook-up Nipple 10 1,723' 4.982 Top of 5-1/2" .012 304SS Screen (64' overall) 11 1,788' 4.75 9-5/8" 47# Model 'D' Sump Packer 12 2,090' CIBP 13 2,099' 3.25" S-22B Snap Latch Seal Assembly 14 2,103' 4.75" SC-1 GP Packer 15 2,109' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV 16 2,135' 4.00" 4 1/2 " , 11.6#, H-503, L-80 Blank Pipe 17 2,189' 3.548" Excluder Screen 4" SLHT (74.6') 18 2,255' 3.25" S-22B Snap Latch Seal Assembly 19 2,256' 4.75" SC-1 GP Packer 20 2,262' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV 21 2,288' 4.00" 4 1/2 " , 9.5#, H-503, L-80 Blank Pipe 22 2,423' 3.548" Excluder Screen 4" SLHT (447.6') 23 2,872' 4.75" Baker Model D Sump Packer SZ-19 SZ-20 SZ-21 SZ-22 SZ-23 TD = 7,450’(MD) PBTD = 1,800’ (MD) Max Hole Angle=44.8° @ 2,400’(MD) RKB to Tbg Hanger = 73.4’ A6 13 18&19 20 TOC 1,800’ B-1,2 & 21 22 D6 D16A D16B & C 20” 16” 13-3/8” 9-5/8” 10-3/4” SZ-11 SZ-13 SZ-17 23 13&14 15,16 &17 SZ-12 1 2 BX 3 4 5 6 7 8 9 10 11 12 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Status Date SZ-11 1,497' 1,578' 1,480' 1,555' 81' 12 Open 10/16/2012 SZ-12 ±1,644’ ±1,662’ ±1,615’ ±1,632’ ±18’ Proposed Future SZ-13 1,737' 1,749' 1,698' 1,709' 12' 12 Open 10/14/2012 1,759' 1,767' 1,717' 1,724' 8' 12 Open 10/14/2012 1,773' 1,781' 1,730' 1,737' 8' 12 Open 10/14/2012 CASING DETAIL Size Type WT Grade ID Top BTM 20” Conductor 94 X-56 19 Surf 951’ 16” Intermediate 75 K55 15.124 Surf 1,462’ 13-д” Surf Csg 61 K-55 12.515 Surf 2,923’ 10- 3/4" Prod Csg 55.5 N-80 9.76 Surf 504' 9 5/8" Prod Csg 43.5 N80 8.755 504' 2,010' 9-5/8 Prod Csg 47 N80 8.681 2,010' 7,450' TUBING DETAIL 3-1/2" 9.3 N-80 2.992 Surf 1,788’ Isolated perforations are listed on the next page. Packer 1375ft TOC 1,800’ NOTE: SZ-12 perforations will be through tubing and casing. 1602-1607 ft 1644-1662 ft 1479-1484 ft sqz perfs SZ-12 ±1,644’±1,662’±1,615’±1,632’±18’Proposed Future sqz perfs verify OA is isolated from perfs SZ-11 Updated by: JLL 05/05/20 PROPOSED Steelhead M-13 Completed: 10/18/12 PTD: 189-049 API: 50-733-20407-00 Isolated-Perforation Data Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Status Date SZ-11 1,479’ 1,484’ 1,463’ 1,468’ 5’ 2 Squeezed 10/03/12 SZ-11 1,602’ 1,607’ 1,577’ 1,582’ 5’ 4 Squeezed 10/02/12 SZ-13 1,727’ 1,732’ 1,689’ 1,694’ 5’ 4 Squeezed 10/01/12 SZ-14 1,820’ 1,823’ 1,770’ 1,773’ 3’ 1 Isolated 9/30/12 SZ-14 1,846.5’ 1,850.5 1,793’ 1,796’ 4’ 6 Isolated 10/07/12 SZ-15 1,870’ 1,875’ 1,812’ 1,817’ 5’ 5 Isolated 9/30/12 SZ-16 2,082’ 2,084’ 1,984’ 1,985’ 2’ 10 Isolated 09/29/12 SZ-16 2,085’ 2,088’ 1,986’ 1,988’ 3’ 10 Isolated 09/30/12 SZ-17 2,190' 2,234' 2,065' 2,097' 44' 12 Isolated 11/8/08 SZ-19 2,461' 2,470' 2,259' 2,265' 9' 12 Isolated 11/6/08 2,470' 2,479' 2,265' 2,272' 9' 6 Isolated 10/15/04 2,492' 2,497' 2,281' 2,285' 5' 12 Isolated 11/6/08 Stray 2,518' 2,522' 2,300' 2,303' 4' 12 Isolated 11/6/08 SZ-20 2,538' 2,550' 2,314' 2,323' 12' 6 Isolated 11/2/03 2,538' 2,550' 2,314' 2,323' 12' 12 Isolated 11/6/08 2,569' 2,583' 2,336' 2,347' 14' 12 Isolated 11/6/08 2,576' 2,590' 2,341' 2,352' 14' 6 Isolated 10/15/04 2,598' 2,602' 2,357' 2,360' 4' 12 Isolated 11/6/08 SZ-21 2,641' 2,653' 2,389' 2,398' 12' 12 Isolated 11/6/08 2,650' 2,662' 2,395' 2,404' 12' 6 Isolated 10/15/04 2,690' 2,712' 2,425' 2,441' 22' 12 Isolated 11/6/08 2,698' 2,718' 2,431' 2,446' 20' 6 Isolated 10/15/04 2,719' 2,734' 2,446' 2,458' 15' 12 Isolated 11/6/08 2,733' 2,742' 2,457' 2,464' 9' 6 Isolated 10/14/04 SZ-22 2,780' 2,789' 2,492' 2,499' 9' 12 Isolated 11/6/08 2,789' 2,798' 2,499' 2,506' 9' 6 Isolated 11/19/03 SZ-23 2,846' 2,852' 2,542' 2,547' 6' 4 Isolated 11/6/08 SZ Coal 2,850' 2,862' 2,554' 2,554' 12' 6 Isolated 10/14/04 A-6 3,570' 3,610' 3,103' 3,134' 60' 12 Isolated B-1 3,754' 3,778' 3,245' 3,264' 24' 12 Isolated B-2 3,790' 3,809' 3,273' 3,288' 19' 12 Isolated B-3 3,948' 4,006' 3,396' 3,442' 58' 12 Isolated D-6 5,950' 5,978' 5,140' 5,166' 28' 12 Isolated 10/19/89 D-16A 7,035' 7,042' 6,150' 6,157' 7' 12 Isolated 10/19/89 D- 16B,C 7,106' 7,134' 6,217' 6,243' 28' 12 Isolated 10/19/89 RECEIVED STATE OF ALASKA ALOIL OIL AND GAS CONSERVATION COM SIGN NOV 2 0 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations El Perforate El Other El Gravel Pack Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development El Exploratory ❑ 189 -049 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20407 -00 — 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 — Trading Bay Unit / M -13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Present Well Condition Summary: Total Depth measured 7,450 feet Plugs measured 1,800 feet true vertical 6,543 feet Junk measured N/A feet Effective Depth measured 1,800 feet Packer measured 1,375', 1,596', 1,788' feet true vertical 1,753 feet true vertical 1,364',1,572', 1,743' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 951' 20" 951' 950' Surface 1,462' 16" 1,462' 1,447' 2,630 psi 1,020 psi Intermediate 2,923' 13 -3/8" 2,923' 2,601' 3,090 psi 1,540 psi Production 504' 10 -3/4" 504' 504' 6,450 psi 4,020 psi Production 6,946' 9 -5/8" 7,450' 6,543' 6,330 psi 3,810 psi Perforation depth Measured depth See Schematic feet FEB 2 �1 ry True Vertical depth See Schematic feet SCANNED B 2 8 2013 Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# N -80 1,788' (MD) 1,743' (TVD) Model 'D' Packer 1,375' (MD) 1,364' (TVD) Model 'D' Packer 1,596' (MD) 1,572' (TVD) Packers and SSSV (type, measured and true vertical depth) Model 'D' Packer 1,788' (MD) 1,743' (TVD) Baker TE5, SCSSV 471' (MD) 471' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): (1) 1,479'- 1,484'; (2) 1,604'- 1,607'; (3) 1,727- 1,732'; (4) 1,870'- 1,875' Treatment descriptions including volumes used and final pressure: Cement Squeeze (1) 25 bbls /15.8 ppg /415 -685 psi; (2) 20 bbls /15.8 ppg /420 psi; (3) 20 bbls /15.8 ppg /325 -960 psi; (4) 20 bbls /15.9 ppg /440 -660 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 687 0 950 92 Subsequent to operation: 0 3,380 17 200 100 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas El WDSPL❑ ^ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ sUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -351 Contact Ted Kramer Email tkramer @hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature /°/' -' ' " Phone 907 777 -8420 Date 11/19/2012 r Form 10-404 Revised 10/2012 " r;'] 2 1 j ;'; J v 4 � l 7 k-2.-- Submit I 'naI Only pit,0 • Hilcorp Alaska, LLC HiIcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -13 50- 733 - 20407 -00 189 -049 9/25/2012 10/22/2012 Daily Operations:` 09/25/12- Tuesday Prep rig for skid. Skid rig south and west to get over M13. Rig up lines to circ and kill well. Pressure test to 500 psi. 09/26/12 - Wednesday Rig up wireline, test lubricator to 2,500 psi. RIH with wireline and punch 6 holes in the tbg f/ 2,087' t/ 2,089'. POOH and rig down wireline equip. Rig up to pump down tbg. Pump 9.5 brine down tbg taking gas return off 9 -5/8" [10 -3/41 annulus back to production. After pumping 190 bbls we started getting brine back to surface. Pump 18 bbls sized salt pill leave in tbg let soak into perfs. R/D circulating equip. R/U hose from trip tank to annulus and keep well full. Set BPV in tree. Move cement unit to top deck. N/D tree and move to deck. N/U BOPE. 09/27/12 - Thursday N/U BOPs. Rig up to test BOPs. Test BOPE 250 psi low / 3,000 psi high. Pull TWC valve. R/U tbg running tools. M/U TC II cross over, made up 7 -1/2 turns. P/U unseat hgr at 80k (no over pull). Unseat snap latch at 98k (16k overpull). Pull hgr to floor. L/D hgr R/U sheave for control line, repressure CL to 4,300 psi to keep SSSV open w/ POOH. Pull 2 std and CBU. POOH standing tbg in derrick. 09/28/12 Friday POOH with 3 -1/2" tbg completion string. Recovered entire string. Lay down tools and rig down tbg equip. Rig up and install wear ring. Pick up scraper BHA #1, RIH to 2,103' filling pipe. Work on #2 pump and CBU. POOH w/ bit and scraper, L/D same. P/U 9- 5/8" CIBP on E -line. RIH w/ CIBP and set with eline at 2,090'. POOH. P/U 1- 9/16" perf gun with 10 shots. RIH shoot circ perfs at 2,085' - 2,088'. Good surface indication gun fired. POOH and confirmed gun fired. Prep to run 2nd gun. M/U and RIH with 2nd 1- 9/16" perf gun and reperfed depth at 2,085' - 2,088' - gun misfired - POOH. Redress firing head, RIH reperfed same depth 2,085' - 2,088'. Good surface indication gun fired. POOH and confirmed shots fired. 09/29/12 - Saturday Waiting on a -line perf guns. Rigging up lines for cmt returns. Rigging up wireline. RIH with perf gun, fire shots f/ 2,082' t/ 2,084'. POH w/ wireline. Close blind rams and pressure up to 1,500 psi. Rig down wireline. Spot SLB unit on pipe rack, R/U to run USIT log. RIH with USIT, lightly tag CIBP at 2,090'. Log up from 2,085' to 74'. Download log and email to Anchorage engr. Discuss log and perf point for circulating. Picked perf depth at 1,820' based on cmt bond area. L/D SLB USIT log tools. Rig up to run perf gun, RIH w/ perf gun to perf 9 -5/8' csg. 09/30/12 - Sunday RIH w/ csg punch type perf gun. Perf at 1,820' t/ 1,823'. POOH w/ wireline. Close blind rams and pressure up to 1,500 psi. R/U SLB pack off to one jt DP. Arm guns, P/U guns and stab pack off. Close hydril on dp /pack off. RIH with perf gun 3' at 5 spf - log on depth with SLM -RST dated 9/27/03 with top shot at 1,870' - 1,875'. Good surface indication gun fired. POOH with gun, all shots fired. R/D SLB. Conduct injectivity test. P/U Baker BHA with K -1 Mech Set Cement Retainer. RIH w /cmt retainer to set.at 1,855'. • Hilcorp Alaska, LLC Hilcurp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -13 50- 733 - 20407 -00 189 -049 9/25/2012 10/22/2012 Daily Operations; 10/01/12 - Monday Rig up cmt equip. Perform squeeze job: Unstung from retainer with hydril closed. Pump 5 BBLS water, test lines to 1,000 and 3,000 psi. Sting into retainer, pump 20 bbis 15.9 PPG cmt, 5 BBLS water, 10.5 BBLS 9.5 brine letting back side pressure on annulus build as neededto holdback t fromperf at 1,820'. Bleed off annulus. Unsting from retainer and lay down cmt head. Pull 2 stds. Put h wipper plug in DP and circ pipe clean. Pump entire squeeze job at .5 BPM with a starting pressure of 440 psi and a final pressure 630 psi. POOH and lay down setting tool. Prep to P/U 9 4 -3/4" DC. Pick up DCs and stand them back in the derrick. WOC. M/U lubricator for perfs. R/U eline unit, m/u 3 -1/8" guns loaded 5' at 4spf. RIH and perf at 1,727' - 1,732'. Good surface indication gun fired. R/D Pollard eline. Conduct injectivity test. Clear rig floor to P/U HES cmt retainer. RIH and set fast drill squeeze packer at 1,712'. Rig up Schlumberger to squeeze, Pump 5 bbis water, test lines to 1,000 and 3,000 psi. Sting into retainer, pump 20 bbis cmt, 5 bbls water, and squeeze with 12.2 bbls 9.5 brine at .5 BPM. Cmt in place 5:45. Unsting from retainer, lay down cmt head, pull 2 std, put wipper ball in pipe, and circ. 10/02/12 - Tuesday Put wiper ball in pipe and CBU - trace of cement back. RIH with two stands that were stood back - circ / cond well. Clean underneath shakers and clean out trip tanks. POOH and stand back DP and L/D HES running tool. WOC. M/U lubricator, drain stack below annular. Redress csg punch gun. R/U eline, close hydril on lubricator. RIH with csg punch- on depth and fire gun at 1,604' - 1,607' - good surface indication guns fired. POOH and L/D gun. All shots fired. Close blinds and pressure well - 1500 psi. k Load 5' - 3 -1/8" perf gun with 4 spf. RIH with 3 -1/8" gun - on depth at 1,602' - 1,607' - good surface indication gun fired. POOH L/D perf gun. Conduct injectivity test. Finish L/D eline and lubricator. Prep floor to run BP. M/U & RIH with HES 9 -5/8" EZSV set at 1,585'. Unsting, break circ to verify tool open and sting into BP. Conduct injectivity test. Batch 20 bbl 15.8 ppg Uni -Slurry - pump 5 bbis FIW -test lines 1,000 psi low / 3,000 psi high - pump 20 bbis cmt -5 bbis FIW -9.7 bbis Brine. S/D pump hesitate 5 min -(WHP held at 420psi) -pump remaining 1 bbl for total 15.7 bbis disp leaving 1 bbl cmt in DP. Unsting from BP. L/D cmt head -pull 2 stds- load and pump wiper ball to clean DP. Appy 1/4 bbl cmt returns. Puli 2 stds. RIH with 1st 2 stds -circ clean well. Clean out from under shaker and clean trip tank. POOH with BP setting tool. 10/03/12 - Wednesday P/U & M/U csg punch gun. RIH, place gun on depth f/ 1,481' t/ 1,484', fire gun w/ no surface indication. POOH and chk tools (mis fire - pinched wire on booster). Change out booster RIH w/ csg punch & place on depth and fire gun. Punch 9 -5/8" csg interval f/ 1,481' t/ 1,484' w/ good surface indication of fire. POOH all shots fired. Close blinds and stage pressure t/ 500 & 1,000 psi w /no response on 13 -3/8" X 9 -5/8" annulus (100 psi). M/U & RIH w/ 3 -1/8" pert guns, place gun on depth and perf interval f/ 1,479' t/ 1,484', both 9 -5/8" & 13 -3/8" w/ no response on 13 -3/8 ". POOH all shots fired. PU and RIH Howco 9 -5/8" EZSV. M/U cmt head break circ at 1,460 to verify EZSV is open - set EZSV at 1,459'. PT lines to 1,000 psi low / 3,000 psi high. Mix and pump 25 bbis Uni Slurry at 15.8 ppg. Pump 5 bbis FIW -25 bbis cmt -5 bbis FIW -14.5 bbis brine -left 1 bbl on top of EZSV. (last 4 bbis of cmt away was hesitation squeezed at 5 min intervals -bbl 20 cmt at 0.5 bpm whp 415/165 -bbl 21 cmt at 0.5 bpm whp 570/195 -bbl 22 cmt at 0.5 bpm whp 600/250 -bbl 23 cmt at 0.5 bpm -whp 680/295 -bbl 24 cmt at 0.5 bpm whp at 685/300). Unsting from EZSV leaving 1 bbl cmt on top of plug. L/D cementing equip. Pull 2 stds DP and stand back. Circ. / cond. well - trace of cmt returns at shakers. Puli 2 stds DP and stand back. RIH with 1 st 2 stands DP pulled to flush cmt out of the DP - circ /cond well. Prep for weekly BOPE test, AOGCC Jim Regg notified 10/03/12. POOH with EZSV setting tool and L/D same. R/U to test BOPE's. • • Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -13 50- 733 - 20407 -00 189 -049 9/25/2012 10/22/2012 Daily Operations: 1,010,4112 - Thursday Test on riser to wellhead B PE s 250 psi low / 3 000 psi high. Jeff Jones, AOGCC, waived witness. Had two failures #1 0 est O p p g ed it mar - kill line valve. R/D test equipment & install wear ring. P/U BHA #3 and RIH on 4" HWDP. Tag TOC at 1,444'. Drill thru cement and work on EZSV at 1,459'. Current depth at report 1,461'. 10/05/12 - Friday Drill hard cmt f/ 1,461' t/ 1,531'. No cmt f/ 1,531' t/ 2nd retainer @ 1,582'. Test csg t/ 1,000 psi. Drill 2nd retainer f/ 1,582' t/ 1,588'. Drill hard cement f/ 1,588' to 1,655'. 10/06/12 - Saturday Continue drill hard cmt t/ 1,653'. POOH t/ 1,023', rack back HWDP & collars. P/U BHA #4 and RIH t/ 1,591' wash down t/ 1,653'. Drill hard cmt f/ 1,653' t/ 1,675'. Fell thru t/ 1,692' cmt stringers t/ 1,706'. Drill cmt, junk f/ 1,706' - 1,708'. Drill 3rd retainer f/ 1,708' to 1,712'. Drill weak cement 1,712' - 1,800'. Drill weak cement 1,800' - top of retainer at 1,855'. Stand back collars and clean out boot baskets. M/U casing scraper BHA. RIH to 1,855'. POOH with casing scraper. L/D casing scraper and boot baskets. 10/07/12 - Sunday R/U a -line. RIH w/ 3 -1/8" 10' gun Dn loaded t/ 4' w/ SDP 6 spf (25 shots) @ 60 deg phased. Place gun on depth & perf 9 -5/8" & 13- 3/8" interval f/ 1,846.5' t/ 1,850.5'. POOH (all shots fired). R/D wire line. P/U BHA #6 (9 -5/8" EZSV & running tool), RIH and set EZSV @ 1,706' t/ 1,709'. Break circ & test csg above EZSV t/ 1,008'. R/U Cmt head & lines. Mix & pump 27.3 bbls Uni slurry @ 15.8 ppg, displaced w/ 5 bbls FIW, 5 bbls 9.5 ppg filtered brine, hesitated last 4 bbl (wait 5 min & 10 min) cut displacement short 4 4) bbls unsting & lay 4 bbls on top CIP @ 14:45 hrs. POOH one std, brk dn cmt head & lines. Circ & Pump 4" nerf ball w/ trace cmt @ shakers. POOH and L/D setting tool and stinger. Wait on cement. M/U BHA #7 (Bit, boot baskets, drill collars) and RIH to 1,620'. Encounter soft/medium cement @ 1,684'. Drill cement 1,684' - 1,695'. 10/08/12 - Monday Drill Firm /hard Cmt f/ 1,695' t/ 1,708'. Drill retainer f/ 1,708' t/ 1,711'. Drill hard cmt f/ 1,711' t/ 1,800'. POOH with drilling assembly. M/U casing scraper assembly. RIH to TOC @ 1,800'. POOH with scraper assembly. 10/09/12 - Tuesday Continue POOH w/ scraper assy. R/U E -line. RIH w/ 3 -3/8" 6' gun dn loaded to 5' w/ SDP 6 spf w/ 31 shots @ 90 deg phased. Place gun on depth & re-perf interval f/ 1,727' t/ 1,732' wim. POOH (all shots fired). R/D E -line & Rebuild EZSV running tool & M/U 9• 5/8" EZSV. RIH w/ EZSV & set @ 1,700' & extend stinger. Unsting. POOH and inspect stinger and setting tool. M/U drilling BHA. RIH to top of EZ Drill @ 1,702'. Drill EZ Drill 1,702' - 1,705'. Push EZ Drill to top of cement @ 1,796'. POOH with drilling assembly. P/U EZ Drill and RIH with same. • • Hilcorp Alaska, LLC Hilcorp Alaska, LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -13 50- 733 - 20407 -00 189 -049 9/25/2012 10/22/2012 Daily Operations: 10/10/12 - Wednesday Continue RIH w/ Howco 9 -5/8" EZSVB t/ 1,695'. R/U head pin & cmt lines. Break circ thru retainer. Close rams & confirm injectivy. Set retainer f/ 1,695' t/ 1,698'. Extend stinger & test csg & EZSV f/ 1,050' t/ 1,026' psi in 10 min. Stab retainer & preform injectivity test. Batch up cement, mix & pump 39.5 bbls Uni slurry at 15.8 ppg. Displaced w/ 2 bbls 11.3 ppg cmt + 10.8 bbls of FIW & dumping last 5 bbls on top (3 bbls 15.8ppg & 2 bbls 11.3 ppg) @ 3.4 bpm @ 1,189 psi @ 30 bbls away & 10 bbl in formation. Hesitated as follows #1 shut dn for 32 min WHP to 53 psi & suck 3/4 bbl out of mix tub. Pump 4 bbls cement @ .5 bpm @ 319 psi. #2 shut dn 30 min (Mix tub MT) WHP to 90 psi. Batch up 5 bbls Pump @ .6 bpm, @ 400 psi. #3 shut dn 49 min (mix tub Mt) WHP to 29 psi. Out of cmt, go to displacement Pump 2 bbls cmt @ 11.3 ppg & 3 bbls FIW @ .5 bpm 590 psi. #4 shut dn 45 min WHP to 37 psi. Pump 5 bbls FIW @ .5 bpm @ 949 psi. #5 shut dn 45 min Pump 2.8 bbls FIW @ .5 bpm @ 1280 psi. Shut dn & un -sting Dump 3 bbls 15.8 & 2 bbls 11.3 PPG cmt on top EZSV. CIP @ 1505 hrs. Pooh 2 std. Load nerf ball. Circ clean w/ trace cmt back. I'I POOH and lay down setting tool /stinger. Pull wear bushing. Set 4" test joint and fill stack. Test BOPE 250 psi Low / 3,000 psi High. • ,) Repair manual kill line valve. Change out test joint to 3 1/2 ". Test bottom pipe rams, blind rams and annular 250 psi Low / 3,000 psi High. AOGCC inspector, Jeff Jones, witnessed test. Set wear bushing. R/D test joint. P/U drilling BHA. 10/11/12 - Thursday P/U BHA # 12 (drilling assy) RIH t/ 1,591'. Kelly up wash dn f/ 1,591' t/ tag @ 1,665'. Drill soft/firm cmt f/ 1,665' t/ 1,681'. Drill firm /hard cmt f/ 1,681' t/ retainer @ 1,697'. Drill retainer f/ 1,697' t/ 1,700'. Drill hard cmt f/ 1,700' t/ 1,798'. Circulate hole clean. Test csg t/ 1,050 psi. POOH with drilling assembly. Clean out boot baskets. M/U casing scraper BHA. RIH and tag @ 1,798'. Circulate G hole clean while reciprocating pipe @ 8 BPM /290 psi. Displace well bore with filtered 9.5 ppg 6% KCL. Flush lines, clean trip tanks, . shakers and degasser pit. 44 10/12/12 - Friday Continue flush lines. Clean trip tanks, shakers & degasser pit. Drop 2.5" rabbit & POOH. L/D BHA and clean junk bsk's. P/U Howco 9 -5/8" RTTS & bypass, RIH t/ 1,740'. Test #1 set RTTS center of rubber @ 1,740'. Test #2 set RTTS center of rubber @ 1,745'. Test #3 set RTTS @ 1,720' test for 30 min @ 1,148 psi. Good test. Test #4 same set depth. Test #5 set RTTS center of rubber @ 1,785'. POOH L/D RTTS. R/U E -line. Run #1 8.33 GR to 1,798'. RIH #2 sump packer, correlate on depth and set top of packer @ 1,788'. R/D E -line. M/U safety joint and bar drop assembly. R/U circulating and return hoses, manifolds and reversing lines. P/U perf gun assembly. RIH with 7.00 HSD 12 SPF 58C perf guns. M/U bar drop assembly to top drive. Prepare to test lines. • • Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -13 50- 733 - 20407 -00 189 -049 9/25/2012 10/22/2012 10/13/12 - Saturday Snap in and out of sump packer and lace guns on depth w/ btm shot 1,781'. R/U drop bar assy and test lines t/ 836 -3025 psi. P 9 p @ ' p Y Blow dn all lines. Drop bar and fire guns. Perf interval SZ -13 f/ 1,773'- 1,781', 1,759'- 1,767', 1,737' - 1,749' w/ 7" guns loaded w/ HSD 12SPF 58C ultra pack. Reverse 2X dp volume thru choke to remove shot gas. Open well move guns, monitor well on trip tank for 30 min. Break out drop bar assy. Well flowing out of dp. Reverse circ 2X dp volume. Monitor well, finish break dn drop bar assy. POOH. L/D and check BHA. L/D and check guns (all shots fired as planned). Load floor w/ tri -point gravel pack handling equipment & P/U 2 -7/8" stinger. RIH and tag sump packer @ 1,798'. R/U hoses for gravel pack. Test lines to 3,000 psi. Perform pre -pack job @ 3 BPM. Pumped 3,300 Ibs of sand for sand -out @ 1050 psi. RIH tagged fill @ 1,7.29'. Reverse sand out while washing down into t'` sump packer @ 1,798'. Reversed out 2,550 Ibs of sand 3 BPM /70 psi for 26.8 PPF in perforations. (750 lbs to formation). POOH with stinger. Prepare to pick up gravel pack assembly. R/U false rotary table and safety joint. P/U Stage 1 gravel pack assembly. 10/14/12 - Sunday Continue P/U stage #1 gravel pack assembly. RIH w/ stage #1 gravel pack assembly on dp. Snap in out of sump packer & set JS -3 GP Packer @ 1,597'. R/up lines. Preform Gravel pack @ 3 bpm. Pumped 2,450# of 20 -40 econo -pack gravel pack sand for sand out @ 1,250 psi w/ 1,400# to cover screens additional 350# 12.5 ppf to perfs. W/ 700# to blank 29' covered. Open by -pass. Reverse out 2x DP volume. Restress twice @ 1,250 psi. Un -seat GP packer & release from hook up nipple. POOH 2 std (wash pipe above screens). Monitor static well on trip tank. POOH. Lay down packer and 5 joints of 2 -7/8' tubing. P/U packer assembly and RIH @ 4 - 5 minutes per stand. Locate top of stub @ 1,623'. Swallow over to 1,627' and P/U 1'. 80K P/U & S /O. Drop ball and set packer @ 1,596'. Pressured up to 2,600 psi. POOH and lay down setting tool. R/U slick line and lubricator. RIH with 2.76 GR. Not able to get past packer top @ 1,596'. Attempt several times. Discuss options. RIH with PX plug and set in nipple @ 1,611'. RIH with prong and set in PX plug. 10/15/12 - Monday Set PX prong in PX plug @ 1,610' RKB wlm w/ top prong @ 1,607'. POOH & R/D same. Presure test packer & plug t/ 1,032 psi w/ 22 psi loss in 5 min . P/U 7" HSD 12spf 58C perf guns assembly #2. RIH w /gun assembly #2 on DP. Tag & install protection plug in top of isolation packer @ 1,596'. R/U drop bar assy & lines. Drop bar fire guns / perf interval SZ -11 f/ 1,497' - 1,578' w/ 7" guns loaded w/ 12spf 58C ultra pack. Reverse out 44 bbls thru choke to remove shot gas. Open well. Move guns, monitor well on trip tank. POOH and lay down perf guns. All shots except one scallop fired. Close blind rams and conduct injectivity test. M/U 2 -7/8" stinger for pre -pack. RIH with stinger to top of fill /packer @ 1,597'. Pull back up to above perfs @ 1,432'. R/U circulating joint. Test lines @ 3000 psi. Establish circulation and injection rates. Perform pre -pack. • Hilcorp Alaska, LLC Hikorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -13 50- 733 - 20407 -00 189 -049 9/25/2012 10/22/2012 Daily Operations. 7 10/16/12 - Tuesday Perform pre pack job 3 bbl/ min, pumped 6,959# of sand for a sand out at 1,060 PSI. RIH and tag fill at 1,475'. Reverse out sand while washing down to top of perfs at 1,497'. Reversed out 5,096 # of sand at 3 bbl /min at 100 PSI for 1,853 # or 22.88 PPF of sand into perforations. Pull off bottom 45', monitor well, 11.4 bbl for 30 minutes. RIH and tag at 1,596'. Reverse out 1.5 volumes, no sand in returns. Lay down pump -in circulating assembly and blow down lines. POOH and lay down mule shoe assembly. Pick up overshot assembly and RIH to 1,586'. Rig up pump in assembly and hoses. Tag fill at 1,589'. Rev circ down to 1,594' and circ DP clean at 3 BPM. Shut in and rev circ while washing down on top of plug latch assembly. Shut pump down, set down 35K over latch, and pull 25K over to release plug. Monitor well (3.4 BPH) while rigging down circulating joint. Blow down top drive. POOH and lay down overshot and plug. Prepare to run gravel pack screens. R/U false rotary table. P/U gravel pack screens, blanks and 2 -7/8" inner string. RIH to 1,590'. M/U circulating joint. Locate and set packer @ 1,355'. Test backside @ 500 psi. Test lines @ 3,000 psi. Establish circulating and injection rates. Perform stage 2 gravel pack job. 10/17/12 - Wednesday Established injection rates: 1 BPM =100 PSI, 2 BPM =400 PSI, 3 BPM =430 PSI. Establish circ rates: 1 BPM =75 PSI, 2 BPM =200 PSI, 3 BPM =430 PSI. Start gravel pack. Pumped 3600 # of sand. Sandout at 1.1 BPM at 1150 PSI. Restressed the gravel pack twice to 1150 PSI. Pressured up on the backside to 300 PSI and open the packer by -pass. Reverse out 2 DP volumes. Didn't see any sand back on returns. Shut down and unseat the pkr. [2350# of sand at screens, 1250# of sand at blanks w/51' of blank pipe coverage] Release from the hook up nipple. Rig down circ head and pull 2 stds. Monitor well. 5 BPH static loss. POOH and lay down Pkr and concentric string. Pick up production packer assembly. Monitor well 2.5 BPH static loss. RIH with production packer assembly. Set down over seals at 1,385' to ensure talley. Pick back up to connection and drop ball. Make connection back up and slack back off over seals at 1,385', Pressure up down DP, 1 st set of shear pins sheared at 1000 psi. Continued to pressure up to 2500 Psi. Pull 30K over pull to set and release from packer. Blow down top drive. POOH and lay down packer setting tool. Pull wear bushing. RIH with stand of DP and wash out tubing hanger profile. Pick up inner string and completion assembly and RIH. Had to rotate string 1/2 turn to get into packer top @ 1,375' with inner string. M/U SCSSV and control line. Test same @ 4,500 psi. Continue in hole to 1,377'. Space out completion string. Observed seals engaging. M/U tubing hanger (BPV installed) and control line. Drain stack. Land tubing @ 1,377'. P/U 75K, S/O 75K (including top drive @ 64K). Run in lock down screws. B/O landing joint and stand back in derrick. Clear rig floor. Nipple down BOPE. 10/18/12 - Thursday Nipple Down BOPs. Nipple up tree and flow lines. Test flange and seal to 5,000 Psi. Rig up line to annular for gas lift. Test annular to 500 Psi. Install actuator on tree. Pull BPV and install TWC. Test tree to 5,000 Psi. Rig up lubricator. Change out DSA on 16 -3/4" riser. Test lubricator @ 250 psi low / 2,000 psi high. Slick line work: Run #1 shear up tool. Not able to get on depth due to fill. Bail sand /metal debris 1,600' - 1,606' (2" pump bailer /10'stroke). 10 bailing runs @ report time. Run #11 shear up tool. Flanging up 4- 1/16" riser on drill deck. Coil unit is spotted. Hilcorp Alaska, LLC Hilcorp Alaska. LLC Well operations Summary Well Name API Number Well Permit Number Start Date End Date M -13 50- 733 - 20407 -00 189 -049 9/25/2012 10/22/2012 Daily Operations: 10/19/12 - Friday Running slick line: POOH with prong pulling shear up tool 1,606'. Run # 12 bailer to 1,608'. Run # 13 bailer to 1,608'. Keep running 2" bailer runs. Still getting good recovery every run but not gaining very much footage. Made 17 runs and only made 1/2'. Make two runs with a magnet, 19 runs total. Run shear down tool for pulling prong, failed to latch onto prong. 20 runs total. Have BJ testing there BOPs on a stump on the deck to save time on the rig up. Test waived by James Regg. Run 2 -1/4" flapper bailer run #21. Change tool and run 2" long tapper flapper bailer on run #22. No recovery but there was a mark in the tool that could have been made by the prong. Run back in with 2 -1/4" flapper bailer #23, No recovery but good, indication of top of prong on inside bevel. RIH and attempt to pull prong, couldn't get latched on. POOH and pickup impression block, Couldn't see any marks from the top of the prong. 25 runs. RIH #26 w/ Pump Bailer recovered '-1/2 cup metal pieces. RIH #27 w /PB recovered —1/2 cup metal pieces. RIH #28 w /PB recovered —4 cups metal pieces. RIH #29 w /PB recovered —3 cups metal pieces. RIH #30 w /PB recovered —1/2 cup sand. RIH #31 w /PB recovered —1/2 cup sand. RIH #32 w/ pulling tool - POOH w /prong. RIH #33 w /PB recovered — 3 cups sand. RIH #34 w /PB recovered — 1 cup sand. MU / RIH #35 w/ 2 -1/4" Hydrostatic Bailer recovered slight amt of sand - no change in well head psi. RIH #36 w/ Hyd Bailer recovered —1 cup muddy sand - no change in well head psi. RIH # 37 w/ Hyd Bailer. 10/20/12 - Saturday Finish bailer run #37. Got down to 1,617'. POOH. Minimal recovery. Change tool and run plug retrieving tool, Run #38. POOH with plug. Make up kick over tool and RIH for Dummy in GLM. Tag up on GLM at 1,275'. POOH, No dummy plug. Run #39, Modify tool and RIH to retrieve the dummy tool, POH with Dummy plug. Run # 40, Change tool and RIH gas lift valve. Set valve in GLM, Run #41. Rig down slick line. Production started gas lifting well. Move Rig BOP stack off to drillers side. Rig up Coil tubing unit. CTU rigged up - PT surface equip - 4,500 psi. Meet with production regarding N2 lift procedures, roles responsibilities, communication, monitoring flow back rate /volumes. Install fusible cap on SSV, RIH w/ 2 -1/8" jet nozzle pumping min rate —300 scfm. Tag at 1,790' P/U to 1,788' start increasing N2 rate to 650 scfm. 10/21/12 - Sunday Pumping N2 with coil at 1,788' approx. 1 BBL brine back. POOH to 1,338' but still not getting any fluid returns. RIH to 1,788' and started pumping N2 again holding 200 psi on production gauge. Still not getting hardly any fluid returns after pumping 150,000 scf and 2 BBLS back. Shut down Pumping N2. POOH and shut master valve on tree. Bleed press off lubricator, break off injector head and stand it back on the drillers side. Production put well back on gas lift. R/U slick line. Tested lubricator to 2,000 Psi. Shut down gas lift, bleed well down. Open swab, RIH with PX plug. Couldn't get past 1,580'. POOH and run 2.80 GR. It wouldn't go through the SSSV at 470'. POOH and run 2.75 GR. GR made it down through x- nipple at 1,615'. RIH with PX plug and set it in the X. nipple. POOH. Pick up prong and RIH. Set on Plug in X- nipple. POOH and rig down slick line. Put well back on gas lift. RU / CTU, RIH and pump 68k N2 to lift well - production reports no fluid to surface. POOH w /coil tbg- Turn well over to production. POOH and RD CTU. 10/22/12 - Monday RD Coil Tubing Equip. Rig released from M -13 at noon. . • • Trading Bay Unit SCHEMATIC Well No.: M -13 Hilcorp Alaska, LLC Completion 10/25/1989 CASING DETAIL v RKB to Tbg Hanger = 73.4' Size Type WT Grade ID Top BTM 20" Conductor 94 X -56 19 Surf 951' �� -G' 10 -3/4" +. 4' 16" Intermediate 75 K55 15.124 Surf 1,462' < • t . , le i 13 - %" Surf Csg 61 K -55 12.515 Surf 2,923' IMMO r* . ▪ ; M 2 10- 3/4" Prod Csg 55.5 N -80 9.76 Surf 504' ` 9 5/8" Prod Csg 43.5 N80 8.755 504' 2,010' MB Mai '''.1.* 4 9 -5/8 Prod Csg 47 N80 8.681 2,010' 7,450' 16'`:x' 4 TUBING DETAIL 31/2" 9.3 N -80 2.992 Surf 1,788' ; :fit 5 ti - SZ -1 1 JEWELRY DETAIL T- 6 j11Z1 , 1? No Depth ID Description ' i 1 469' 2.992 BX Nipple 7 '.NL' "+; 2 471' 2.82 SCSSV, Baker TE5 8 _� ,' ",. 3 1,267' 2.992 Gas lift mandrel 1. 4 1,375' 6 9 -5/8" 47# Model 'D' Isolation Packer 9 't " 5 1,483' 4.892 Top of 5 -1/2" .012 304SS Screen (109' overall) +-; 6 1,578' 2.813 3 -1/2" CS Hydril Benoit5 Sliding Sieve w/ 2.813 X nipple 1 0 "- ' - j: 7 1,596' 6 9 -5/8" 47# Model 'D' Isolation Packer ''- ^SZ -13 8 1,612' 2.813 3 -1/2" 8rd x 2.813 "X" Nipple 9 1,625' 4 Overshot is 4.71' over the Hook -up Nipple 11 �ami-• � TOC 10 1,723' 4.982 Top of 5 -1/2" .012 30455 Screen (64' overall) 12 - 1,800' 11 1,788' 4.75 9 -5/8" 47# Model 'D' Sump Packer 13 &14 12 2,090' CIBP inp 13 2,099' 3.25" S -22B Snap Latch Seal Assembly 15,16 14 2,103' 4.75" SC -1 GP Packer &17 SZ -17 15 2,109' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV 16 2,135' 4.00" 4 1/2 ", 11.6 #, H -503, L-80 Blank Pipe 18 &19 17 2,189' 3.548" Excluder Screen 4" SLHT (74.6') • iii mow 1 1 20 - SZ - 19 18 2,255' 3.25" S -22B Snap Latch Seal Assembly . SZ -20 19 2,256' 4.75" SC -1 GP Packer 21 5z -21 20 2,262' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV mismigi [ SZ - 22 21 2,288' 4.00" 4 1/2 ", 9.54, H -503, L -80 Blank Pipe 22 {' SZ - 23 22 2,423' 3.548" Excluder Screen 4" SLHT (447.6') 13 -3/8" " - $:. 23 2,872' 4.75" Baker Model D Sump Packer 23 PERFORATION DETAIL T• Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Status Date �`„, SZ -11 1,497' 1,578' 1,480' 1,555' 81' 12 Open 10/16/2012 IC A6 1,737' 1,749' 1,698' 1,709' 12' 12 Open 10/14/2012 SZ -13 1,759' 1,767' 1,717' 1,724' 8' 12 Open 10/14/2012 B - 1,2 & 3 1,773' 1,781' 1,730' 1,737' 8' 12 Open 10/14/2012 D6 Isolated perforations are listed on the next page. p...- D16A D16B & C 9 . TD = 7,450'(MD) PBTD = 3,000'(MD) Max Hole Angle =44.8° @ 2,400'(MD) REVISED by TDF: 11/16/12 • Trading Bay Unit .. iu SCHEMATIC Well No.: M -13 Hi lcorp Alaska, LLC Completion 10/25/1989 Isolated- Perforation Data Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Status Date SZ -17 2,190' 2,234' 2,065' 2,097' 44' 12 Isolated 11/8/08 2,461' 2,470' 2,259' 2,265' 9' 12 Isolated 11/6/08 SZ -19 2,470' 2,479' 2,265' 2,272' 9' 6 Isolated 10/15/04 2,492' 2,497' 2,281' 2,285' 5' 12 Isolated 11/6/08 Stray 2,518' 2,522' 2,300' 2,303' 4' 12 Isolated 11/6/08 2,538' 2,550' 2,314' 2,323' 12' 6 Isolated 11/2/03 2,538' 2,550' 2,314' 2,323' 12' 12 Isolated 11/6/08 SZ -20 2,569' 2,583' 2,336' 2,347' 14' 12 Isolated 11/6/08 2,576' 2,590' 2,341' 2,352' 14' 6 Isolated 10/15/04 2,598' 2,602' 2,357' 2,360' 4' 12 Isolated 11/6/08 2,641' 2,653' 2,389' 2,398' 12' 12 Isolated 11/6/08 2,650' 2,662' 2,395' 2,404' 12' 6 Isolated 10/15/04 SZ -21 2,690' 2,712' 2,425' 2,441' 22' 12 Isolated 11/6/08 2,698' 2,718' 2,431' 2,446' 20' 6 Isolated 10/15/04 2,719' 2,734' 2,446' 2,458' 15' 12 Isolated 11/6/08 2,733' 2,742' 2,457' 2,464' 9' 6 Isolated 10/14/04 SZ 22 2,780' 2,789' 2,492' 2,499' 9' 12 Isolated 11/6/08 2,789' 2,798' 2,499' 2,506' 9' 6 Isolated 11/19/03 SZ -23 2,846' 2,852' 2,542' 2,547' 6' 4 Isolated 11/6/08 SZ 2,850' 2,862' 2,554' 2,554' 12' 6 Isolated 10/14/04 Coal A -6 3,570' 3,610' 3,103' 3,134' 60' 12 Isolated B -1 3,754' 3,778' 3,245' 3,264' 24' 12 Isolated 8 -2 3,790' 3,809' 3,273' 3,288' 19' 12 Isolated 13-3 3,948' 4,006' 3,396' 3,442' 58' 12 Isolated D -6 5,950' 5,978' 5,140' 5,166' 28' 12 Isolated 10/19/89 D -16A 7,035' 7,042' 6,150' 6,157' 7' 12 Isolated 10/19/89 D- 7,106' 7,134' 6,217' 6,243' 28' 12 Isolated 10/19/89 16B,C REVISED by TDF: 11/16/12 7- A KifE OF ALR\SE / SEAN PARNELL, GOVERNOR ALASKA OIL AND G,I .S 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Re: McArthur River Field, Middle Kenai Gas Pool, Trading Bay Unit M -13 . Sundry Number: 312 -351 Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy F Foerster Chair, Commissioner DATED this : day of September, 2012. Encl. • g RECEIVED �r13 , SEP 1 1 20 ;/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ plug Perforations ,j Sp.- Perforate 13 ' Pull Tubing ❑ Tjfne E ens' n 0 Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: („_fir -" c ict.c WI 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development p • Exploratory ❑ 189-049 - 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 20407 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership c'langes: Spacing Exception Required? Yes ❑ No 0 Trading Bay Unit / M -13 ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0017594 McArthur River Field / Middle Kenai Gas Pool ✓ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,450 ' 6,543 . 3,000 2,660 3,000 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 951' 20" 951' 950' Surface 1,462' 16" 1,462' 1,446' 2,630 psi 1,020 psi Intermediate 2,923' 13 -3/8" 2,923' 2,601' 3,090 psi 1,540 psi Production 504' 10 -3/4" 504' 503' 6,450 psi 4,020 psi Production 6,946' 9 -5/8" 7,450' 6,543' 6,330 psi 3,810 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3 -1/2" 9.3# N -80 2,093' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): SC - 1 GP Packer, SC - 1 GP Packer, Baker Model D Packer / BOT TE - 5 SCSSV Packers 2,103'MD/1,999'TVD; 2,256'MD/2,112'TVD; 2,872'MD/2,562'TVD / SSSV 444'MD/443'TVD 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development El ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/15/2012 Oil ❑ Gas 0 . WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Printed Name Ted Kramer / Title Sr. Operations Engineer Signature _ 1 ‘ <" Phone 907 - 777 -8420 Date 9/11/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 34,7 — 3.5 1 Plug Integrity ❑ BOP Test �' ' Mechanical Integrity Test ❑ Location Clearance ❑ Other: BU p r to 331)00 p5 1 Subsequent Form Required: O RIGINAL l0 40 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 4/1 -/ 3 - / Z. F SEP 14q � ° ".-W� `-75? V' Form 10-403 Revised 1/2010 7 Submit in Duplicate \ • • Well Work Plan Well: M -13 nllror' Alaska, I.I.c Date: 09/07/2012 Well Name: M -13 API Number: 50- 733 - 20407 -00 Current Status: Gas Producer Leg: Leg Al, SW Corner Slot #1 Estimated Start Date: October 15, 2012 Rig: Steelhead Rig 51 Reg. Approval Req'd? October 1, 2012 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 189 -049 First CaII Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Melissa Eisele (907) 777 -83119 (0) AFE Number: 1222741 Current Bottom Hole Pressure: 273 psi @ 2,4300' TVD (Calculated from shut in and build up) Maximum Expected BHP: 720 PSI @ 1,578' TVD Max. Anticipated Surface Pressure: 563 psi (Using 0.1 psi /ft to surface) Well Summary M -13 was completed in its current configuration as a gas producer in November of 2008. The completion plan for this well was to perforate the well in 6 zones (See Current Perforations), install sand screens across the perforated interval and pump a two stage gravel pack to reduce the risk of sand production. This completion was executed as planned with the top zone SZ 17 being isolated from the rest between two isolation packers in case it began to make water. This well produced water from the start and reached 85 BWPD when in June of 2011 the SZ -17 perfs were squeezed eliminating water production. The well has produced water free up until now. Forward Plan: The workover plan for this well is to pull out of the top packer and isolate the current completion with a cement squeeze. Perforate the SZ -11 and the SZ -13 intervals, pump a two stage gravel pack, and return the well to production. Procedure: 1. MIRU Steelhead Rig # 51. 2. ND wellhead and NU BOP stack. Pressure test BOP to 250 psi. low / 3,000 psi high. Note: notify AOGCC 48 hours in advance of test for the opportunity to witness bop test. 3. Kill well with Kill fluid 6% KCL. 4. Pill Tubing out of well disengaging from the snap latch at 2,099'. 5. RU E -line. RIH with CIBP and set at 2,090'. 6. PU Perf guns and RIH to 2,089 ft and perforate from 2,089' to 2,079 ft. POOH with perf gun. i • Well Work Plan Well: M -13 I Iilrnr , Alaska, LLC Date: 09/07/2012 7. PU CMT retainer and run in hole on 4" workover string and set at 2,070 ft. 8. Pump Cement squeeze as directed in cement squeeze procedure. Sting out of cement retainer and place 50' of cement on top of the retainer. WOC. 9. Pressure test casing to 1,000 psi. 10. RU Schlumberger and Tripoint, begin perforation and Gravel Pack stages as indicated in the perforation / gravel pack procedure and the perf chart below: Stage / Zone Top Bottom 1 / SZ11 1,497' 1,578' 2/ SZ13 1,737' 1,749' 1,759' 1,767' 1,773' 1,781' Total 109' 11. RD Schlumberger and Tripoint. 12. ND BOP NU Well head. 13. RU Coil Tubing. Jet in well with Nitrogen. 14. RD Coil tubing. 15. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics II • • Trading Bay Unit PROPOSED Well No.: M -13 11ilcorl, Alaskn, l.IA' Completion 10/25/1989 Casing Detail RKB to Tbg Hanger = 73.4' I Size Type WT Grade ID To BTM J 20" Conductor 94 X -56 19 Surf 951' 10 - 3/4" . ' .. L 16" Intermediate 75 K55 15.124 Surf 1,462' 20" di 13 -Y." Surf Csg 61 K -55 12.515 Surf 2,923' , I 0 }-• 1 10 -3/4" Prod Csg 55.5 N -80 9.76 Surf 504' CH1:1 ' ' 9 5/8" Prod Csg 43.5 N80 8.755 504' 2,010' 9 -5/8 Prod Csg 47 N80 8.681 2,010' 7,450' ' " ECP 2,874' 2,890 c' ubing Detail sz•11 3 -1/2" 9.3 N -80 2.992 Surf 2,093' 16" " , Jewelry = = SZ -13 No Depth ID Description 1 444' 2.813" BOT TE -5 SCSSV . O 2 2 2,051' 2.992 Gas lift mandrel ' ' ' ,/ ;, 2a 1,392 6.00" Tripoint Gravel Pack packer assembly (3 packers plus two Screens) 2b e2,090' CIBP , 3 & 4 3 2,099' 3,25" 5 -22B Snap Latch Seal Assembly = 4 2,103' 4.75" SC -1 GP Packer S •17 5 2,109' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV • 5, 6 2,135' 4.00" 41/2 ",11.64,14- 503,L -80 Blank Pipe • 8 &9 & 7 7 2,189' 3.548" Excluder Screen 4" SLHT (74.6') 8 2,255' 3.25" S -220 Snap Latch Seal Assembly 10 ,.' =- 9 2,256' 4.75" SC -1 GP Packer 4 p - 10 2,262' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV f : a s0, ',,,; � SZ -19 11 2,288' 4.00" 41/2 ", 9.58,H-503,1.-80 Blank Pipe - SZ -20 12 2,423' 3.548" Excluder Screen 4" SLHT (447.6') 11 ` ' MINOMM. �. ,,, • - SZ -21 13 2,872' 4.75" Baker Model D Sump Packer . : ,1 -iL~ 57 -22 '."•" (. SZ -23 12 7 it'.'''. - 13 - 3/8" 13 New Perforations will be: SZ -11 /.,''.' '.,•.'. ,' ;•;.,' , ;: 1 1,497 - 1,578' 81' i ___ SZ -13 A6 �` 00-=.7.011 1,737 - 1,749' 12' - B-1,2 & 3 1,759 - 1,767' 8' 1,773 -1,781 8' il. Top Packer - 1392' Middle Pkr.- 1,588' D6 Bottom Pkr. - 1,791' Ids 016A D16B &C 9 -5 /8'A ',, , . j : , 1;4" TD = 7,450'(MD) PBTD = 3,000'(MD) Max Hole Angle =44.8° @ 2,400'(MD) REVISED by TDF: 9/11/12 • • Trading Bay Unit PROPOSED Well No.: M -13 Ilitcorp Alaska, IAA: Completion 10/25/1989 Isolated - Perforation Data Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Status Date ±2,089' ±2,079 11,996' ±1,981' 10' 21 Future 52 -17 2,190' 2,234' 2,065' 2,097' 44' 12 Shut Off 11/8/08 2,461' 2,470' 2,259' 2,265' 9' 12 Open 11/6/08 SZ -19 2,470' 2,479' 2,265' 2,272' 9' 6 Open 10/15/04 2,492' 2,497' 2,281' 2,285' 5' 12 Open 11/6/08 Stray 2,518' 2,522' 2,300' 2,303' 4' 12 Open 11/6/08 2,538' 2,550' 2,314' 2,323' 12' 6 Open 11/2/03 2,538' 2,550' 2,314' 2,323' 12' 12 Open 11/6/08 SZ -20 2,569' 2,583' 2,336' 2,347' 14' 12 Open 11/6/08 2,576' 2,590' 2,341' 2,352' 14' 6 Open 10/15/04 2,598' 2,602' 2,357' 2,360' 4' 12 Open 11/6/08 2,641' 2,653' 2,389' 2,398' 12' 12 Open 1116/08 2,650' 2,662' 2,395' 2,404' 12' 6 Open 10/15/04 SZ -21 2,690' 2,712' 2,425' 2,441' 22' 12 Open 11/6/08 2,698' 2,718' 2,431' 2,446' 20' 6 Open 10/15/04 2,719' 2,734' 2,446' 2,458' 15' 12 Open 11/6/08 2,733' 2,742' 2,457' 2,464' 9' 6 Open 10/14/04 SZ -22 2,780' 2,789' 2,492' 2,499' 9' 12 Open 11/6/08 2,789' 2,798' 2,499' 2,506' 9' 6 Open 11/19/03 SZ -23 2,846' 2,852' 2,542' 2,547' 6' 4 Open 11/6/08 SZ 2,850' 2,862' 2,554' 2,554' 12' 6 Open 10/14/04 Coal A•6 3,570' 3,610' 3,103' 3,134' 60' 12 Iso. 8 -1 3,754' 3,778' 3,245' 3,264' 24' 12 Iso. 8 -2 3,790' 3,809' 3,273' 3,288' 19' 12 Iso. 8 -3 3,948' 4,006' 3,396' 3,442' 58' 12 Iso. 0-6 5,950' 5,978' 5,140' 5,166' 28' 12 Iso. 10/19/89 0 -16A 7,035' 7,042' 6,150' 6,157' 7' 12 Iso. 10/19/89 D- 7,106' 7,134' 6,217' 6,243' 28' 12 Iso. 10/19/89 16B,C _ I REVISED by TDF: 9/11/12 II • • Steelhead Platform 16'/4 5M BOP (Oil Leg) M -13 Iliknrp %Iasi*.l.lA: 3/16/2012 999oor 9otlae 000 193a I I 674 22" pipe for air boot flanges 9.43' 2623 £ Moon mot deal to to 5 y, f No I tl�ll� rl If r. 5.10' • Hydril • *, I 5.46' 1614 - 5000 _ Meenpo3aeIXtap to � � . weeder room tmra.94 fit Iii lit fir fit Top GI Ar deck 9W " " ' 11 1011 { II . di 0 3.00' 3.58' DSA16 %10MX16 %5M .66' las flange above N VE VWng Riser, 16 ''A 5M API hub X 16 3/4 10M FE Upper NMeed Moon to Mg Sub 2 5.34 mm9e .9B9ler Upper wetead room floor Riser, 16%5M FE X 16% SM API hub wmwemer to UGGer Mlle. frf frf Moon 2289 , " Fii TVA ti -. _ 1�,' T i!LT y #C i m ni r �,, ' : fit , ' 4' 4-1 I �. 1 el pp LIE: .. Tr 1iYT jal y11x1 "'III ii 1 11 :14 • • Well Work Plan Well: M -13 Hilcorp Alaska, LLC Date: 09/07/2012 Well Name: M -13 API Number: 50- 733 - 20407 -00 Current Status: Gas Producer Leg: Leg Al, SW Corner Slot #1 Estimated Start Date: October 15, 2012 Rig: Steelhead Rig 51 Reg. Approval Req'd? October 1, 2012 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 189 -049 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Melissa Eisele (907) 777 -83119 (0) AFE Number: 1222741 Current Bottom Hole Pressure: 273 psi @ 2,430' TVD (Calculated from shut in and build up) Maximum Expected BHP: 720 PSI @ 1,578' TVD Max. Anticipated Surface Pressure: 563 psi (Using 0.1 psi /ft to surface) Well Summary M -13 was completed in its current configuration as a gas producer in November of 2008. The • completion plan for this well was to perforate the well in 6 zones (See Current Perforations), install sand screens across the perforated interval and pump a two stage gravel pack to reduce the risk of sand production. This completion was executed as planned with the top zone SZ 17 being isolated from the rest between two isolation packers in case it began to make water. This well produced water from the start and reached 85 BWPD when in June of 2011 the SZ -17 perfs were squeezed eliminating water . production. qq}} { 3 { The well has produced water free up until now. Forward Plan: . ...,�. ,. _ _ The workover plan for this well is to pull out of the top packer and isolate the current completion with a cement squeeze. Perforate the SZ -11 and the SZ -13 intervals, pump a two stage gravel pack, and . return the well to production. f Ted l&ro*e- 744/e 4r? Co,Cerif LA/14 CfYd61►- fill 7Ar 5Z-II + S1-19 ,,? f to Tire t4,t' frff der 10 74e 4Nrt nD1 r 4r f Z - '! .6 f2 - t5 i''r'// k 4 r "'Ike /�' e fEa6o(� amtl �G c ct Tie r(odr , frog" Ike �,, till i ll k *wed 64 Proced - � iiereio,e Z keve izeif 1 yok1 10 /yoke 14c eck earActlem 1. MIRU Steelhead Rig # 5 1. i f ( d�ear Q�r will for fit ?% Mier /742 g 2. ND wellhead and NU BOP stack. Pressure test BOP to 250 psi. low / 3,000 psi high. Note: notify AOGCC 48 hours in advance_of test for the opportunitX to witness bop test. 3. Kill well with Kill fluid 6% KCL. 4. PII Tubing out of well disengaging from the snap latch at 2,099'. 5. RU E -line. RIH with CIBP and set at 2,090'. 1,_,, 6. PU Perf guns and RIH to 2,089 ft and perforate from 2,089' tit) 2,079 ft. POOH with perf gun. • • • Well Work Plan . n Well: M -13 Hilcorp Alaska, LLC Date: 09/07/2012 7. PU CMT retainer and run in hole on 4" workover string and set at 2,070 ft. 8. Pump Cement squeeze as directed in cement squeeze procedure. Sting out of cement retainer and 50' of cement on tof the retainer. 9. RU Schlumberger and Tripoint, begin perforation and Gravel Pack stages as indicated in the perforation / gravel pack procedure and the pert chart below: Stage / Zone Top Bottom 1 1,497' 1,578' 8 I SZ11 1,737' 1,749' / 2 2 1,759' 1,767' SZ1 1,773' 1,781' Total 109' 1o 10. RD Schlumberger and Tripoint. 11. ND BOP NU Well head. 12. RU Coil Tubing. Jet in well with Nitrogen. 13. RD Coil tubing. 14. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics r I • • Trading Bay Unit SCHEMATIC Well No.: M -13 Hilcortl Alaska, LLC Completion 10/25/1989 Casing Detail RKB to Tbg Hanger = 73.4' Size Type WT Grade ID Top BTM 20" Conductor 94 X -56 19 Surf 951' J I. Intermediate 75 K55 15.124 Surf 1,462' 13- Surf Csg 61 K -55 12.515 Surf 2,923' fil o i 10 -3/4" Prod Csg 55.5 N -80 9.76 Surf 504' I 9 5/8" Prod Csg 43.5 N80 8.755 504' 2,010' 47 N80 8.681 2,010' 7,450' ECP 2,874' 2,890' Tubing Detail 3 -1/2" 9.3 N -80 2.992 Surf 2,093' Jewelry . No. Depth ID Description I.- 1 444' 2.813" BOT TE -5 SCSSV B 1 7 -- 2 2 2,051' 2.992 Gas lift mandrel 3 2,099' 3.25" S -22B Snap Latch Seal Assembly 4 2,103' 4.75" SC -1 GP Packer 3 & 4 5 2,109' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV - S 17 6 2,135' 4.00" 4 1/2 ", 11.6 #, H -503, L -80 Blank Pipe 7 2,189' 3.548" Excluder Screen 4" SLHT (74.6') t ,;1 ` `4 5, 6 8 2,255' 3.25" S -22B Snap Latch Seal Assembly 8 &9 & 7 9 2,256' 4.75" SC -1 GP Packer 10 2,262' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV 10 .'` - _ : 11 2,288' 4.00" 4 1/2 ", 9.5 #, H-503,1-80 Blank Pipe 12 2,423' 3.548" Excluder Screen 4" SLHT (447.6') 1 ° ` SZ -19 13 2,872' 4.75" Baker Model D Sump Packer r SZ-20 11 Perforation Data sz -21 SZ -22 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Status Date SZ -23 SZ -17 2,190' 2,234' 2,065' 2,097' 44' 12 Shut Off 11/8/08 2,461' 2,470' 2,259' 2,265' 9' 12 Open 11/6/08 rR r SZ -19 2,470' 2,479' 2,265' 2,272' 9' 6 Open 10/15/04 12 - TT 2,492' 2,497' 2,281' 2,285' 5' 12 Open 11/6/08 _-- Stray 2,518' 2,522' 2,300' 2,303' 4' 12 Open 11/6/08 1 3 2,538' 2,550' 2,314' 2,323' 12' 6 Open 11/2/03 2,538' 2,550' 2,314' 2,323' 12' 12 Open 11/6/08 SZ -20 2,569' 2,583' 2,336' 2,347' 14' 12 Open 11/6/08 2,576' 2,590' 2,341' 2,352' 14' 6 Open 10/15/04 2,598' 2,602' 2,357 2,360' 4' 12 Open 11/6/08 �� 2,641' 2,653' 2,389' 2,398' 12' 12 Open 11/6/08 -A6 2,650' 2,662' 2,395' 2,404' 12' 6 Open 10/15/04 ' 2,690' 2,712' 2,425' 2,441' 22' 12 Open 11/6/08 • B -1,2 & 3 SZ -21 2,698' 2,718' 2,431' 2,446' 20' 6 Open 10/15/04 2,719' 2,734' 2,446' 2,458' 15' 12 Open 11/6/08 2,733' 2,742' 2,457' 2,464' 9' 6 Open 10/14/04 1 1 isomilll SZ -22 2,780' 2,789' 2,492' 2,499' 9' 12 Open 11/6/08 2,789' 2,798' 2,499' 2,506' 9' 6 Open 11/19/03 SZ -23 2,846' 2,852' 2,542' 2,547' 6' 4 Open 11/6/08 SZ 2,850' 2,862' 2,554' 2,554' 12' 6 Open 10/14/04 Coal D6 A -6 3,570' 3,610' 3,103' 3,134' 60' 12 Iso. B -1 3,754' 3,778' 3,245' 3,264' 24' 12 Iso. B -2 3,790' 3,809' 3,273' 3,288' 19' 12 Iso. -- II ' B -3 3,948' 4,006' 3,396' 3,442' 58' 12 Iso. D -6 5,950' 5,978' 5,140' 5,166' 28' 12 Iso. 10/19/89 0 -16A 7,035' 7,042' 6,150' 6,157' 7' 12 Iso. 10/19/89 D16A 1 B'C 7,106' 7,134' 6,217' 6,243' 28' 12 Iso. 10/19/89 D16B &C TD = 7,450'(MD) PBTD = 3,000'(MD) Max Hole Angle =44.8° @ 2,400'(MD) REVISED by TDF: 7/20/12 . • Trading Bay Unit PROPOSED Well No.: M -13 fiacore Alaska, LLC Completion 10/25/1989 Casing Detail RKB to Tbg Hanger = 73.4' Size Type WT Grade ID Top BTM 20" Conductor 94 X -56 19 Surf 951' At Ir 10 -3/4" 16" Intermediate 75 K55 15.124 Surf 1,462' 13-%" Surf Csg 61 K -55 12.515 Surf 2,923' o 1 10 -3/4" Prod Csg 55.5 N -80 9.76 Surf 504' L 9a /8" Prod Csg 43.5 N80 8.755 504' 2,010' r�7 a " ;g5 /8 Prod Csg 47 N80 8.681 2,010' 7,450' ... ECP 2,874' 2,890' alliPlor • : ' Tubing Detail i i pJ_ 16" Il 111 3 -1/2" 9.3 N -80 2.992 Surf 2,093' Jewelry _ No. Depth ID Description I '`' TOC Y � 5 . 1 444' 2.813" BOT TE -5 SCSSV ±2,020 r' 2 2,051' 2.992 Gas lift mandrel 2a 1,392 6.00" Tripoint Gravel Pack packer assembly (3 packers plus two Screens) �"`" _.. 2b ±2,090' CIBP 3 & 4 3 2,099' 3.25" S -22B Snap Latch Seal Assembly S 17 4 2,103' 4.75" SC -1 GP Packer ----- ....._.. 5 2,109' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV -- - - - - -_ II 1 5, 6 2,135' 4.00" 41/2 ", 11.64, H -503, L -80 Blank Pipe 8 &9 s � ' & 7 6 7 2,189' 3.548" Excluder Screen 4" SLHT (74.6') 8 2,255' 3.25" S -22B Snap Latch Seal Assembly 10 ' A -" 9 2,256' 4.75" SC -1 GP Packer ' 10 2,262' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV rattammat m=1 mm SZ -19 11 2,288' 4.00" 4 1/2 ", 9.54, H -503, L -80 Blank Pipe 1 1 SZ -20 12 2,423' 3.548" Excluder Screen 4" SLHT (447.6') SZ -21 13 2,872' 4.75" Baker Model D Sump Packer . ■ 1 p SZ -22 �` s2 -23 _ - Perforation Data r- �In Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount SPF Status Date 12 ■ ±2,089' ±2,079 ±1,996' ±1,981' 10' 21 Future 13 - 3/8" 10 ..... 4 1 SZ -17 2,190' 2,234' 2,065' 2,097' 44' 12 Shut Off 11/8/08 13 2,461' 2,470' 2,259' 2,265' 9' 12 Open 11/6/08 SZ -19 2,470' 2,479' 2,265' 2,272' 9' 6 Open 10/15/04 2,492' 2,497' 2,281' 2,285' 5' 12 Open 11/6/08 .. Stray 2,518' 2,522' 2,300' 2,303' 4' 12 Open 11/6/08 R�� P�� 2,538' 2,550' 2,314' 2,323' 12' 6 Open 11/2/03 IIIII A6 2,538' 2,550' 2,314' 2,323' 12' 12 Open 11/6/08 ` = :. SZ -20 2,569' 2,583' 2,336' 2,347' 14' 12 Open 11/6/08 ® ME B -1,2 & 3 2,576' 2,590' 2,341' 2,352' 14' 6 Open 10/15/04 VIM 2,598' 2,602' 2,357' 2,360' 4' 12 Open 11/6/08 2,641' 2,653' 2,389' 2,398' 12' 12 Open 11/6/08 2,650' 2,662' 2,395' 2,404' 12' 6 Open 10/15/04 SZ -21 2,690' 2,712' 2,425' 2,441' 22' 12 Open 11/6/08 1 --� 2,698' 2,718' 2,431' 2,446' 20' 6 Open 10/15/04 2,719' 2,734' 2,446' 2,458' 15' 12 Open 11/6/08 2,733' 2,742' 2,457' 2,464' 9' 6 Open 10/14/04 D6 SZ -22 2,780' 2,789' 2,492' 2,499' 9' 12 Open 11/6/08 2,789' 2,798' 2,499' 2,506' 9' 6 Open 11/19/03 SZ -23 2,846' 2,852' 2,542' 2,547' 6' 4 Open 11/6/08 I SZ 2,850' 2,862' 2,554' 2,554' 12' 6 Open 10/14/04 11110-111 11110-111 �� Coal A -6 3,570' 3,610' 3,103' 3,134' 60' 12 Iso. D16A B-1 3,754' 3,778' 3,245' 3,264' 24' 12 Iso. B -2 3,790' 3,809' 3,273' 3,288' 19' 12 Iso. B -3 3,948' 4,006' 3,396' 3,442' 58' 12 Iso. D16B & C D -6 5,950' 5,978' 5,140' 5,166' 28' 12 Iso. 10/19/89 D -16A 7,035' 7,042' 6,150' 6,157' 7' 12 Iso. 10/19/89 D 7,106' 7,134' 6,217' 6,243' 28' 12 Iso. 10/19/89 9 -5/8" . r3 , 16B,C TD = 7,450'(MD) PBTD = 3,000'(MD) Max Hole Angle =44.8° @ 2,400'(MD) REVISED by TDF: 9/11/12 • • Ferguson, Victoria L (DOA) From: Ted Kramer [tkramer @hilcorp.com] Sent: Wednesday, September 12, 2012 3:43 PM To: Ferguson, Victoria L (DOA) Subject: RE: TBU M -13 (PTD 189 -049, Sundry 312 -351) Attachments: Corrected Procedure for M- 13.pdf Victoria, Good to hear from you. I have answers for you below in Blue. Also I saw that the proposed sketch was somewhat lacking. I prepared a more complete one. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907 - 777 -8420 C 985 -867 -0665 From: Ferguson, Victoria L (DOA) f mailto :victoria.ferguson(aalaska.govl Sent: Wednesday, September 12, 2012 1:41 PM To: Ted Kramer Cc: Schwartz, Guy L (DOA) Subject: TBU M -13 (PTD 189 -049, Sundry 312 -351) Ted, We have some questions on this procedure: 1. Need more detail on the perforation /gravel pack procedure a. What is Tripoint? Tripoint is the vendor we will be using to perform the two stage gravel pack. b. Schematic has future perfs for squeeze job but no perfs for gravel pack Please see the attached corrected procedure and Proposed Schematic. c. Don't understand the Stage /Zone designation in perf chart in procedure I can see why you were confused. The table should read this way: Stage / Zone Top Bottom 1 / SZ11 1,497' 1,578' 2/ SZ13 1,737' 1,749' 1 • • 1,759' 1,767' 1,773' 1,781' Total 109' We plan to perforate the SZ13 zone, run the screens and pump a gravel pack. Then we will move up hole to the SZ11 zone, perforate, run screens and gravel pack that zone (2 Stages). 2. Pressure test casing after setting CIBP or after dumping cement on retainer? 1,000# work for you at this depth? I added it to the attached procedure. Thanx in advance, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson a(�alaska.gov 2 • • Ferguson, Victoria L (DOA) From: Ted Kramer [tkramer @hilcorp.com] Sent: Wednesday, September 12, 2012 3:43 PM To: Ferguson, Victoria L (DOA) Subject: RE: TBU M -13 (PTD 189 -049, Sundry 312 -351) Attachments: Corrected Procedure for M- 13.pdf Victoria, Good to hear from you. I have answers for you below in Blue. Also I saw that the proposed sketch was somewhat lacking. I prepared a more complete one. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907 - 777 -8420 C 985 - 867 -0665 From: Ferguson, Victoria L (DOA) [ mailto :victoria.ferguson @alaska.govl Sent: Wednesday, September 12, 2012 1:41 PM To: Ted Kramer Cc: Schwartz, Guy L (DOA) Subject: TBU M -13 (PTD 189 -049, Sundry 312 -351) Ted, We have some questions on this procedure: 1. Need more detail on the perforation /gravel pack procedure a. What is Tripoint? Tripoint is the vendor we will be using to perform the two stage gravel pack. b. Schematic has future perfs for squeeze job but no perfs for gravel pack Please see the attached corrected procedure and Proposed Schematic. c. Don't understand the Stage /Zone designation in perf chart in procedure I can see why you were confused. The table should read this way: Stage / Zone Top Bottom 1 / SZ11 1,497' 1,578' • 2/ SZ13 1,737' 1,749' 1 • • 1,759' 1,767' 1,773' 1,781' Total 109' We plan to perforate the SZ13 zone, run the screens and pump a gravel pack. Then we will move up hole to the SZ11 zone, perforate, run screens and gravel pack that zone (2 Stages). 2. Pressure test casing after setting CIBP or after dumping cement on retainer? 1,000# work for you at this depth? I added it to the attached procedure. Thanx in advance, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(a�alaska.gov 2 • • Ropy, David S (DOA) From: Ted Kramer [tkramer@hilcorp.com] Sent: Tuesday, September 11, 2012 9:49 PM To: Roby, David S (DOA) Subject: Re: Sundry Application for TBU M -13 It is going well. I would say busy but I know no more so than you guys are. Have they recruited a reservoir guy to help out or are you crossing over from reservoir to the dark side? The answer to you question is two pronged. First you are correct that the two new zones are expected to be virgin pressure so cross flow was a concern. Secondly the reservoir engineers over here felt that there are other take points for the water free zone we will be isolating. Therefore, they wanted to eliminate the cross flow possibility so they could get a good idea what the two new zones contain. I originally proposed setting a retrievable plug to isolate the current completion with the idea of going back and pulling it when the upper pressure equalized but gave up on that idea when they told me that the reserves from the lower zone would be captured in an offset well. I hope this helps. Ted Kramer Sent from my iPhone On Sep 11, 2012, at 6:11 PM, "Roby, David S (DOA)" < dave. robyPalaska. gov<mailto:dave.roby@alaska.gov » wrote: Hi Ted, How's it going? I'm reviewing your application to workover the subject well and have — a question on your proposed procedure. As the well is currently completed it's clearly not a great producer, but it does produce water free, so I am curious as to why your workover plan would isolate the current perforations instead of just adding new perforations? Are you concerned with the potential for crossflow between the existing perforations and the proposed ones, or is there some mechanical reason that would dictate conducting the proposed workover as you propose, or some other reason entirely? Thanks in advance, Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793 -1232 1 VJG STATE OF ALASKA o7 ii 3401 t ALASKAOAND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Repair Well Li Plug Perforations Lf Stimulate 11 Other Li CT Water Shut Off Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 189 -049 .. 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic Service ❑ 6. API Number: 50- 733 - 20407 -00 w 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 (Steelhead Platform) Trading Bay Unit M -13 0 9. Field /Pool(s): McArthur River Field/ Middle Kenai Gas Pool 10. Present Well Condition Summary: Total Depth measured 7,450 feet Plugs measured 3,000 feet true vertical 6,543 feet Junk measured N/A feet 2,103', 2,256', Effective Depth measured 3,000 feet Packers measured 2,872' feet GU � '� JUL 1 20t true vertical 1,999', 2,112', true vertical 2,660 2,562' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 951' 20" 951' 950' Surface 1,462' 16" 1,462' 1,446' 2,630 psi 1,020 psi Intermediate 2,923' 13 -3/8" 2,923' 2,601' 3,090 psi 1,540 psi Production 504' 10 -3/4" 504' 503' 6,450 psi 4,020 psi Production 6,946' 9 -5/8" 7,450' 6,543' 6,330 psi 3,810 psi Perforation depth Measured depth 2,190- 2,234, 2,461 - 2,479, 2,492 - 2,497, 2,518- 2,522, 2,538- 2,550, 2,569- 2,590, 2,598- 2,602, 2,620 - 2,625, 2,641 - 2,662, 2,690 - 2,742, 2,760 - 2,766, 2,780 -2,862 Feet True Vertical depth 2,065- 2,096, 2,258 - 2,271, 2,280- 2,284, 2,299- 2,302, 2,313 - 2,322, 2,336- 2,351, 2,357- 2,359, 2,373 - 2,377, 2,388 - 2,404, 2,425 - 2,464, 2,477- 2,482, 2,492 -2,554 Feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3 #, N -80 2,093' 1,992' SC -1 GP 2,103'MD/1,999'TVD SC -1 GP 2,256'MD/2,112'TVD Packers and SSSV (type, measured and true vertical depth) Baker Model D Sump 2,872'MD/2,562'TVD BOT -55 � ( SCSSV 444'MD/443'TVD � 11. Stimulation or cement squeeze summary: Intervals treated (measured): JUI.. 11 2011 2,189 -2,255 CTM Treatment descriptions including volumes used and final pressure: ,, r , Squeeze Activated w/ CaCI and Blow Down w/ N t a E: Gil 3N ems. w iiilYiiS$Ion 10 bbl Sodium Silicate S 4 z z 12. Representative Daily Average Production oit6NSta Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A 1,370 73 112 psi 59 psi Subsequent to operation: N/A 1,465 2 64 psi 53 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development 0 . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ❑ Gas U WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -161 Contact Dave Ross Phone 263 -7696 Printed Name i! Timothy C. Brandenburg Title Drilling Manager Signature ✓ 4 ` -J Phone 276 -7600 Date 7/5/2011 , Form 10 -404 Revised 10/2010 �C LL RBDMS JUL 1 1 Submit Original Only • • Chevron Steelhead M -13 Steelhead Platform A ctual Wellbore Schematic Trading Bay Unit ift. Well M -13 I Size II type 11 VI/ II II (hide II ID II (op II BTM I RKB to TBG Head = 73.4' 20" Conductor 94 X -56 19 Surf 951' Tree connection: 16" Intermediate 75 K55 15.124 Surf 1,462' 13-%" Surf Csg 61 K -55 12.515 Surf 2,923' 1. 1 1 10 -3/4" Prod Csg 55.5 N -80 9.76 Surf 504' + }J ' J 9 5!8" Prod Csg 43.5 N80 8.755 504' 2,010' 47 N80 8.681 2,010' 7,450' ECP 2,874' 2,890' 3 -1/2" 9.3 N -80 2.992 Surf 2,093' 951' L II II 11 II II II I Size W( Grade l[? Length Bbls /Ft Bbls 10 -3/4" 55.5 N -80 9.76 498 0.01972 9.8 9- 5/8" 43.5 N -80 8.755 1769.61 0.01553 27.5 9- 5/8" 47 N -80 8.681 732.39 0.01768 12.9 Total II 50.3 I Jewelry I # Depth ID Description 1,462' d 1 444 2.813" BOT TE -5 SCSSV 2 2,051 2.992 Gas lift mandrel 3 2,099 3.25" S -22B Snap Latch Seal Assembly 4 2,103 4.75" SC -1 GP Packer dT - ='m ■1 2 "'� x 5 2,109' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV - 2190' E Sodium Silcate 2234' WSO Treatment' 6 2,135' 4.00" 4 1/2 " , 11.6 #, H -503, L -80 Blank Pipe I+r `_r z 2 5 (0 7 2,189 3.548" Excluder Screen 4" SLHT (74.6') 2461' 8 2,255 3.25" S -22B Snap Latch Seal Assembly 9 2,256 4.75" SC -1 GP Packer 10 2,262' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV ..rL ji 2862' 11 2,288 4.00" 4 1/2 " , 9.5 #, H -503, L -80 Blank Pipe ` - ] 12 2,423 3.548" Excluder Screen 4" SLHT (447.6') 1 13 2,872 4.75" Baker Model D Sump Packer ' = --- 3000' - . I Existing Perforation Data I Top II Btm II Amount II SPF lI S atus II Top II Btm II Amount II SPF II Status I 2,190 2,234 44 12 Shut Off 2,650 2,662 12 6 Open 2,461 2,470 9 12 .open 2,690 2,712 22 12 Open 2,470 2,479 9 6 Open 2,698 2,718 20 6 Open 2,492 2,497 5 12 Open 2,719 2,734 15 12 6 Open 2,518 2,522 4 12 Open 2,733 2,742 9 Open 2,538 2,550 12 6 Open 2,760 2,766 6 8 Open 2,538 2,550 12 12 Open 2,780 2,789 9 12 Open 2,569 2,583 14 12 Open 2,789 2,798 9 6 Open It 2,576 2,590 14 6 Open 2,780 2,852 72 12 Open 2,598 2,602 4 12 Open 2,846 2,852 6 4 Open 2,620 2,625 5 4 Open 2,850 2,862 12 6 Open 2,641 2,653 12 12 Open PBTD = 3000' TD = 7450' MAX HOLE ANGLE = 44.8° @ 2400' MD Prepared by TDF 6/30/2011 Chevron • • Chevron - Alaska • %. Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -13 TRADING BAY UNIT M -13 ADL0017594 5073320407 IW7621 152.00 Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Plug - Permanent Well 6/13/2011 Services Primary Wellbore Affected Wellbore UWI Well Permit Number M -13 507332040700 1890490 Deity Operations 6/13/2011 00:00 - 6/14/2011 00:00 Operations Summary R/U E -line unit, M/U and lubricate 2.5" IBP BHA and setting tool. Stab on well and P/T lubricator to 250 psi low /2,500 psi high. RIH and position IBP. 6/14/2011 00:00 - 6/15/2011 00:00 Operations Summary Set 2.5" IBP with the middle of the element at 2,350', tag top of plug to confirm set. POOH, UD setting tool and P/U a 2.5" x 30' dump bailer and fill w/16 -30 carbolite. RIH. Dumped carbolite on top of IBP and tagged fill at 2,338', POOH and R/D E -line. Notify Jim Regg with AOGCC of upcoming BOP test. 6!15/2011 00:00 - 6/16/2011 00:00 Operations Summary Begin R/U CTU , N2 equipment, HP iron and BOP stack. Test BOP Stack and Stripper to 250 psi low 0 a psi high, Test accumulator with system -----• - S pressure of 3,200 psi after closure 2,800 psi. Build 200 psi in 2 mins full recovery in 4 mins. BOPE to witness waived by AOGCC Jim Regg. / 6/16/2011 00:00 - 6/17/2011 00:00 Operations Summary M/U Roto -Pulse assembly and stab onto well. P/T lubricator to 2,000 psi. RIH w/ CT and tag fill at 2,351' CTM, Pick up clear nozzle, Load well through kill line. Mix 20 bbls of CaCl2 , load CT with squeeze treatment. 6/17/2011 00:00 - 6/18/2011 00:00 Operations Summary / Perform sodium silicate squeeze on upper GP, load well and perform leak -off test. POOH and UD Roto -Pulse assembly and M/U IBP retrieving assembly, P/T lubricator to 2,000 psi, RIH and set down at 2,135', attempt to work through w/o success. POOH and P/U standard jet nozzle, P/T lubricator and RIH to 2,170' w/o problem. Wash down w/ drill H2O and N2 to 2,358.5' pump 3 annular volumes , shut down drill H2O and blow well dry with N2 while POOH. M/U IBP retrieval assembly replacing double acting jar w/ single action jar and M/U injector on well head. 6/18/2011 00:00 - 6/19/2011 00:00 Operations Summary I RIH w/ IBP retrieval assembly on CT and make several attempts to latch fish w/o success. R/D CT and R/U slick -line. M/U fishing asse I with a baited 1.75" fish neck and P/T lubricator. 6/19/2011 00:00 - 6/20/2011 00:00 Operations Summary RIH w IBP overshot assembly on slick -line and bait fish w/ a 1.75" fish neck on the 2nd attempt. RIH w/ a Jar Down Disconnect and attempt to fish plug w/o success, shear off and leave baited fish neck in the hole, R/D slick -line and R/U CT. M/U 1.75 hydraulic JDC disconnect assembly and RIH, confirm latch on fish neck and re- attempts to jar fish free w/o success. POOH w/ baited fish neck but no fish. RIH again w/ 2nd retrieval assembly w 1 3/8" over shot but would no st ,300' , POOH and lay down retrieval assembly. M/U standard jet nozzle assembly and RIH, tagged at 2,355' , pumped 3 bbls of drill H2O and c w/ N2, while POOH. Set injector aside for slick -line operations. 6/20/2011 00:00 - 6/21/2011 00:00 Operations Summary RIH and bait fish w/ a 1.75" fish neck, POOH, RIH with JDC tool assembly in an attempt to retrieve plug but could not latch, POOH and add knuckle joint to BHA, could not latch fish. POOH and add bell guide to BHA, RIH still no success. POOH and R/D slick -line, R/U CT. M/U JDC hydraulic release assembly RIH and set down at 2,301', attempt to work through w/o success. POOH and change out jars, RIH could not pass 2,301', pump N2 while trying to get through 2301' w/o success. POOH and set injector aside. R/U slick -line and M/U 1 - 11/16" camera assembly, RIH to 2,230' and wait for timer, log down at 15 FPM, set down at 2,315' and 2,349'. POOH, fluid level at 2,245', no images of fish neck. Notify Jim Regg with AOGCC of upcoming BOP Test on 6/22/2011 6/21/2011 00:00 - 6/22/2011 00:00 Operations Summary M/U Hydraulic disconnect overshot BHA on CT w/ 2 additional 3' straight bars, RIH an attempt to pass 2,301' w/o success. POOH and rest CT crew. M/U hydraulic indexing tool to the BHA and RIH to 2,351' w/o problem. Attempt to latch fish w/o success. Pump N2 to clear debris off of fish neck and attempt to latch again w/o success. POOH and inspect fishing tools, grapple full of carbolite. Clean tools and RIH to 2,330', pump 6% KCI to load coil, RIH to 2,350' and circulate to clean off carbolite. Blow down well with N2 an attempt to latch fish w/o success. POOH and inspect fishing tools. Add 1.5° bent sub to assembly and RIH attempting to latch fish while cycling the indexing tool, no success. POOH 6/22/2011 00:00 - 6/23/2011 00:00 Operations Summary M/U 2.625 Venturi Junk Basket to CT BHA, RIH to 2,350', pump @ 1.25 BPM while working venturi and shifting index tool 7 times. POO and inspect junk basket, recovered 1/2" piece of 0-ring, finger baskets damaged indicating basket had swallowed the fish. Test BOPS to 250 psi low 500 i high , — M/U a 2.625" hydraulic release overshot for a 1.75" fishing neck. RIH and latched onto fish 7 times but slipped off each time, POOH, L/ ing BHA. AOGCC Jim Reg waived witness 6/21/2011. 6/23/2011 00:00 - 6/2412011 00:00 Operations Summary Fill CT and pull test to 15K, Pressure test coil tubing to 4,000 psi. M/U BHA w/ Bowen #10 overshot w/ 1.75" grapple, RIH and attempt to latch fish but unable to latch fish. POOH, found guide barrel egged. M/U indexing tool and 1.5° bent sub to the BHA, RIH could not pass SSSV, POOH and break out bent sub and RIH to 2,350' attempt to latch fish. Worked coil up and down still tagging at 2,350' . POOH, recovered baited sub and retrieval head. Chevron • • 11110 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -13 TRADING BAY UNIT M -13 ADL0017594 5073320407 IW7621 152.00 Daily Operations 6/2412011 00:00 - 6/25/2011 00:00 Operations Summary M/U a 6 -5/8" venturi junk basket to the CT fishing BHA and RIH and tag 2,354'. Circulate while working the venturi, POOH and inspect basket, no debris. Break out venturi junk basket and M/U sure catch tool, RIH to 2,354' and attempt to latch fish while shifting the index tool and pumping. Fire the jars once and POOH, found full recovery of IBP. L/D fishing BHA and M/U nozzle and RIH to 3,002' to blow well dry w/ N2., POOH shut -in well. 6/25/2011 00:00 - 6/26/2011 00:00 Operations Summary R/D CT equipment and prepare for de -mobe. 6/26/2011 00:00 - 6/27/2011 00:00 Operations Summary Continue to demobe CT equipment. • • stirnp ALAsIKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager C h Union Oil Company of California V q6( P.O. Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, TBU M -13 Sundry Number: 311 -161 Dear Mr. Brandenburg: . LiY Enclosed is the approved Application - pproval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this) Z day of May, 2011. Encl. JG A- 0 (//41P‘ - ll of * 5 STATE OF ALASKA MAY . 0 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1aska Oil & rn Cow Gonntwssiun 20 AAC 25.280 ,,ia�pp 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Rpproveu Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension p Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: CT Water Shut Off El • 2. Operator Name: Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Development 0 . Exploratory ❑ 189 -049 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic ❑ Service ❑ 6. API Number: 50- 733 - 20407 -00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ❑ No 0 • Trading Bay Unit M -13 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0017594 [Steelhead Platform] McArthur River Field / Middle Kenai Gas Pool r 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): 7,450' 6,543' • 3,000' 2,660' 3,000' N/A Casing Length Size MD / TVD Burst Collapse Structural Conductor 951' 20" 951' 950' Surface 1,462' 16" 1,462' 1,446' 2,630 psi 1,020 psi Intermediate 2,923' 13 -3/8" 2,923' 2,601' 3,090 psi 1,540 psi Production 504' 10 -3/4" 504' 503' 6,450 psi 4,020 psi Production 6,946' 9 -5/8" 7,450' 6,543' 6,330 psi 3,810 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2,190- 2,234, 2,461 - 2,479, 2,492- 2,065- 2,096, 2,258- 2,271, 2,280- 3 - 1/2" 9.3#, N - 2,093 2,497, 2,518- 2,522, 2,538- 2,550, 2,284, 2,299 - 2,302, 2,313 - 2,322, 2,569- 2,590, 2,59k ,602, 2,620- 2,336 - 2,351, 2,357- 2,359, 2,373- 2,625, 2,641 -2,66e, '- 3690 -2,74P , 2,377, 2,388 - 2,404, 2;422,484; Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): / BOT SC -1 GP Packer, SC -1 GP Packer, Model D Sump Packer / 2,103 MD (1,999 TVD), 2,256 MD (2,112 TVD), 2,872 MD (2,562 TVD) and BOT TE -5 SCSSV and 444 MD (443 TVD) 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Development 0 - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 15(7)44-11 Oil ❑ Gas El ' WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Ross 263 -7696 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature s .---- -- r ' hone 276 -7600 Date 5/6/2011 .�„__� COMMISSION USE ONLY 4 311-11 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: 1 0 - 40 4. fi APPROVED BY S// 2/1 Approved by: ,` COMMISSIONER THE COMMISSION Date: Br MS MAY •�2t�Z ?2QR161NA Duplicate �� /r Form 10-403 Revised 1/2011 /201 r I : G LY _� Submit in Duplicate Chevron • 0 Steelhead I M -13 %. 5/03/11 OBJECTIVES: • Perform water sh ff (WSO) of SZ -17 zone. • uto Current BHP: 56pii @ 2,387' TVD Max Downhole Pressure: 156psi @ 2,387' TVD (Based on production log of SZ -17 sand) MASP: 1psi (Based on actual reservoir conditions) PROCEDURE SUMMARY: 1. RU E -line. Pressure test lubricator to 250psi low /2500psi high. / 2. RIH with gauge ring until tag ( + / -) 3,000'. 3. RIH with and set 2 -1/2" inflatable bridge plug (IBP) at (+/-280'. 4. Dump bail ( + / -) 10' sand on top of IBP. 5. Rig down E -line. 6. RU CTU. Pressure test BOP to 250psi low /2500psi high. 7. RIH to perform squeeze with Sodium Silicate WSO treatment solution from ( + / -) 2,255' to ( + / -) 2,180'. 8. Displace well with FIW while POOH. 9. RIH to ( + / -) 2,270, displace well with Nitrogen and jet sand off of IBP, POOH. 10. RD CTU. 11. RU slick -line. Pressure test lubricator to 250psi low /2500psi high. 12. RIH with gauge ring to tag top of IBP: ( + / -) 2,280', POOH 13. RIH with memory Press/Temp log to ( + / -) 2,280', to evaluate WSO, POOH 14. RIH with retrieving tool to pull the IBP at ( + / -) 2,280'. 15. RD slick -line. Turn well over to production. 1 Chevron 1110 Steelhead M -13 Steelhead Platform Proposed Wellbore Schematic Trading Bay Unit IN. Well M -13 I Size II Type II • /T II t3rA;/e II ID II Top II BT" I RKB to TBG Head = 73.4' 20" Conductor 94 X -56 19 Surf 951' Tree connection: 16" Intermediate 75 K55 15.124 Surf 1,462' 13 - %" Surf Csg 61 K -55 12.515 Surf 2,923' 10 -3/4" Prod Csg 55.5 N -80 9.76 Surf 504' I F' 9 5 /8" Prod Csg 43.5 N80 8.755 504' 2,010' / 47 N80 8.681 2,010' 7,450' ECP 2,874' 2,890' 3 -1/2" 9.3 N -80 2.992 Surf 2,093' 431' 951' I Si" II �„ I Gr 1 fr.; II Length I Snk,f 11 Bills 10 -3/4" 55.5 N -80 9.76 498 0.01972 9.8 9- 5/8" 43.5 N -80 8.755 1769.61 0.01553 27.5 9- 5/8" 47 N -80 8.681 732.39 0.01768 12.9 I I Total II 50.3 I I I # Depth ID Description 1,462' t 1 444 2.813" BOT TE -5 SCSSV 2 2,051 2.992 Gas lift mandrel 3 2,099 3.25" S -22B Snap Latch Seal Assembly 4 2,103 4.75" SC -1 GP Packer I. -- 1 5 2,109' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV _ 2190' Sodium Silcate 2234' WSO Treatment' 6 2,135' 4.00" 4 1/2 " , 11.6 #, H -503, L -80 Blank Pipe `'r 7 2,189 3.548" Excluder Screen 4" SLHT (74.6') .--- - 2461' 8 2,255 3.25" S -22B Snap Latch Seal Assembly 9 2,256 4.75" SC -1 GP Packer e 10 2,262' 3. 5 0 p " Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV 2862' 1 1 2,288 4.00" 4 1/2 " , 9.5 #, H -503, L -80 Blank Pipe 12 2,423 3.548" Excluder Screen 4" SLHT (447.6') 13 2,872 4.75" Baker Model 0 Sump Packer 's-- - 3000' I Existing Perforation Data Top II Btm II Amount II SPF II Status II Top II Btm II Amount II SPF II Status I 2,190 2,234 44 12 Shut Off 2,650 2,662 12 6 Open 2,461 2,470 9 12 Open 2,690 2,712 22 12 Open 2,470 2,479 9 6 Open 2,698 2,718 20 6 Open 2,492 2,497 5 12 Open 2,719 2,734 15 12 Open 2,518 2,522 4 12 Open 2,733 2,742 9 6 Open 2,538 2,550 12 6 Open 2,760 2,766 6 8 Open „_.,,e' 2,538 2,550 12 12 Open 2,780 2,789 9 12 Open 2,569 2,583 14 12 Open 2,789 2,798 9 6 Open 2,576 2,590 14 6 Open 2,780 2,852 72 12 Open 2,598 2,602 4 12 Open 2,846 2,852 6 4 Open 2,620 2,625 5 4 Open 2,850 2,862 12 6 Open 2,641 2,653 12 12 Open PBTD = 3000' TD = 7450' MAX HOLE ANGLE = 44.8° @ 2400' MD Prepared by DR 4/5/2011 - I I • • Chevron %.I Steelhead M -13 Steelhead Platform Actual Wellbore Schematic Trading Bay Unit Well M -13 II type II WT I Grade II ID II Top II Br RKB to TBG Head = 73.4' 20" Conductor 94 X -56 19 Surf 951' Tree connection: 16" Intermediate 75 K55 15.124 Surf 1,462' 13-%" Surf Csg 61 K -55 12.515 Surf 2,923' J J 10 -3/4" Prod Csg 55.5 N -80 9.76 Surf 504' 9 5/8" Prod Csg 43.5 N80 8.755 504' 2,010' 9 5/8" Prod Csg 47 N80 8.681 2,010' 7,450' ECP 2,874' 2,890' 3 -1/2" 9.3 N -80 2.992 Surf 2,093' 431' 951' I II I II II J II II - Size N Grade ID Lent th Bbls /F 10 -3/4" 55.5 N -80 9.76 498 0.01972 9.8 9- 5/8" 43.5 N -80 8.755 1769.61 0.01553 27.5 9- 5/8" 47 N -80 8.681 732.39 0.01768 12.9 I I Total II 50.3 I I Jeweliy I # Depth ID Description 1,462' ‘ 1 444 2.813" BOT TE -5 SCSSV 2 2,051 2.992 Gas lift mandrel 3 2,099 3.25" S -22B Snap Latch Seal Assembly 4 2,103 4.75" SC -1 GP Packer 5 2,109' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV J „ 2190' I 2234' 6 2,135' 4.00" 4 1/2 " , 11.6 #, H -503, L -80 Blank tr--- ' 7 2,189 3.548" Excluder Screen 4" SLHT (74.6') 2461' 8 2,255 3.25" S -22B Snap Latch Seal Assembly 9 2,256 4.75" SC -1 GP Packer 10 2,262' 3.50" Upr Ext, GP Sleeve, Seal Bore, Lwr Ext, KOIV 2862' 11 2,288 4.00" 4 1/2 " , 9.5 #, H -503, L -80 Blank Pipe 12 2,423 3.548" Excluder Screen 4" SLHT (447.6') L - 13 2,872 4.75" Baker Model D Sump Packer 3000' Existing Perforation Data I 1 Top II Btm II Amount II SPF II Top II Btm II Amount I SPF I 2,190 2,234 44 12 2,650 2,662 12 6 2,461 2,470 9 12 2,690 2,712 22 12 2,470 2,479 9 6 2,698 2,718 20 6 2,492 2,497 5 12 2,719 2,734 15 12 2,518 2,522 4 12 2,733 2,742 9 6 2,538 2,550 12 6 2,760 2,766 6 8 2,538 2,550 12 12 2,780 2,789 9 12 2,569 2,583 14 12 2,789 2,798 9 6 2,576 2,590 14 6 2,780 2,852 72 12 2,598 2,602 4 12 2,846 2,852 6 4 2,620 2,625 5 4 2,850 2,862 12 6 2,641 2,653 12 12 PBTD = 3000' TD = 7450' MAX HOLE ANGLE = 44.8° @ 2400' MD • • MY/On Steelhead Platform ONO M-13 IWO 05/02/2011 # s Lubricator to injection � head ni I _ Blind /She 41/16 10rvi Blind /Shear _- • C • 0 l C = Pipe /Slip Pipe /Slip _ _ : N- iel on - "' Mud Cross 1111 CO - IN o 1 41/1610 I on ma outlet Riser 4 1/16 10M FE X FE frh Ur = Blind /Shear 4 1/16 10M Bli /Shear ^ _ U IU Riser 4 1/16 10M X 4 1/16 5M r lin Xmas Tree Connection 4 1/16 5M Chevron Fran.° Castro Chevron North Ameri •Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 111011 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcastro@chevron.com DATE May 10, 2011 To: AOGCC Shartzer, Christine R 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WELL : LtNE CD ' " • i TBU M-13 PRODUCTION PROFILE 20-Apr-2011 0-2862 X X TBU M-13 PRODUCTION PROFILE REPORT 20-Apr-2011 0-2862 X TBU G-24 PLUG SETTING RECORD 13-Mar-2011 306-7342 X X TBU G-24 USIT-GR-CCL 08-Mar-2011 300-9300 X X 4 °Z;' /41635— 11) /4-1&3(.- toONNEDMAN 2 3 2011 Please acknowledge receipt b signing and returning one copy of this transmittal or FAX to 907 263 7828. Received riFi Date: / 51 r,, ;::: ;;~~~: ~. • Francisco Castro Technical Assistant Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE December 9, 2008 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 - --- WELL - LOG TYPE SCALE LOG DATE - - ~, INTERVAL B-LINE ~ LOGGED ,- - NOTES -LAS. PD3, i ~ DLIS PACKER SETTING TBU M-13 RECORD GR/CCL 5" 3-Nov-08 1 1815-2953 PDS CORRELATION TUBING CONVEYED GUNS TBU M-13 GR/CCL 5" 8-Nov-08 1 1942-1946 PDS ~~~ ^ ~~ 1 ~~ ~ I ~ ~~~~ Plezse acknowledge receipt by signing and returning one copy of this transmittal or;FAX to 907 25.3 7f32.8, ( Received ey,• Date: STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U StimulateL Other U Install GP completion Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ Waiver Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Perforate El • Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 • Exploratory❑ 189 -049 • 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service❑ 6. API Number: 50- 733 - 20407 -00 7. KB Elevation (ft): 9. Well Name and Number: 73.4' Trading Bay Unit M -13 8. Property Designation: 10. Field /Pool(s): ADL0017594 [Steelhead Platform] McArthur River Field / Middle Kenai Gas' 11. Present Well Condition Summary: Total Depth measured 7,450' ' feet Plugs (measured) 3,000' true vertical 6,543' . feet Junk (measured) N/A Effective Depth measured 3,000 feet Y . '7 ) true vertical 2,660 feet Les,*, .,,:, '0 tii vli Casing Length Size MD TVD Burst Collapse Structural 480' 34" 480' 480' Conductor 951' 20" 951' 950' 1,530 psi 520 psi Surface 1,462' 16" 1,462' 1,446' 2,630 psi 1,020 psi Intermediate 2,923' 13 -3/8" 2,923' 2,601' 3,090 psi 1,540 psi Production 7,450' 10 -3/4" & 9 -5/8" 7,450' 6,543' 6,330 psi 3,810 psi Liner Perforation depth: Measured depth: See Attached Schematic True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 3 -1/2" 9.3 #, N -80 2,093' Packers and SSSV (type and measured depth) (2) SC -1 GP & Baker Model D 2,093', 2,256', Sump Packer / SCSSV 2,872' / 449' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1720 1 0 0 Subsequent to operation: 0 5460 1 0 165 14. Attachments: 15. Well Class after work: _ Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 Service ❑ Daily Report of Well Operations X 16. Well Status after work: OHO Gas El - WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308 -258 Contact David Ross 263 -7696 Printed Name Timothy C. Brandenburg _ Title Drilling Manager Signature '� `�~ ' Phone 263 -7600 Date 12/5/2008 ..,_ ___� t /Z'•t.os Form 10 -404 Revised 04/2006 Submit Original Only 4 i A is/r /o 8 T 1 • • Chevron Steelhead M -13 Steelhead Platform A ctual Wellbore Schematic Trading Bay Unit %I. Well M -13 I Size II lytike II Wi II Grade 11 in II Tap II BIM I RKB to TBG Head = 73.4' 20" Conductor 94 X -56 19 Surf 951' Tree connection: 16" Intermediate 75 K55 15.124 Surf 1,462' 13-%" Surf Csg 61 K -55 12.515 Surf 2,923' 951' t U J - 10 -3/4" Prod Csg 55.5 N -80 9.76 Surf 504' 9 5/8" Prod Csg 43.5 N80 8.755 504' 2,010' 47 N80 8.681 2,010' 7,450' Fluid As per tag 4 -25 -07 1,594' 2,844' Fill As per tag 4 -25 -07 2,844' 2,890' 431' ECP 2,874' 2,890' 3 -1/2" 9.3 N -80 2.992 Surf 2,093' 1 s,Le 11 wT II Grade II ID II Length II BbIsIFt II i3hIs I 10 -3/4" 55.5 N -80 9.76 498 0.01972 9.8 9- 5/8" 43.5 N -80 8.755 1769.61 0.01553 27.5 9- 5/8" 47 N -80 8.681 732.39 0.01768 12.9 Total II 50.3 1,462' t I Jewelry I # Depth ID Description © 1 449 2.992" SCSSV 2 2,057 2.992 Gas lift mandrel 0= "' t 2190 3 2,093 4.75" SC -1 GP Packer III © I 1 1 2234' 4 2,179 -2,253 3.548" Excluder Screen 4" SLHT (min GP ID 2.319 ") -'� i 5 2,256 4.75" SC -1 GP Packer :- 2461' _� = 6 2,423 -2,870 3.548" Excluder Screen 4" SLHT (min GP ID 2.319 ") 6 7 2,872 Baker Model D Sump Packer C' 't _" I Existing Perforation Data I 2862' '. >C. am: • . . I Top II Btm II Amount II SPF 1 L 2,190 2,234 44 12 3000' 2,461 2,470 9 12 2,470 2,479 9 6 2,492 2,497 5 12 2,518 2,522 4 12 2,538 2,550 12 6 2,538 2,550 12 12 2,569 2,583 14 12 - 2,576 2,590 14 6 2,598 2,602 4 12 2,620 2,625 5 4 2,641 2,653 12 12 _ 2,650 2,662 12 6 = - + 2,690 2,712 22 12 2,698 2,718 20 6 2,719 2,734 15 12 2,733 2,742 9 6 PBTD = 3000' TD = 7450' 2,760 2,766 6 8 MAX HOLE ANGLE = 44.8° @ 2400' MD 2,780 2,789 9 12 2,789 2,798 9 6 2,780 2,852 72 12 2,846 2,852 6 4 2,850 2,862 12 6 'Chevron • • %go Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -13 TRADING BAY UNIT M -13 ADL0017594 5073320407 IW7621 152.00 Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Completion - Reconfigure Major Rig Recomplete well with Gravel Pack. 10/20/2008 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number M -13 5073320407 -00 1890490 Daily Operations 7/9/2008 00:00 - 7/10/2008 00:00 Operations Summary RU Slickline 7/10/2008 00:00 - 7/11/2008 00:00 Operations Summary Perform pump and bleed off test on 13 3/8 "x 9 5/8" Annulus, Pressure annulus to 1000 psi and Shoot Casing puncher while monitoring pressures. No Change. 7/11/2008 00:00 - 7/12/2008 00:00 Operations Summary Rig lubricator off well and secure APRS E -line for transport. Pressure 13 3/8 "x 9 5/8" Annulus and monitor . 10/20/2008 00:00 - 10/21/2008 00:00 Operations Summary Cleaning mud pits and mud system, built and filtered 1100 bbls of 6% KCI completion fluid, built 75 bbl sized salt FLC pill, pressure tested 5" DP lubricator and line to 3 1/2" x 10 3/4" annulus 10/21/2008 00:00 - 10/22/2008 00:00 Operations Summary Pumped 30 bbl size salt pill, killed well, punched tubing above and below packer @ 1405', circulating gas out of well 10/22/2008 00:00 - 10/23/2008 00:00 Operations Summary Monitored well backside on vacuum, drained lubricator and set BPV, ND tree, locked out flow line to production, pulled tree with blocks, no pressure under BPV, broke down landing joint, dressed threads on tbg hanger, pumped open SCSSV and wrapped control lines, Set XO spool, run risers, set BOPE and greylock clamps, installed choke lines and kill lines, installed 3 1/2" piperams under mud cross, energized koome unit to funtion test rams 10/23/2008 00:00 - 10/24/2008 00:00 Operations Summary Installed 5" pipe rams , installed blind rams, replaced 1 door seal , centered BOPE, function test pipe rams and upper and lower blind rams, reinstalled choke line, pre -spud meeting, tested upper and lower pipe rams, blind rams 5" and 3 1/2" floor valves, choke manifold, choke line valves, kill line valves. 250 psi low, 3000 psi high for 5 minutes all tested OK, Total losses to well 24 bbls. ,Witness waived by Jim Reggs with AOGCC at 10am on 10/22/2008. 10/24/2008 00:00 - 10/25/2008 00:00 Operations Summary Installed BPV and performed koomey test, stood back landing joint, removed bales and elevators, set blocks on rig floor, removed drilling line from drum, string back old blocks and put drilling line on spool, removed old blocks from floor, strung up new blocks 10/25/2008 00:00 - 10/25/2008 00:00 Operations Summary Finished stringing up 3/8" string up line and connected it to drill line, strung up blocks on 10 line, made up drilling line on drum anchor and installed side guards on block, PU and installed block rail trolly to block, installed dynaplex hook to block, calibrated block height , serviced accumulator lines and glycol lines, mixed 270 bbls of 6% KCI and filtered to 2 microns, installed stops on top drive rails, freed up hook, hung kelly hose, cut out floor deck for rat hole, changed relief valve on gas buster, R/U bails and elevators. Daily losses to well 12 bbl, Total losses to well 36 bbl 10/26/2008 00:00 - 10/2712008 00:00 Operations Summary Pulled BPV, filled hole with 26 bbls , adjusted bell nipple, MU 5' DP lubricator and APRS chemical cutter, RIH w/ 2 5/8" OD chemical cutter to 1400', overpulled 10K and severed pipe @ 1400'„POOH with APRS and layed down tools, CBU A 2.6 BPM, 26 psi, lost 18 bbls, pulled hanger to floor and LD 5" DP, monitored losses 1.5 BPH, pulled and recovered 1325' of 3 1/2 tbg. RD Weatherford tongs, monitored losses 1 BPH, PU kelly and bump connection, total losses for day 22.5 bbls, total losses to well 58.5 bbls 10/27/2008 00:00 - 10/28/2008 00:00 Operations Summary Secured kelly spinner to swivel, stood back kelly, installed wear bushing, P/U packer milling BHA. layed down elevators and bails, rigged up kelly and kelly hose tested same to 3000 psi, blew down kelly and stood back, picked up 5" DP taaaed tubing stub 1399.61', milling packer. Daily losses to well 24 bbls, total losses to well 82.5 bbls. 10/28/2008 00:00 - 10/29/2008 00:00 Operations Summary Millina S -3 packer to 1400 -1402' at 1403' observed flow increase. closed well circulated gas bubble below packer through choke manifold, continued to mill packer @ 1405' slips gave way and packer fell away, set kelly back, P/U 5" DP and chased packer to bottom, tbg tail @ 2830', Circulated bottoms up @ 8. BPM with 210 psi, POOH with 5" DP, lay dow BHA, P/U fishing BHA with overshot w/ 3 5/8" grapple, RIH set down 15K and pulled 75K to free fish, pulled up 15', CBU @ 8 BPM 160 psi, broke off kelly and blew down and stood back. Daily losses to well 30.9 bbls, total losses to well 113.4 hhls I _. j Chevron S • tisio Chevron - Alaska %. Daily Operations Summary Well Name Legal Well Name Lease Surface U M ChevNo Original RKB (ft) Water Depth (ft) M -13 TRADING BAY UNIT M -13 ADL0017594 5073320407 IW7621 152.00 Daily Operations 10/29/2008 00:00 - 10/30/2008 00:00 Operations Summary POOH with fish from 2212'- 1590', pulled tight 30K over came off fish Cd)_ 35K over, made several additional attempts with no luck, changed to a 3 1/2" grapple w/ pack off, RIH tagged fish a 1624' beat down with bumber sub and jarred up with 60K, no luck, POOH with fishing BHA and P/U milling BHA, burned over fish from 1624'- 1628'. stacked 10K on fish. still no movement. Daily losses 17.9 bbls, total losses 131.3 bbls 10/30/2008 00:00 - 10/31/2008 00:00 Operations Summary Milling on packer from1626'- 1629',POOH to replace worn mill shoe, recovered 22 Ibs of debris from junk baskets. RIH to 1629' milled on packer to 1631', packer dropped free. Reamed from 1611' to 1646' w/ no indication of tigt spots, CBU , monitored well and stood kelly back. RIH to 2217' and tagged fish, POOH encountered 5 -7K bobbbles at 2020'- 2018', determined to be 43.5# to 47# casing weight change. Changed out milling BHA to overshot BHA, recovered another 22 Ibs of iron. RIH w' drill collars and 5" DP with fishing BHA to 2180' tagged fish at 2217' set down 15K and continued to 2197', CBU @ 8 BPM, stood back kelly and started out of hole with fish. total daily losses 19 bbls, total losses 150.3 bbls. 10/31/2008 00:00 - 11/1/2008 00:00 Operations Summary POOH with fish, LD overshot assembly, LD 3 1/2 tubing tail ,changed out elevators, drained stack , flushed stack of metal cuttings and pulled wear ring. P/U test joint function test rams and set test plug, test all b BOPs 5 min low pressure and 5 mins high, AOGCC witnessed tesj. Finished accumulator test, reset methane detectors, swapped to 3 1/2" pipe and finished BOP test. Total daily losses 22.2 bbls. o a osse 11/1/2008 00:00 - 11/2/2008 00:00 Operations Summary Installed wear bushing, M/U cleanout BHA RIH to 2821' set down 5K, washed and reamed 2821 -3001' no tight spots, circulated hole clean @ 10.5 BPM , 295 psi, stood back kelly and monitored hole, no losses. POOH , LD BHA and emptied junk baskets, recovered 47 lbs of steel from junk baskets and 12 Ibs off of magnet sub. P/U new BHA with bit , string mill, scraper, junk basket and string magnet.,RIH to 2047'P/U single and M/U kelly. Shut down pumps to repair leak in kelly hose. Total daily losses 16.2 bbls total losses 188.7 bbls. 11/2/2008 00:00 - 11/3/2008 00:00 Operations Summary Removed kelly hose and repaired on rig floor, washed and reamed from 2062' -2122' @ 10 BPM, 250 psi, broke circulation, sttod kelly back. RIH to 2837' broke circulation, kelly hose leaking., POOH to 2400, tightened set screws on hose, pressure tested hose to 3000 psi, RIH to 2872 , washed and reamed to 3001', pumped 3 -50 bbl pills (2 ppb Caustic, Baraklean, N -Vis) 3 full circulation NTU reading 340. changed out shaker screens and cleaned ditch magnets, circulated hole at 10 BPM, 325 psi, pulled up to 2400' above perfs in an attempt to clean hole better, fluid did'nt clean up, decided to mix 400 more bbls of clean 6% KCI and displace fluid in hole with 2 -50 bbl pils (Dit Magnet, N -vis) follwed by clean brine. total daily losses 20.8 bbls, total losses 209.5 bbls. 11/3/2008 00:00 - 11/4/2008 00:00 Operations Summary Mixed and pumped 2 -50 bbl pills (Dirt Magnet, N -Vis) displaced with 250 bbls , 75 NTU brine, monitored hole for 10 min and POOH from 2400'. Layed down clean out BHA, cleaned rig floor, recovered 10 Ibs of steel from junk basket and magnet. R/U e-line to run Model D sump packer, RIH to 2950' and attempted to tie into DIL -SFL dated 8- 25 -89, confirmed tie in with geologist Brent Voorhees and adjusted depth 8' down before setting packer at 2872' DIL depth, POOH and R/D e-line, spotted TCP tools on rig floor, PJSM ,,P /U 590' TCP assembly checking space out of guns and blanks every q, Total daily losses 29.5 bbls, total losses 239 bbls. 11/4/2008 00:00 - 11/5/2008 00:00 ��\� Operations Summary M/U champ packer and firing head, RIH w/ TCP assembly filling first 11 stands with clean brine, tagged sump packer @ 2882 DPM, As per DIL measurement positioned top shot @ 2j6' and bottom shot c(0, 2852', loaded drop bar standing by waiting on filtered fluid. latched into sump packer set down 20K and P/U 10k to release latch. Released from packer and spaced out 16', set champ packer and tested, open and closed bypass, dealing with filtration issues, decided to dilute clean volume of 6% KCI with 12 NTU FIW and compensate with ClayMaster 5C for additional clay control. DE filtration unit , identified and ordered., Total daily losses24.0 bbls, total losses263.0 bbls.. 11/5/2008 00:00 - 11/6/2008 00:00 Operations Summary Finished filtering 3% KCI, dropped bar perfed the SZ -19 -22 zones, 74 net feet of perfs 12 spf. Reverse circulated 150 bbls of clean brine isolating dirty returns. Monitored well, static losses at 6.6 BPH, POOH with TCP assembly. LD guns all shots fired , static losses 4.6 BPH, no change in annuli pressures after firing guns. P/U cleanout BHA with mag sub, VAC tool and 2' tail pipe ,RIH to 2885' 2' in sump packer and circulated 50 bbls. POOH to 2445' above perfs. broke circulation and pumped a 5 bbl high vis pill and chased it with 245 bbls of clean brine @ 10 BPM, fluid out with 373 ppm solids. Monitored losses, 3 BPI-I, mixed an additional 500 bbls of 3% KCI . Performed full mask up drill and tested BOPs. Prepared to PU GP assembly. total daily losses 105 bbls, total losses 368 bbls. 11/6/2008 00:00 - 11/7/2008 00:00 Operations Summary P/U and hung off lower GP assembly, RIH rabbiting DP going in hole. Rigged up BJ line, filled lines and tested to 6000 psi. Set pop -off valves 4500 psi on DP and 2000 psi on annulus., set packer and tested to 20K. tested annulus to 2000 psi. Pickled pipe with 5 bbls of acid & solvent. Performed step rate injection and decline tests. Began HRWP pumping at 4 BPM taking returns at 1 BPM while pumping 1 ppa sand until BJ blender ran out of diesel. 8126 lbs of sand behind pipe at shut down. P/U and reversed sand out of DP and waited on BJ blender to be refueled and started. Total daily losses 79.6 bbls, total losses 447.6 bbls Chevron • • Chevron - Alaska 1 10 Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -13 TRADING BAY UNIT M -13 ADL0017594 5073320407 IW7621 152.00 Daily Operations 11/7/2008 00:00 - 11/8/2008 00:00 Operations Summary Re- commenced HRWP . Started pumping @ 5 BPMw/ 1 BPM returns and 1.5 ppa sand, increased rate to 8.7 BPM with 1.5 ppa sand. Sanded out after pumping an additional 14,756 Ibs below the GP packer © 3595 psi. Re- stressed pack and pumped an additional 120 Ibs of sand in attempt to cover more balnk pipe. Final pressure indicated 10' of blank pipe covered. Total sand behind screen 23,002 Ibs = 45 Ibs / ft of net perfs. rigged down BJ blew down lines. POOH and P/U Baker SP packer plug and RIH to set in GP packer. Dumped 300 Ibs of sand on plug equivelant to 7.5 ft of fill. POOH and !eyed down Baker BHA, Performed BOP test, AOGCC waived the witnessing of the test. Total daily losses 68 bbls, total losses 515.2 bbls 11/8/2008 00:00 - 11/9/2008 00:00 Operations Summary Finished testing BOPs, P/U upper zone TCP assembly and tripped in hole filling 1st 900 feet of DP, RIH with Schlumberger to correlate RA tag with DIL tie -in IogRA tag correlated to DIL depth of 1892' guns required a 4' down shift. POOH with e-line shifted guns 4' and ran back in hole with Schlumberger to re- correlate RA tag, RA tag found at 1896' OK, POOH w/ a -line, RD Schlumberger.Set Champ packer at 2003' and tested backside with 490 psi OK, dropped bar, shot 44 net feet of perfs, opened bybass and reversed 80 bbls through the choke @ 5 BPM, caught fluid at 15 bbls pumped. Unset packer monitored losses @ 11 BPH., POOH slowley losses slowed to 8.5 BPH, LD guns all shots fired. Total daily losses 64 bbls, total losses 579.2 bbls 11/9/2008 00:00 - 11/10/2008 00:00 Operations Summary Finished servicing rig, P/U cleanout BHA with overshot, VACs tool pup out sub and string magnet, RIH and cleaned debris and sand to 2265' w/ 2 BPM and 220 psi. Set down on plug w/ slight indication plug was latched . PU 15' , dropped bar, opened circ sub and pumped a 12 bbl Hi Vis pill followed by 175 bbls of completion fluid © 10 BPM, Losses @ 8 BPH. POOH, no fish, redressed circ sub, ran back in hole with same BHA. $uccesfully latched plug, POOH, LD BHA, set up to run GP assembly. Began running screen assembly. Total daily losses 175.1bbls , total losses 754.3 bbls 11/10/2008 00:00 - 11/11/2008 00:00 Operations Summary Pressure tested BJ treating line to 6000 psi, OK, set SC -1 packer @ 2102' tested same, Pickled tubing w/ 5 bbls of acid Performed DP friction test, friction very high in comparison to 1st stage. Switched to circulating position and attempted step rate test, friction very high. Reversed 1 DP volume with rig in an attemp to clear restriction. Switched back to circulating position and performed step rate test. Adjusted choke to achieve 2.2 BPM returns at 9.5 BPM down DP. Started job,,sanded out with 3900 psi. 4268 Ibs behind pipe. Reversed out and switched bac to circulating position to perform stress test which indicated 5' of blank covered. Pumped 600 Ibs of sand @ 1 BPM , 0.5 ppa sand and displaced below packer, pressure indicated 30' of blank pipe covered. Total sand behind pipe = 4868 Ibs = to 41 Ibs /net feet of perfs. Blew down lines and rigged down. Soft closed KOIV . holding w/ 7 rn Inssei. POOH with service tool assembly layed down same, P/U 3 1/2 in tubing string and RIH, stabbed into seal bore with 4 -5K Ibs, M/U landing joint and M/U SSSV control line to hanger and tested same to 5000 psi. Total daily losses 72.0 bbls, total losses 826.3 bbls. 11/11/2008 00:00 - 11/12/2008 00:00 Operations Summary Completed spacing out completion string, spotted annular volume of packer fluid, landed tubing hanger, tested packer and tba to 2000 psi for 30 mires, good test. Broke put landing joint, set BPV, ND BOP and choke and kill lines, stump back BOP and LD risers, NU tree test void to 5000 psi for 30 mins, good test, Pressure tested tree 250 low , 5000 psi high, held for 30 mins. A couple of Vetco Gray tree flanges leaked, Pulled TWC and replaced tree cap. R/U slickline 11/12/2008 00:00 - 11/13/2008 00 :00 Operations Summary R/U slickline RIH to retrieve dummy valve in gas lift mandrel @ 2058', retrieved dummy ands RIH with 1" orifice valve, POOH and turned well over to production. 11/13/2008 00:00 - 11/14/2008 00:00 Operations Summary • ~l~Q~~ Co L G!'~ ~~'a~[~Q ALA-SS-A OIL AI~TD GAS CO1~T5ER'QA7'IOI•T COMDIISSIOI~T Timothy Brandenburg • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Drilling Manager UNOCAL ;~~~~~ JUL ~ ~ 2008 ~a PO Box 196247 G~ ~ ~ l Anchorage, AK 99519 $ Y 1 C~ Re: McArthur River Field, Middle Kenai Gas Pool, Trading Bay Unit M-13 Sundry Number: 308-258 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions- of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~! ~a of Jul , 2008 Y Y Encl. Sincerely, ^" ~.ei.rn d~ w !~ ~~ Q STATE OF ALASKA i J~ ~ ~~D$ ALA OIL AND GAS CONSERVATION COMMON 'l~ ~ Z~1~~ ~-'~/ APPLICATION FOR SUNDRY APPROVAL ~k~ *c. ,~,_, ~,. ,. 20 AAC 25.280 „ _ `~4' 1. Type of Request: Abandon^ Suspend ^ Operational shutdown^ Perforate ^~ Waiver^ Other Alter casing^ Repair well ^ Plug Perforations^ Stimu late^ Time Extension ^ Add SZ-17 gg Change approved progran^ Pull Tubing Perforate New Poo jTRe-enter Suspended Well^ ~~"'~~'\~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 189-049 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20407-00 7. If perforating, closest approach in pools} opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^~ Trading Bay Unit M-13 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~ ADL0017594 Steelhead Platform 73.4' MacArthur River Field/ Middle Kenai Gas / SZ-17 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,450' 6,543' 2,844' 2,540' N/A N/A Casing Length Size MD TVD Burst Collapse Structural 480' 34" 480" 480' Conductor 951' 20" 951' 950' 1530 psi 520 psi Surface 1.462' 16' 1,462' 1,446' 2630 psi 1020 psi Intermediate 2,923' 13-3/8" 2,923' 2,601' 3090 psi 1540 psi Production 7,450' 10 3/4" & 9-5/8" 7,450' 6,543' 6450; 6330 psi 4020; 3810 psi Liner N/A N/A N/A N/A N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" N-80 2,014' Packers and SSSV Type: Packers and SSSV MD (ft): BOT 19-47 S3 Permanent Packer and Halliburton SSSV 1,405' and 431' 13. Attachments: Description Summary of Proposal ^./ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 8/21/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Ross 263-7696 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ Phone 276-7600 Date 7/16/2008 ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: -~~~y~° ~ t ~~~ ~ ~C ~j'~,. .~ Subsequent Form Required: ~~!„~ APPROVED BY 0 A roved b : MMISSIONER THE COMMISSION Date: ~~ yS! pp y ~/ ~ ~D ? t3, og Form 10-403 Revised 06/200 ~ ~ G ~ ~ ~' ~~~ ~~L ry ~ Z~QB Subm~ Duplic to r+_ @Vf0 Steelhead Platform Steelhead M-13 Trading Bay Unit Well M-13 Well Schematic As Completed 4-30-08 Actual as of 4-25-07 RKB to TBG Head = 73.4' 05' Size Type WT Grade ID Top BTM 20" Conductor 94 X-56 19 Surf 951' 16" Intermediate 75 K55 15.124 Surf 1,462' 13'/e" Surf Csg 61 K-55 12.515 Surf 2,923' 10-3/4" Prod Csg 55.5 N-80 9.76 Surf 498' 9-5/8 Prod Csg & 47 N80 8.681 498' 7,450' Fluid As per tag 4-25-07 1594' 2844' Fill As per tag 4-25-07 2844' 2890' ECP 2874' 2890' 3-1/2" 9.3 N-80 2.992 Surf 2,014' # Depth ID Jewelry Description 431' 2.813" Halliburton SSSV 1,356' 2.867" 3-1/2" BST (SPM) A-1, (DK Dummy Valve) 1,405' 4.75" BOT 19-47 S3 Perm Packer (409-12-7201) 1,479' 2.813 BX Nipple 1,981' 2.813 BX Nipple 2,014' 2.992 Mule Shoe 44' PafaafimQ~ Zone Tap Bfil krart 8PF CumEtis 2470 24FJ 9 6 Si~ot10"15at SZ19 298 2,5H7 12 6 St~t1v~3 2~ 2~ 14 6 5~t10'15tk1 Rrtch _ 2Q0 2625 5 4 9tt10'3~ .290 2,6Q 12 6 Shot10"~l 2®B 2718 20 6 Shot10''15C~ 2733 2742 9 6 Shot10'14Rk1 R.rrh 2~ 2,7FTo 6 8 Shotiwoe1029'C8 SZ~2 2789 z7~8 9 6 Stiot1'V1903 Rrrh 28x6 2,89 6 4 S'ot1d2a03 2 Ff(7 i ~ ~;r 12 6 tut 10''kl~kl MAX HOLE ANGLE =44.8° @ 2400' • • Chevron RKB to TBG Head = 73.4' 951' 1,462 210 236 2,8 2,9i 30' t4' 1' ~~ Steelhead M-13 Proposed Wellbore Schematic Steelhead I Trading Ba Well M-13 Size Type WT Grade ID Top BTM 20" Conductor 94 X-56 19 Surt 951' 16" Intermediate 75 K55 15.124 Surt 1,462' 13-'/" Surf Csg 61 K-55 12.515 Surf 2,923' 10-3/4" Prod Csg 55.5 N-80 9.76 Surf 504' 9 5/8" Prod Csg 43.5 47 N80 N80 8.755 8.681 504' 2010' 2010' 7450' Fluid As per ta g 4-25-07 1594' 2844' Fill As per tag 4-25-07 2844' 2890' ECP 2874' 2890' 3-1/2" ~ 9.3 N-80 2.992 Surf 2,014' Size WT Grade ID Length Bbls/Ft Bbls 10-3/4" 55.5 N-80 9.76 498 0.01972 9.8 9- 5/8" 9- 5/8" 43.5 47 N-80 N-80 8.755 8.681 1769.61 0.01553 732.39 0.01768 27.5 12.9 Total 50.3 Existing Perforation Data Proposed Perforation Data Top Btm Amount SPF Top Bottom Feet SPF 2,470' 2,479' 9 6 2190. 2234 44 18 2,538' 2,550' 12 6 2,461' 2,470' 9 18 2,576' 2,590' 14 6 2,492' 2,497' S 18 2,620' 2,625' S 4 2,518' 2,522' 4 18 2,650' 2,662' 12 6 2,538' 2,550' 12 18 2,698' 2,718' 20 6 2,569' 2,583' 14 18 2,733' 2,742' 9 6 2,598' 2,602' 4 18 2,760' 2,766' 6 8 2,641' 2,653' 12 18 2,789' 2,798' 9 6 2,690' 2,712' 22 18 2,846' 2,852' 6 4 2,719' 2,734' 15 18 2,850' 2,862' 12 6 2,780' 2,789' 9 18 105 2.840' 2.852' 12 18 11S ~ ~o us,c~Z ~Z~ °~ PBTD = 3000' TD = 7450' MAX HOLE A4JGLE = 44.8° @ 2400' MD Tree connection: 13 16 3/4" BOP Stack up • Flu l[ri. 7R d1' 73.41' I I I I I ~ Drip Pan ~ I 136.25' s.7s' zs.o3 8.38 16 3/4" SM Hydril Annular 17.83 5.40' 18 3/4" 10M Mud Cross 2.45' ALL Wing valves 3" 5M . F.... 3.75' 2.95' Rig Sub Grating Upper well Bay Floor 16 3/4" 5M Riser Hub Connection on top Flanged Bottom 20.05' 58.28' 11" SM X 16 3/4" 5M DSA '"~;":.' .62' b ~\ Top of 11" 5 M Tbg Spool TBG Spool FMC Chevron ~ ~ MacArthur River Field Steelhead Platform Well # M-13 7/7/08 OBJECTIVE: • Gravel pack workover PROCEDURE SUMMARY: RIG -Move in rig and equipment over well ~ 13 . 2 RIG -Mix 1 I00 bbls of 6% KCl workover fluid and filter to 2 microns / R U pump down tubing to load hole, spot FL pill if necessary. ND Tree ,NU BOPE test same. R/[J E-line and P/l.J a tubing punch, ensure well is loaded with 300 psi on tubing,RIH to punch holes in the tubing above the BOT S-3 permanent packer set @ 1405' (+/-), POOH 4. RIG -Circulate well to 6% KCl until clean fluid is seen at surface monitor H2S concentration 5 EL - R/i T EL and P/iJ chemical tubing cutter , RIH to sever tubing above permanent packer, pull 15k tension on tubing while making cut, POOH 6. RIG -Pull existing 3 ''/z" completion 7 RIG - P/U mill and boot basket and RIH to mill permanent packer and chase to bottom until it stops, clean up, fish permanent packer and tbg.tail 8. RIG - Pick-up bit and RIH to clean out hole to PBTD at 3000' (+/-) RIG -Pick-up 9 5/8" scaper and brush and make a scraper trip to PBTD, circulate a 25 bbl pill of 9. Baraklean FL, continue to circulate with filtered 6% KCl fluid until an NTU reading of 20 or less is achieved. If required pump another pill of Baraklean. POOH 10. EL -Pick-up sump packer on EL and RIH, set packer @ 2900' (+/-) referenced to approved tie in log depths, POOH 11. RIG -Pick-up packer plug on D.P. and RIH to set in sump packer, dump 5' (2001bs) of clean sand down drill pipe on top of packer plug, POOH RIG -Pick up TCP perf gun assembly with circulation port and RIH toperforate (250 psi 12. underbalance) the proposed perforations in the , S~ 19,21,22 and 23 sands, (391 gross ft of guns) pump saturated salt pill if necessary and POOH 13. RIG -Pick up plug retrieving tool with string magnets and RIH to reverse circulate( if possible) perf debris and retrieve packer plug RIG - PUMU lower screen assembly and ,latch into sump packer, set lower GP packer @ 2360'(+/-) 14. ,establish circulation, perform step rate injection test, perform high rate water pack on the lower intsval, POOH 15. RIG -Pick-up packer plug on D.P. and RIH to set in lower GP packer, dump 5' (2001bs) of clean sand down drill pipe on top of packer plug, POOH 16. RIG -Pick-up TCP assembly, RIH tag plug and space out to perforate proposed S~17 intervals (250 psi underbalanced), pump fluid loss pill POOH 17 RIG -Pick up plug retrieving tool with string magnets and RIH to reverse circulate (if possible) perf debris and retrieve packer plug M-13 REVISED BY: BCA 7/7/08 Chevron ~ • MacArthur River Field Steelhead Platform Well # M-13 7/7/08 RIG -P/LJ upper GP assembly and RIH ,latch into lower GP packer, set upper GP packer, reverse out ball, 18. establish circulation, perform step rate injection test, perform high rate water pack on upper interval, POOH 19. RIG - P/iJ 3 ''h" tubing with packer seals and RIH ,space out tubing, make up landing joint and stab into SC-1 packer seal bore @ 2100' (+/-) while landing tubing in hanger. 20. RIG - PJSM - ND BOPE - NU tree, release rig 21. SL - R/U slickline with weight bar and RIH to break KIOVs, POOH, RIH to drift KIOVs M-13 REVISED BY: BCA 7/7/08 Page 1 of 2 • • Maunder, Thomas E (QOA) From: Ross, David A. [Petro Technical Resources of AKj [rossda@chevron.comj Sertt: Thursday, July 24, 2008 11:33 AM To: Maunder, Thomas E (DOA) Subject: FW: TBU M-13 (189-049) Hi Tom, In regards to your questions below, 1) We plan to test the BOP stack to 3000 psi., 2) The shut in tubing pressure on M-13 is currently 132 psi, and 3) No we are planning to use 5" DP as our work string. Should you require any additional information don't hesitate to contact me at your earliest convenience! Regards, David Ross Alaska Wellbore Maintenance Team Chevron North America Exploration 8 Production (MCA) Office: (907) 263-7686 Cell: (281) 660-2483 Fax: (866)244-1439 Email: rossda@chevron.com From. alsh, Chantal [Petrotechnical] Sent: Th ay, July 24, 2008 8:58 AM To: Ross, Davl . [Petro Technical Resources of AK] Cc: 'Maunder, Tho s E (DOA)' Subject: FW: TBU M- 189-049) FYI From: Maunder, Thomas E (DOA) [mailto: Sent: Thursday, July 24, 2008 8:44 AM To: Walsh, Chantal [Petrotechnical~-~ Subject: TBU M-13 (189-049''' Chantal, -~'" Would you pleasey€drward this on to David Ross. 1 don'i have his ed s. Thank you. David, t am sewing the sundry submitted to workover over TBU M-13 and have a coup of questions. 1. What BOP test pressure is planned? 2. What is the present SI tubing pressure? 7/24/2008 Page 1 of 1 • • Maunder, Thomas E (DOQ) From: Walsh, Chantal [Petrotechnical] [WalshC@chevron,com] Sent: Thursday, July 24, 2008 8:58 AM To: Ross, David A. [Petro Technical Resources of AK] Cc: Maunder, Thomas E (DOA) Subject: FW: TBU M-13 (189-049) FYI From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent; Thursday, July 24, 2008 8:44 AM To: Walsh, Chantal [Petrotechnical] Subject: TBU M-13 (189-049) Chantal, Would you please forward this on to David Ross. 1 don't have his eddress. Thank you. David, I am reviewing the sundry submitted to workover over TBU M-13 and have a couple of questions. 1. What BOP test pressure is planned? 2. What is the present SI tubing pressure? 3. Will you be using 3-1/2" DP as your work string? Thanks in advance. Tom Maunder, PE AOGCC ?/24/2008 , STATE OF ALASKA ) ALA....,.l OIL AND GAS CONSERVATION COMf\",~'810N REPORT OF SUNDRY WELL OPERATIONS RECE,IVED JUL 062009 1, Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D i'i::iL:~"ka Oil a Gas Con.. Corrmllsior Stimulate U OtherJ~_J AnChBIIV81plete Waiver D Time Extension'D ' Re-enter Suspended Well D 5. Permit to Drill Number: ExploratoryD 89-49 ServiceD 6. API Number: 50-733-20407 9. Well Name and Number: M-13 10. Field/Pool(s): McArthur River Field/Grayling Gas Sands 7. KB Elevation (ft): 152' 8. Property Designation: Steelhead Platform 11. Present Well Condition Summary: Total Depth measured 7,450' true vertical 6,543' feet feet Plugs (measured) 3,005' EZSV Junk (measured) none Effective Depth measured 4,050' true vertical' 3,476' feet feet Casing Structural Conductor Surface Intermediate Production Liner Length 480' 951' 1 ,462' 2,925 7,450' Size 34" 20" 16" 13-3/8" 10-3/4"; 9-5/8" MD 480' 951' 1 ,462' 2,925' 7,450' TVD Burst Collapse 480' 950' 1,530 psi 520 psi 1 ,447' 2,630 psi 1,020 psi 2,603' 3,090 psi 1,540 psi 6,543' 6,450; 6,330 psi 4,020; 3,810 psi Perforation depth: Measured depth: See attached SCANNED ,JUt 0 7 2005 True Vertical depth: See attached Tubing: (size, grade, and measured depth) 3-1/2",9.3#, L-80 AB Mod BTC @ 2,014' Packers and SSSV (type and measured depth) Baker SC-1L @ 3,491' & 3,625'. Otis XXO SSD @407' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 55 2557 1110 000 15. Well Class after proposed work: Exploratoryn Development fJl 16. Well Status after proposed work: OilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 196 o Tubing Pressure 280 o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service n x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 303-317 Contact Larry Buster 263-7853 Printed Name Timothy C. BrandenbJrq ~ ~~/? Signature é ~ /'..---- . > _ ~ ¿:;) Title Drilling Manager Phone 907-276-7600 Date 7/6/2005 RBDMS 8Fl JUL 0 7 2DD5 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only 10/14/03 ) ) Tested tbg hanger neck seals and body seal to 3000 psi for 15 min. Tested 13-3/8" x 10-3/4" pack off U 3000 psi for 15 min, Pumped 250 bbls of salt water down 9-5/8" annulus @ 1,5 bpm. SD for crew rest. 10/15/03 Clear deck and in prep for Injection test down tbg, Platform Orientation and PJSM and go over plan forward. RU on tbg and test to 250/2,000 psi. Start pumping FIW down tbg @ 1.5 bpm @ total of 214 bbls away. Tbg = zero vacuum, SD for crew rest. 10/16/03 Slick line hands on board Platform orientation PJSM and go over plan, Test lubricator U 250/2500 psi. RIH w/3.8" gauge ring U 3,503'. Pooh and LD gauge ring and MU braided line brush. RIH w/ braided line brush U 3503' and work brush across profiles. POOH, RIH w/ "PX" plug body on X-line running tool and locate and set body in "X" profile @ 3472'. RIH w/ "PX" prong and set in "PX" body @ 3469'. Pooh. 10/17/03 Simops w/ production, PJSM and monitor dead tbg, Pull tree cap and CIW hand ran BPV profile tap and cleaned profile Ran, set and pulled, CIW type"H" BPV. Rig HP line off tbg and r/up on 10-3/4" annulus and test (ok). Bring pum p on line @ 1 bpm @ 325 psi monitoring tbg and all annulus and pump FIW down 10-3/4" X tbg annulus, R/up S/L and m/up XXO shifting tool RIH and locate out @ 403' RKB wlm, RD slick line equipment. 10/1 8/03 . Continue.monitor well pressures. Bleed 10-3/4" and tbg f/ 60 psi U 30 psi, shut in and monitor. Shut in and monitor well pressures. 10/1 9/03 Continue 'monitor well pressures Simops w/ production and PJSM w/ crews (no pressure slight blow both sides). Pump approx 5 bbls in to 10-3/4" annulus w/1/2" line off suction of water flood pump and vent tbg to flair. 10/20/03 Down pump and monitor and let water gas/air flop and vent tbg to flair 10-3/4" = zero, Pump approx 5 bbls in to tbg w/1/2" line off suction of water flood pump and vent 1 0-3/4" annulus to flair, Down pump and monitor and let water gas/air flop and vent 1 0-3/4" to flair TBG = slight vacuum. 10/21/03 Pump approx 5 bbls in to tbg w/1/2" line off suction of water flood pump and vent 10-3/4" annulus to flair. Shut in and monitor tbg = 0 psi tubing dead and 10-3/4" = 5 psi and H20 returns. 1 0/22/03 Shut in and monitor tbg = 0 psi tubing dead and 10-3/4" = 0 psi casing side dead. 1 0/23/03 Shut in and monitor tbg = 0 psi tubing dead and 10-3/4" = 0 psi casing side dead. 1 0/24/03 Tubing and Annulus both 0 psi. Pre-job safety and operations meeting. Install BPV, Nipple down flowline and bonnet from surface safety valve on tree. Pull tree free. Prepare to Nipple up BOP. M-13 (AFE 161413) morning report summary, CONFIDENTIAL: last reVi~,et7¡6/\\fO, '!-\gp 1. I ; I"'; ~ L ~, ~...,..,~ ~ .~ 10/25/03 ) Nipple up BOP. Fire and abandon platform drill. Make up choke and kill hoses, install bell nipple and flowline. 10/26/03 Make up 5" test joint. Test BOPs and all related equipment to 250 psi low and 3000 psi high. Test witnessed by state man. Blow down lines, Pull two way check. 10/27/03 .~ .~ H2s mask up drill. Rig up Pollard slick line and RIH w/ shifting tool locate SSSVand pressure up tbg U 2000 psi. RIH w/ GS pulling tool in attempt to pull "POX" prong, M/up 1-75" Drive Down bailer RIH and tag @ 3249', RIH w/ 3.80" LIB and set down @ 3249'. M/U perf guns, RIH tag fill at 3258', shoot 3254' to 3256'.8 - 3/8" holes, Displace well with 8.7 PPG gel mud at 6 BPM. Pull hangar free and work seals free. 10/28103 Lay down pup joints and tubing cutting up dual encapsulated control line. Lay down 4 1/2" 12.6# tubing and jewelry. Loss rate less than 2 BPH, POH to shot holes. Pick up 9 5/8" EZSV and run in the hole slowly to 3000'. Set 95/8" EZSZ per Halliburton rep @ 3005'. Shut pipe rams and test 95/8" x 5" drill pipe to 2000 psi. Held PJSM during casing test. Pump 2 bbl water, SLB Test line to 3000 psi, mix and pump 66 bb115.8 ppg cement. Displace with rig pump 46 bbls @ 4 bbl per min. Pull up to 2930' and reverse circulate 2 drill pipe volumes, no sign of cement in returns. 10/29/03 Weight up mud to 9.4 ppg. RIH to 2703'. Make up 6' 1 9/16" perf Tubing punch 23 shots. RIH with APRS log on depth and tie into Schlumberger Cement Scan log dated 10/16/89. Pressure up to 600 psi on 9 5/8". Perforate 2,760' to 2,766'. Attempt to break circulation pressure up to 1700 psi and bleed. Saw no change in 22 psi on 13 3/8" annulus. RIH w/ Tubing punch. Pressure up on 9 5/8" annulus to 500 psi, fire gun and reshoot 2760' -2766'. No sign of pressure change on 13 3/8" x 9 5/8" Annulus, POOH. 10/30/03 Attempt to break circulation on 13 3/8" x 9 5/8" Annulus, Perforate 2620' to 2625' with 1 9/16" 23 shot gun. Attempt to break circulation on 13 3/8" x 9 5/8" Annulus. Displace well to 6% KCL fluid. POOH. Change top rams to 3 1/2" and rig up hydraulic tongs to run tubing. 10/31/03 Continue to change Top rams to 31/2", test door seals to 3000 psi, Rig up to run tubing. PJSM, Run 3 1/2" completion. Install BPV In hanger, Make up landing joint. Land tubing. With tubing tail @ 2014' and top of BOT S3 Packer at 1404'. Circulate around CRW-132 corrosion inhibitor. LD landing joint. ND BOP. NU 4-1/16" 5M, tree. 11/01/03 Test neck seals, ring gasket and hanger to 5000 psi. Shell test tree to 5000 psi. Pull two way check. RIH with XX plug with 2.72 body to lower profile at 1980' work until latched, shear off plug, POH. Pump down tubing stage up pressure to 3500 psi set S-3 packer. Swab fluid out from SSSV to surface. M-13 (AFE 161413) morning report summary, CONFIDENTIAL: last revised 7/6/2005, Page 2. UNOCAL(; ~J 1 "thnical Schematic Trading Bay Unit, Steelhead, M-13 Recompletion as of 11/1/03 Casing and Tubing Detail Jewelry . r LJ ~ L L ~ J- . ~ -EZSV @ 3,005' with 251 cement on top --- ~ Size 2a' 16" 13-3/8" 1 0-3/4" 9-5/8" Wt. Type 94# X-56 Casing 75# K-55 Casing 61 # K-55 Casing 55.5# N-80 Casing 43.5#, 47# N-80 Casing ECP Casing Packer Tubing Size 3-1 /2" Wt. Type 9.3# L-80 eue 8RD tbg (MOD) Top Bottom 0 951' 0 1 ,462' 0 2,925' 0 498' 498' 7,450' 0' 2,874' Top Bottom 77 2,014 MD ID Description 431 2.813 Halliburton SSSV 1,356 2.867 3-1/2" BST (SPM) A-1, (OK Dummv Valve) 1,405 4,750 BOT 19-47 S3 Perm Packer (409-12-7201 1,479 2.813 BX Nipple 1,981 2.813 BX Nipple 2,014 2.992 Mule Shoe (Abandoned 10103) 3,491' Baker 96A4-60 SC-1L packer 3,494' Baker 190-60 upper extension 3,499' Baker 190-60 sliding sleeve 3,501' Baker 190-60 seal bore 3,503' Baker lower extension 3,524' X-over 7" x 5-1/2" 3,525' 5-112", 15.5#, K-55 blank pipe 3,565' 5-112" Wire wrap screen, 0,012 gauge 20/40 Baker bond 3,622' Seal bore receptical 3,624' Baker &22 snap latch w/seal extension 3,625' Baker 96A4-60 SC-1L packer 3,629' Baker 190-60 perforated upper extension 3,635' Baker 190-60 seal bore 3,637' Baker 190-60 lower extension 3,653' X-over 6-5/8" x 4-1/2" 3,659' Otis "XN" nipple w/3, 725" no-go 3,660' X-over 4-112" X 5-112" 3,661' 5-112", 17#, N-aa blank pipe 3,721' 5-112" wire wrap screen 0.012 gauge 4,010' Bull plug 4,050' Cast iron bridge plug 5,245' Long string cut 5,250' Short string cut 5,866' Dual packer Squeezed 66bbls cement Perforations Perforations (Abandoned 10/03) I nterval Zone FT 3,570-3,610' A-6 60' 3,754-3,7781 B-1 24' 3,790-3,809' B-2 191 3,948-4,006' B-3 581 SPF 12 12 12 12 Deg. 45 45 45 45 PBTD: 7,350' TD: 7,450' RKB 73.4' Max Angle 44.8 degrees @ 2,400' RECEIVED JUL 0 (; 2005 Stimulate U Ot~~¡lm Oil & Gas Cons C . Waiver D . Time Extension D A '. h . On-n'1 Re-enter Susp~nçied Well 0 nc orage 5. Permit to Drill Nurriber: ExploratoryD 89-49 ServiceD 6. API Number: 50-733-20407 9. Well Name and Number: M-13 10. Field/Pool(s): McArthur River Field/Grayling Gas Sands ) STATE OF ALASKA ) ALA5, v-\ OIL AND GAS CONSERVATION COMM.~QION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 152' KB above MSL 8. Property Designation: Steelhead Platform 11. Present Well Condition Summary: Total Depth measured 7,450' true vertical 6,543' Effective Depth measured 2,997' true vertical 2,658' Casing Structural Conductor Surface Intermediate Production Liner Size 34" 20" 16" 13-3/8" 10-3/4"; 9-5/8" Length 480' 951' 1 ,462' 2,925 7 ,450' Perforation depth: Measured depth: See attached True Vertical depth: See attached Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) Plug Perforations U Perforate New Pool D Perforate 0 4. Current Well Class: Development 0 Stratigraphic D feet feet Plugs (measured) 3,005' EZSV Junk (measured) none feet feet MD 480' 951' 1 ,462' 2,925' 7,450' TVD Burst Collapse 480' 950' 1,530 psi 520 psi 1 ,447' 2,630 psi 1,020 psi 2,603' 3,090. psi 1,540 psi 6,543' 6,450; 6,330 psi 4,020; 3,810 psi 3-1/2",9.3#, L-80 AB Mod BTC @ 2,014' Baker SC-1L @ 3,491' & 3,625'. Otis XXO SSD @407' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 55 2557 1110 794 2677 75 15. Well Class after proposed work: Exploratoryn Development fJl 16. Well Status after proposed work: oilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Timothy C. Brandenburg _ Signature? .ç¡c/S _;j?- RBDMS BFL ,JUt 072005 13; Oil-Bbl 196 273 x Contact, Steve Tyler 263-7649 Form 10-404 Revised 04/2004 Tubing Pressure 280 75 Service n GINJ D WINJ D WDSPL D SUndry Number or N/A if C.O. Exempt: 303-337 Title Drilling Manager Phone 907-276-7600 Date 7/6/2005 r~"r, 1 I~" ¡ f\ ,I. .~ , ~ \. ___ ~ l \.. J ~ ~ '.......... Submit Original Only ) ) 11/01/03 RU Schlumberger for perforating, 11/02/03 PU Gamma Ray and CCL, Test Lubricator to 2000 psi. RIH wI GAMMA Ray and CCL. MU 2 1/2" HSD Hollow carrier, 20' gun (12' hot) and CCL. RIH to depth. Perforate 2,538 to 2,550'. RD Schlumberger. Rig down Pollard, install night cap, release well to production. 11/19/03 RU SL and test to 2000 psi (ok). RIH and tag fill @ 2982' WLM RKB - POOH. RD Slick line. RU SWS & hold Safety meeting. Arm Gun #1 10' wI 9' loaded 2.50" HSD hollow carrier @ 60 deg phasing wI 6SPF Rih noting jewelry U 2800' pull tie in strip to 2500' placed guns on depth and tied gun gamma to Schlumberger log RST - PSP dated 9/27/03. Shoot S2 - 22 sand at 2789' to 2798'. POH all shots fired, RD Schlumberger. M-13 (AFE 161413) morning report summary, CONFIDENTIAL: last revised 7/6/2005, Page 1. UNOCAL(Ð ~J 1_thnical Schematic Trading Bay Unit, Steelhead, M-13 Recom pletion as of 11/19/03 Casing and Tubing Detail Jewelry . r L ~ LJ L ~ ~ ~ ]I . ~ - = 1;1 Size 2IT' 16" 13-3/8" 1 0..3/4" 9-5/8" Top Bottom 0 951' 0 1,462' 0 2,925' 0 498' 498' 7,450' 0' 2,874' Top Bottom 77 2,014 Wt. Type 94# X-56 Casing 75# K-55 Casing 61# K-55 Casing 55.5# N-80 Casing 43.5#, 47# N-80 Casing ECP Casing Packer Tubing Size 3-1 /2" Wt. Type 9.3# L-80 eue 8RD tbg (MOD) MD ID Description 431 2.813 Halliburton SSSV 1,356 2.867 3-1/2" BST (SPM) A-1. (DK Dummv Valve) 1,405 4.750 BOT 19-47 S3 Perm Packer (409-12-7201 1,479 2.813 BX Nipple 1,981 2.813 BX Nipple 2,014 2.992 Mule Shoe (Abandoned 10/03) 3,491' Baker 96A4-60 SC-1L packer 3,494' Baker 190-60 upper extension 3,499' Baker 190-60 sliding sleeve 3,501' Baker 190-60 seal bore 3,503' Baker lower extension 3,524' X-over 7" x 5-1/2" 3,525' 5-112", 15,5#, K-55 blank pipe 3,565' 5-112" Wire wrap screen, 0.012 gauge 20/40 Baker bond 3,622' Seal bore receptical 3,624' Baker 5022 snap latch w/seal extension 3,625' Baker 96A4-60 SC-1L packer 3,629' Baker 190-60 perforated upper extension 3,635' Baker 190-60 seal bore 3,637' Baker 190-60 lower extension 3,653' X-over 6-5/8" x 4-1/2" 3,659' Otis "XN" nipple w/3, 725" no-go 3,660' X-over 4-112" X 5-112" 3,661' 5-112", 17#, N-8Q blank pipe 3,721' 5-112" wire wrap screen 0.012 gauge 4,010' Bull plug 4,050' Cast iron bridge plug 5,245' Long string cut 5,250' Short string cut 5,866' Dual packer Perforations Date Interval Zone Ft. SPF Deg. Squeezed 11/2/2003 2,538 - 2,550' SZ-19 12' 6 60 66bbls cement 11/19/2003 2,789 - 2,798' SZ-22 9' 6 60 Aban 10103 3,570 - 3,610' A-6 60' 12 45 ~ Aban 10103 3,754 - 3,778' B-1 24' 12 45 Aban 10/03 3,790 - 3,809' B-2 19' 12 45 Aban 10103 3,948 - 4,006' B-3 58' 12 45 PBTD: 7,350' TD: 7,450' RKB 73.4' Max Angle 44.8 degrees @ 2,400' ') STATE OF ALASKA ALAS. .. {OIL AND GAS CONSERVATION COMrv¡,JION REPORT OF SUNDRY WELL OPERATIONS RE'" iO'"""¡;'E"'''''''' V (.;; IE'Q JUL 0(; 2005 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D Stimulate lJf,\!a!OhDtllll ,GaS _~)I!y~l.· Waiver D Time Extension Ot nch A~ðrøx~cr~I1^~'O'! Re-enter Suspended Well IT 0 ge 5. Permit to Drill Number: ExploratoryD 89-49 ServiceD 6. API Number: 50-733-20407 9. Well Name and Number: M-13 10. Field/Pool(s): McArthur River Field/Grayling Gas Sands 7. KB Elevation (ft): 152' 8. Property Designation: Steel head Platform 11. Present Well Condition Summary: Total Depth measured 7,450' true vertical 6,543' feet feet Plugs (measured) 4,050 bridge plug Junk (measured) none Effective Depth measured 4,050' true vertical 3,476' feet feet Casing Structural Conductor Surface Intermediate Production Liner Length 480' 951' 1 ,462' 2,925 7,450' Size 34" 20" 16" 13-3/8" 10-3/4"; 9-5/8" MD 480' 951' 1 ,462' 2,925' 7,450' TVD Burst Collapse 480' 950' 1,530 psi 520 psi 1 ,447' 2,630 psi 1,020 psi 2,603' 3,090 psi 1,540 psi 6,543' 6,450; 6,330 psi 4,020; 3,810 psi Perforation depth: Measured depth: 3,570 to 4,006' True Vertical depth: 3,120 to 3,442' Tubing: (size, grade, and measured depth) 4-1/2", 12.6#, L-80 AB Mod BTC @4,010' Packers and SSSV (type and measured depth) Báker SC-1L @ 3,491' & 3,625'. Otis XXO SSD @407' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf I Water-Bbl I Casing Pressure n/a no operations Tubing Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run n/a Daily Report of Well Operations n/a 15. Well Class after proposed work: Exploratoryn Development fJl 16. Well Status after proposed work: oilD Gas 0 WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service n GINJ D WINJ D WDSPL D I Sundry Number or N/A if C.O. Exempt: 303-260 (attached) Contact Larry Buster 263-7853 printe.d Name T~mothY_~yBrand~r I _ -4" C ----;:,; Signature C- ~ I C// Cf'" >:./ ,,/ ¿ Title Drilling Manager Phone 907-276-7600 Date 7/6/2005 RBDMS BFl J U L 0 7 2005 (.,',\-"..'., l.) .f~.)~ It~ L \ L~~, Form 10-404 Revised 04/2004 Submit Original Only STATE OF ALASKA ALASKA OiL .'!ND GAS CONSERVATION ('~~MISSION APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator Unocal Corporation 3. Address P.O. Box 196247 Anchorage, AK 99519-6247 4. Location of well at surface 1,048' FNL, 453' FWL, Sec. 33-9N-R13W, SM (Leg A-1 Conductor #1 Steelhead Platform) At top of productive interval 2,055' FNL, 1,958' FEL, Sec. 32-T9N-R13W, SM At effective depth , . . ~I ' ,""' 1. Type of Request: Abandon: x Suspend: Alter casing: _ Repair well: Change approved program: Pull tubing: At total depth 2151'FNL, 2,479' FEL, Sec. 32-T9N-R13W, SM 12. Present well condition summary Total depth: measured true vertical 7,450 feet 6,543 feet Effective depth: measured true vertical 4,050 feet 3,476 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 480' 951' 1 ,462' 2,925' 7,450' Size 34" 20" 16" 13-3/8" 10-3/4" & 9-5/8" measured 3,570'-3,610', 3,754'-3,778', 3,790'-3,809', 3,948'-4,006' true vertical 3, ~ 00'-----3,440' Operation shutdown: Plugging: _ Variance: 5. Type of well: Development: Exploratory: Stratigraphic: Service: Plugs (measured) Junk (measured) Cemented 'Drive 2,~30 sx 1,400, sx 2,245 sx 1,780 sx Tubing (size, grade, and measured depth) 4-1/2", 12.6# L-80 AB Mod BTC @ 4,010' Re-enter suspended, \NeU: Time extension: ' Stimulãtë:" Perforäte: Other: 6. Datum elevation (DF or KB) 152' KB Above MSL feet 7. Unit or Property name x Trading Bay Unit 8. Well number M-13 9. Permit number 89-49 10. API number 50- 733-20407 11. Field/Pool McArthur River Field/Grayling Gas Sands 4,050' - Bridge Plug None Measured depth 480' 951' 1 ,462' 2,925' 7,450' True vertical depth 480' 950' 1 ,447' 2,603' 6,543' 13. Attachements Description summary of proposal: x Packers and SSSV (type and measured depth) Baker SC-1 L @ 3,491' & 3,625'. Otis XXO SSD @ 407' BOP sketch: Detailed operations program: 14. Estimated date for commencing operation 1 0/1/2003 16. If proposal well verbally approved: 115. Status of well cl~i~~m~~. a :L ' ',', . -;-,. ) J~, ~ <..:,; Uy Oil: l"Gas: x SU~'é'hded: ~""t' p 0 ~) ?rrn "'" _I, j '_.,Jv,-, I , Date approved Service: ALASKA DRtG Title: Drilling Engineer FOR COMMISSION USE ONLY Date: 8/29/2003 Conditions of approval: NO~, ~commission so repre$~tive may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test_ Subsequent form required 1 0- '-\~ '3aOOD~' M.\~\""~t"\.. ~a~~\- "'L-~ -- ~kh' \\ ~~~c:.:\-O\- ~~~~ 'v..S,\,,,cs.<> ,~~* .-\-~~~ 0-\ 'CO \l S.'~é 0" ,,'\~S \j r~ Approved by order of the Commissioner ~~1 Form 10-403 Rev 06/15/88 ,~¿/~~- Approval No. .--1073 -~cJ Commissioner 9',- fJS-- ~] Date SUBMIT IN TRIPLICATE DU?UCATE ) ) Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudcand@ullocaI.com UNOCALe Debra Oudean G & G Technician Date: March 16, 2005 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 SCANNED JUN 1 ~12005 ~llIdD " y'E~~~R/. ::'::"·.:~~.~Ft/}:·.';·:.r. ",.:.:: ..:.' .':·:·;'::<.:~·:·.t L~,G'!xr,~·:,,'~·/;/.::·I.:. .::.:/:::i~.~ ::.: .:: ssf.~~·:}"~~~,{ ;:}~b~~VE~L::.:: L~i ~~~M c~ I ~2¡w(:~:~:~~ ::~-:~:------'~~:¡~;:~¡::::~-::::::::::~~:~-'--":'::-~.-~::~~~:::~~---._-----: ---~ --~j ~q, {if¡ 'ii~hi~;;;¡;,g.~ï:BÜM-13---g~~:~~~7Ï:~ëõRõ2~HŠÕ¡;ÕWË-ÃjËT6ŠP¡:--ŠIÑCH'·1óì14Ï2õõ135õ:2šão·-T---j----i-"11 ! lša;¡;;;;;¡;;,-;g;,yrnur;¡:;-Š-¡ëÕMPLEmr,riiECÕR[)1.56TuEì"íNGi'ÜÑa:¡20Ëš-~15TÑëH¡1õïi3í2õõ4äõöõ:¡¡3õõ---T--1r1f11 } r?;; « s~¡;i~;;;¡;~;g~;'TBìTM:;-Š---~~~~Ë~~~~~~~~ÃD1~TûBïÑG-pu'Ñcif2í)EšTI5íÑC¡i'-i2iiŠÎ2oõ4~5õõö~6942·-'r'·--'1--1--1 {'fa 'ö 1 ~~~~~~~~t~I~~~F-~·~i~~L~['f~~~~~~~~~~:~~:~~~~~:;~~~~~~~;=r~~H~~~~~~lÞSYf~~F-'F:=~=:=::l:~fl J ~~, /'; '3 . s-,,~lu,,:,~~r~~r1~~U_f>1:~"__.~t~~~()~~~~ciN ,R_EE().~()~:~ 2.~~~_ ~E. S~F._ _. _._....J~IfJ.c.BI.1.0!1 ~~~(}4"~92:.3942__._..L_....1 L.11...1.1 Please acknowledge rec . t by signing and turnl g one copy of this transmittal or FAX to (907) 263-7828. Rec~Y: ullt -- Date: :!~~ RE: TBV M-13 ') ) Subject: RE: TBU M-13 From: "Brandenburg, Tim C" <brandenburgt@unoca1.com> Date: Fri, 05 Nov 2004 08:20:53 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> &C; -OLf. ( Tom, We will rectify this, thank you for brining it to our attention. Tim -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sen t: Thursday, Novembe·r···....Ò·4···~·········2..6·64··...·8..··;..·5·4··...··.AM........·..··..·...···..........·.........·...·.....·...·...··....................·.....·...·...·...··· To: Tim Brandenburg Subject: TBU M-13 Tim I was looking at the file for M-13 and it does not appear that any "report of operations", form 404 was submitted for the cementing and perforating work done about this time last year. Although you have a new sundry (304-371) to add some additional perforations in the well, it would be appreciated if Unocal would submit the report for the work done last year. Thanks in advance. Tom Maunder, PE AOGCC SCANNED OC1 2 8 2005 1 of I 11/5/2004 8:25 AM ., STATE OF ALASKA, ALA, ...~ OIL AND GAS CONSERVATION COMI\t..JSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: POBox 196247, Anchorage, AK 99519 7. KB Elevation (ft): 73.4' 8. Property Designation: Steelhead Platform, Cook Inlet 11. Present Well Condition Summary: Total Depth measured 7,450' feet true vertical 6,543' feet Effective Depth measured 2,975' feet true vertical 2,641' feet Casing Length Size Structural 951' 20" Conductor 1 ,462' 16" Surface 2,925' 13-3/8" Intermediate 498' 10-3/4" Production 6,952' 9-5/8" Liner Perforation depth: Measured depth: 2,470' to 2,862' True Vertical depth: 2,265 to 2,554' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: 0 Subsequent to operation: 0 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact Steve Tyler 263-7649 Printed Name Neil Magee Signature '-i1f)AKf\,~ Form 10-404 Revised 04/2004 Plug Perforations U Perforate New Pool D Perforate 0 4. Current Well Class: Development 0 Stratigraphic D Stimulate U /l !Ç?t~~f 'SJ WaiverD Time E~~'~~Mn d Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory 0 8949 Service 0 6. API Number: 50-733-20407 9. Well Name and Number: M-13 10. Field/Pool(s): McArthur River Field/GGS Plugs (measured) 2,975' Junk (measured) MD 951' 1,492' 2,925' 498' 7,450' TVD 950' 1,475' 2,602' 497' 6,543' Burst 2,630 psi 3,090 psi 6,450 psi 6,330 psi SCANNED fEB 2 3 2005 3-1/2" L-80 2,014' Collapse 1,020 psi 1 ,540 psi 4,020 psi 3,810 psi BOT 1947 S3 Perm Packer @ 1,405' (see schematic for Packers abandoned 10/03) Halliburton SSSV @ 431' Service D Tubing Pressure 489 565 GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 304-371 Title Acting Drilling Manager Phone 907-276-7600 Date 2/16/2004 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 1770 1 350 2210 1 320 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: oilD Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ORIGINAL. RBDMS BFL FEB 2 2 20D5 Submit Original Only UNOCAL8 ~- L ~ L ~ ~ .. 11 F\ - ! . 1~hnical Schematic Trading Bay Unit, Steelhead, M-13 Recompletion last revised 12/16/04 - DED ') Casing and Tubing Detail Size Wt. Type 20" 94# X-56 Casing 16" 75# K-55 Casing 13-3/8" 61# K-55 Casing 10-3/4" 55.5# N-80 Casing 9-5/8" 43.5#,47# N-80 Casing ECP Casing Packer Tubing Size 3-1/2" wt. 9.3# Type L-80 EUE 8RD tbg (MOD) Jewelry Top Bottom 0 951' 0 1 ,462' 0 2,925' 0 498' 498' 7,450' 0' 2,874' Top Bottom 77' 2,014' MD ID Description 431' 2.813 Halliburton SSSV 1,356 2.867 3-1/2" BST (SPM) A-1, (DK Dummy Valve) 1,405 4.750 BOT 19-47 S3 Perm Packer (409-12-7201) 1,479 2.813 BX Nipple 1,981 2.813 BX Nipple 2,014 2.992 Mule Shoe (Abandoned 10/03) 3,491' Baker 96A4-60 SC-1L packer 3,494' Baker 190-60 upper extension 3,499' Baker 190-60 sliding sleeve 3,501' Baker 190-60 seal bore 3,503' Baker lower extension 3,524' X-over 7" x 5-1/2" 3,525' 5-1/2", 15.5#, K-55 blank pipe 3,565' 5-1/2" Wire wrap screen, 0.012 gauge 20/40 Baker bond 3,622' Seal bore receptical 3,624' Baker S-22 snap latch w/seal extension 3,625' Baker 96A4-60 SC-1L packer 3,629' Baker 190-60 perforated upper extension 3,635' Baker 190-60 seal bore 3,637' Baker 190-60 lower extension 3,653' X-over 6-5/8" x 4-1/2" 3,659' Otis "XN" nipple w/ 3.725" no-go 3,660' X-over 4-1/2" X 5-1/2" 3,661' 5-1/2", 17#, N-80 blank pipe 3,721' 5-1/2" wire wrap screen 0.012 gauge 4,010' Bull plug 4,050' Cast iron bridge plug 5,245' Long string cut 5,250' Short string cut 5,866' Dual packer Perforations (Abandoned 10/03) Interval Zone FT 3,570-3,610' Ä-6 60' 3,754-3,778' B-1 24' 3,790-3,809' B-2 19' 3,948-4,006' B-3 58' ~ - EZSV @ 3,000' with 25' cement on top - Squeezed 66bbls cement SPF 12 12 12 12 Deg. 45 45 45 45 Perforations Date Interval Zone Ft. SPF Phasing 11/2/2003 2,538 - 2,550' SZ -19 12' 6 60 deg 11/19/2003 2,780 - 2,789' 8Z-22 9' 6 60 deg 10/14/2004 2,850 - 2,862' 8Z-23 12' 6 60 deg 10/14/2004 2,733 - 2,742' 8Z-21A 9' 6 60 deg -~~ 10/15/2004 2,698 - 2,718' SZ-21 L 20' 6 60 deg ~ ~ ~ ~ 10/15/2004 2,650 - 2,662' SZ-21 L 12' 6 60 deg 10/15/2004 2,576 to 2,590' SZ-21 L 14' 6 60 deg 10/15/2004 2,470 to 2,479' SZ -21 L 9' 6 60 deg PBTD: 2,975' TD: 7,450' RKB: 73.4' Max Angle 44.8 deg. @2,400' r,:.JI ') ) 10/14/04 PJSM. Finish rig up, load gun, check out electronics, pressure test 2500#. Shut in well and WIH wI GRICCL and 12 foot gun. TP@570 psi. Tie in wI Schlumberger RST 9/27/03. Perforated 2850-2862 (12) 2.5 HSD PJ, 6spf. All shots fired. Logged up and POOH. TP at 570. Stand by for well test. PJSM. Loaded gun and finished rig up. Pressure tested 2500#. WIH with CCL and 9 foot gun. TP 580 'psi. Tied in wI Schlumberger RST 9/27/03. Perforated 2733-2742 (9) 2.5 HSD PJ, 6 spf. All shots fired. Logged up and POOH. TP @ 580. Secured well. Well in test. 10/15/04 PJSM. Armed gun and picked up lubricator. (No press test). WIH with CCL and 20' gun. Tied in as before. TP@ 589 psi. Perforated 2698-2718 (20 feet) 2.5 HSD PJ at 6 spf. TP@ 620. POOH and rearmed gun. TP@ 650 psi. WIH with CCL and 12' gun. Tied in as before. TP@ 601 psi. Perforated 2650-2662 (12 feet) 2.5 HSD as before. Logged up and POOH, laid down lubricator. WIH with CCL and 30' gun carrier. Tied in and checked CCL to top shot dimensions. TP @ 595 psi. Perforated 2576-2590 (14 feet). Saw wt loss and positive polarity discharge. TP@ 650 psi. Logged up and tied in. TP@ 665 psi. Perforated 2470-2479 (9 feet). Saw wt loss and negative polarity discharge. TP@ 675 psi. POOH. Monitored well. Laid down lubricator. Well in test. M-13 (162926) morning report summary CONFIDENTIAL: last revised 2/16/2005, Page 1. STATE OF ALASKA RECEIVED Y ALASKA Oil AND GAS CONSERVATION COMMISSION .. ~tOl APPLICATION FOR SUNDRY APPROVAL OCT 0 6 2004 ~Y...)- ì'( ......-; 20 AAC 25.280 Alð..li.. nil R. ~ftA ('ftftA - t::? 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate ~ ~,v~D AnnularUi os. Alter casing D Repair well D Plug Perforations D Stimulate D Time Exten~~n ~ Other D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory D 89-49 3. Address: Stratigraphic D Service D 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20407 7. KB Elevation (ft): 9. Well Name and Number: 73.4' M-13 8. Property Designation: 10. Field/Pools(s): Steel head Platform/Cook Inlet McArthur River Field/Grayling Gas Sands 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): 7,450' 6,543' 2,975' 2,641' 2.975' Casing Length Size MD TVD Burst Collapse Structural 951' 20" 951' 950' Conductor 1,462' 16" 1 ,492' 1,475' 2,630 psi 1,020 psi Surface 2,925' 13-3/8" 2,925' 2,602' 3,090 psi 1,540 psi Intermediate 498' 10-3/4" 498' 497' 6,450 psi 4,020 psi Production 6,952' 9-5/8" 7,450' 6,543' 6,330 psi 3,810 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2,538 to 2,789' 2,313' to 2,499 3-1/2" L-80 2,014' Packers and SSSV Type: BOT 19-47 S3 Perm Packer Packers and SSSV MD (ft): 1 ,405' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/15/2004 Oil D Gas 0 Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Tim C. Brandenburg Title Drilling Manager - Signature ~Cð; ~.. Phone 907-276-7600 Date 10/5/2004 ,,--:J COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30Y-3'7( Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: ~Q.\\~"'~\~'\.\,;)l~"-Q"\-~~ \t~\-Ç>~ dû ~~d--S t~~ :RBDMS BfL OCT 1 1 ?O~~\ Subsequent Form Required: ORIGINAL Appro.." by r1l'f1t¡ Dote Jf' ß / # \...- BY ORDER OF COMMISSIONER THE COMMISSION ...- '-""" ....... ~/~( su{mit t DuPI~ate Form 10-403 Revised 12/ 03 INSTRUCTIONS ON REVERSE UNOCAL8 Technical Schematic Trading Bay Unit, Steel head, M-13 Recompletion last revised 10/05/04 - OED Casing and Tubing Detail Jewelry Size Wt. Type Top Bottom 20" 94# X-56 Casing 0 951' 16" 75# K-55 CasinQ 0 1 ,462' 13-3/8" 61# K-55 CasinQ 0 2,925' 10-3/4" 55.5# N-80 Casing 0 498' 9-5/8" 43.5#,47# N-80 Casing 498' 7,450' ECP CasinQ Packer 0' 2,874' Tubina Size Wt. Type Top Bottom 3-1/2" 9.3# L-80 EUE 8RD tbQ (MOm 77' 2,014' MD ID Description 431' 2.813 Halliburton SSSV 1,356 2.867 3-1/2" BST (SPM) A-1, (DK Dummy Valve) 1 ,405 4.750 BOT 19-47 S3 Perm Packer (409-12-7201 \ 1,479 2.813 BX Nipple 1,981 2.813 BX Nipple 2,014 2.992 Mule Shoe - EZSV @ 3,000' with 25' cement on top Abandoned 10/03) 3,491' Baker 96A4-60 SC-1L packer 3,494' Baker 190-60 UDDer extension 3,499' Baker 190-60 slidinQ sleeve 3,501' Baker 190-60 seal bore 3,503' Baker lower extension 3524' X-over 7" x 5-1/2" 3,525' 5-1/2",15.5#, K-55 blank pipe 3565' 5-1/2" Wire wrap screen 0.012 eaUQe 20/40 Baker bond 3,622' Seal bore receotical 3,624' Baker S-22 snap latch w/seal extension 3625' Baker 96A4-60 SC-1 L packer 3,629' Baker 190-60 oerforated upper extension 3,635' Baker 190-60 seal bore 3,637' Baker 190-60 lower extension 3,653' X-over 6-5/8" x 4-1/2" 3,659' Otis "XN" nipple wi 3.725" no-go 3,660' X-over 4-1/2" X 5-1/2" 3661' 5-1/2" 17# N-80 blank Dice 3,721' 5-1/2" wire wrap screen 0.012 gauee 4,010' Bull clue 4050' Cast iron bridQe oluQ 5,245' Long string cut 5250' Short strine cut 5,866' Dual packer - Squeezed 66bbls cement Perforations Date Interval Zone Ft SPF Deg. 11/2/2003 2,538-2,550' SZ-19 12' 6 60 11/19/2003 2,780-2,789 SZ-22 9' 6 60 Perforations Abandoned 10/03) Interval Zone FT SPF Dea. 3,570-3,610' A-6 60' 12 45 3,754-3,778' B-1 24' 12 45 3,790-3,809' B-2 19' 12 45 3,948-4,006' B-3 58' 12 45 PBTD: 2,975' TD: 7,450' RKB: 73.4' Max Angle 44.8 deg. @2,400' M-13 Work Summary Perforate and Test SZ sands . MIRV Slickline. Tag fill. RIH wI dummy gun. RD Slickline. . MIRV Eline. RIH wI 2-1I2"guns (HSD, 6spf, 60ophasing). . Perf SZ sands as follows (GR log will determine DIL depth for perf): SZ23 sand 2850'md to 2862'md Flow test SZ21A sand 2733'md to 2742'md Flow test SZ21L sand 2698'md to 2718'md 2650'md to 2662'md 2576'md to 2590'md 2470'md to 2479'md SZ17 sand 2226'md to 2240'md 2200'md to 2220'md Flow test Flow test . RD Eline. . Turn well over to production. ~W~WŒ (ill~ ~~~~æ~ / / AI,ASIiA. OILA5D GAS / CONSERVATION COMMISSION / í FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: McArthur River M -13 Sundry Number: 304-371 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed fonD. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. BY ORDER OF !J'E COMMISSION DATED this~ day of October, 2004 Enc!. Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 T ele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com UNOCAL8 "~-Alaska Debra A Oudean G & G Technician ø[iY-f January 29, --- DATA TRANSMITTAL To: From: Lisa Weepie Debra Oudean 333 W 7tn Ave, Suite 100 909 W. 9th Avenue AnchoraQe, AK 99501-3539 Anchorage, AK 99519-6247 AOGCC Unocal Alaska Transmitting as follows: J L'{ð'- dP L{ TBU G-21 RD COMPLETION RECORD 5 INCH 9380-9900 ' 1 J'9 LJ::]X 1 1 0 TBU M-l COMPLETION RECORD OWEN X-SPAN PATCH 5 INCH 12/1212003 4100-4296 ~ 0 f::¡&:tŒ'7 ~BU Mol . IRS~ SIGMA LOG ~____15INC~J .!I2~/20031950-4360 [~Il 11 0 ~ ) '?J9.<f/C¡ I:!:.~U M-13- .- J~.~'~~~~~~!ION RECORE 2.5 HSD POWER~ETS .__-'5 INCH_~ 1!~~~?0õ32789-2798 I1IM~if~1!t r~. ~----_.I ) ?59'QLJC¡ ITBU M-13 PERFORATING RECORD 2.5 HSD POWERJETS 5 INCH 111/21200312538-2700 11' t. 1 I' 10 ) q '1- } ú> WTBU M-16 ICOMPLETION RECORD EZSV DRILL PACKER 5 INCH I 11131200311560-1606 1 J.9J,1~rf ~ ~~U M-16RD ICEMENT BOND LOG Is INCH 111/13/200313859-3958 11 1 0 10 x03- 'f5~ M-16RD ~~~~t~~~~~~~~~~~:2 HSD POWËRFLowsr ---IS INCH 1111312012755-3806 [1J9'HTfrr çq /;:::> ITBU M-5--lCõMPLETION RECORD VELOCITY STRING PACKER lSlNCH111125J2003Ts0-3350 11Jå1J{J'1I1l1To- J u . - cð I TUBING PUNCHER I I 'I I I RECEIVED FED 2 6 2004 .Alaska on & Gas Cons. Commisston Anchorage t of this transmittal or FAX to 907 263-7828. Date: ~lC#~NN[ED' MAR 1 ~ 2004 Ii STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of'Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Unocal Corporation Development: x 152' KB Above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well number 1,048' FNL, 453' FWL, Sec. 33-9N-R13W, SM (Leg A-1 Conductor #1 Steelhead Platform) M-13 At top of productive interval 9. Permit number 1.395' FNL, 220' FEL, Sec. 32-T9N-R13W, SM 89-49 At effective depth 10. APl number 50- 733-20407 At total depth 11. Field/Pool 2151' FNL, 2,479' FEL, Sec. 32-T9N-R13W, SM McArthur River Field/Grayling Gas Sands 12. Present well condition summary Total depth: measured 7,450 feet Plugs (measured) 4,050'- Bridge Plug true vertical 6,543 feet Effective depth: measured 4,050 feet Junk (measured) None true vertical 3,476 feet Planned PBTD: measured 2,800 feet true vertical 2,507 feet Casing Length Size Cemented Measured depth True vertical depth Structural 480' 34" Drive 480' 480' Conductor 951' 20" 2,230 sx 951' 950' Surface 1,462' 16" 1,400 sx 1,462' 1,447' Intermediate 2,925' 13-3/8" 2,245 sx 2,925' 2,603' Production 7,450' 10-3/4" & 9-5/8" 1,780 sx 7,450' 6,543' Liner Perforation depth: measured 3,570'-3,610', 3,754'-3,778', 3,790'-3,809', 3,948'-4,006' .~' : true vertical 3,100'- .... 3,440' Tubing (size, grade, and measured depth) 4-1/2", 12.6¢ L-80 AB Mod BTC @ 4,010' Packers and SSSV (type and measured depth) Baker SC-1L @ 3,491' & 3,625'. Otis XXO SSD @ 407'. 1-,~. Atmcnemen[s Oescnpuon summary or proposal; X ~e~allec~ operations program: ,,, 14. Esumated oa[e for commencing operation 15, hiatus Of Well classlflcauon as: 11/19/2OO3 i6. if proposal weii verbaiiy approved: Oil: Gas: x Suspended: Name of approver Date approved Service: 'i 7. i hereby ceru~y [nat the ~oregolng Is true and correc[ (u the besi. of my ~nowiedge. Signed: ~,. ~,~ S teveTyler Title: E ngineeringTeohnician Date: 11/14/2003 rurx ~OMMi$SiON USE ONLY Conditions of approval: e'L;~ Approva N . Not,fy 'ommlss,on so representat,ve may w,tness Plug integrity~ BOP Test Location clearance -- Mechanical Integrity Test Subsequent form required 10- L.{~"'~I-.-~, ^pproved by order of the Commissioner Commissioner 'Date ~'~ ' Form 10-403 Rev 06/15/88 OA NEr;'"' i 10V g 8 2003 SUBMIT IN TRIPLICATE Operational Plan for M-13 APl# 50-733-204007-00 Permit# 89-49 Objective: Current: Add Perforate SZ-22 Add Perforate SZ-17 Upper Add Perforate SZ-17 Lower Producing from the SZ- 19 2789'-2798' 2201' - 2221' 2227'-2241' 2538'-2550' Operation: 1. Spot/MIRU Eline unit. 2. RI w/2-1/2" HSD Power Jet carriers. 3. Perforate SZ-22 ~ 2789' - 2798' 4. POOH RD Eline. 5. Turn well over to production. 6. Produce well for 2- 4 weeks. 1. Spot/MIRU Eline unit. 2. RI w/2-1/2" HSD Power Jet carriers. 3. Perforate SZ- 17 Lower & Upper ~ 2227' - 2241' '& 2201' - 2221' 4. POOH RD Eline. 5. Turn well over to production. ALASKA OIL GAS CONSEP,.VATI ON FAX 907-276-7 542 PHONE 907-279-1433 COMMI SSI.ON FACSIMILE TRANSMITTAL SHEET COMPANY: FAX NUMBER: PHONE NUMBER: TOT)iL'NO. OF PAGES INCLUDING CO'VER: SENDER'S REFERENCE NUMBER: RE: YOUR REFERENCE NUMBER: [] URGENT . [] FOR REVIEW [] PLEASE'COMMENT [] PLEASE REPLY N OTES/COMMENTS: [-'[PLEASE RECYCLE AOGCC 333 WEST 7TM AYENUE, SUITE I 00 ANCHORAGE, AK 99501-3935 Re: Steelhead, M-13 Plug Back Sundry Approval Subject: Re." Steelhead, M-13 Plug Back Sundry Approval Date: Thu, 16 Oct 2003 07:12:45 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Coyner, Vern -ASRC" <coynerv@unocal.com> CC: "Buster, Larry W" <lbuster@unocal.com> Skip and Larry, The latest sundry for the work planned on M-13 should be approved today. The plans have significantly changed since the original sundry to abandon the existing perforations in preparation for sidetrack. Everything is happening within the existing wellbore now. That being the case, it is not necessary to file a 407 as required by the original sundry (303-260). The 404 required by the new sundry will satisfy the reporting requirements for the planned well work. Tom Maunder, PE AOGCC "Coyner, Vern -ASRC" wrote: The Re-Completion application and 403 form will be sent to you shortly. A detailed Pre-Rig procedure is included which describes how we will put our barriers to flow in place.Thanks,Skip Coyner263-7690 ..... Original Message ..... From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, October 13, 2003 8:57 AM To: Coyner, Vern -ASRC Cc: Buster, Larry W Subject: Re: Steelhead, M-:[3 Plug Back Sundry Approval Skip and Larry, My presumption was that the well would be killed and stand full in recommending approval of the original sundry. I have a note on our copy regarding "killing the well" prior to ND and NU. Based on depleted zones out there, it is likely as you point out that the hole will not stand full so you can trip pipe. In your message, you state that "barriers to flow will be put in place" which is necessary. Although you are not specific with regard to how you will accomplish the work, I am familiar with some' techniques for "squeezing/plugging" operations with the production tubing in place. Your new plan recognizes the need to have control of the well at all times and it appears that you have modified your operation plans to accomplish this. Based on that assessment, I do not have any objection to your proposed change. The Commission still desires to witness the initial stack test for the 16" BOP. Please call with any questions. Tom Maunder, PE AOGCC "Coyner, Vern -ASRC" wrote: Our Application for Sundry Approval to plug back the existing perforations in M-13 was approved on 9/05/03: #303-260. The plug back procedure was as follows: o Kill the well o POOH with production tubing o RIH with cement retainer and work string o Squeeze at least 26 bbl of cement into the existing perforations Due to the well's current geometry, it is not feasible to round trip tubing before we plug off the existing perforations. The hole will not stay full as is. So for safety, we propose the following change in the approved procedure: o Put barriers to flow in place o N/D tree. N/U BOPE & test same as per the previously approved 403 form. o Squeeze cement into the existing perforations through the production tubing. of 2 10/16/2003 7:14 AM Unocal Alaska Union Oil Company of California P,O. Box 196247 Anchorage, AK 99519-6247 Telephone (907) 276-7600 UNOCAL Larry Buster Drilling Engineer October 13, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn' Commission Chair Sarah Palin Re: Sundry to Re-Enter & Re-Complete (form 10-403) Steelhead Well M-13 Commissioner Palin: Attached is an Application for Sundry Approvals (form 10-403) for the Steelhead Well M-13 Re-Entry and Re-Completion. We plan to abandon the existing perforations in accordance with the approved Application for Abandonment (form 403): approval No. 303-260. We then plan to Re-complete well M-13 in the SZ-19 gas sand as per the attached procedure. Please call myself at 263-7804 or Skip Coyner at 276-7690 with any questons or concerns you may have. LWB/sc Attachments Larry Buster Drilling Engineer RECE 'VEU OCT 14 20[ 3 Alaska Oil & Gas Cons. Commission Anchorage { STATE OF ALASKA,{ ALASKA OIL AND GAS CONSERVATION t.,dMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: ~'"~ Alter casing: Repair well: Plugging: Time extension: Stimulate: _ Change approved program: ~ Pull tubing: Variance: Perforate: Other: 2. Name of Operator,~ 5. Type of well: 6. Datum elevation (DF or KB) Unocal Corporation Development: x 152' KB Above MSL feet ,, 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well number 1,048' FNL, 453' FWL, Sec. 33-9N-R13W, SM (Leg A-1 Conductor #1 Steelhead Platform) M-13 At top of productive interval 9. Permit number 1.395' FNL, 220' FEL, Sec. 32-T9N-R13W, SM at the Top of SZ-19 Sand 89-49 At effective depth 10. APl number 50- 733-20407 At total depth 11. Field/Pool 2151' FNL, 2,479' FEL, Sec. 32-T9N-R13W, SM McArthur River Field/Grayling Gas Sands 12. Present well condition summary (See Approved 10-403 Form 303-260) Total depth: measured 7,450 feet Plugs (measured) 4,050'- Bridge Plug true vertical 6,543 feet Effective depth: measured 4,050 feet Junk (measured) None true vertical 3,476 feet Planned PBTD: measured 2,800 feet Cement Retainer To be set at +/- 2810' MD BHP _< 1128 psi true vertical 2,507 feet Casing Length Size Cemented Measured depth True vertical depth Structural 480' 34" Drive 480' 480' Conductor 951' 20" 2,230 sx '951' 950' Surface 1,462' 16" 1,400 sx 1,462' 1,447' Intermediate 2,925' 13-3/8" 2,245 sx 2,925' 2,603' Production 7,450' 10-3/4" & 9-5/8" 1,780 sx 7,450' 6,543' Liner Perforation depth: measured 3,570'-3,610', 3,754'-3,778', 3,790'-3,809', 3,948'-4,006' true vertical 3,100'- .... 3,440' .' Tubing (size, grade, and measured depth) 4-1/2", 12.6# L-80 AB Mod BTC @ 4,010' Packers and SSSV (type and measured depth) Baker sC-1L @ 3,491' & 3,625'. Otis XXO SSD @ 407' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 10/20/2003 16. If proposal well verbally approved: Oil: Gas: x Suspended: Name of approv~ \ Date approved Service: 17.I hereby ce~l~a~,tfle f0r~egcil~g is, true and correct to the best of my knowledge. Sig Larry Buster Title: Drilling Engineer Date: 10/13/2003 ~ -" ~ ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represe,.n}ative may witness Approval No. Plug integrity BOP Test ~ Location clearance ..~ -~ I ~7 Mechanical Integrity Test Subsequent form required 10-~---'~''~' ~ tl ¥'~[,~ ~ ~'~' ~"~ ~""'~ ~ A~'~ ~=%~=, ~,~ ~"~, OCT 1 4 2,' 03 Approved by order of the Commissioner ~'~ --'~ Commissioner Date //r ,j/ , Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 0 RIG INA ~", ~,-,~,f, '~-, ~-~ UNOCAL October 13, 2003 Steelhead Platform, Slot A1-1' Well No.' M-13 Trading Bay Unit, McArthur River Unit Re-Completion Summary Proposal Prepared by: S Coyner Objective: Re-complete the well in the SZ-19 gas sand. Current Status: M-13 is currently loaded up and unable to produce against line pressure Current Mechanical Status: RKB: Annulus fluid: · Injection port: · FMXSCSSV: · 10-3/4"x 9-5/8" X-O: · Upper SC-1L Packer: · Perforations: · Lower SC-1L Packer: · X nipple: · XN nipple: · Current PBTD 3570'- 3754'- 3790'- 3948'- 152' (original) RKB is now 160 ft 9.5 PPG KCL brine w/corrosion inhibitor 407' MD, 3.813" ID 416" 498' 3491' 3610' 3625' 3778' 3809' 4O06' 3478' 3659' 4011' MD, 3.813" ID MD MD MD , 5-1/2" Screens: MD MD 5-1/2" Screens: MD MD, 3.813" ID MD, 3.75" NoGo MD (bullplug EOT) 3565'- 3622' MD 3721' - 4010' MD Pre-Rig Work: 1. Check the "Lock-Down-Screws" on the tubing head. 2. Run an MIT-IA to 2000 psi. 3. Test the OA to + 500# against the ECP. 4. Establish an injection rate down the tubing and through the gravel-pack screens. 5. Set a plug in the 3.812 ....X" nipple at 3478' MD. Load the tubing with inlet water. Install a BPV. Secure the well. ~ UNOCAL$ Barriers to flow: a) Kill weight fluid b) PKR & PX plug c) TBG HGR pack off & BPV. Notify the AOGCC field inspector 24 hrs before moving the rig over the well and when ready for the BOPE tests. The field inspector must witness the first tests of the BOP stack, etc. Rig Work: 1. MIRT. N/D tree. N/U and test BOPE. 2. N/U a 4-1/2" landing joint and a full opening safety valve. Retrieve the plug from the "X" nipple at + 3470' MD. 3. Pick up the tubing to be sure the tubing hanger and seal assembly are free. Prepare to squeeze the old perforations. Re-establish injection into the old perforations and gravel-pack scr~e/,ens. 4. Mix and pump + 146 sx (30 bbl) of class "G" cement down the tubing. Displace with 52 bbl of filtered inlet water and squeeze the old perforations. . . After squeezing cement, reverse circulate bottoms up with 9.5 ppg brine. POOH and LID the 4-1/2", tubing. Spool up the dual-encapsulated control lines including the 15 steel bands on the control line. R/U E-Line and a 9-5/8" "shooting nipple". Run a gage ring and junk basket inside the 9-5/8" casing to + 3450'. Tag the TOC from the squeeze job. Set a CIBP at + 3450' MD and test the CIBP to 2000 psi. , 10. Perforate the 9-5/8" at 2820'-24'. POOH with E-Line. R/D the shooting nipple. Establish circulation down the production casing taking returns from the 13-3/8" casing return line. Circulate with 9.5 ppg brine until the 13-3/8" is displaced. RIH and set a RTNR at + 2800' MD. Circulate the 13-3/8" and prepare to circulate cement into the OA through the squeeze holes at 2820'-24'. Cement is calculated to fill: 2800' to 800' MD. Mix and pump: 35 bbl of 10.5 ppg Mud Push XLO spacer followed by 300 sx of 12 ppg LiteCrete (128 bbl) with Gas Block. Displace the cement with 48.7 bbl of brine. After displacing, pull out of the RTNR and dump the last bbl of cement on the RTNR. Pull up and reverse circulate the work string clean. Check for flow. 11. Displace the 9-5/8" casing with clean, KCL water with corrosion inhibitor. POOH. UNOCAL 12. 13. 14. Pick up the packer assembly and completion tubing. Space out the tubing hanger and land same. N/D BOP's. N/U and test the tree. Test the tree and hanger to 3000 psi with the 9-5/8" casing valve open. Displace the tubing with diesel. Drop the ball & rod. Pressure up and set the PKR. Test the tubing to 2000 psi. Test the IA and PKR to 2000 psi. 15. Install a BPV. Secure the well. Release the Rig. Post-Rig Work: 1. After the rig moves off leg A-l, Re-install and test the flowline. Tie "lift gas" into the OA for use later. 2. R/U SLU. Retrieve the ball/rod, and then the RHC sleeve. R/D SLU. 3. R/U E-Line. Perforate the SZ-19 2536'- 2553' MD. RID E-Line. 4. Turn the well over to production. S~ i p(.,~,~0y nt ' Attachments: · Wellbore diagrams · Approved "Plug Back" sundry application (10-403) · BOP Diagram ';TRADIN~ BAY UNIT STEE~HEAD'PLf ' RM WELL £ompletlon 11/8/91 951' 1.46EY 2,925' 0'-498' 498'-7450' 8,874' 80% 94fl, X-56 16', 75~, K-55 Csg. 13-3/8', 61fi, K-55 Csg. 10-3/4% 55.5fl, N-80 CSD. 9-5/8', 43.5~ & 47~, N-80 Cs9. ECP C~g. Pkr. Tubing: 4-1/2% 12.6#, L-BO AB Mod Butt 40;? 407' 410' 416' 4~6' Cnmco Flow Coupling Otis XXD SSD (3.813' ProFile) CaMco F/ow Coupling Otis FMX SCSSV (3,813' .C~MCO FLow Couptin9 -3,478' 3,490' 3,491' 3,494' 3,499' 3,501' 3,503' 3,584' 3,585' 3,565' 3,6;=,p' 3,6B4' 3,685' 3,689' 3,635' 3,637 3,653' 3,659' 3,660' 3,661' 3,781' 4,010' Otis 'X° Nipptej 3.813' ProFile Baker S-i~B Locater Se~l Assembly Baker 96A4-60 SC-1L Packer Baker 190-60 Upper Extension Baker 190-60 Stiding Sleeve Baker 190-60 Seat Bore Baker Lower Extension X-over 7" X 5-l/O' 5-1/8" 15.5~, K-55 Bt~nk Pipe 5-1/~' Wire Wrap Screen, 0,018 Guoge, 80/40 B~ker Bond Se~l 'Bo~e .~ecep~cte B~ker S-~ Sn~p L~tch w~ Se~t'E,xt B~ker 96A4-60 SC-IL P~ker B~ker 190-60 PerForated Uppe~ Ex,ers;on Boke~ 190-60 Semi Bo~e B~kep 190-60 Lower Extension X-ove~ 6-5/8" X 4-1/~' Otis 'XN' Nipple ~/ 3.785' No-Go X-over 4-1/B' X 5-1/8' ' 5-1/~', 17~, N-80 B[~nk Pipe " 5-1/E' ~;~e ~p Screen Bull Plug PERFOBAT[ON~ ']ntervo. l Zone F._T.T ~;pF. ~ 3,570'-3,610' A-6 60' 1;:' 45 3,754~-3,778' B-1 84' lB 45 3,790'-3,809' B-8 19' 12 · 45 ,3,'B48'-4,006' B-3 58' 12. 45 4,050' C:s~ Iron BriFge P~ug 5,845' Long String Cut 5,B50' Shor~ String Cut 5,866' Du~l P~cker PBTD 8 7350' TD 8 7450' Steelhead Platform M-13, Leg A~I, Slot 1 Plug Back Squeeze Job: 30 bbl "G' below SC-1L PKR 4-1/2" Tubing ~g PKR 3570' - 3610' Screens: (0.012 9age wire wrap) 5-I/2" OD, 3565' 3622' SC-IL PKR (0012 gage wire wrap) 3754' 3778~h 3790' 3809' 5-1/2", 3721'-4010' 3948' 4006 9-5t8", 47#, L-80 Casing -~-- 20" Casing 951' MD (950' TVD Casing Stee~head P~atform M-13, Leg A-l, Slot 1 Set a RTNR on DP and Circulate Cement into the OA 2800' - 700' MD 700' _< TOC _< 1000' 1462' MD (1447 TVD) ;~13-3/8' Cas ng RTNR: 2810' MD Squeeze Holes: 2820' - 24' MD MD 2925' MD (2603" TVD) E-Line Set, CIBP at 3450' ME) 4---9-5/8", 47#, L-80 Casing Steelhead Platform M-13, Leg A-l, Slot 1 Run the 3-1/2" Completion Perforate SZ-19, Post-Rig 20" Casing 700' E TOC ~< 1000' 951' MD (950 TVD) Casing pple 1462' MD (1447 FVD) pple w. 2.75": NoGo SZ-19: 2536'-2553' MD ig 2925' MD (2603' FVD) ~- 9-5/8', 47#, L-80 Casing ,;. STATE OF ALASKA ALASKA OIL GAS CONSERVATION CO,,, .... iSSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: x Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Unocal Corporation Development: x 3. Address Exploratory: 7. P.O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. 1,048' FNL, 453' FWL, Sec. 33-gN-R13W, SM (Leg A-1 Conductor #1 Steelhead Platform) At top of productive interval 2,055' FNL, 1,958' FEL, Sec. 32-TgN-R13W, SM At effective depth At total depth 2151' FNL, 2,479' FEL, Sec. 32-TgN-R13W, SM Datum elevation (DF or KB) 152' KB Above MSL feet Unit or Property name Trading Bay Unit Well number M-13 9. Permit number 89-49 10. APl number 50- 733-20407 11. Field/Pool McArthur River Field/Grayling Gas Sands 12. Present well condition summary Total depth: measured true vertical 7,450 feet ' Plugs (measured) 4,050°- 6,543 feet Bridge Plug Effective depth: measured 4,050 feet Junk (measured) None true vertical 3,476 feet Casing' Length Size Cemented Structural 480' 34" Drive Conductor 951' 20" 2,230 sx Surface 1,462' 16" 1,400 sx Intermediate 2,925' 13-3/8" 2,245 sx Production 7,450' 10-3/4" & 9-5/8" ' 1,780 sx Liner Perforation depth: measured 3,570'-3,610', 3,754'-3,778;, 3,790'-3,809', 3,948'-4,006' " irue vertical 3,100'----3,440' Tubing (size, grade, and ~easured depth) Packers and SSSV (type and measured depth) Measured depth 480' 95~' 1,462' 2,925' 7,450' 4-1/2", 12.6~ L-80 AB Mod BTC @ 4,010' Baker SC-1L @ 3,491' & 3,625'. Otis XXO SSD @ ~,07' True vertical depth 480' 950' 1,447' 2,603' 6,543' 13. Attachements 14. 16. Name of appro~ 1.7. I he~ ! Description summary of proposal: x Detailed operations program: BOP sketch: Estimated date for commencing operation 15. Status of well cl~'~'jtl¢~li~n~.''''~*.2~£.. 1i ~' ~::" '" ' If proposal well verbally ~pproved: Oil: ~ ~as: ~ ~uB~ded: SEP 0 9 2003 ~'f°reg°i~rreC~~A I to the best of my knowledge. ALASKA DRLG ~ ~/~ Buster Title: Drilling Engineer Date: 8/29/2003 FOR COMMISSION USE ONLY Conditions of approval: No~f), Commission so represien~ative may witness No. Plug integrity ,_"~% BOP Test ~ Location clearance~ .,~----~--- [ .... ,...~3 -~-~ ~ Mechanical Integrity Test Subsequent fo~ required 10- ~~ , ..... Approved by order of th~Commiss,onor . ~~ Comm,ss,oner ~ate ~... ~'~ Form 10-403 Rev 06/15/88 DUPLICATE SUBMIT I'N TRIPLICATE iu 3/4" uOOOpm 16 3/4' ~ PIPE ~ 10,000psi {}, DOUBLEGATE ~ ~ ~ PIPE " iI . K~,~ I GATE VALVE ~HCR VALVE " 4~/ 16:3/¢" §000psi RISER I I 1 GATE VALVE ,,:' STEELHEAD PLATFORM PREVENTER SC.HENATIC Re: S.teel~ead, M-13 Plug Back Sundry Approval Subject: Re: Steelhead, M-13 Plug Back Sundry Approval Date: Mon, 13 Oct 2003 08:57:06 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Coyner, Vern -ASRC" <coynerv@unocal.com> CC: "Buster, Larry W" <lbuster@unocal.com> Skip and Larry, My presumption was that the well would be killed and stand full in recommending approval of the original sundry. I have a note on our copy regarding "killing the well" prior to ND and NU. Based on depleted zones out there, it is likely as you point out that the hole will not stand full so you can trip pipe. In your message, you state that "barriers to flow will be put in place" which is necessary. Although you are not specific with regard to how you will accomplish the work, I am familiar with some techniques for "squeezing/plugging" operations with the production tubing in place. Your new plan recognizes the need to have control of the well at all times and it appears that you have modified your operation plans to accomplish this. Based on that assessment, I do not have any objection to your proposed change. The Commission still desires to witness the initial stack test for the 16" BOP. Please call with any questions. Tom Maunder, PE AOGCC "Coyner, Vern -ASRC" wrote: Our Application for Sundry Approval to plug back the existing perforations in M-13 was approved on 9/05/03: #303-260. The plug back procedure was as follows: o Kill the well o POOH with production tubing o RIH with cement retainer and work string o Squeeze at least 26 bbl of cement into the existing perforations Due to the well's current geometry, it is not feasible to round trip tubing before we plug off the existing perforations. The hole will not stay full as is. So for safety, we propose the following change in the approved procedure: o Put barriers to flow in place o N/D tree. N/U BOPE & test same as per the previously approved 403 form. o Squeeze cement into the existing perforations through the production tubing. o Once the existing perforations are squeezed off, LID tubing with the hole full. o We will then set a CIBP in the 9-5/8" casing just above the TOC and/or SC-1L PKR at 3491' MD. In modifying the procedure in this way, we still put all of the required elements in place and we do so in a safer manner. Please let us know if this change meets with your approval. Pre-Rig work on Steelhead will commence later this week. Skip Coyner 263-7690 <<AOGCC Drawing Plug Back.ppt>> I Tom Maunder <tom maunder~admin.state.ak.us> ISr. Petroleum Engineer Alaska Oil and Gas Conservation Commission ., 1 of 2 10/13/2003 8:57 AM Steelhead Platform M-13, Leg A-l, Slot 1 Plug Back Operation 4-1/2" Tubing 9-5~8" Casing SC-1L PKR Perf's: 3570'- 3610' Screens' (0.012 gage wire wrap) 5-1/2" OD, 3565' - 3622' Sand\ SC-1L PKR Perf's' 3754'- 3778'" 3790'- 3809' 3948' - 4006'-, Screens' (0.012 gage wire wrap) )' 5-1/2", 3721' - 4010' 9-5/8", 47#, L-80 Casing Steelhead Platform M-13, Leg A-l, Slot 1 Plug Back Operation ~- 9-5/8" Casing ~-- 9-5/8" CIBP SC-1 L PKR Perf's: 3570'- 3610' Screens: (0.012 gage wire wrap) 5-1/2" OD, 3565' - 3622' Sand\ SC-1 L PKR Perf's: 3754'- 3778'~ 3790'- 3809' 3948' - 4006'- Screens' (0.012 gage wire wrap) 5-1/2", 3721' - 4010' 9-5~8", 47#, L-80 Casing Unocal Alaska Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519-6247 Telephone (907) 276-7600 UNOCAL Larry Buster Drilling Engineer August29,2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Commission Chair Sarah Palin Re: Sundry to Abandon (form 10-403) Steelhead Well M-13 Commissioner Palin: Attached is an Application for Sundry Approvals (form 10-403) for the Steelhead Well M-13 Abandonment. We intend to abandon this well and then utilize the slot to drill the Steelhead Well M-13RD. I will be submitting an Application for Permit to Drill for the M-13RD Well under separate cover. Please call myself at 263-7804 with any questions you may have. LWB/s Attachment Larry Buster Drilling Engineer SCAfi~NEi::~:, SE? 1 ~ 2003 ORIGINAL (i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: x Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Unocal Corporation Development: x 152' KB Above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface V/' ¢ / 8. Well number 1,048' FNL, 453' FWL, Sec. 33-9N-R13W, SM (Leg A-1 Conductor #1 Steelhead Platform) M-13 At top of productive interval 9. Permit n.urr'~5'er 2,055' FNL, 1,958' FEL, Sec. 32-T9N-R13W, SM 89-49 At effective depth 10. APl number 50- 733-20407 ~ At total depth 11. Field/Pool 2151' FNL, 2,479' FEL, Sec. 32-T9N-R13W, SM McArthur River Field/Grayling Gas Sands 12. Present well condition summary Total depth: measured 7,450 feet/ Plugs (measured) 4,050'- Bridge Plug true vertical 6,543 feet ~/ Effective depth: measured 4,050 feet Junk (measured) None true vertical 3,476 feet Casing Length Size Cemented Measured depth True vertical depth Structural 480' 34" Drive 480' 480' Conductor 951' 20" 2,230 sx 951' 950' Surface 1,462' 16" 1,400 sx 1,462' 1,447' Intermediate 2,925' 13-3/8" 2,245 sx 2,925' 2,603' Production 7,450' 10-3/4" & 9-5/8" 1,780 sx 7,450' 6,543' Liner Perforation depth: measured 3,570'-3,610', 3,754'-3,778', 3,790'-3,809', 3,948'-4,006' true vertical 3,100'- .... 3,440' Tubing (size, grade, and measured depth) 4-1/2", 12.6# L-80 AB Mod BTC @ 4,010' Packers and SSSV (type and measured depth) Baker SC-1L @ 3,491' & 3,625'. Otis XXO SSD @ 407' 13. Attachements Description summary of proposal: x Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 10/1/2003 16. If proposal well verbally approved: Oil: Gas: x Suspended: Name of ap~ I Date approved Service: Sig~,~m,---'-~ ~ \ ,~L/ Buster Title: Drilling Engineer Date: 8/29/2003 I --' " FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represenJative may witness ~ IApproval No. Plug integrity '~ BOP Test .'~ Location clearance ~] Mechanical Integrity Test Subsequent form required 10- t'~OI~ Approved byorderoftheCommissioner ~/~-~~ ~..-.r-~,~_~. ~,~, Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL /I SUBMIT IN TRIPLICATE Unocal Alaska Business Unit Steeihead Platform Well M-13 Abandonment Procedure to Abandon Gas Well UNOCAL No. Preliminary Procedure Time CUM CUM Estimate Time RIGTime (Hours) (Hours) (Days) Step # PROCEDURE STEPS ABANDON M-13 0.0 0.0 1 Accept Ris and Mob. Cement Equipment. . ~_ ~.1:~,~,,o~,~, 12.0 20.0 0.8 2 NFO and Test 16-3/4" BOPE to 3,000 psi. 26.0 46.0 1.9 3 R/U and Pull 4-1/2" tubin$, seals from SC-IL Packer at 3,491'. * 4.0 50.0 2. ! 4 Circulate Well with.kill weishtfluid and pull and L/D 4-1/2" tubin$. 10.0 60.0 2.5 5 MFtJ 9,5/8'" cement retainer °n'Drill Pipe. P/II Drill Pipe andRlH t° 3400'. 12.0 . 72.0 3.0 6 Mix and pump cement belOw retainer. Circulate Well with kill wt. mud.. , .' 18,0 90.0 3.8 7 POOH~.¥rithDfillPipe,., i , ' ." ..' ' 12.0 102.0 4.3 8 N/D Tuliii~$ Sp601:&.'.NAJ.:~nd"test °n' Casirq~ Spool"', . ' ' : 14.0' .' ' 116.0 4.8 ........... , , ..,.,. .,,,., ' "'""~' "' '"' '"' ' '" ' :' 4 i 9 M/U BO~.9.45/8.' casin$~cat~erassianbly;~lI-i,toiT00'...,,,:, ,.., ;..' · ,.. '. :.'". "it..:.. , r ' ,' ' ' ','''' ', :0 "' 120.0 5.0 10 ' '" ' ' '" ' " .... ' .......... ' ........ " 128.0 5.3 Cut 9~5/8 caslnl~,. ,ClrcUlate.thru. Cut. wlthlall Well~ht mud.. ' ' ..' :' · , '. '. ' . 8.0 ," 11 POOH and L/D 6~isln$.eutter'assembl}};,.., "'.' . '.r.I, ' .. : ' :: ... ', . .' 6:0 .~ 134.0 5.6 ..... ., ,, a' . ' '" ,,, ': '...,...':.'i ...i. '.. ,,,.. ' .'18.0 .. 152.0 6.3 12 UU. ~and:.~l and, L/D,l '0,-3/,4.. .:X 9,5/8 ,,. c sing, ,, . ., ... .... 14 *Ma havb to 'erf0fate'.thrU 'avel" aCk?sCreen'S' if unable' to in'eet thru thm.'rior to ' ' ' .. ' cem~ntdisplacement.,/...:.... ......... , , .~ : .... .,... ,,. ·. ',':.. "' ,., ,,,... ,... 16 ``;:``'..`.`~)&~.~.~i~.'i`<~.i~.~.'~i.```..;~'.g`.:i`~..;~:~:i~:~`¢.:~¢`':.::':*:.`.~`&``;~.i~.in~:~::..~.~`.`:~...:::; .~x.=.:.:~/.'.:,.;...);:.,¢i.,!.i:},:i~.::: i:i2,..¢..~,~'. ...;:/,,..';:i:i:;.:i:,:,=;:~:,':L,:..~.::.',,,..,,:;i,..2::.i,:, :... ,.;:..:j.....,,,:,=, 5,...,'..,;: .:.¢..: ...;,..,2.,=.,.i.. ,.:.::,=.,k · . . .. .. , . 18 ,. ". '.,.'- .' ...,.. ' '.-' ." . '.,,.::?'.i",; .'::.:'. .....: ::,..'"il.'.' ,'.'.... ,. .,.' ...:' '5.' ':.i .' .:' . ' ,:.,.:.' ',.'?: ..'.".:.-' ",' .'" "' .'.i ........... . - . '. '. '. 19 ...':.'....'-:......'./.."....i.:.'..-.'...". .:'...::.;..."..........,,' .' ,..'..:::'...;.'...' :.;..'.:.:. :..!.:..':.....: .'..i ."....'... :'. ". ..... · :.:.".:.'.....,..' '..y.....:... ..... " .. ..'; .... .'.' ..': 20 ?'"' :."": ".',' ."i.':"' ."" :'.'" "."'~.. ":.":'".::.'.?'""' '?" '":;;:?' .?" i'":'"...~'"':""":". "..: :,.'"' :'i '.'"" !"::".: .' ':': ';':" '" "!:".'"" ';'":' ':':.'." '""'.': ,' "'. i' ".... 21 "..' '.." .';:. '.." ...... '..... ...., ...' :," '.' . " . ' ' - .:".'. ' '.' .... '. 22 .:: :.. :..........:.......'..:....-....':'.....'-.:',:. i..:,...i.. :..... . ::',..i...',..: ...-....,.~:'.....' .'.....i ....... .. ::i ..,....... ,.. '...'....:.::.)..: ......i,..:' .:-.....'..'.....'. ...... .,.'.. , ...... . .. ..... .-.:: 25 ' ' 26 ........... ,.. ........ .... ~... ...... ~..~. .... ... ......... .. ',.. i'i.i'..'.~,..:, !'..,i.;.('i:."., :"'~,,,.' ' .... ., 29 ' '.... . ..' '. .,." ...' .... '... '... . . ....... .; .:. .'... . 31 '.:. ' ' ...... . · . . . ,. .. , , 36 ",.. ~ "'.". ,.i.'..' ". '. '::' . ' ;'i . ' .':,'. ''. .~ . ',' ' :' '," 37 41 ,. ,'.'., , :':~ ,:, ' .... .': '. :'.'.,,,',. ],:.' .,...,:'.":,.?:i' '...'./~i, ' ...... . .,, ..., .... . ......... ': ':'. . , 44 . ': ". '.. ' . . . i '. , . . M-13 Abandonment AFE Cost Est.xls Page 1 of 1 8/29/2003 Well M-13 Abandonment Abandonment Cement Volumes Depth Length ff ff 3400-3491 91 3491-3570 79 3570-3610 40 3610-3754 144 3754-3778 24 3778-3790 12 3790-3809 19 3809-3948 139 3948-4050 102 Area 9-5/8" Csg 4-1/2" Tbg 9-5/8" Csg 4-1/2" Tbg 9-5/8" Csg 4-1/2" Tbg 9-5/8" Csg 4-1/2" Tbg 9-5/8" Csg Capacity bbl/ft 0.0744 0.01522 0.0744 0.01522 0.0744 0.01522 0.0744 0.01522 0.0744 Volume bbl 6.77 1.20 2.98 2.19 1.79 0.18 1.41 2.12 7.59 Total 26.23 ;TRADIhi' BAY UNIT STEE-HEAD PL:~FFE]RM WELL Compte tlon 1l/@/91 COs;hq De ~c~;l 951' 1.462' 2,925' 0'-498' 498'-7450' 2,874' 20% 94~t, X-56 Csg. 16% 75t~, K-55 Csg. 13-3/8% 61t~, K-55 Csg. 10-3/4', 55.5ff, N-80 Csg. 9-5/8% 43.5ff 8. 47~t, N-80 Cs9. ECP Cs9, Pkr. Tubing: 4-1/2% 12.6~, L-BO AB Mod Butt 408' 407' 410' 416' 426' Coreco Flow Coupling Otis XXO SSD (3.813' ProFiLe) Cc~mco Flow Coupling Otis FMX SCSSV (3.813" Pr'oFite) Cc~mco Flow CoupLing 3,478' 3,490' 3,491' 3,494' 3,499' 3,501' 3,503' 3,524' 3,585' 3,565' 3,622' Otis 'X' NippLe; 3.813' ProFiLe Bctker S-22 Locater Sectt AssembLy Bc~ker 96A4-60 SC-1L Packer Bc~ker 190-60 Upper Extension Bc~ker 190-60 Stid;ng SLeeve Bc~ker 190-60 Seat Bore Bc~ker Lower Extension X-over 7" X 5-1/2" 5-1/2" 15.5t~, K-55 BLank Pipe 5-1/2" Wire Wrap Screen, 0.018 Gut, ge, 80/40 Baker Bond Se~t 'Bone .l~ecep~acte 3,624' Bo, ker S-28 Snap Lc~tch w~' Sec~t' Ext. 3,625' . Baker 96A4-60 SC-1L P6ker 3,689' Bc~ker 190-60 PerFora±ed Upper Extension 3,635' Bc~ker 190-60 Seat Bore 3,637 B(tker 190-60 Lower Extension 3,653' X-over 6-5/8" X 4-1/8' J I 3,659' Otis °XN' Nipple ~/ 3.785' No-Go ~/ I 3,660' X-over 4-1/2' X 5-1/2' ~3,661' 5-1/2', 17~t, N-80 Bl~nk Pipe ~3,721' 5-1/2" Wire wrap Screen 0.012 Gauge 4,010' Bull Plug ,, PERFORATIONS ' Iotervot Zone FT SPF. Den. ~ 3,570'-3,610' A-6 60' 18 45 //. ~" 3,754'- 3,778' B-t 84' 18 45 ") 3,790'-3,809' B-2 19' 18 45 ' f,,3,948'- 4,006' B-3 58' 12. 45 ' 4,050' Cc~st Iron Bridge P[ug 5,245' Long String Cut 5,850' Shor~ String Cut 5,866' Duc~ Packer PBTD ~ 7350' TD ~ 7450' Revision D~te: 3/85/98 Revised By:, JCH/evo Reason', ~ecomDLetion O~ev,o~s E~evis;on: iO/16/gi 462' ~.925' O'-498' 49B'-7450' -uiaing: 4-]/2', 12.6~, L-80 AB MoO ~ut~ .. .,, _;0°, 94~. X-56 ~.s_~ '!6% 75~, K-55 Csc, 13-3/85 5ira, K-5,=- Csg. 10-3/4'. 55.5#, N-S0 Csg. 9-5/8', 43.5~ & 47~. N-80 Csg. ECP Cscj. Pkr. 3.494' · 3,5.01' 3,503' 3,584' 3,585' 3,565' 3,68B' 3,684' 3,685' 3,689' 3,635' 3,637 3,653' 3,659' 3,660' 3,661' 3,721' 4,010' B:ker 96A4-60 SC-IL ~:ker !90-60 Uooe~ Exzen$ion 2~ker i90-60 Stidin9 S~eeve ~ker !~0-60 Semi Bore ~ke:r ~ower Extens,on ,K-over'. 7' X 5-I/8" ,.,5~, K-55 Blonk P;pe 5-1/8' ~;re Wr~ Screen, 0.018 Guoge, 20/40 B~ker Bon~ Se~[ Bo~ Receptacle Bmker 96A~-60 SC,IL 2raker 190-60 PerPormteo Uope~ Extens;on 2oker 190-60 ~eo~ Bore Broker ~90-60 Lo.er Extens;on 5-[/8', lTW, N-BO Bl~nk 5-118' W,re ~r~ Screen 0,012 3u~l Ptu9 4,050' 5,845' 5,866' C~st Iron Bridge Plug Long Str.ing Cut ~BTD ~' TO ,~ Re: 10-403 M-13 Abandonment ) Subject: Re: 10-403 M-13 Abandonment From: Tom MjllJRder <tom_maund~~~in.state.ak.us> Date: Mo~~2003 09:57:29 -~ To: "Buster, Larry W't<lbusÍ\..l@unocal.com> ) t Ç-.<=\ --ù ~ ~ Larry , The only addition to the retainer would then be to cement your 9-5/8" casing such that you bring the cement above the retainer/whipstock. As I remember our discussion, that is your intent. Tom "Buster, Larry W" wrote: Dear Tom, As per our discussion of last week, I would like to make an addition the M-13 Abandonment Procedure as submitted with the 10-403. After cutting and recovering the 10-3/4" x 9-5/8" casing at +/- 700, we will run and set a 13-3/8" retainer on top of the 9-5/8" stub. We will then pressure test the casing and retainer to 1,500 psi. As per my understanding, this will satisfy the Well Plugging Requirements as outlined in 20 MC 25.112. We still intend to utilize this well bore to drill the proposed M-13RD well. Thank You and Regards, Larry W. Buster Drilling Engineer Unocal Alaska (907) 263-7804 - Office (907) 263-7884 - Fax (907) 351-6730 - Mob. SCANNED OCT 2 8 20D5 1 of 1 11/4/2004 8:42 AM Re: M-13 abandon Subje~;t: Re: M-13 abandon Date: Wed, 03 Sep 2003 14:11:00 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Buster, Larry W" <lbuster@unocal.com> Larry, Thanks for your prompt reply. I know how it is writing out those summary procedures. I will incorporate this information into the review. I will get back to you with any other questions. Tom Maunder "Buster, Larry W" wrote: Hello Tom, 1. You are correct. I wasn't specific enough in the summary procedure I sent to you. We will kill the well prior to rig arrival. We will ensure the well is secure prior to proceeding with the N/D of the tree and the N/U of the BOPE. 2. In the proposed M-13RD well we are targeting shallow gas sands (from - 2, 300' - 2, 700 tvd). I am planning on utilizing a 13-3/8" whipstock to side-track out of the existing casing strings...,~,,,c 9 5/8" c~ing ctub a?'.!- ~nn, ,,,~, cc* ~* my ~ ~ tc '~- ~ ...... ~ '- ~'~ ~" ~ ~ "- - ~v .... ~ ~,,~,,~ / ~ou/d pre,er to se~ ~e ~/ps~oc~ deeper (~e/o~ 2~" cas/n~ at 95~ ~, ~ut t~/s ~ou/d ~a~e ~ d/rect/o~a/well des/~n a~///~ ~o run ~/re//ne too/s)~c~ ~ore d/fficu/L 3. My plans for casing design would be to sidetrack out of the 13-3/8", 16" and 20" casing with 12-1/4" and drill to +/- 1,600' (tvd) where I would set 9-5/8" as a long string back to surface. I would then drill to well TD at +/- 2, 700' (tvd) with 8-1/2" and case as liner. We would then complete with a single stage gravel pack completion with 3-1/2" tubing back to surface. 4. There is a ECP in the 9-5/8" casing at 2,874'. Also, my research shows that the 20", 16" and 13-3/8" casing strings are all cemented back to surface. Let me know if you need any more information. I am working to submit the 10-401 for M-13RD shortly. Regards, Larry ..... Original Message ..... From: Tom Maunder [mai/to:tom maunderC, admin.state, ak. us/ Sent: Tuesday, September 02, 2003 1:28 PM To: Larry Buster Subject: M-13 abandon Hi Larry, /just started looking at the M-13 program and had a couple of questions. Great cement detail sheet, answered all my questions there. 1. In your procedure, you propose to NU the BOP and then kill the well. Won't you be killing the well prior to ND?? 2. You are proposing to cut > the 9,5/8" 250' above the 20" shoe. What are your plans for the RD > portion of the well?? How are you proposing to case the new wellbore > section?? I am looking at the old well file now. Both the 20" and 16" > should be cemented to surface, and it appears that the 9-5/8" has an ECP > about 50' above the 16" shoe. 1 of 2 9/3/2003 2:11 PM Re: M-13 abandon > Look forward to your reply. > Tom Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 9/3/2003 2:11 PI~ ":'",~ STEELHEAD PLATFORM ' .._ /? 3,494' 3.499' · 3,5.01' 3,503' 3,584' 3,585' 3,565' 3°682' 3,684' 3,625' 3,689' 3,6:35' 3,627 3,653' 3,659' 3,660' 3,661' 3,721' 4,010' ~ker' !90-60 Uo~e-Exl;en$ion lBc~ker i90-60 S~ici~ng Sleeve .~aker !~0-60 Se~t Bore ~ke.~ Lo-er Ex,ems,on X-ove~.7' X 5-1/~' 5-1/8" 15.5~, K-55 Bl~nk P;pe 5-1/2' W;~e Wrap ~creen, 0.012 Gu~ge. ~0/40 B~ker Bon~ Se~L Bo~e Recent=cie 3oker S-2~ Sn~0 L~tch ~/ Se~( Ext. B~ker 96A~-60 SC-1L P~ker 3~ker 190-60 Per?or~e~ Uo~er Extension 3oker ~90-60 Seo~ Bore B~ker ~90-60 Lo,er ExPerts;on X-over 6-5/B' X ~-~/~' ~;$ 'XN' Nioo~e ~/ 3.Y25' No-Go X-ove~ ~-1/2' X 5-~/2' 5-~/2'. ~7~, N-BO Brink P~oe 5-1/~' ~,re er~p Screen 0.0~2 G~uge BuLL Ptug PERK ORA l" IONS :~ervo, Zone 3.570'-3,610' A-6 ~¢~0' !_~ 45 3.754'-3,778' B-1 84' !~ 45 3,79D'-3,sag' B-~ !9' 18 45 3.948"-4,oa6' B-3 58' 18 45 4,050' CC~$t Iron Brictge .~tug 5,,~45'' Long Strlng Cut ~.P.c.m ~.hor-. S":.rlng Cut 5,866' Du~ Ptcker Unocal Energy Resource. '}ivision Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL Alaska DOCUMENT TRANSMITTAL May 3, 1994 TO' Larry Grant LOCATION- 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM: Kirk Kiloh LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOC~ TRANSMITIING AS FOLLOWS 1 Sepia each for the following wells: TRADING BAY UNIT '?~ Bev D-28 Production Log c/t>~tt>~ M-19 Production Profile ~?~& M-25 Production Log ct~'"~-~' M-29 Production Log ,:/z---sq M-7 Production Log ~:~-~q vfVI-13 ~roduction Log ~--S"/ M-14 Production Log 6/25/94 11/23/93 11/11/93 11/23/93 3/30/94 4/01/93 4/03/93 PLEASE ACKNOWLEDGE RECFJFI' BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITrAL TO: RECEIVED BY: DATED: DEBRA CHILDERS C/O UNOCAL P.O. BOX 196247 ANCHO~L&GE .A5 995 , 19 Unocal Energy Resourcr"~"'ivision Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL Alaska DOCUMENT TRANSMITTAL April 15, 1994 TO: Larry Grant LOCATION: 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. LOCATION' P.O.BOX 196247~ ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS 1 Blueline each for the following wells: TRADING BAY UNIT 7~" 30 D-28 -Production Log c~0-- 103 M-19 "Production Profile ~?- Cfo M-25 'Production Log c/t -- ~-9 M-29--Production Log c~-%q M-7 ~Production Log 8¢t-qq M-13/Production Log ~q- 5-+ M- 14 / Production LOg 6/25/94 11/23/93 11/11/93 11/23/93 3/30/94 4/01/93 4/03/93 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL TO: RECEIVED BY: DATED: DEBRA CHILDERS C/O UNOCAL P.O. BOX 196247 ANCHO_~AGE, A~ 99519 STATE OF ALASKA '-"" 0 RIG IN /:,'-' ,aKA OIL AND GAS CONSERVATION COMk. ~. ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Harathon 0ii Co - Sub Operator) Development , Exploratory 3. Address Stratigrapnic __ P. O. Box 190247 Anchorage, AK 995~9 Service 4. Location of well at sudace Leg A-1 Cond. #1 Steelhead Platform 1,048' FNL, 453' FWL, .Sec. 33- 9N - 13W - SM Perforate __ Other X Recomp 1 eti on 6. Datum elevation (DF or KB) 152' KB above HSL feet .rU nit.or Prq,oerty acing uay ~lr~c 8. Well numDer H-13 At top of productive interval 2,055' FNL, 1,958' At effective depth FEL, Sec. 32- 9N- 13W- SM Attot~d¥~t~, FNL, 2,479' FEL, Sec. 32-9N- 13W- S" 9. Permit number/approval number 91 - 218/f'~ ,',~. '~ ,r~,- ¢? 10. APl nu r §-20407 Gas Sands Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 951 ' Surface 1,462' Intermediate 2,925 ' Production 498' Liner 6,952' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 4050' cast iron bridge 7 450' 6,' 543' feetfeet Plugs (measured) p 1 ug 7,350' feet Junk(measured) None 6,448' feet Size Cemented Measured depth ~ue veAical depth 20" 2230 sx 951' 950' 16" 1400 sx 1,462' 1447' 13-3/8" 2245 sx 2,925' 2603' 10-3/4" 1760 sx 498' 498' 9-5/8" 7,450' 6543' 3,570' - 3,610' MD 3,105' - 3,134' TVD 3,754' - 3,778' MD 3,245' - 3,264' TVD 3,790' - 3,809' MD 3,273' - 3,288' TVD 3,948' - 4,006' MD 3,396' - 3,442' TVD 4-1/2", 12.6#, L-80 AB Mod Butt. Packers and SSSV ftvI2e and measured depth) . 416' 0tis FMX SSSV; 3491' Baker 96A3-60 SC-1L Pkr.; 3625' Baker 96A4-60 SC-1L Pkr. 13. Stimulation or cement squeeze summary R[~[EiVED 14. Intervals treated (measured) APR 1 G 1992 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Oom~ssiot~ Representative Daily Average Production or Injection Data ~'lG~lorage. Prior to well operation Subsequent to operation OiI-Bbl H-13 L M-13 S Gas-Mcf Water-Bbl Casing Pressure 5,213 J 3 960 Shut in due to sanding 32,047 j 0 700 Tubing Pressure ! ,335 990 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations .X_ 16. Status of well classification as: Oil ~ Gas .__x Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_,_,~ ~--~..~'b~~ Title ~,~, ~ Form 10-404 Re¢..~/15,1~" SUBMIT IN DUPLICATE Attachment #1 Daily Well Operations Report Steelhead Well M-13 07/08/91 Accepted rig f/Well M-29 at 1100 hrs 7/7/91. Skid rig to Well M-13. 07/09/91 Finished skidding to Well M-13. Hooked up all service lines. Made up 3-1/2" tubing as lubricator and made up to M-13 L/S. Bullheaded down long string and killed same. Squeezed long string w/160 SX cement. WOC. 07/10/91 Wait on cement. Tested squeeze job on L/S, did not test. Squeezed long string with 140 SX cement. Wait on cement. 07/11/91 Wait on cement. Tested squeeze job on L/S to 2500 psi. Lost 150 psi in 30 minutes. Rigged up on short string. Bullheaded 100 bbl 34 KCL down tubing. Monitored well. Squeezed short string with 100 sx cement. Wait on cement. 07/12/91 Wait on cement. Tested squeeze job on S/S to 2500 psi. Lost 25 psi in 30 minutes. Shut in wells. Set BPV. Nippled down tree. Nippled up BOPE. Test BOPE. 07/13/91 Tested BOPE. Pulled BPV short string. Attempted lock out SCSSV. RIH with gauge ring. Valve closed. Attempted to lock out SCSSV. RIH with gauge ring. Valve closed. Lost wireline tools. RIH, locked open SCSSV. RIH with jet cutter, cut short string 5250'. POOH SCSSV wireline stuck. Test casing 1600 psi. Picked up BOP. Opened SCSSV. POOH wireline. N/U and test BOP. Pulled BPV, long string. RIH, lock open SCSSV, long string. 07/14/91 RIH with gauge ring on slickline to 600'. RIH with jet cutter on wireline to 5245'. Cutter failed. Reprimed cutter. RIH and cut long string at 5245' WLM. POOH and laid down dual strings of 3-1/2" tubing. Tested casing to 2000 psi. Changed pipe rams. Tested pipe rams. RIH with bit and scraper. Alaska Oil & Gas Cons. Commission Anchorage Daily Summary of Wc . Operations Well M-13 Page 2 07/15/91 Finished RIH with bit and scraper. CBU. POOH. RIH with CET/CBT/GR/CCL. CBT failed. Repair same. CET failed. Logged CBT/GR/CCL 4200'- 3400' at 0 and 500 psi. RIH with CET/GR/CCL logged 4200'-3400' at 0 and 500 psi. Rigged up perforating guns. 07/16/91 Serviced rig while waiting on orders. RIH and perforated casing 4018'-4020'. RIH with cement retainer. Circulated. Set retainer at 3963'. Squeezed perforations with 100 SX cement. POOH. RIH with wireline and perforated casing 3632'-3634'. RIH with cement retainer. Circulated. Set retainer at 3588'. Squeezed perforations with 100 SX cement. Circulated. 07/17/91 POOH with retainer running tool. RIH w/wire line and perforated casing 3550'-3552' DILo RIH with cement retainer. Circulated. Had excessive gas. Circulated through choke. Set retainer at 3496'. Squeeze perforations with 100 SX cement. Circulated. POOH laying down drill pipe. RIH with 4-1/2" tubing. 07/18/91 Finished RIH with 4-1/2" tubing. Landed hanger and tested to 3000 psi. Nippled down BOPE. Nippled up tree. Tested void and tree to 5000 psi. Prepared to stack rig. 07/19/91 Prepared to stack rig. Cleaned all pits. Cleared rig floor. Cleaned and drained all pumps and lines. Prepared tools to be sent in. 07/20/91 Prepared to stack rig. Prepared and inventoried all equipment to be sent in. Checked wiring in top drive, MCCl, and SCRs 1, 2, and 3. Checked emergency generator. Skid rig. Backloaded equipment on boat. 07/21/91 Finished backloading equipment. Released rig crew at 1300 hrs. 7/20/91. 10/17/91 Mobilized crews at 12:00 hrs 10/16/91. Rigged up rig. Skid rig from Well M-15 to Well M-13. Rigged up mud pumps and service lines. RECEIVED APR 1 ro 1992 Alaska Oil & Gas 0OHS. Anchorage Daily Summary of We 3perations Wel 1 M-13 Page 3 RECEIVED 10/18/91 APR 1 6 ,992 Alaska Oil & Gas Cons. (Jommission Anchorage Rigged up on Well M-13. Tested lines and tree. Circulated hole on choke. Nippled down tree. Nippled up BOPE. Function tested BOPE. 10/19/91 Trouble shoot accumulator. Found motor for control valve pump seized up. Tested BOPE to 250/3000 psi. Repaired valves in choke manifold and kill line. Replaced mud seals in top rams. Retested rams and choke manifold. Replaced motor on accumulator. Pulled tubing hanger and laid down 66 joints of 4-1/2" tubing. Changed top rams to 5". Tested top and bottom rams. 10/20/91 BHA. RIH with bit and boot baskets, picking up drill pipe. Washed and reamed cement 3463'-3481'. Isolated ground fault in SCR room. Drilled cement and retainer to 3570'. CBU. Tested squeeze perforations to 1500 psi. Drilled cement and retainer to 3587'. Washed 3587'-3714', no cement. Drilled cement 3714'-3717'. CBU. Tested perforations to 1500 psi. Bled to 700 psi in 30 min. 10/21/91 POOH with bit. RIH with bit and scraper to 3717'. Circulated. POOH. RIH with RTTS to 3565'. Set RTTS. Established injection rate at I BPM and 1900 psi. POOH. RIH with cement retainer to 3580'. Set retainer and squeezed 100 sx cement into perforations at 3632'-3634' with final 1/2 BPM at 1500 psi. POOH. RIH with bit. WOC. 10/22/91 WOC. Serviced rig. RIH. Drilled retainer and cement 3531'-3717'. CBU. Tested squeeze perforations 3632'-3634' to 1500 psi. Drilled cement 3717'-3835'. 10/23/91 Drilled cement 3835'-3961'. Drilled retainer 3961'-3962'. Well flowed. Circulated well on choke. Well dead. CBU. Drill retainer. Washed 3963'-4100'. CBU. Tested squeeze perforations 1500 psi. POOH. RIH with scrapers to 4200'. Circulated. POOH. RIH with CBT/CET/GR. Logged 4200'-3400~. POOH. RIH with gauge ring/junk basket. 10/24/91 Set bridge plug at 4050' DIL. Changed pipe rams to 3-1/2" and tested BOP's. RIH with bit and scrapers, P/U 3-1/2" DP. Displaced hole with inlet water. Scoured DP with sand pill. Pumped dirt magnet pill around. Displaced inlet water wi th 9.1 ppg KCL. Daily Summary of WE Operations Well M-13 Page 4 RECEIVED 10/25/91 APR 1 6 1992 Alaska Oil & Gas Cons. Commissior~ Anchorage ¢irc and filtered KCL. POOH. P/U auger perforating assembly. RIH with same. R/U W/L and correlated guns. Spaced out guns. R/U surface lines. Set packer. Finished R/U surface lines. 10/26/91 Perforated the B-l, B-2, B-3 Grayling Gas Sands. Monitored pressure. Reversed out. Pumped three prepacks for a total of 14,500 lbs of sand in prepacks. POOH with guns. L/D perf assembly. P/U auger gravel pack screens and assembly and RIHo 10/27/91 RIH with auger gravel pack assembly. Augered from 3734' to 3949'. Lost 100 amp and 1OK string weight. POOH. Left I jt blank auger, 13 jts auger screen and auger bit in hole. RIH, tagged TOF at 3635'. Spot 15 bbl HIVIS pill. POOH. P/U spear and RIH. Attempted to latch fish. POOH. RIH w/overshot and latched fish. POOH. 10/28/91 L/D i jt blank auger and 2 joints auger screen. RIH with overshot and latched onto fish. POOH, recovered i jt auger screen. RIH with over shot and latched onto fish. Work same up hole, hole swabbing. Well flowed. Shut in well and circulated on choke. Circulated two bottoms up. SICP 440 psi. SIDPP 0 psi. Bullheaded 40 bbls down back side. CBU on choke. SICP 700 psi, SIDPP O. 10/29/91 Monitored casing press. Increased to 800 psi. Pumped and bled 105 bbl. Casing press dropped to 690 psi. Pumped 10 bbls HEC pill and displace out of DP. Circulated well on choke. Monitored pressures. SICP 0 psi SIDPP 0 psi. CBU. POOH. Recovered all of fish. RIH with bit. Tagged sand at 3780'. Circulated and filtered fluid. 10/30/91 Washed sand from 3780' to 4013' in stages. Sweeping hole with HI-UIS pills. POOH to 3722'. Monitored hole. Losing 4-1/2" bph, RIH, tagged sand at 3945'. Washed sand to 4013', swept hole with 10 bbls HI-UIS pill. Spotted 15 bbls HEC pill. POOH to 3722'. Monitored well, losing 3/4 BPH. Pumped dirt magnet pill around. POOH. Tested BOP's. RIH. 10/31/91 RIH with bit. Tagged fill at 4004'. Washed to 4013'. Circulated and filtered. Monitored well. Tagged fill 4016' POOH. Laid down assembly. Picked up gravel pack assembly. RIH tagged fill at 4013'. Spaced out. Rigged up lines. Broke circulation. Tested lines to 3000 psi. Daily Summary of W~ Operations Wel 1 M-13 Page 5 11/01/91 -'RECEIV 'D A?R 992 Alaska Oil & Gas Cons. Commission Dropped ball. Set packer at 3625'. Tested annulus to 1000 psi. Circulated gravel pack. Final circulating pressure 3/4 BPM at 2000 psi. Monitored well. POOH with gravel pack tools. Ran gravel pack evaluation log 4010'-3500'. RIH with packer plug. Set plug at 3625'. Attempted to test failed. POOH with packer plug. Found equalizer open. RIH with packer plug. 11/02/91 RIH with packer plug. Set plug at 3625'. Tested plug to 1000 psi. Dropped 3 sx sand on plug. Tagged at 3621'. POOH. RIH with TCP perforating assembly. RIH with GR/CCL and correlated guns. Checked free rotation of guns. Rigged up surface lines. Waited on daylighto 11/03/91 Waited on daylight. Tested surface lines. Set perforating packer at 3491'. Tested packer to 300 psi. Fired guns at 1300 psi. Perforated A-6 3570'-3610'. Opened by pass and reversed out. Observed well. Reset packer at 3491'. Established injection rate. Pumped and squeezed 30 sx sand. Reversed out 13.65 sx sand. Augered out of sand. Tagged sand at 3578'. POOH. RIH with plug retrieving tool. Washed sand. Latched plug at 3625' circulated. POOH. RIH with gravel pack assembly. 11/04/91 Finished RIH with gravel pack assembly. Stung into packer at 3625' set packer at 3491'. Tested annulus to 1500 psi. Circulated gravel pack. Final circulating pressure 1/2 BPM at 1350 psi. POOH laying down drill pipe. Laid down drill collars and HWDP from derrick. Changed out top BOP rams and tested. RIH with 4-t/2" tubing. 11/05/91 Finished running 4-1/2" tubing. Spaced out hanger. Spotted inhibited fluid in annulus. Set X plug in methonal injection sub. Closed SCSSV. Set check valve in hanger. Landed tubing. Tested annulus to 1000 psi. Nippled down BOPE. Nipped up tree and flowline. Tested void and tree to 5000 psi. Tested flow line to 3200 psi. 11/06/91 RIH with GS pulling tool. Pulled XX plug at 413'. POOH. RIH with shifting tool. Shift sleeve open at 413'. Had leak in needle valve on well head on methonol line. RIH shift sleeve closed at 413'. Changed out needle valve. RIH shift sleeve open at 413'. Cleared rig floor. Laid down drill pipe from derrick. Drained and cleaned pits. Flushed brake cooling tank. Mothballed rig pump #2. Service and changed dies on iron roughneck. Daily Summary of We,. 'Operations Wel 1 M-13 Page 6 11/07/91 Prepared rig for stacking. Unloaded Well M-13 at 6 MMCFD rate, avg of 2.5 bbls fluid per hour. Recovered 117 bbls fluid last 24 hours. 11/08/91 Finished stacking out rig. Cleaned platform. Rig released from Well M-13 at 1200 hrs 11/01/91. ~shp~m13.doc Alaska Oil & Gas Cons. Com~tss'~'Ot~ Artchor2ge oF'Z. M-13 GRAVEL PACK PUMPING SUMMARY 0 Formation: Gravel: Screen-. B-1,2,3 (101' of perfs) 20/40 Baker low fine 5-1/2", . 012 gage, Baker Weld a. PREPACK -- using gravel infuser, pump (squeeze) sand around auger TCP guns until screenout, and rotate guns out. Repeat until sand top above top shot. 1. Stage #1: SQUEEZE TEST: 1 bpm = 200 psi 2 bpm = 750 psi 3 bpm = 1000 psi 4 bpm = 1400 psi INFUSE SAND: 3.4 bpm; 1200 psi; 3 ppg Screenout at 1500 psi. Total sand pumped = 7,000 lbs. Calc. sand in perfs = 300 lbs (.03 ft~/ft). 2. Stage #2: SQUEEZE TEST: 1 bpm = 700 psi 2 bpm = 1000 psi 3 bpm = 1200 psi INFUSE SAND: 3 bpm; 1200 psi; 3 ppg Screenout at 1400 psi. Total sand pumped = 5,500 lbs. Calc. sand in perfs =.1500 lbs (.35 ft /ft). 3. Stage #3: SQUEEZE TEST: 1 bpm = 750 psi 2 bpm = 1000 psi 3 bpm = 1200 psi . INFUSE SAND: 3 bpm; 1400 psi; 3 ppg Screenout at 1700 psi. Total sand pumped = 2000 lbs. RECEIVED Stage #1 - #3 summary: A?R 1 G 199~ Total sand pumped: 14,500 lbs. Sand in casing: 12,700 lbs. ~ Alaska 0il &Anchomg~Gas Cons. Sand in perfs: 1,800 lbs (0.18 ft-/ft). be CIRCULATING GRAVEL PACK -- following auger screen attempt and wellbore cleanout. · SQUEEZE TEST: 1 bpm = 0 psi 2 bpm = 100 psi 3 bpm = 300 psi 4 bpm = 500 psi 2. CIRC. TEST: 1 bpm = 0 psi 2 bpm = 200 psi 3 bpm = 300 psi 4 bpm = 400 psi 3. INFUSE SAND: 4.5 bpm; 260 psi; 2.7 ppg Screenout at 1 bpm; 1600 psi. Sand behind screen = 8100 lbs. 4. CIRC. RETEST: 0.5 bpm; 2000 psi; no returns . Formation: Gravel: Screen: A-6 (40' of perfs) 20/40 Baker low fine 5-1/2", .012 gage, 20/40 Baker Bond a. PREPACK -- using gravel infuser, pump (squeeze) sand around auger TCP guns until screenout, and rotate guns out. SQUEEZE TEST: 1 bpm = 1000 psi 2 bpm = 1200 psi 2.5 bpm = 1200 psi INFUSE SAND: 2.7 bpm; 1100 psi; 3.25 ppg Screenout at 3 bpm; 1350 psi. Total sand pumped = 1635 lbs. Calc. sand in perfs = 114 lbs (.03 ft /ft). b. CIRCULATING GRAVEL PACK -- following wellbore cleanout. SQUEEZE TEST: 1 bpm = 600 psi 2 bpm = 750 psi 3 bpm = 1000 psi NOTE: injecting into "B" sands, also. 2. CIRC. TEST: 3. INFUSE .SAND: i bpm = 150 psi RECE VE ) 3 bpm = 400 psi 3.3 bpm; 200 psi; 2.86 ppg Screenout at 0.5 bpm; 1400 p~ek. 0i~&SasQ0~$-G0m~$~0n Sand behind screen = 2450 lb~T~''~ Ancho[~ 4. cIRC. RETEST: 0.25 bpm; 1350 psi; no returns 5. CLOSE SLIDING SLEEVE AND TEST: 0.0 bpm; 1400 psi. TRADING BAY L ST£ELHEAD PLATFSRM 'LL ~om 1118191 951' ~0', 9a~, X-56 Cst,. 1.468' 16', 7~I~, K-~ Cso. 2,925' 13-3/8', 61~, K-55 Usg. 0'-498' 10-3/4', 5=~,5~, N-80 Csg, 498'-7450' 9-5/8', 43.5~ & 47~, N-BO Csg. 2,874' ECP Csg. Pkr. Tubing: 4-1/2', 12.6t~, L-80 AB Naa Butt 402' 407' 410' 416' 426' Camco FLow CoupLing Otis XXO SSD (3,81,3' P~oF~Le) Camco FLow CoupLing Otis FMX SCSSV (3.813' ProFiLe) Camco FLow CoupLing 3,478' 3,490' 3,491' 3,494' 3,499' 3,501' 3,503' 3,524' 3,525' 3,565' 3,682' 3,624' 3,625' 3,629' 3,635' 3,637 3,653' 3,659' 3,660' 3,661' 3,721' 4,010' Q,is 'X' Nipple; 3,813' P,'-oFite 3aker 5-22 LocaTer Seal assemoLy 3aker 96A4-60 SC-iL 3aker !':30-60 Upper Ex'[en$ion 3aker t90-60 SLiding SLeeve 3aker 190-60 Sea[ Bore Baker Lower Exten$;on X-over 7' X 5-1,/2' 5-1./2' 15.51~, K-55 BLank Pioe 5-1,/2° ~/ire ~/rap Screen, 0.012 Guage, 20/40 Baker Bonct Se~ Bore Receptacle 3~ker S-22 Sn~p L~tch w/ Se~ Ex* B~ker 96A4-60 SC-1,L Poker 3~ker ~90-60 PerForcte~ Upper Ex,ers;on 3~ker 190-60 Se~l Bore B~ker ]90-60 Lower Extension X-over 3t~s 'XN' Nipple w/ 3.725' No-Go X-over 4-1/2' X 5-1/2' 5-i/~', i7~, N-BO B~nk Pipe 5-1/~' ~;re wrap Screen 0.012 G~uge 3ull Plug 4,050' 5,245' 5,250' 5,866' PERFORATfONS Int~'rvat Zone ~__T SPF Des, 3,570'-3,610' A-6 60' 12 45 3,754'-3,778' B-1 24' 12 45 3,790'-3,809' B-2 19' 12 45 3,948'-4,006' B-3 58' 18 45 RECEIVED Long String Cut Alaska Oil & Gas [;0ns, uummbsl Short S~ring Cut Dual Packer Anchorage gBTD e 7350' TD @ 7450' Revision Date: 3/25/92 Revise,.~ By: JCM/evo Reason: Recomptetion Ppevious Revision: 10/16/91 STATE OF ALASKA 0 # I G I ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging Pull tubing j Alter casing m Repair well __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Harathon 0il Co - Sub 0pera~.or) De._vel.opm. ent_~_X / ~-xplora[ory 3. Address _ _[_ Stratigraphic P. 0. Box 190247 Anchorage, AK 995lL9 Servicem 4. Location of well at surface Leg A-1 Cond. #1 Steelhead Platform 1,048' FNL, 453' FWL, Sec. 33- 9N - 13W - SM Perforate __ Other_,~. Recomp] eti on 6. Datum elevation (DF or KB) 152' KB above HSL .rU nit.or Property a(]~ ng uay 8. Well number M-13 At top of productive interval 2,055' FNL, 1,958' At effective depth FEL, Sec. 32- 9N- 13W- SM At tot~ ,d¥1~t~, 9. Permit number/approval number 91-218 / ,'~./,~ ;¢_.. ~ .¢~- ~ APl nu r 10. 50-- ~§-20407 FNL, 2,479' FEL, Sec. 32- 9N - 13W- SM feet 1 hlel IN O ~ra~g Gas Sands Pool 12. Present well condition summary Total depth: measured true vertical 7 450' ' feet Plugs (measured) 6,543' feet 4050' cast iron bridge plug Effective depth: measured true vertical 7,350 ' feet Junk (measured) 6,448' feet None Casing Length Structural Size Cemented Measured depth True vertical depth Conductor 951' 20" 2230 sx Surface 1,462' 16" 1400 sx Intermediate 2,925' 13-3/8" 2245 sx Production 498' 10- 3 / 4" 1760 S X Liner 6,952' 9-5/8" 951' 950' 1,462' 1447' 2,925' 2603' 498' 498' 7,450' 6543' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3,570' - 3,610' MD 3,754' - 3,778' MD 3,790' - 3,809' MD 3,948' - 4,006' MD 3,105' - 3,134' TVD 3,245' - 3,264' TVD 3,273' - 3,288' TVD 3,396' - 3,442' TVD 4-1/2", 12.6#, L-80 AB Mod Butt. Packers and SSSV ¢~:~ and measured Ce, pth, b,) , 416' Otis SSSV; 349t' ~aKer 96A3-60 SC-IL Pkr.; 3625' Baker~~-~l~lS~/br~kr. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure I\L~,;,L I V I-~./ APR 1 0 1992 Alaska 0il & 6as Cons, Commissio" Anchoraoa 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbt Gas-Mcf Water-Bbl Casing Pressure M-13 L 5,213 ~ 3 960 M-13 S Shut in due to sanding Tubing Pressure 1,335 32,047 - 0 700 990 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas .__x Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~., (~ ,.,..~ Title ~7'r--~ % ~-~,~j, Form 10-404 /15~ Date SUBMIT IN DUPLICATE Attachment #1 Daily Well Operations Report Steelhead Well M-13 07/08/91 Accepted rig f/Well M-29 at 1100 hrs 7/7/91. Skid rig to Well M-13. 07/09/91 Finished skidding to Well M-13. Hooked up all service lines. Made up 3-1/2" tubing as lubricator and made up to M-13 L/S. Bullheaded down long string and killed same. Squeezed long string w/160 SX cement. WOC. 07/10/91 Wait on cement. Tested squeeze job on L/S, did not test. Squeezed long string with 140 SX cement. Wait on cement. 07/11/91 Wait on cement. Tested squeeze job on L/S to 2500 psi. Lost 150 psi in 30 minutes. Rigged up on short string. Bullheaded 100 bbl 34 KCL down tubing. Monitored well. Squeezed short string with 100 sx cement. Wait on cement. 07/12/91 Wait on cement. Tested squeeze job on S/S to 2500 psi. Lost 25 psi in 30 minutes. Shut in wells. Set BPV. Nippled down tree. Nippled up BOPE. Test BOPE. 07/13/91 Tested BOPE. Pulled BPV short string. Attempted lock out SCSSV. RIH with gauge ring. Valve closed. Attempted to lock out SCSSV. RIH with gauge ring. Valve closed. Lost wireline tools. RIH, locked open SCSSV. RIH with jet cutter, cut short string 5250'. POOH SCSSV wireline stuck. Test casing 1600 psi. Picked up BOP. Opened SCSSV. POOH wireline. N/U and test BOP. Pulled BPV, long string. RIH, lock open SCSSV, long string. 07/14/91 RIH with gauge ring on slickline to 600'. RIH with jet cutter on wireline to 5245'. Cutter failed. Reprimed cutter. RIH and cut long string at 5245' WLM. POOH and laid down dual strings of 3-1/2" tubing. Tested casing to 2000 psi. Changed pipe rams. Tested pipe rams. RIH with bit and scraper. RECEIVED APR 1 0 199 , Alaska Oil & Gas Cons. GommiSsio~ Anchorage Daily Summary of Wel, Operations Well M-13 Page 2 07/15/91 Finished RIH with bit and scraper. CBU. POOH. RIH with CET/CBT/GR/CCL. CBT failed. Repair same. CET failed. Logged CBT/GR/CCL 4200'- 3400' at 0 and 500 psi. RIH with CET/GR/CCL logged 4200'-3400' at 0 and 500 psi. Rigged up perforating guns. 07/16/91 Serviced rig while waiting on orders. RIH and perforated casing 4018'-4020'. RIH with cement retainer. Circulated. Set retainer at 3963'. Squeezed perforations with 100 SX cement. POOH. RIH with wireline and perforated casing 3632'-3634'. RIH with cement retainer. Circulated. Set retainer at 3588'. Squeezed perforations with 100 SX cement. Circulated. 07/17/91 POOH with retainer running tool. RIH w/wire line and perforated casing 3550'-3552' DIL. RIH with cement retainer. Circulated. Had excessive gas. Circulated through choke. Set retainer at 3496'. Squeeze perforations with 100 SX cement. Circulated. POOH laying down drill pipe. RIH with 4-1/2" tubing. 07/18/91 Finished RIH with 4-1/2" tubing. Landed hanger and tested to 3000 psi. Nippled down BOPE. Nippled up tree. Tested void and tree to 5000 psi. Prepared to stack rig. 07/19/91 Prepared to stack rig. Cleaned all pits. Cleared rig floor. Cleaned and drained all pumps and lines. Prepared tools to be sent in. 07/20/91 Prepared to stack rig. Prepared and inventoried all equipment to be sent in. Checked wiring in top drive, MCCl, and SCRs 1, 2, and 3. Checked emergency generator. Skid rig. Backloaded equipment on boat. 07/21/91 Finished backloading equipment. Released rig crew at 1300 hrs. 7/20/91. 10/17/91 Mobilized crews at 12:00 hrs 10/16/91. Rigged up rig. Skid rig from Well M-15 to Well M-13. Rigged up mud pumps and service lines. Daily Summary of Weli Operations Wel 1 M-13 Page 3 10/18/91 Rigged up on Well M-13. Tested lines and tree. Circulated hole on choke. Nippled down tree. Nippled up BOPE. Function tested BOPE. 10/19/91 Trouble shoot accumulator. Found motor for control valve pump seized up. Tested BOPE to 250/3000 psi. Repaired valves in choke manifold and kill line. Replaced mud seals in top rams. Retested rams and choke manifold. Replaced motor on accumulator. Pulled tubing hanger and laid down 66 joints of 4-1/2" tubing. Changed top rams to 5". Tested top and bottom rams. 10/20/91 BHA. RIH with bit and boot baskets, picking up drill pipe. Washed and reamed cement 3463'-3481'. Isolated ground fault in SCR room. Drilled cement and retainer to 3570'. CBU. Tested squeeze perforations to 1500 psi. Drilled cement and retainer to 3587'. Washed 3587'-3714', no cement Drilled cement 3714'-3717'. CBU. Tested perforations to 1500 psi. Bled t~ 700 psi in 30 min. 10/21/91 POOH with bit. RIH with bit and scraper to 3717'. Circulated. POOH. RIH with RTTS to 3565'. Set RTTS. Established injection rate at I BPM and 1900 psi. POOH. RIH with cement retainer to 3580' Set retainer and squeezed 100 sx cement into perforations at 3632'-3634' wit~ final 1/2 BPM at 1500 psi. POOH. RIH with bit. WOC. 10/22/91 WOC. Serviced rig. RIH. Drilled retainer and cement 3531'-3717'. CBU. Tested squeeze perforations 3632'-3634' to 1500 psi. Drilled cement 3717'-3835'. 10/23/91 Drilled cement 3835'-3961'. Drilled retainer 3961'-3962'. Well flowed. Circulated well on choke. Well dead. CBU. Drill retainer. Washed 3963'-4100'. CBU. Tested squeeze perforations 1500 psi. POOH. RIH with scrapers to 4200'. Circulated. POOH. RIH with CBT/CET/GR. Logged 4200'-3400'. POOH. RIH with gauge ring/junk basket. 10/24/91 Set bridge plug at 4050' DIL. Changed pipe rams to 3-1/2" and tested BOP's. RIH with bit and scrapers, P/U 3-1/2" DP. Displaced hole with inlet water. Scoured DP with sand pill. Pumped dirt magnet pill around. Displaced inlet water with 9.1 ppg KCL. Daily Summary of Wel, Operations Well M-13 Page 4 10/25/91 RECEIVED APR 1 0 199~ Alaska Oil & Gas Cons. Comm~ss~O'n Anchorage Circ and filtered KCL. POOH. P/U auger perforating assembly. RIH with same. R/U W/L and correlated guns. Spaced out guns. R/U surface lines. Set packer. Finished R/U surface lines. 10/26/91 Perforated the B-l, B-2, B-3 Grayling Gas Sands. Monitored pressure. Reversed out. Pumped three prepacks for a total of 14,500 lbs of sand in prepacks. POOH with guns. L/D perf assembly. P/U auger gravel pack screens and assembly and RIH. 10/27/91 RIH with auger gravel pack assembly. Augered from 3734' to 3949'. Lost 100 amp and 1OK string weight. POOH. Left i jt blank auger, 13 jts auger screen and auger bit in hole. RIH, tagged TOF at 3635'. Spot 15 bbl HIVIS pill. POOH. P/U spear and RIH. Attempted to latch fish. POOH. RIH w/overshot and latched fish. POOH. 10/28/91 L/D i jt blank auger and 2 joints auger screen. RIH with overshot and latched onto fish. POOH, recovered i jt auger screen. RIH with over shot and latched onto fish. Work same up hole, hole swabbing. Well flowed. Shut in well and circulated on choke. Circulated two bottoms up. SICP 440 psi. SIDPP 0 psi. Bullheaded 40 bbls down back side. CBU on choke. SICP 700 psi, SIDPP O. 10/29/91 Monitored casing press. Increased to 800 psi. Pumped and bled 105 bbl. Casing press dropped to 690 psi. Pumped 10 bbls HEC pill and displace out of DP. Circulated well on choke. Monitored pressures. SICP 0 psi SIDPP 0 psi. CBU. POOH. Recovered all of fish. RIH with bit. Tagged sand at 3780'. Circulated and filtered fluid. 10/30/91 Washed sand from 3780' to 4013' in stages. Sweeping hole with HI-UIS pills. POOH to 3722'. Monitored hole. Losing 4-1/2" bph, RIH, tagged sand at 3945'. Washed sand to 4013', swept hole with 10 bbls HI-UIS pill. Spotted 15 bbls HEC pill. POOH to 3722' Monitored well, losing 3/4 BPH. Pumped dirt magnet pill around. POOH. Tested BOP's. RIH. 10/31/91 RIH with bit. Tagged fill at 4004' Washed to 4013'. Circulated and filtered. Monitored well. Tagged ~ill 4016' POOH. Laid down assembly. Picked up gravel pack assembly. RIH tagged fill at 4013'. Spaced out. Rigged up lines. Broke circulation. Tested lines to 3000 psi. Daily Summary of Wel, Jperations Wel 1 M-13 Page 5 11/01/91 Dropped ball. Set packer at 3625'. Tested annulus to 1000 psi. Circulated gravel pack. Final circulating pressure 3/4 BPM at 2000 psi. Monitored well. POOH with gravel pack tools. Ran gravel pack evaluation log 4010'-3500'. RIH with packer plug. Set plug at 3625'. Attempted to test failed. POOH with packer plug. Found equalizer open. RIH with packer plug. 11/02/91 RIH with packer plug. Set plug at 3625'. Tested plug to 1000 psi. Dropped 3 sx sand on plug. Tagged at 3621'. POOH. RIH with TCP perforating assembly. RIH with GR/CCL and correlated guns. Checked free rotation of guns. Rigged up surface lines. Waited on daylight. 11/03/91 Waited on daylight. Tested surface lines. Set perforating packer at 3491'. Tested packer to 300 psi. Fired guns at 1300 psi. Perforated A-6 3570'-3610'. Opened by pass and reversed out. Observed well. Reset packer at 3491'. Established injection rate. Pumped and squeezed 30 sx sand. Reversed out 13.65 sx sand. Augered out of sand. Tagged sand at 3578'. POOH. RIH with plug retrieving tool. Washed sand. Latched plug at 3625' circulated. POOH. RIH with gravel pack assembly. 11/04/91 Finished RIH with gravel pack assembly. Stung into packer at 3625' set packer at 3491'. Tested annulus to 1500 psi. Circulated gravel pack. Final circulating pressure 1/2 BPM at 1350 psi. POOH laying down drill pipe. Laid down drill collars and HWDP from derrick. Changed out top BOP rams and tested. RIH with 4-1/2" tubing. 11/05/91 Finished running 4-1/2" tubing. Spaced out hanger. Spotted inhibited fluid in annulus. Set X plug in methonal injection sub. Closed SCSSV. Set check valve in hanger. Landed tubing. Tested annulus to 1000 psi. Nippled down BOPE. Nipped up tree and flowline. Tested void and tree to 5000 psi. Tested flow line to 3200 psi. 11/06/91 RIH with GS pulling tool. Pulled XX plug at 413'. POOH. RIH with shifting tool. Shift sleeve open at 413'. Had leak in needle valve on well head on methonol line. RIH shift sleeve closed at 413'. Changed out needle valve. RIH shift sleeve open at 413'. Cleared rig floor. Laid down drill pipe from derrick. Drained and cleaned pits. Flushed brake cooling tank. Mothballed rig pump #2. Service and changed dies on iron roughneck. Daily Summary of Wel, Jperations Well M-13 Page 6 11/07/91 Prepared rig for stacking. Unloaded Well M-13 at 6 MMCFD rate, avg of 2.5 bbls fluid per hour. Recovered 117 bbls fluid last 24 hours. 11/08/91 Finished stacking out rig. Cleaned platform. Rig released from Well M-13 at 1200 hrs 11/01/91. ~shp~m13.doc RECEIVED APR 1 0 1992, Alaska Oil & Gas Cons. L;ommissio~'~ Anchorage ...... / M-13 GRAVEL PACK PUMPING SUMMARY ® Formation: Gravel: Screen: B-1,2,3 (101' of perfs) 20/40 Baker low fine 5-1/2", .012 gage, Baker Weld a® PREPACK -- using gravel infuser, pump (squeeze) sand around auger TCP guns until screenout, and rotate guns out. Repeat until sand top above top shot. 1. Stage #1: SQUEEZE TEST: 1 bpm = 200 psi 2 bpm = 750 psi 3 bpm = 1000 psi 4 bpm = 1400 psi INFUSE SAND: 3.4 bpm; 1200 psi; 3 ppg Screenout at 1500 psi. Total sand pumped = 7,000 lbs. Calc. sand in perfs = 300 lbs (.03 ftg/ft). 2. Stage #2: SQUEEZE TEST: 1 bpm = 700 psi 2 bpm = 1000 psi 3 bpm = 1200 psi INFUSE SAND: 3 bpm; 1200 psi; 3 ppg Screenout at 1400 psi. Total sand pumped = 5,500 lbs. Calc. sand in perfs = 1500 lbs (.35 ft /ft). 3. Stage #3: SQUEEZE TEST: 1 bpm = 750 psi 2 bpm = 1000 psi 3 bpm = 1200 psi INFUSE SAND: 3 bpm; 1400 psi; 3 ppg Screenout at 1700 psi. Total sand pumped = 2000 lbs. 4. Stage #1 - #3 summary: Total sand pumped: Sand in casing: Sand in perfs: 14,500 lbs. 12,700 lbs. 1,800 lbs (0.18 ft-/ft). CIRCULATING GRAVEL PACK -- following auger screen attempt and wellbore cleanout. · SQUEEZE TEST: 1 bpm = 0 psi 2 bpm = 100 psi 3 bpm = 300 psi 4 bpm = 500 psi 2. CIRC. TEST: 1 bpm = 0 psi 2 bpm = 200 psi 3 bpm = 300 psi 4 bpm = 400 psi 3. INFUSE SAND: 4.5 bpm; 260 psi; 2.7 ppg Screenout at 1 bpm; 1600 psi. Sand behind screen = 8100 lbs. 4. CIRC. RETEST: 0.5 bpm; 2000 psi; no returns · Formation: Gravel: Screen: A-6 (40' of perfs) 20/40 Baker low fine 5-1/2", .012 gage, 20/40 Baker Bond a. PREPACK -- using gravel infuser, pump (squeeze) sand around auger TCP guns until screenout, and rotate guns out. · SQUEEZE TEST: 1 bpm = 1000 psi 2 bpm = 1200 psi 2.5 bpm = 1200 psi INFUSE SAND: 2.7 bpm; 1100 psi; 3.25 ppg Screenout at 3 bpm; 1350 psi. Total sand pumped = 1635 lbs. Calc. sand in perfs = 114 lbs (.03 ft /ft). b. CIRCULATING GRAVEL PACK -- following wellbore cleanout. SQUEEZE TEST: 1 bpm = 600 psi 2 bpm = 750 psi 3 bpm = 1000 psi NOTE: injecting into "B" sands, also. 2. CIRC. TEST: 1 bpm = 150 psi 2 bpm = 200 psi 3 bpm = 400 psi 3. INFUSE SAND: 3.3 bpm; 200 psi; 2.86 ppg Screenout at 0.5 bpm; 1400 psi. Sand behind screen = 2450 lbs. 4. CIRC. RETEST: 0.25 bpm; 1350 psi; no returns 5. CLOSE SLIDING SLEEVE AND TEST: 0.0 bpm; 1400 psi. TRADING BAY Uh'~" STEELHEAD PLATFORM g. _L M-13 RECEIVED APR 10 t9 2 Alaska Oil & Bas Cons, ~ommissm~'~ Anchorage CompLetion 11/8/91 Casln.c) DeCal[ 951' 1.462' 2,925' 0'-498' 49B'-7450' 2,874' 20', 94~t, X-56 Csg. ]6', 75t~, K-55 Cs9, 13-3/8', 61t% K-55 EsS. 10-3/4', 55.5~, N-80 Csg. 9-5/8', 43.5t~ & 47~t, N-80 Csg. ECP Csg. Pkr. Tubing: 4-1/2', 12.6~, L-80 AB Mod Butt 402' 407' 410' 416' 486' Camco FLow Couptin9 Fl±is XXO SSD (3.813' ProFiLe) Camco FLow Couptln9 E]±;s FMX SCSSV (3.8]3' ProFile) Camco FLow CoupLing 3,478' 3,490' 3,491' 3,494' 3,499' 3,501' 3,503' 3,524' 3,585' 3,565' 3,682' 3,684' 3,685' 3,689' 3,635' 3,637 3,653' 3,659' 3,660' 3,661' 3,781' 4,010' Otis 'X' NippLe; 3,813" ProFiLe Baker S-22 Locater Seat AssembLy Baker 96A4-60 SC-]L Packer Baker ]90-60 Upper Extenslon Bakem 190-60 S~idlng SLeeve Baker 190-60 Seal Bore Baker Lowem Extenslon X-over 5-1/2' 15,5t~, K-55 BLank Pipe 5-1/2' %/ire ~/rap Screen, 0.012 Ouage, E]O/40 BoNer Bond Seat Bore ReceptacLe Baker S-22 Snap Latch w/ Seal Ext, Baker 96A4-60 SC-iL Paker Baker 190-60 PerRora±ed Upper Extenslon Baker 190-60 Seal Bore Baker ]90-60 Lower Extension X-over 6-5/8' X 4-1/8' FILls 'XN' NippLe w/ 3.725' No-Go X-over 4-1/2' X 5-1/2' 5-1/2', 17ti, N-80 Blank Pipe `5-1/2' ~/ire wrap Screen 0.012 Gauge BuLl PLu9 PERFBRAT[ONS Interva[. Zone E_T_T SPF De.g. 3,570'-3,610' A-6 60' ]2 45 3,754'-3,778' B-1 24' 12 45 3,790'-3,809' B-8 19' ]8 4.5 3,948'-4,006' B-3 58' 12 45 4,050' 5,245' 5,250' 5,866' Cast Iron Bridge Ptu9 Long String Cut Short String Cut Dual Packer PBTD 8 7350' TD @ 7450' Revision Date: 3/85/98 Revised By: JCM/evo Reason: Recomptetion Previous Revision: 10/16/91 SENT BY'Marathon Otl Company '10-16-91 ;12'44PM ; Anchor STEELHEAD 8-13 RECOMPLETION MARATilON AFE ~8373-1 PROCEDURE CURRENT STATUS: Abandoned dual 0-6 and D-16A,BC gas producer OBJECTIVE: Complete as a single A-6, B-l/2, and .B-3 gas p~roducer. Auger gravel pack the B-1/2 and B-3 sands. Circulate gravel pack the A-6 sand. TEST CEMENT SQUEEZES, SET BRIDGE PLUG, AHD CLEAll HOLE OCT 1 5 1991 ~)lJ)lL& Gas Cons. Go 1. Inspect and interna!ly, clean 5"~ 19.5~, 4-1/2" il~m~i~lll~str~ng prior to loadout. If additional squeeze work is required, ~~gcr'lbed below, change out the ~rkstring with clean 3-1/2", 13.3~ IF drillpipe prior to Step Set BPV. ND tree. NU and test BOPE. Pull BPV. Run landing joint and screw into hanger, unseat hanger and CBU with drill water. POOH with 4-1/2" 12.6# L-80 AB Mod Butt tubing. Send adapter flange and tubing hanger to FMC to drill ports for methanol injection line. Also, send ~roduction choke in for'.redressing. Send tubing to beach for cleaning and inspection. PU workstr~ng0 junk baskets, and 8.5" bit and RI~. . Drill retainer at 3496' DPIq and clean out to 3588'. Test squeeze perfs at 3550'- 3552' to ~500 psi. Re-squeeze as needed. , Drill retainer at 3588' DPN and clean out to 3600'. Test squeeze perfs at 3632'- 3634' to 1500 psi. Re-squeeze as needed. . Drill retainer at 3963' DPM and clean out to 4100'. Test squeeze perfs at 4018'- 40:)0' to 1500 psi. Re-squeeze as needed. 1 Clean wellbore with bit and casing scraper prior to logging. POOH. Do not d'~e connect(ohs when PO0it. 1 )U: ele'~t~-lc line. Run CBL/C£T from 4100' to 3500' with 1500 psi on casing. Eve;l.~l~e ~eed foe additional squeeze work. 8~ RI#:wttb gauge ring and junk basket on electric line to 4100' DIL. POOH, (Gauge 'ring to be supplied by the service company providing the bridge plug.) 9~ RIH with cast iron bridge plug on electric 'line and set at 4050~ DIL. POOH & RD, I0. Prep.a~e completion fluid: 8.5 pp~ fresh water + 3k KCl For the remainder of the reco~pletion, al. fluids pumped into t~e well must be filtered to 2 microns absolute. 11. RIH with bit and dual casing scrapers. Do not dope connections RIH or POOH. ~horoughly scrape casing ~ith reciprocating motion from surface to SP. Using the ~ravel ~nfuser, clean workstring by pumping 3 ppg 20/40 frac ~rade sand at 4 BPM to end of workstring and reversing out with 2 to 3 str]n~ volumes or until returns are clean. Circulate filtered brine · _i, .......... ~ lena LL~ note DPH E×=enoeo ~age z, 1 PERFORATE AND PREPACK B-l, B-2, and B-.3 i2. Conduct safety and operational proced?re meeting with rig, service company, and MOC personnel prior to p~cking up the guns and prior to POOH with the guns. ~. MU and RIH with auger perforating guns (6", 12 SPF, 32 gram carrot free gravel pack charges), auger blank spacer$,'and associated annulus pressure firing system as described in Figure 1. Include a bundle carrier with gauges for this perforation run. It is critical to know downhole RE E!VED SF~N~ BY:Marat, hon 0tl Company ;10-16-01 ;12:4~1-'~ ; Well M-13 Recorapletton Procedure Page 2 pressures prior to PU the auger screen assembly. Fill workstring for a 300 psi underbalance (1135 psi workstring hydrostatic). 14. Position guns on depth by tagging BP and picking-up to desired depth. Space out with s!ngles and pups. Note DPM vs DIL for use in depth control for screen augerlng, 15. Record' PU and SO weights. Using top drive, determine amount of torque to maintain free rotation at 30, 60, and 80 RPM, Set packer by slacking off. RU and test flow control head and surface lines to Baker test manifold and the rig's choke manifold to 3000 psi. 16. Close annular preventer and pressure annulus to ~iO0 psi to test packer. Continue increasing pressure to 1000 psi to fire guns. Monitor flow into workstring with bubble bucket. SI well when liquid returns are observed at surface. Obtain 30 min. of pressure data, 17. Bleed annulus to 200 psi, and slowly pickup workstring to open packer bypass. Reverse circulate through rig manifold and gas buster to kill well. Continue reversing and filter until returns are clean. Monitor fluid loss throughout reversing procedure. SD pumps.. Monitor fluid loss. OD not spot any LCM unless unable to keep up with fluid loss rate. Drain and flush any debris from gas buster. 18. RD flow lines. Using top drive, check rotating torque again at 30, 60, and 80 RPM. Continue rotating for a minimum of 10 min. ~ 30 RPM to push remaining fines into rathole. 19. Close packer bypass by slacking off, install surface lines and squeeze manifold, and test to 3000 psi. Establish injection (squeeze) rates at 1, 2, 3, and 4 BPM. Record pressures. Determine infused sand slurry rate and concentration based on these pressures. The prepack should be pumped without exceeding frac pressure. RU lines to minimize downtime between screenout and reversing out. ~pen ~acker bypass by picking up workstring. E)tab!ish circulation while infusing Baker 20/40 Low Fine sand, When sand ~s mthin 10 bbls of the packer, slackoff to close bypass and squeeze sand slurry into perfs. Close hydril and pressure casing to 200 psi. Continue pumping until screenout occurs or until sufficient sand volume has been pumped to cover the auger blank spacer {see Figure 2). Bleed workstring pressure. Open packer bypass by strippin~ through hydril and reverse-out excess slurry. Monitor fluid loss. 21. Remove flow lines. Unset packer and rotate auger assembly out of sand pack at g$O0 ft-lbs above free rotation, keeping a little weight on the ~orkstring. Continue POOH until bottom of auger guns is at 3734'. Rotate at 45 RPM for 5 minutes to allow sand to fall past auger blades and ~ettle. orop down and tag top of sand. Pick back up to 3734' and reset packer, 22. Repeat infusing and augering process until sand top.is at 3744'. Monitor fluid loss. If greater than 5 BPH, spot HEC pill, f~ltered and sheared, ~ith breaker (Baker 25 bbl bl_ender to .be__on stan.dby _f_o.r..this purpose). 23. Evaluate downhole pressure data. Discuss need for dual up-facing packer cup tool to be used in the auger screen assembly. ~UN AUGER SCREEN ASSEMBLY 24. P~J and RII~ with auger screen assembly (see Figure 3): A~ Auger bit. 4-1/2" Auger Slim-Pak screen, 0.012 gage, 20-40 Bakerbond. Torque rin~s in couplings. (275') 4-1/2" Auger blank pipe with torque rings. (50') Knock Out Isolation Yalve. 4-1/2" rotationally locked hookup nipple. SENT BY:Mara~.hon 0tl Company '10-16-~1 ;12'4~ ' Well )4-13 Recompletion Procedure Page 3 F~ G~ Rotationally locked hydraulic releasing tool with Auger blades and 2-3/8',', stinger to keep KOIV open. 4-1/2 Auger blank pipe with torque ringf. (180') X-over, 4-1/2" short 8RD P x $-1/2" XF B. Workstr(ng to surface. 25. RIH slowly and tag top of prepack. Space-out with singles if necessary. PU and engage top drive and rotate the assen~bly at 60 RPM to determine the torque at free rotation. Note: Three stands of pipe will be required to auger the screen to the appropriate depth. Install TIW valves to the top of each stand before they are racked in the derrick. Five TIW valves should be ava(lable (two backups). These TIW's must have large enough ID to allow 2-I/8" ball to pass. Close each TIW valve (at floor) when a connection is made and reopen prior to RIH below floor. 26. while rotating, lower assembly into the prepack. Continue until a connection is necessary or the auger a~sembly has augered to 4011' Limit torque to 2500 ft-lbs above free rotation. Do not slack off more ~han 5000 lbs on the assembly. If screen becomes stuck, raise assembly until rotation can be achieved. Then rotate for several minutes at this depth prior to lowering the assembly again. During the augering ~rocess, pump completion fluid into annulus via the fillup l(ne to maintain a full annulus. 27. Allow gravel to settle for 30 minutes, keeping hole full. Close hydril and pressure up on the annulus to 1000 psi to test top of pack. 28. Drop 2-1/8" ball and allow it to gravitate to the ball seat in the hydraulic releasing tool {approximately 5 rain per 1000 ft). 29. Pressure up on workstring to 1500 psi to release from hookup nipple. Slowly PU on workstring and POOH. Overpull will be required to pull out of sand. KOIV valve will close as string is pulled. 30. PU Baker auger hookup nipple washover tool with stinger. Stinger is placed such that it is not possible to bre~k the KOIV. RIH. Tag top of sand (approximately 60' above top of hookup nipple}. Reverse circulate excess sand froa hole until washover tool bottoms out on hookup nipple. Continue to reverse until hole is clean. POOH. RUN LOWER COMPLETION ASSEMBLY 31. PU the following complet(on assembly and RIX (see Figure 4, Items 6-11): A~ D, E. F. G. Baker hookup nipple overshot with 3 "T" seals. Blank casing, 4-1/2" LTC B x P. Otis "XN" N(pp)e Blank casing, 4-1/2" LTC B X P. X*over, 6-5]8" LT~ B x 4-1/2" LTC P. Retrieving extension, 6-5/8" x 4' long. SC-IA size 96A4-60 packer.. ...... ~x~enaea 32. Prior to stabb. ~ onto the hookup n~pple, es~b, ~sh c~cul~on ~t ~ m~x~m~m of 3 BP~. SD pymps. St~b onto hookup n~pple. Set d~n 5000 and PU to neutr~t. Apply 500 psi to the workstr'tng to ensure overshot has swallo~d the h~kup nipple, - 33~ Orop 1-7/%6" stainless steel ball. Let ball gravitate to ball seat in setting tool. 34. Set SC-1 packer (at 3625') by slowly pressur(ng workstring to 1000 psi. Hold for 5 minutes, then bleed off. Pressure to 2500 psi. Hold for 5 minutes, then bleed off. Pressure to 3100 psi. gold for 5 minutes, then bleed off. Verify slip anchoring of packer by alternately setting down and picking up 10,000 - 15,000 lbs. SENT BY:~ara~.hon 0tl Company ;10-1~-.81 ;12'4~Y~ ; Well M-13 Recompletton Procedure Page 4 A~CI~OF ag~-~ 35. Increase annular pressure to 1000 psi to release service tools from packer and test same. Hold for 5 minutes, then bleed off. The service tools may now be snapped out of the packer. PO0~I. PERFORATE T~JE A-6 SAND 36. PU and RIH with Baker S-~ latching type packer plug with compensating valve. Locate and set 10,000 lbs on SC-lA packer at 3625'. Packer plug is now latched into SC-lA packer. 37. Using the sand infuser~ spot a 5' sand plug on top of the packer. This sand will protect the packer_plug d. uring perforating. Weight up completion fluid to 8.7 ppg (25 ps~ overbalance to the A-6 sand) and displace hole volume. POOH. 38. Conduct safety and operational procedure meeting with rig, service company, and MOC personnel prior to picking up the guns and prior to POOH with the guns. 39. MU and R!H ~ith auger perforating guns (6", 12 SPF, 32 gram carrot 'free gravel pack charges), a. uger blank spacers, and associated annulus pros. sure firing system as described in Figure 5. Fi!l.workstring for ~ 300 underbalance (~085 psi workstr(ng hydrostatic). RU electric line and RIH with GR/CCL to correlate guns to OiL depths. Space out guns with singles and pups. 41. Record PU and SO weights. Using top drive, determine amount of torque to maintain free rotation at 30, 60, and 80 RPM Set packer by slacking off. RU and test flow control head and surface li~es to Baker test manifold and the rig's choke manifold to 3000 psi. 42, Close annular preventer and pressure annulus to 500 psi to test packer. Continue. inc.reasing pressure to ~000 psi to fire guns. Monitor flow into workstr~ng w~th bubble bucket. SI well when liquid returns are observed at surface. ~3. Bleed annulus to 200 psi, and slowly pickup workstring to open packer bypass. Reverse circulate through rig manifold and gas buster to kill well. 44. Continue reversing at a minimum of 3 BPM and filter until returns are clean. Monitor fluid loss throughout reversing procedure. SI) pumps. Monitor fluid loss. ~)o not spot any LCM unless unable to keep up with fluid loss rate. Drain and flush any debris from gas buster. 45. RD flow lines. Using top drive, check rotating torque again at 30, 60, and 80 RPM. Continue rotating for a minimum of 10 min ~ 30 RPM to push remaining fines below perforations. 46. Close packer bypass by slacking off, install surface lines and squeeze manifold~ and test to 3000 psi. Establish injection (squeeze) rates at 1, 2, .3, and 4 B~. ~ecor~d pr.e.ssures. Determine. infused sand s]u.r.ry rate Ex1; e n d erd_.P, rag_e ......... J .............. ,~'~.~' ~r ~ ............ without exceedi~''- frac pressure. Rig up lines" ~lnlmlze downtime between sceeeno..~ and reversing out, 47. ~pen packer bypass by picking up workstring. Establish circulation while ~nfusing Baker 20/40 Low Fine sand. When sand is within XO bbls of the packer, slackoff to close bypass and squeeze sand slurry into perfs. Close hydril and pressure casing to 200 psi. Monitor pressure. Continue pumping until screenout occurs or until sufficient sand volume has been pumped to cover the auger blank spacer. Bleed workstring pressure, Open packer bypass by stripping through hydril and reverse-out excess slurry. Monitor fluid loss. 48. Remove flow lines. Unset packer and rotate auger assembly out of sand pack at 2500 ft-lbs above free rotation, keeping a little weight on the workstring. Continue POOH until bottom of auger guns is at 3554'. Rotate at 45 RPM for 5 minutes to allow sand to fall past auger blades and Company '10-16-~1 ;12'&TF~ ; Well H-13 Recc~plet(°n Procedure Page 5 DU/7. t13/O~Z ' ;q: 13,: t settle. Drop down and tag top of sand. Pick back up to 3554' and reset packer. 49. Repeat infusing and auge~ing process until sand top is at 3564'. Monitor fluid loss. If greater than 10 BPH, spot HEC. pill. POOH. 50. PU and RIH with Baker "S" plug retrieving tool. Tag top of sand. Pick up and reverse circulate to wash out fill. Monitor fluid loss. If greater than lO BPH, spot I~EC pill. Pump down workstring while slacking off to latch plug. PU and condition fluid. POOH with plug. #OlE: It is extremely i. mt?.rtant to clean-up the well thoroughly before pulling the plug (to mimmze debris on top of KOIV). GRAVEL PACK THE A-6 SAND 51. PU and RIH with the following GP assembly (see Figure 6).' QC'-[i 1~91 B. C. D. E. F~ "$:22" snaplatch seal assembly. Sl~m-Pak. screen, $-1/2" x 0.012 gage x 56'.~.~o~asJ~p, 'JJ~.~,.?~S~'.c°~missi-qll- Blank p~pe 5-1/2" ~5:5( N-80 x 40' long w~c, cent~m.~ gs' of 4-1/2" flush joint wash pipe. Model "S" gravel pack extension with sliding sleeve and upper extension. ~del 190-60 "SC-1L" packer with gravel pack crossover tool. ~el "SC" hydraulic setting tool. X-over to ~r'kstring. 52. Space out pipe to achieve a safe working height on the rig floor. Locate packer at 3625'. Snap in and out to verify depth. Snap in and hang pipe in neutral weight. Circulate 5 bbls of completion fluid to clean ball seat at no more than 3 BPM or 300 psi. Orop ~-7/16" Kirksite Baker ball and let gravitate to bottom. 53. Set SC-1L packer (at 3493') by slowly pressuring work string to 1900 psi. Hold for 5 min, then bleed off. Pressure to gDO0 psi. Hold for 5 min, then bleed off. 54. Verify slip anchoring of the SC-IL packer by alternately setting down and picking up 10,000- 150000 lbs. 55. Increase annular pressur~ to lO00 psi to release service tools from packer and test same. Hold for 5 minutes, then bleed off. The service tools may now be snapped out of the packer. 56, RU infuser and test lines to 3000 psi. 57. Position and test the crossover tool in the squeeze,, circulating0 and reverse positions. Obtain injection and circulating rates at 1, 2, and 3 BPM. Record pressures and rates. 58. w~th the crossover tool in the circulating position~ pump slurry at 3-4 BPM with 2-4 ppg sand concentration until screenout is achieved. Ex:enQeQ Page bY. ~everse clrcula~e excess oravem Ttom p~pe oy ap~ng =uu psi on ~,ne annulus. Pick I ':rossover tool to the reverse , ition. Pump a mlnimum of 3 pipe volumes~ Monitor returns. Do not SI) pump until all excess gravel in pipe has been circulated out. 60. Test pack by attempting to pump in the circulating position. POOH with service tools. 61. RU to run production tubing. Refer to Figure 7 'for Proposed Completion Schematic. All tubing to be drifted with 3.83" rabbit. Field connections to be externally tested to 3,000 psi. All other connections to be internally tested to 3000 psi. 62. RIH with tubing. Oual encapsulated control line to be run above the SCSSV and methanol injection sleeve and tested to 5000 psi. Locate seals ir) packer. Close hydril. Apply 500 psi to annulus to test seals. Bleed off. PU and space out with tubing pups. Before making up tubing hanger, SEN} BY:Mara;hon Oil Company ;lO-16-BI ;12'48PM ; Well M-13 Reconq~letion Procedure Page 6 reverse circulate 205 bbls of completion fluid and 0.64~ KW-132 corrosion inhibitor {! drum). MU hanger and RIH until landed. Test annulus to 1000 psi for 30 minutes. 63. Set BPV, ND BOPE. NU and test tree. Pull BPV. 64. RU slickline. Isolate SCSSV with hand pump and 4000 psi. Install fusible cap on master manumatic. PT lubricator to 2500 psi. RIH with "pineapple" broach to break KOIV. POC)tI and RD. NOllE: Have bailers available. 65. Release rig, 66. Bring well on line by running a j~.mper from M-14L and bullheading completion fluid to desired depth/pressure, Unload well. NOTE: If available, coiled tub(rig may be used for unloading the well. \oe59\4g.doc OCT 1 5 1991 Oi!.& ~as Cons. Commission ~chomge SENT' BY:Marathon 011 Company Anchorage~ uu'zz'/o'zo~z;w t/ z ;10-16-91 ;12'43PM ; Alaska Region Domestic Pro~'uction IVlarathon Oil COmpany P,O. Box 190168 Ar~l'~orage, AleaKa 99519 Telephone 9071561-5311 .,,FACSIMILE DATE: /~//~, / '~ t ....... TitlE: PLEASE DELIVER THE FOLLOWING PAGES TO: COMPANY/FIRM: v{//3/:. ~',...~ TELECOPY NUMBER: 2 7..~,.-__7_.~..~.. - -,,,, ~ ............................. ,,,,, RE: ALASKR REGION WE ARE TRANSMITTING IF TRANSMISSION IS NO~T COMPLETE, PLEASE CALL: TELE£OPIER NUMBER: (907) 564-6489 r7 PAGES (.INCLUDING THIS C0V.ER..P. AGE). (907) 561-5311 NOTE: TRANSMISSION COHPLETED: mi ( Time ) (Date) (Operator) Oil compan ;IU-l~-;;:Jl ; z;;~/l"~ ; .~rlcnorage-* Duizi~)lO~Z;~: z! z STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Y 1. Type of Request: .Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Pull tubing __ Variance __ 2. Name. r~f_O.z)_erator. _ ! 5. Type of VYell: UNOCAL (Marathon Oil Company - Sub pperat~opment__ ! Exploratory __ 3. Addr s Stratigraphic ~s~ O. Box 190247 Anchorage, AK 995~t9 Service-- 4. L°catiJn of well at surface Leg A-1 Cond. '#1 Steelhead Platform 1,048' FNL, 453' FWL, Sec. 33- 9N - 13W- SM Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pedorate __ Other _Eec omp 1 et i on At top. of [:)roductive interval · 2,055' FNL, 1,958' FEL, Sec. 32- 9N - 13W- SM At effective depth Attot~d~t~, FNL, 2,479' FEL, Sec. 32- gN - 13W- SM .. Datum elevation (DF or KB) 52' KB above MSL feet or Proi~erty lng uay ~nft 8. Well number M-13 9. Permit number 89-49 10. APl number 50- 733-20407 i--. , ,,,-, /:11,.,~'"~1 bllUI r~lV~'l · Itl ,k I'-IelCV~OOI .. .. . uray~ng uas banas Pool 12. Present well condition summary Total depth: measured true vertical 7,450' feet Plugs (measured) 6,543' feet None Effective depth: measured true vertical 7,350 ' feet Junk (measured) 6,448' feet None Casing Length Size Cemented Measured depth Structural Conductor 951' 20" 2230 sx 951' Surface 1,462' 16" 1400 sx 1,462' Intermediate 2,925' 13-3/8" 2245 sx 2,925' Production 498' 10-3/4" 1760 sx 498' Liner 6,952' 9-5/8" 7,450' Perforation depth:measured 5,950' - 5,978' MD 5,140' 7,035' - 7,042' MD 6,149' truevertical 7,106' - 7,134' MD 6,217' · True vertical ~lepth ' 950' 1447' 2603' 498' 6543' - 5,165' TVD - 6,156' TVD - 6,243' TVD Tubing(size, grade, and measured depth) Short String: 0' - 5,898' - 3 5" · Long String: O' - 6,984'- 3.5", 9.3#, N-80 CS Hydril Tbg Packers and SSSV (type and measured depth) 5866' Baker AL-5 Dual Pkr. 6930' Baker SC-1 Pkr. 9.3#, N-80 CS Hydrill Tbg 13. Attachments 1 & 2 Description summary of proposal ..-.--X Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation ~ 15. Status of well classification as: Jul 7, 1991 16, If proposal was verbally approved Blair Wondezell 7/5/91 Name of approver Date approved Service 17. I hereby/c.~ify that the foregoing is true and correct to the best of my knowledge. Signed/ ~\~Z~.~ ~-"~ , ~"3~~ Title ~.i ..~ ~ - .... FOR COMMISSION USE ONLY Conditions o~.ap~rova 'kl~C4otify Commission so representative may witness PI0'g'integrity ~ BOP Test ~ Location clearance ~ /__./¢/¥ Mechanical Integrity Test ~ Subsequent form required 10-. ...... Oil __ Gas ~ Suspended __ Date IApproval ORIGIN/~! em~,cO BY Approved by order of the CommissioLd:)NNil~ ~J. SMITH Form 10-403 Rev 06/15/88 .,,,1 l~"}~sioner SUBMIT'IN TRIPLIC~,TE ~:~ Attachment #1 STEELHEAD M-13 RECOMPLETION ABANDONMENT PROCEDURE 1. RU slickline on LS. Isolate SSSV with hand pump and pressure to 3500 psi. Pressure test lubricator to 2500 psi. RIH with 2.5" gauge ring to fill. POH. Evaluate need for coiled tubing cleanout prior to abandonment. 2. RU slickline on SS. Isolate SSSV with hand pump and pressure to 3500 psi. PT lubricator to 2500 psi. RIH with 2.75" gauge ring to bottom of tubing tail to ensure tubing is clear of any sand bridges. POH and RD slickline. NOTE: Abandonment of the LS and SS intervals to conform with AOGCC 20 ACC 25.105 (h) (1) (B) -- down squeeze method. 3. RU HOWCO on LS. PT surface lines. Establish injection into and kill LS with 3% KC1 completion fluid. SI and monitor surface pressure buildup. 4. Mix and bullhead cement down LS. Squeeze cement into LS perfs leaving TOC in LS above dual backer (5866'). WOC. Pressure test squeeze to 2500 psi. 5. RU HOWCO on SS. PT surface lines. Kill SS by bullheading 34 KCl completion fluid. SI and monitor surface pressure buildup. 6. Mix and bullhead cement down SS. Squeeze cement into SS perfs leaving TOC in SS above dual packer (5866'). WOC. Pressure test squeeze to 2500 psi. 7. Set BPV's. ND tree. NU and test BOPE. 8. RU on SS and RIH with chemical cutter. Cut SS above TOC. g. POH and LD SS tubing. 10. RU on LS and RIH with chemical cutter. Cut LS above TOC. 11. POH and LD LS tubing. 12. PU workstring and RIH with bit and csg scraper. Circulate hole clean. 13. RU electric line and run CBL-CET from 4200' - 3400'. Evaluate need for cement squeeze work to ensure isolation below B-3 and above and below A-6. 14. RIH with bridge plug on electric line and set so that top of plug is between 4036' and 4046' DIL. 15. RIH with workstring, test bridge plug to 2500 psi, and circulate 34 KCl completion fluid containing 0.5 - 0.754 by volume KW-132 corrosion inhibitor. 16. Secure well for future gravel pack recompletion. \docs\oe58\m13. doc Attachment #2 TRADING BAY UNIT STEELHEAD PLATFORM WELL M-13 951' 20', 94#, X-56 Csg, 1462' 16; 75#, K-55 Csg. ! 2925' 13-3/8; 61#, K-55 Cs9. / 0'-498' 10-3/4; 55.5~, N-80 Cs 498'-7450' 9-5/8', 43.5 8, 47#, N-80 Csg. 2874' ECP Csg Pkr. Comp{eted 10/27/89 FMC Dual Spilt Hanger (TC-60) w/8RD EU x CS Crossovers SHORT STRING 0'-5898' 3.5', 9.3it, N-80 CS HydrK Tb9. 396'-416' Flow Coupling (2,992' ID) Otis XXO InJ N~ppte (2.813' X prof'lLe) Flow Coup{lng (2.992' ID> Otis Series 10 SCSSV (2.813' 'X' Flow Coup{in9 (2.992' ID) LONG STRING 0'-6984' 3.5~ 9.3~ N-8~ CS Hydrll Tbs, I21'-448' Flow Coupi;ng (2.992' tls XXD Inj N~ppte (2.813' X proPRe> iow Coup{;ng (2.992' ID) tis Set;es 10 SCSSV (2.813' 'X' roF;[e) iow Coupbng (2.992' ID) 5866' 5913' Baker AL-5 Dual Pkr. (Long String Meas,) Otis 'X' Nipple (2.813' ID) 5943'-5981' (Th9 Meas.) 5946'-5984' <DIL Meas,) 2 J~s Tbg w/38' oF Carbide B{ast R~ngs. 5871' Baker 'K' Anchor Latch Seat Sub (2,82' ID> 5891' Dtls XN Nlppte (2,813' pro~'lle) (2.75' NoGo) 5898' Baker WL Entry Guide (3.00' ID) 3-6 PERFORATIONS In-tervat Zone FT SPF D~l-te 5950'-5978' D-6 28 12 10/19/89 7035'-7042' D-16A 7 12 10/16/89 7106'-7134' D-16BC 28 12 10/16/89 6927' S-22 Snap Latch Locator 6930' 6930' 6951' 6984' LOWER PACKER ASSEMBLY SC-1 Pkr (9-5/8') Baker/Brown Type 6 w/MO Ex~ Otis 'XN' Nipple (2,813' profile) Baker SheorOut Sub w/WL Entry Guide, D-16A ])-16BC PBTD 8 7350' ~ TD 8 7450' Revision Date, 11/89 Revised By, PMO/neF Reason, New Wet[ Completion Prev;ous Rev;s;on, None Memorandum UNOCAL~ DOCUMENT TRANSMITTAL February 2, 1990 HAND DELIVERED TO' John Boyle FROM: R.C. Warthen K. O. Kiloh (]2j LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows' Trading Bay Unit, McArthur River Field~ Steelhead M-13 Four (4) boxes - washed and dried well cuttings Box Depth 1 483-2300''/ 2 2300-4190'~ 3 4190-6560'/ 4 6560-7450'/ ,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. ~,T~-~: ~--~ --~ ~ RECEIVED FEB - 2 1990 Alaska Oil & 6as Cons. '¢' ' ~-,~", STATE OF ALASKA f-'"--, n I:) I c ! A ALASKi .,' AND GAS CONSERVATION U.,,,,MISSION '~ ~ t~ ~ COMPLETION OR RECOMPLETION REPORT AND LOG WELL 1. Status of Well Classification of Service Well OIL [] GASY'{] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number UNOCAL (Marathon 0il Co. Sub-operator) 89-49 3. Address 8. APl Number P. 0. Box 190247 Anchorage, AK 99519 s0- 733-20407 4. Location of well at surface Leg Ai, t;ond. #1 :;tee I head P1 at, form 9. unit or Lease Name 1,048' FNL, 453' FWL, Sec. 33 9N-13W-SM LOC^-no ; T Trading Bay Unit At Top Producing Interval VERIFIED ~ 10. Well Number . [ M-13 2,055' FNL, 1,958' FEL, Sec 32 9N-13W-SM At Total Depth .~ i.t r~-'~,,.j i 11. Field and Pool 2,151' FNL, 2,479' FEL, Sec. 32 9N-13W-SM~ McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Grayl ing Gas Sands Pool 152' KB above MSL ADL 17594 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 7/17/89 10/1/89 ~ /¢'/'¢-5'//~I 187' feetMSL 2 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7,450' & 6,543' 7,350' & 6,448' YESE~ NODI ss = 405' feetMD N/A 22. Type Electric or Other Logs Run ES = 436' GR, CAL, CBL, CNL, CVL, DIL, LDT, Mud Log, SHDT, Sonic 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# X-56 0' 951' 26" 2230 sx cmt N/A 16" 75# K-55 0' 1,462' 22" 1400 sx cmt N./A 3-3/8" 61# K-55 0' 2,925' 17.5" 2245 sx cmt N/A )-3/4" 55.5// N-80 0' 498' 12.25" 1780 sx cmt N/A )-5/8" 43 5/47# N-80 498' 7,450' 12.25" N/A 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) SS 3.5" 5,898' 5,866' D-6 5950'-5978' MD 5140'-5165' TVD LS 3.5" 6,984' 6;9.30' D-lEA 7035'-7042' MD 6149'-6156' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. D-16BC 7106'-7134' MD 6217'-6243' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED All zones 'were perforated-@ I2 HPF 27. PRODUCTION TEST See Attachm~_nt #1 Date First Production I Method of Operation (Flowing, gas lift, etc.) · I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE [GAS-OIL RATIO TEST PERIOD I~ I OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED '~taslia :0ii & Gas Cons. C0mmiSSiO-~".: Anchorage Form 10-407 Submit in duplicate 29. 30. NAME Top "A'l Zone Top "D" Zone Top "E" Zorie GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 2974' 5037' 7296' 2643' 4321' 6396' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS Attach. i, Item #27 "Production Test"; Attach. 2, Daily Summary of Well I0perations;_Attach. 3, Curre~t_Wellbore Dia.: Ai':itach. 4. i)iroctio?,al q,~rvey 32~ ~ ~ I hereby certify that the foregoing is true and correct to the best of my knowledge Signed --~;L~ .... ~ .... . .-~,~ <,~-..; ~..~- ~ ' .- ~z~-~ ~- - Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 Attcchment ~1 Item ~27 M-13 Short String 27 PRODUCTION TEST D~¢e First Pmoductlon I Method o~ Oper~lon (Flowlng, gas li~t, etc,) 11-04-89I Flowing Go, s Well I]a~e oF Test Hours Tested PRDI]UCTIDN FOR DIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO I1-07- 89 16 TEST PER~OD 0 4,817 5 N/A N/A FLora Tubin9 C~$in9 Pre,sure CALCULATED O~L-BBL GAS-MCF ~ATER-BBL O~L GRAVITY-APl (copp) P~' 1670 0 a~-HOU~ ~A=E 0 7,225 7,5 N/A M-13 Long String 27 PRODUCTION TEST D~e First Production Method oF Operation (F[owin9, §as LiFt, etc,) 11-04-89 F[owing 6cs WeLL ]]~e o~ Test Hours Tested PRODUCTION FOR DIL-BBL 6AS-NCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11-12-89 24 TEST PERIOD 0 9,989 7 N/A N/A FLow Tubin§ C~sin9 Pressure CALCULATED O[L-BBL GAS-NCF WATER-BBL OIL GRAVITY-AP1 (corr) Press, 1820 0 P4-HOUR R^TE 0 9,989 7 N/A RECEIVED 0Ec221989 /~iaslm Oil & Gas ¢op.s. ~_o_BB~S.~.[O~' Anchorage Attachment #2 Daily Summary of Well Operations Well M-13 07/07/89 ACCEPT RIG to AFE #8333-9 @ 1730 hrs on 7/7/89. Skid rig onto transverse truss. Secure rig. Move SCR building. Installing false capping beam. 07/08/89 Prep electrical cable trays. Weld skid beams down. 07/09/89 Repaired 29-1/2" - 500 psi annular. Offloaded BOPE. Installing skid beams. 07/10/89 RU trip tank. Set 16-3/4" BOP stack in upper wellroom. Hook up mud return line. Set 30" riser in upper wellroom. Skid rig over to Slot #1, Leg A-1. Secure substructure. Continue RU. 07/11/89 Continue RU. 07/12/89 Continue RU. 07/13/89 RU rat hole. Weld on starting flange. NU diverter. 07/14/89 Continue RU diverter system. 07/15/89 Fin RU diverter. Start mixing spud and kill mud. Test cmt unit. Mix and circ n a'r' . cmt. 3" cmt line thru SPRM would not test. Reconstructio ~.~~?VED A~ehora~ Daily Summary of Wei ..perations Well M-13 Page 2 07/16/89 Fin RU. Function test diverter. BHA. Mix mud. Spud @ 0500 7/17/89. RIH. Tag @ 368'. Prep to wash to 480'. 07/17/89 Clean out pile 369'-378'. Bit torquing up. POOH. Change bits. RIH. Change over to spud mud. Clean out pile 378'-483'. RU and run gyro. POOH for drilling BHA. 07/18/89 RIH. Attempt to orient motor. Unable to get gyro to seat in mule shoe. POOH. Change out UBHO sub. Drill .488'-753'. Lost returns. Mix and spot LCM pill. Regained returns. Drill 753'-955'. Circ. POOH. 07/19/89 PU MWD logging tool. RIH. Log 840'-950'. POOH. PU 26" opener. RIH. Open hole 480'-949'. 07/20/89 Open hole 949'-952'. CBU. ST 3 stds OK. CBU. POOH. PU d.p. for cmt string. RU and run 24 jts 20" csg Shoe @ 951'. RIH w/ stab-in string. Stab into float shoe. Unable to circ after several attempts. Welders building 20" x 5" cementing swedge. Able to move pipe. 07/21/89 Build 20" x 5" head. RU to cmt. Circ. Mix and pump 1200 sx "G" w/ additives at 12.5 ppg and 400 sx "G" @ 15.8 ppg. Had good returns for first 200 sx intermittent returns for remainder of job. No cmt to surface. WOC six hrs. POOH w/ d.p. Prepare to run temp log. 07/22/89 RU and run temp log. TOC @ +300'. PU 1" RIH. Tag @ 286'. Mix and pump 630 sx "G" w/ additives. Circ 35 sx overboard. ND diverter. Cut off 20". Weld on 20" starting head. Repair hydril. Well M-13 07/23/89 Finish welding starting head. NU diverter. Test to 500 psi. OK. RIH. Drill cmt 936'-955'. Drill to 956'. Circ. POOH. 07/24/89 RECEIVED ! ! MU BNA. RIH Circ Orient motor Drill and survey 956 -1375 ,,', ~m,,, Oii& Gas Con~. Anchomg~ Daily Summary of We Jperations Well M-13 Page 3 07/25/89 Drill and survey 1375'-1470'. Circ. POOH. RU loggers. Run GR-DIL and GR-CNL-LDT from TD to 950'. BHA. RIH. UR to 17-1/2" from 953'-1227'. 07/26/89 UR 12-1/4" hole to 17-1/2" from 1227'-1465'. CBU. POOH. BHA. RIH. UR to 22" from 951'-1215'. 07/27/89 UR 1215'-1465'. CBU. ST 3 stds. CBU. POOH. RU casers. Run 34 jts 16", 75#, K-55 butt csg. Shoe @ 1462'. RIH w/ stab-in string. Stab into float collar. 07/28/89 Circ. Mix and pump 1000 sx Trinity lite-wate w/ additives and 400 sx Class "G" w/ additives. CIP @ 0900 hrs. POOH w/ d.p. WOC. ND diverter lines. Clean out wellhead. Prep to cut off csg. 07/29/89 Cut off 16" csg. 16" is 1" off center. Can't set slips. ND lower riser. Weld plate between 16" and 20" in starting head. ND diverter. 07/30/89 ND 30" diverter. Weld on head. NU BOPE. 07/31/89 NU 16-3/4"-10M BOP stack and function test. NU bell nipple. NU choke line. 08/01/89 Fin NU chokeline. Attempt to test BR and csg w/o success. RIH w/ 6 std HWDP and RTTS. Test BOPE to 1850 psi. Found controls to HCR reversed. POOH w/ RTTS. Tested BR and csg to 1850 psi, ok. BHA. RIH. Test csg to 1850 psi, ok. Drill FC and cmt 1414'-1430'. Test csg to 1850 psi, ok. Drill shoe and cmt to 1470' Test shoe to 12.1 ppg EMW. POOH. 08/02/89 Finish POOH. RI,. Orient motor. Drill 14170;-1692' ,Had 500 u gas from AC-4 sand. MW cut from 9.2-9.0 ppg. CBU. Dril..692'-1~26- Raise MW to 9.4 ppg. CBU. ST to shoe. RIH. CBU. TG = 105 u. Trip for new BHA. Wash and ream 1808'-1926'. Drill 1926'-2000'. Daily Summary of We 2erations Well M-13 Page 4 08/03/89 Drill 2000'-2184'. CBU. POOH for BHA. RIH to 2125'. W/R 2125'-2184'. Drill 2184'-2232'. CBU. BGG 860 u (AD-4 or AD-5 sand). Raise MW to 9.5 ppg. Drill 2232'-2437'. 08/04/89 Drill 2437'-2482'. CBU. POOH for BHA. RIH. W/R 2440'-2482'. Drill 2482'-2937'. CBU. ST to shoe. CBU. POOH to log. o8/o5/89 LD BHA. RU and run DIL/SFL/GR/CAL/CNL/FDC, 2934'-1462'. RD loggers. BHA. RIH. UR 1462'-1927' to 17-1/2". 08/06/89 UR 1927'-2193'. CBU. POOH. BHA. RIH. UR 2193'-2821'. 08/07/89 UR 2813'-2937'. CBU ST to s,h, oe. RIH CBU. POOH for BHA Change rams. RU casers. RIH w/ 74 ji~s, 13-3/8 , 61#, K'55, buttress csg. C[~U. Mix and pump 10 bbls H O, 70 sx TLW @ 11.0 ppg, 1750 sx TLW and additives @ 13.8 ppg, 425 sx premium a~d additives @ 15.8 ppg. Displacing cmt while reciprocating csg. Have full returns. 08/08/89 Fin displacing cmt. CIP @ 0700 hrs. 8/8/89. Set slips w/ 85,000 lbs. Cut off csg. ND bell nipple. NU csg spool. Test csg spool to 1100 psi, ok. NU BOPE. 08/09/89 Change rams. Install bell nipple. RIH w/ OEDP. Tag cmt @ 2826' Circ clean 9.5 ppg mud. Test csg to 2000 psi, ok. POOH. Test BOPE 250/300~ psi, ok. Test annular to 250/1500 psi. Drain lines and prepare rig for shut down. Lock BRs shut. 08/10/89 Finish prepping rig for shut down. Skid rig south to afford more clearance for lifts. RELEASED RIG at 1500 hrs 8/10/89. FINAL REPORT until operations resume. 09/18/89 Mobilized drlg crews RU on Well M-13. Testing BOP ~" ~ At~chom~ Daily Summary of We, perations Well M-13 Page 5 09/19/89 Finish testing BOP control lines. Test BOPE 250/2500 psi. Attempt to screw into test plug. No go. ND riser, screw into test plug and NU BOPE. 09/20/89 NU riser. Test WC kelly cocks 250/2500 psi. BHA. RIH. Drill cmt 2826'-2923'. POOH. RU and run gyro 2910'-100'. Rerun gyro. 09/21/89 Finish rerunning gyro. Second tool agrees w/ MWD. BHA. RIH. SD 1/2 hr. for gas alarm in prod. module. Displace hole w/ mud. Drill shoe, rathole and 10' formation. Run LOT to 14.0 ppg. No leak off. Repair electrical problem in MP SCR. Drill 2947'-3239'. 09/22/89 Drill and survey 3239'-3819'. CBU. POOH for BHA. RIH. Drill w/ motor 3819'-3925'. 09/23/89 Drill w/ mud motor 3925'-4208'. Circ. POOH for BHA. RIH. Tight below 3300'. Stuck pipe. Jar on pipe. RU to circulate. Jar pipe free. W&R 3845'-4000'. 09/24/89 Ream motor run 4000'-4208'. Drill 4208'-4730'. CBU. POOH. RIH w/ bit #12. Wash 30' to bottom. 09/25/89 Drill and survey 4730'-4753' Repair rotary chain. Drill 4753'-5312'. CBU. POOH to shoe. Monitor well Qhile hooking up power to new rig. 09/26/89 Monitor well while hooking up electricity to new rig. Finish POOH for BHA. Test BOPE. RIH w/ bit #13 and RLL. W&R 5236'-5312'. Drill 5312'-5484'. 09/27/89 Drill 5484'-5874'. ST to 3678'. Hole tight. RIH. W/R 15' of fill. Circ. Drill 5874'-5901'. Drill 5901'-6567 . CBU ST to 3710 First 7 stds tite RIH Anchoi'ag~ Daily Summary of We .gerations Well M-13 Page 6 09/29/89 RIH. Wash 30' to bottom. No fill. Drill 6567'-6944'. CBU. POOH for BHA. RIH. 09/30/89 Fin RIH to 6944'. Drill 6944'-7450'. CBU. 10/01/89 ST to 3740. RIH No fill. CBU. POOH for BHA. R/U and run DIL/Sonic/GR 7450'-2936'. 10/02/89 Run CNL-LDT-GR-CAL 7447'-2928'. Rerun sonic-GR 4400'-2928'. RIH for wiper trip. CBU-POOH. Hole good. Run AMS-GR-RFT. 10/03/89 Continue running AMS-GR-RFT. RIH w/ bit. CBU. POOH. R/U and run AMS-GR-SHDT 7447'-2928'. RIH w/ bit for wiper trip. 10/04/89 RIH, CIRC. POOH. Change pipe rams. R/U and run 9-5/8" - 10-3/4" csg. No probl ems. 10/o5/89 Finish RIH / 9-5/8" & 10-3/4" csg to 7459'. R/U and mix and pump 30 bbl. 11 ppg scavenger slurry, 830 ex. TLW w/ additives and 950 sx premium w/ additives. CIP @ 1455 hrs. Did not bump plug. WOC 12 hours. Pressure up on csg. Appeared to inflate ECP @ 2874'. Pressure to 3000 psi OK. N/D stack to set slips. 10/06/89 P/U stack and set slips w/ 150,000 lbs. Cut off csg. L/D cutoff. N/U tbg spool & test to 3000 psi. N/U BOPE. Test BOPE 250/3000 psi. L/D 8" d.c.'s. BHA. RIH w/ 8-1/2" bit and 9-5/8" csg. scraper. 10/07/89 Tag cmt @ 3060'. Wash & drill from 3060' to 3890' Tag @ 7284, washed & drilled cmt to 7441'. Attempted to test csg. Wouid not test. Displaced we]] with saltwater. RU to run CBL log. R~CF. tVED Daily Summary of We .perations Well M-13 Page 7 10/08/89 Ran GR-CBT-CET log. Ran gyro. RIH w/EZSV retainer set @ 7400'. Test csg to 3000 psi. Spot 50 sks cmt on top of EZSV. R/U to perforate for squeeze. 10/09/89 RIH w/perf gun. Perf from 7150-7152'. Squeezed 200 sxs Class G. final squeeze pressure 2400 psi @ 1/2 BPM. WOC. RIH w/BHA. 10/10/89 Clean out cement retainer & cement to 7212, attempt to test casing, pumped in @ 1/2 BPM @ 2600 psi, POOH, RIH & set retainer @ 7041', squeeze perfs to final 1/4 BPM @ 2650 psi, POOH, RIH with bit. 10/11/89 RIH to 6950'. WOC. RIH. Drill cmt 7002'-7212'. RIH to 7260'. CBU. 10/12/89 CBU. Test csg to 3000 psi for 30 min. Ok. Drill cmt 7212'-7350' CBU. POOH. MU dry test BHA and RIH, set pkr @ 6996'. Burst rupture disc and monitor well. Well dead. Attempt to RO. Unable to do so. POOH. Rupture disc did not burst. Rerun dry test BHA. Set pkr @ 6996'. Ruptured disc. Well dead 12 min., bubbled 20 min. Well dead last 10 min. Open bypass and RO, POOH. 10/13/89 POOH. LD DST BHA. Evaluate charts. Pressure test csg to 3000 psi. Bled to 2575 psi and held. RIH w/ OEDP. POOH and LD same. Change PR to 3-1/2". Testing BOPE. 10/14/89 Finish testing BOPE, BHA. RIH. PU 3-1/2" PH-6 workstring. Mix 3% KC1. Displace hole and filter brine. 10/15/89 Circ and filter brine. POOH. PU TCP guns and DST BHA and RIH. 10/16/89 Fin RIH w/ TCP guns. Correlate w/ GR/CCL. Set pkr @ 6997'. Test lines to 3000 psi. Perf D-16A sand 7035'-7042' and D-16BC sand 7106'-7134'. Flowed well @ 3.6 MMCFD @ 2050 psi FTP. SI for PBU. _Reverse out 2 tbg volumes. CBU. R C IVED Daily Summary of We, .perations Well M-13 Page 8 10/17/89 Circ and filter brine. POOH. LD TCP BHA. All shots except I fired. BHFP = 2398 psi @ 3.6 MMCFD, BHSIP : 2412 psi. MU isolation pkr assembly and RIH. Set pkr @ 6918' DPM. POOH. MU pkr plug and RIH. Set plug in pkr. Dump 5 sx sand on plug. Circ and filter brine. lO/18/89 Circ and filter. POOH. MU TCP guns and RIH. Correlate w/ GR and space out. Set pkr @ 5926'. Wait on daylight to perforate. 10/19/89 Wait on daylight. Perfed D-6 sand 5950'-5978' w/ 12 spf. Flowed well @ 5.25 MMCFD @ 1715 psi FTP. SI for PBU. RO to production. Open bypass. Well taking 50-60 bph. Close bypass and spot 30 bbl HEC pill. POOH. Losing 4 bph. 10/20/89 POOH. MU pkr plug ret tool. RIH. Wash sand off plug. Latch plug. POOH. LD work string. Ran GR/CCL to verify pkr @ 6930' DIL. Change pipe rams. RU to run tbg. 10/21/89 RU and run 3-1/2" dual completion. 10/22/89 Cont running 3-1/2" dual completion. Space out. Pressure test dual control lines. Circulate inhibited brine. Land tbg. Prep to set pkr. 10/23/89 Set dual pkr. LD landing jts. Attempt to set BPV w/o success. Control line wrapped around BPV. PU stack and install BPVs. Repair control lines @ tbg hanger. ND BOPs. Installing X-mas tree. 10/24/89 NU tree. Attempt to test void. Would not test. ND tree. Replace seals on tbg sleeve. NU tree. Test SS side, ok. Attempt to test L.S. side, no success. ND tree. Replace L.S. tbg sleeve. NU tree. Test to 5000 psi, ok. RU CTU. Presently testing lines. Daily Summary of We~ Jperations Well M-13 Page 9 10/25/89 Unload long string w/ CTU and Ny. Final rate 7.8 MMCFD @ 1810 psi FTP. SI @ 1400 hrs. RU and unload short ~;tring w/ CTU and N.. Final rate 8 MMCFD @ 1675 psi. SI @ 2030 hrs. RD CTU. RU slickline. Shif~ chem injection sleeves open. RD SL. Close SCSSVs and set BPVs. Prep to skid rig. 10/26/89 Prep to skid rig. RELEASED RIG to M-14 @ 0800 hrs. on 10/26/89. \docs\shp\m13. doc Attachment #3 TRADING ]3AY UNIT STEELHEAD PLATFORM ~/ELL M-13 951' 20% 94#, X-56 Csg. 1462' 16% 75~, K-55 Csg. 2925' 13-3/8; 61~f, K-55 Csg. 0'-498' t0-3/4; 55.5#, N-80 Cs9. 498'-7450' 9-5/8% 4-35 N-80 Csg. 2874' ECP Csg Pkr. Compteled 10/27/89 FMC Dual Split Ho. nger (TC-60) w/SRD EU x CS Crossovers SHORT 0'-5898' 3.5% 9.3~, N-BO CS HydrK Tb9, 396'-416' Flow CoupUn9 (8,992' II)) Btm XXB InJ N~ppte (8.813' X profile> Flow Coupling (2.99P' Otis Series 10 SCSSV (8.813' 'X' proFIte) Ftow CoupUn9 (P,992' [0) LONG.STRING 0'-6984' 3.5% 9.3~, N-8~ CS Hydrit Tbg. I21'-448' Flow CoupUn9 (~.992' II)) %~s XXD Inj Nipple (2.813 X pro¢Ite) tow Couptln9 (2.992' ID) · , , tis Ser~es 10 $CSSV (2.813 X roFite) tow Couphng <2.992' 5866' 5913' Baker AL-5 Duot Pkr. (Long String Meas.) Otis 'X' Nippte (2.813' II)) 5871' Boker 'K' Anchor La"tch Seot Sub (2,82' ID) 5891' D'tls XN Nipple (2.813' pro?lte) (2.75' NoGo> 5898' Baker %/L Entry Guide (3.00' ID) 5943'-5981' (Tbg Meas.) 5946'-5984' (])IL Meos,) 2 Jts TIo9 w/38' oF C0,rbide Blast Rings. PERFDRATIB~2 [ntervol ~ FT 5950'-5978' ])-6 28 7035'-7042' D-16A 7 7106'-7134' D-16BC 28 SPF D~te 12 10/19/89 12 10/16/89 12 10/16/89 6927' 6930' 6930' 6951' 6984' $-22 Shop L~tch Loc~tor .L..O~/ER PACKER ASSEMBLY SC-1 Pkr <9-5/8') Baker/Brown Type 6 w/MD Ex1; B'tls 'XN' Nipple <2.813' pro¢ile) Baker SheorOut Sub w/WL Entry Guide, I)-16A I)-16BC PBTD ~ 7350' ~ TD ~ 74~N' Revision ])ate, 11/89 Revised By, PNO/ne? Re,sam New We[[ Completion Attachment #4 ORIGINAL SURVEY REPORT MARATHON OIL COMPANY SL°T Al-l, WELL NUMBER M-13 TRADING BAY UNIT, KENAI BOROUGH, ALASKA STEELHEAD PLATFORM OCTOBER 8, 1989 ORIGINAL GyrDdat'a · D i r e c i i·o n a 1* ~u r'vi',e y for ~ ,,~ MARATHON OIL COMPANY TRADING BAY UNIT, WELL M~-13, SLOT Al-1 MCARTHUR RIVER UNIT, KENAi' BOROUGH,~ ALASKA Date Run: 8-OCT-89 10: O: 0 Job Number: AKlO89G250 Surveyor: MIKE HOWATT Calculation Method: RADIUS OF CURVATURE Survey Latitude: 60deg 49min 30sec N Bearings are Relative to TRUE NORTH Proposed Well Direction: S 67deg 14min Osec W Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Ref~rence Directional Survey Page 1 MEAS INCL BORE HOLE DOG-LEG VERT VERT DEPTH BEARING SEVERITY DEPTH SECTION ft deg min deg min deg/100' ft ft .0 0 0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 951.0 1000.0 1100.0 1200.0 1300.0 1400.0 1453.0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 2500.0 2600.0 2700.0 0 3 0 5 0 9 0 17 0 25 1 21 2 5O 4 15 5 48 651 8 6 10 35 12 56 15 22 17 19 18 11 20 2 23 58 27 21 30 45 33 39 36 33 40 40 43 12 44 13 44 49 44 39 43 15 42 13 CLOSURE DISTANCE BEARING ft deg min N 0 0 E .00 .0 .0 .0 N 0 0E MEASURED DEPTHS REFERENCED TO POOL 422 RKB ELEV. 152 FT. MSL 0 - 2900 GYRODATA MULTISHOT SURVEY RUN IN 13 3/8 CASING 3000 - 7434 GYRODATA MULTISHOT SURVEY RUN IN 9 5/8 CASING S 70 41 W .05 100.0 .0 .0 S 70 41 W S 73 46 E .12 200.0 ..' .1 .1 $ 21 47 W S 22 37 E .12 300.0 .0 .2 S 24 42 E $ 254 W .16 400.0 .1 .6 S 15 43 E S 43 59 W .28 500.0 .5 S 76 1 W 1.01 600.0 2.0 S 69 55 W 1.50 699.9 5.6 S 64 10 W 1.45 799.7 11.8 S 63 46 W 1.57 899.3 20.5 1.1 S 3 34W 2.4 S 36 8W 5.7 S 58 37 W 11.8 $ 62 59 W 20.6 S 63 25 W S 65 8 W 2.06 950.0 26.2 $ 66 44 W 2.58 998.6 32.5 S 69 24 W 2.53 1097.3 48.8 S 68 8 W 2.36 1195.2 69.1 S 65 24 W 2.53 1292.1 93.6 26.2 $ 63 38 W 32.6 S 64 5 W 48.8 S 65 24 W 69.1 S 66 24 W 93.6 S 66 29 W S 64 8 W 1.97 1388.1 121.7 S 63 55 W 1.66 1438.6 137.8 S 63 34 W 3.91 1483.0 153.2 S 62 17 W 3.97 1575.7 190.5 S 61 47 W 3.39 1665.8 233.6 121.7 S 66 6 W 137.9 S 65 51 W 153.2 S 65 38 W 190.6 S 65 6 W 233.9 S 64 32 W S 61 52 W 3.40 1753.2 281.9 S 61 56 W 2.91 1837.8 335.0 S 61 44 W 2.90 1919.6 392.2 $ 61 44 W 4.11 1997.7 454.3 S 61 47 W 2.54 2072.1 520.9 282.4 S 64 4 W 335.6 S 63 43 W 393.1 S 63 27 W 455.5 $ 63 13 W 522.3 S 63 2 W S 61 47 W 1.02 2144.4 589.7 $ 62 2 W .62 2215.7 659.5 S 62 22 W .28 2286.8 729.6 S 61 56 W 1.44 2358.8 798.7 $ 62 8 W 1.04 2432.2 866.3 591.4 S 62 53 W 661.5 S 62 47 W 731.8 S 62 43 W 801.2 S 62 40 W 869.1 S 62 37 W HORIZONTAL COORDINATES feet .00 N .00 E .01 S .04 W .10 S .04 W .22 $ .10 E .59 S .17 E 1.14 S .07 W 1.91 S 1.39 W 2.97 S 4.87 W 5.38 S 10.55 W 9.22 S 18.42 W 11.64 S 23.49 W 14.24 S 29.31 W 20.31 S 44.36 W 27.69 S 63.35 W 37.33 S 85.81 ~ 49.32 S 111.27 W 56.40 S 125.80 W 63.21 S 139.59 W 80.26 S 172.93 W 100.56 S 211.16 W 123.48 S 253.95 W 148.58 S 300.95 W 175.72 S 351.64 W 205.27 S 406.59 W 236.89 S 465.46 W 269.56 S 526.34 W 302.57 S 588.20 W 335.40 S 650.45 W 367.82 S 711.81 W 399.64 S 771.74 W A Gyrod rectional .~RATHON OIL COMPANY RADING BAY UNIT, WELL M-13, SLOT Al-1 ~ARTHUR RIVER UNIT, KENAI BOROUGH, ALAS~ ~b Number: ~1089G250 MEAS INCL BORE HOLE DOG-LEG VERT DEPTH BE~I NG S EVERI TY DEPTH ft deg min deg min deg/100' ft VERT SECTION ft 2800.0 40 47 S 62 0 W 1.43 2507.1 2900.0 39 28 S 62 29 W 1.36 2583.6 3000.0 39 46 S 61 48 W .53 2660.6 3100.0 39 30 $ 61 27 W .36 2737.6 3200.0 39 8 S 61 55 W .46 2815.0 3300.0 39 8 S 61 56 W .02 2892.5 3400.0 39 1 S 61 36 W .25 2970.1 3500.0 38 41 S 61 33 W .33 3048.0 3600.0 38 58 S 61 1 W .43 3125.9 3700.0 39 32 S 60 49 W .59 3203.4 3800.0 39 4 S 61 10 W .52 3280.7 3900.0 38 29 S 67 22 W 3.92 3358.7 4000.0 38 9 $ 73 42 W 3.94 3437.2 4100.0 36 44 S 73 57 W 1.43 3516.6 4200.0 35 36 S 74 46 W 1.23 3597.3 4300.0 34 31 S 74 49 W 1.09 3679.2 4400.0 33 20 S 74 46 W 1.18 3762.1 4500.0 32 46 S 74 24 W .60 3845.9 4600.0 31 25 S 74 13 W 1.36 3930.7 4700.0 30 14 $ 74 29 W 1.19 4016.5 4800.0 29 35 S 74 57 W .69 4103.2 4900.0 28 22 S 75 6 W 1.21 4190.7 5000.0 27 20 $ 76 9 W 1.15 4279.1 5100.0 26 32 S 76 5 W .80 4368.3 5200.0 26 10 S 77 7 W .59 4457.9 5300.0 26 3 S 77 25 W .18 4547.7 5400.0 25 25 S 78 6 W .69 4637.8 5500.0 25 5 S 77 59 W .33 4728.2 5600.0 24 31 S 78 12 W .57 4819;0 5700.0 23 52 S 78 28 W .67 4910.2 932.3 996.5 1060.0 1123.5 1186.5 1249.3 1312.1 1374.5 1436.9 1499.8 1562.7 1625.2 1687.1 1747.5 1806.0 1863.0 1918.3 1972.4 2025.1 2076.0 2125.4 2173.4 2219.6 2264.3 2308.1 2351.5 2394.1 2436.0 2477.2 2517.5 Survey CLOSURE DISTANCE BEARING ft deg min 935.3 S 62 35 W 999.8 S 62 34 W 1063.5 S 62 32 W 1127.3 S 62 29 W 1190.7 S 62 27 W 1253.8 S 62 25 W 1316.8 S 62 23 W 1379.5 S 62 21 W 1442.2 S 62 18 W 1505.5 S 62 15 W 1568.8 S 62 12 W 1631.3 S 62 16 W 1692.7 S 62 34 W 1752.4 S 62 58 W 1810.2 S 63 20 W 1866.6 S 63 41W 1921.4 S 64 0 W 1975.0 S 64 18 W 2027.3 S 64 33 W 2077.8 S 64 48 W 2127.0 S 65 2 W 2174.7 S 65 15 W 2220.7 S 65 28 W 2265.2 S 65 41 W 2308.8 S 65 53 W 2351.9 S 66 6 W 2394.5 S 66 18 W 2436.2 S 66 31 W 2477.4 S 66 42 W 2517.5 S 66 54 W Page 2 HORIZONTAL COORDINATES feet 430.68 S 830.28 W 460.69 S 887.31 W 490.48 S 943.69 W 520.79 S 999.82 W 550.84 S 1055.59 W 580.54 S 1111.26 W 610.36 S 1166.80 W 640.22 S 1221.97 W 670.35 S 1276.95 W 701.11 S 1332.24 W 731.82 S 1387.63 W 759.00 S 1444.02 W 779.66 S 1502.45 W 796.60 S 1560.83 W 812.51 S 1617.66 W 827.58 S 1673.08 W 842.22 S 1726.93 856.72 S 1779.51 871.10 S 1830.65 w 884.92 S 1879.99 W 898.06 S 1928.08 W 910.58 S 1974.87 W 922.18 S 2020.12 W 933.05 S 2064.09 W 943.34 S 2107.26 W 953.04 S 2150.17 W 962.25 S 2192.60 W 971.09 S 2234.33 W 979.74 S 2275,38 W 988.03 S 2315.52 W A Gyrodata ~RATHON OIL COMPANY .~ADING BAY UNIT, WELL M-13, SLOT A1-1 ~ARTHUR RIVER UNIT, KENAI BOROUGH, ALASKA ~b Number: AK1089G250 Directional Survey Page 3 MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/lO0' 5800.0 23 20 S 78 34 W 5900.0 23 9 S 78 38 W 6000.0 22 41 S 78 58 W 6100.0 22 17 S 79 14 W 6200.0 22 0 S 79 16 W 6300.0 21 49 S 79 35 W 6400.0 21 35 S 79 40 W 6500.0 21 14 S 79 35 W 6600.0 21 3 S 79 50 W 6700.0 20 50 S 79 53 W 6800.0 20 40 S 79 55 W 6900.0 20 38 S 80 10 W 7000.0 20 37 S 80 27 W 7100.0 19 38 S 80 7 W 7200.0 18 50 S 80 8 W 7300.0 18 5 S 79 30 W 7400.0 17 14 $ 78 5 W 7434.0 16 58 S 78 6 W Final Station Closure: 3127.7 feet VERT VERT DEPTH SECTION ft ft .54 5001.8 2556.7 .17 5093.7 2595.4 .49 5185.8 2633.6 .41 5278.2 2671.0 .28 5370.9 2707.9 .22 5463.6 2744.3 .24 5556.5 2780.5 .35 5649.6 2816.1 .21 5742.9 2851.3 .20 5836.3 2886.2 .17 5929.8 2920.8 .09 6023.4 2955.2 .11 6117.0 2989.5 .98 6210.9 3023.0 .79 6305.3 3055.1 .79 6400.2 3086.0 .94 6495.4 3115.7 .80 6527.9 3125.5 South 69 deg 22 min 32 sec West CLOSURE DISTANCE BEARING ft deg min 2556.7 S 67 4 W 2595.4 $ 67 15 W 2633.6 S 67 25 W 2671.0 S 67 35 W 2708.0 S 67 45 W 2744.5 S 67 54 W 2780.7 S 68 3 W 2816.5 S 68 1~2 W 2851.8 S 68 21 W 2886.9 S 68 29 W 2921.6 S 68 38 W 2956.2 S 68 46 W 2990.7 S 68 54 W 3024.5 S 69 2 W 3056.8 S 69' 9 W 3087.9 S 69 15 W 3117.8 S 69 21 W 3127.7 S 69 23 W HORIZONTAL COORDINATES feet 996.00 $ 2354.75 W 1003.80 S 2393.44 W 1011.37 S 2431.64 W 1018.60 S 2469.20 W 1025.64 S 2506.24 W 1032.48 S 2542.92 W 1039.14 S 2579.29 W 1045.71 S 2615.18 W 1052.15 S 2650.66 W 1058.45 S 2685.85 W 1064.66 S 2720.73 W 1070.76 S 2755.47 W 1076.69 S 2790.19 W 1082.50 S 2824.10 W 1088.15 $ 2856.56 W 1093.75 S 2887.7'2 W 1099.65 S 2917.48 " 1101.71 S 2927.26 AUSTIN. T£XJ* CHART NO. 101 / . II£)tlS ION AUSTIN, T£X CH&RI' NO. 10 , + ;;~_'. 7; _-"-? Z;';'~'./ ....... , ........ l_ .... : .... ; ~'. ....... ........ {'0 :UN · I ' ' · 1'"---:-: ]- J .. : OMP. 8N:'l':: ! 1 t D,a~e: I0/l/1989 TZme': ?: 2:41 Ftlene~e: "M-I3fi. SRV" Description: "MOO STEELHEAD " Tar~et. Coordinates: 9S2,0 S 2363.0 W T~rget TUO: 4812.000 Using Radiu~ of curva{ur¢ method, .: TRUE MEASURED DRIFT " DRIFT ooURsE VERTCAL 'VERTCAL RECTANGULAR DOGLE$ DEPTH ANGLE DIREOTION LENGTH DEPTH SEOTION--- COORDINATES -5EUERIYY '100,0 0.05 5 70,88 ~ t00.0 100,0 0.0 2~0,0 0,08 5 ?3.77 E 100.0 200.0 0.1 300.0 0. t~ S 22.~ E 100.0 300,0 -0,0 ~00.~ 0.28 S 2.90 ~ 100,0 400,0 0,1 500.0 0,42 $ 45.98 ~ 100,0 ~00.0 0,~ 0.0 S 0.O.W t3 0. l S 0.0 ~,l 0.2 $ 0,t E 0.12 0,~ .$ 0.2 E 0.1~ 1.1 S 0. l W 0,28 7~0.~ 2.80 g 69.92 ~ I~.~ 699.9 800.0 4.25 B 64.17 ~ 100,0 799.7 11 9~,0 5,8~ 5 ~S.77 ~ 100.0 899.3 951.0 6.85 S 6S.13 W S1.0 950.0 26.2 1.9 S' 1.4 U 1.02 3.0 5 4.9 ~ 1.49 5.4- S 10.6 W 1.46 '9.2 S 18.4 W 1.~ 11.g; S 23.S W 2.138 11 1000,0, 8.18 S ~8,73 W 49.0 B08.6 32.5 12 1.100.0 10,~8. ~ E9,40 U 100.0 1097,~ 48,8 13 1200.0 12.93 S 68,13 W -100.0 1195.2 ~9.1 14 1300,0 15.37 S ~.40 W 100.0 1292,1 93.6 ~ 1~00,0 17.5~ $ 84.13 W t00.0 1388.~ 12l.? 14.2'5 29.3 W 2.59' 20.3 $ 44.4 W 2.52 27.7 $ $3.4 W 2.3~ 37,3 S 8S.8 W 2.S3 49.3 S l l].~ W 1.98 16 '!'453.0 I8,18 S '53,g2 ~ 53.0 14~8.8 137,8 58,4 $ 12518 W 1.~3 17 1500.0 20.03 S ~3,~7 W 47.0 1483.0 153.2 63.2 S 139.6 ~ 3.94 18 1600,0 23.97 S 62.28 W 100.0 1575.7 190.5 80.~ $ 172.9 U 3.97 19 1700,0 27.3~ g ~1.78 W' 10~.13 166S,8 2~.8 109,6 S 211.2 U 3.39 20 1800.0 30,75 S 61.87 W 100.0 1753.2 281,9 123.S 5 25'4.0 U 3.40 .. 2I tB00.~ 33.65 S- ~1:~ W 100,0 t837.8 334.9 148,6 ~ ~01.0 W 2'.B0 22 2008.8. ~,SS S 81.73 W 100.13 I919,'~ 3~2,1 175.? S 3~I.7 W 2.90 23 2100.0 40,67 $ S1,73 W 100,0 19~7,7 4S4,2 '205.3 S 406.~ W 4,12 24 2200.0 43.20 S 61.78 W 100.0 '2072.1 S20,7 238.9 S 465.5 W 2.'53 25. 2300,0 44.22 S ~I,78 W 100.0 2144,4 589.4 289.8 $ S20.4 W 1,02 20 2400,0 .44.82 S, 92.03 W t00,0 2215.7 ~S9.2 302.~'S S~8.2 W 0,¢3 27 2500,0 44.6S S 62.37 W I00.0 2286.7 729.3 335.4 S ~50.S W ~.29 28 2~0~.0 .¢3.2~ $ ~1,~3 ~ 100.0 235~.7 79@,4 3~7.~ $ 71t.8 2~ 2700.0 42.22 $ 62.13 ~ 100.~ 24~2.2 85~.9 ~9.7 S 771.~ ~ 1.04 30 2800.0 ¢0,78 S ~2.00 W 100.0 2S07.1 931..9 430.7 $ 830,3 W 1,44 31 ~900.0 3~.47 S 62.48 W 180.0 2E~83,5 996.13 400.7 S 887:3 W 1.3El ~2 291~.e 39.45 S 62,27 W lO,O 2S91.3 1002,4 483,7 S BB3.~ W 1.3S 33 2982,0 3B.90 S 81.80 W 72.0 2~46.7 1048.1 485.2 S g33.G ~ 0,75 34 ~077.0 39.60 S E1,30 W f15.O 27t9.7 1108.5 514.2 S 987.0 W 0.4B g~ 3172.0 'g9.~O S ~O,9g W B~,g 2793.0 11~8.6 $43,4 S 1039.9 ~ 0,34 3444.0 39.00 S 61,00 W 27'2.0 300~.8 1339.4 626.8 S 1190.2 W 0.15 RECEIVED DEC -81989 Alaska 011 & Gas COns..commissiOn. Anchorage ; ~'~'- TRUE . HEASUR~O DRIFT ,FT ¢OURS£ VERTGAL VERTCAL RECTANAULAR OOBLE~' DEPTH ANSLE DIRECTION LEN6TH DEPTH SECTION --- COORDINATES -SEVERITY (fee~) (deg) (deg) (feet) (feet) (feet) (f~et) D~/100FT 37 3580,0 38,40 S 6t.50 %; 138.0 '3109.~ 1423.9 667.? $ 1264,7 ~ 0.50 - ~8 ~705.0 39.80 S 60.00 %; 125.0 3207,1 1502.0 70S.8 5 1333.5 ~ 1.08 ~9 385~.0 39.~0 S ~4,40 ~ 150,0 332~.~ 1596,? ?49.7 S 141?.8 ~ 1.65 ~0 3949.0 38,80 S 70.40 ~ 94.0 3396,3 165S.7 772.4 S 1472.3 %; 4.01 41 4074,0 ~8.00 S '72.20 ~ 12S.0 ~49~,3 1'73~.1 797,2 ~ 1545,8 ~ 1.10 ¢2 4138,~ 36,30 $ 73,20 ~ 64,~ 3545,3 I771.~ 808.7 $ 1S82,7 ~ 2;82 43 425S,0 3'4.90 S 74,~0 ~ 117.0 ~40.4 1839,~ 82?.? ~ 1849.1 ~ 1.36 ¢4 43~8,0 3~,90 S 7~,3~ ~ 93,0 3717,2 1891.~ 841.8 ~ 1698.7 ~ 1.08 45 4474,8 32,90 S 74.10 ~ 126.0 3822.3 I960.4 800,7 $: 1765.5 [~ 0.80 ~ 4599,0 31.20 S 74,30 ~ 125,0 ~928,3 2026,~ 878.8 S 1829,3 ~ t,~ .47 4675.0 30,40 5' 73,50 ~ 75.0 3993.6 2064.9 889.5 $ 1888,? %; '1.18 48 4793,0 29.40' S 74.00 ~ 118.0 409~,9 2123.4 906.0 S 1923.2 tO 0,87 49 4945,0 27,90 $ 7~,10 W 1~2,0 ¢2~9.2 219~,7 92§.4 S 1993.4 W 50 5070.0 26,80 5 7.7.00 ~ 125.0 4340,3 2252.S 9~9.3 $ 2049.1 ~d 1.12 ~;1 ~196.0 26.20 $ 77.30 ~ 126.0 44~3.0 2308,0 ~1.8 ~ 2103.9 ~ 0",4~ ~2 5257.0 2~.20 5 77,40 ~ Gl.0 4507,8 2334,5 957.7 $ 2130,2 ~ ~.07 ~3 5380,0 2~o~0 S 78.30 ~ I23.0 4f118.5 2387.3 989.0 $ 2182,7 ~ 0.6~ 5;4 5509,~ 24.80 S 77.80 U 129,0 4735.2 244t.2 980,3 S 2236,3 ~ 0,57 55 5~28.0 24,~0 $ 77.50 ~ 119.0 4843,4 2490,0 990.9 $ 22B4.8 tO 0.27 56 5753,0 23.60 S 79,70 ~ 125.0 4957,~ 2S40.0 1001,0 S 2334,7 ~ 1.02 ~7 5883,0 2~.20 $ 78,20 ~ 130.0 5076,8 2590,~ 1010.3 $ 2385,4 ~ 0.55 58 6010,0 22.~0' ~ 78.70 ~ 127.0 5193.8 2~39.2 1020.8 S 2435.8 {~ 0.50 59 6t33.0 22.40 S 79,20 ~. t23.0 S307.5 2685.3 1029.8 S 2480.0 W 0.23 60 6261.0 '22,00 5 80.50 %; 128,0 ~42~.0 2732.5 1038,3 S 2527.~ lJ 0.49 ~1 ~388.0 21.60 S 79.10 ~ t27.0 5543.9 2778.8 .1046.7 S 2574.0 (O 0.52 62 6514,0 Zl,40 .5 80,00 ~ I26,0 566t. I 292~,8 1055,1 S 2819,4 tJ. 0.3t 63 ~39,0 21'.t0 $ 79.S0 %; 12~.0 5777.6 28~8,1 1063.1 S 28~4.0 ~ 0.28 ~4 ~765.0 21.00 S 79,20 ~ 126.0 5895.2 2912.4 1071.5. S 2708.5 ~ 0.12 ~S 5891,0 21.00 S 79.50 U 12.6.0 6012.9 2956,6 1079.8 5 2752,~ [~ ~,09 ~6 7018,0 20,50 S 8t,40 ~ 127.0 6131.6 ~000.4 1087.3 $ 2797,2 [~ 0,66 87 '7i44.0 19.50 S 7B,SO %; ,lZ6,0 6250.0 g04~.4 t'094.4 S 2839.7 [~ 0.95 ~B 7270.0 l~.2g S 79.30.~ 12.G.~ 8369.3 3082.3 !101.9 S 2879.7 U 1,03 69 73B7.0 17,20 S 76.80 ~ 127.0 ~490.2 3120.2 I109 9 S 2917.5 U 0,96 70 '7450.0 17.20 S 76,80 ~ 53.0 6540.9 3t55.7 1113,5 S 2932.8 ~ O,O0 --- Final Closure Direction.: $ $9.21%; --- Final Closure Distance: $137,.037 fart ORIGIf AL SURVEY REPORT MARATHON OIL COMPANY SLOT A-l, WELL NUMBER M-13, TRADING BAY UNIT, KENAI BOROUGH, ALASKA STEELHEAD PLATFORM JULY 25, 1989 Alaska Oil & Gas Cons. Gyrodata Incorporated PO. Box 79389 Houston. Texas 77224 713 461-3!46 July 25,1989 Mr Guy Whitlock Marathon Oil Company 3201 C Street, Suit 800 Anchorage, Alaska 99503 Re: Slot A-I, Well Number M-13 Trading Bay Unit, Kenai Borough, Alaska Dear Mr. Whitlock: Enclosed please find one (1) original and six (6) copies of the completed survey of Well No. Slot A-1. We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely, Gary U~echt Vice President, Technical Services GU/cv Enclosures Gyrodata Services, Inc. Houston. TX Lafayette, LA New Orleans, LA Ventura. CA Aberdeen. U.K. Calgary, Alberta A Gyrodata Directional for Survey MARATHON OIL COMPANY SLOT Al-I, WELL NUMBER M-13, STEELHEAD PLATFORM TRADING BAY UNIT, KENAI BOROUGH, ALASKA Date Run: 18-JUL-89 04:50:00 Job Number: AKO789G244 Surveyor: MIKE BUSH Calculation Method: RADIUS OF CURVATURE Survey Latitude: 60deg 48min 30sec N Bearings are Relative to TRUE NORTH Proposed Well Direction: S 67deg 14min Osec W Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Refere~e ~z: mR A Gyrodata ~RATHON OIL COMPANY LOT Al-l, WELL NUMBER M-13, STEELHEAD PLATFORM RADING BAY UNIT, KENAI BOROUGH ALASKA ob Number: AKO789G244 ' Directional Survey Page I MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft de§ min deg min deg/lO0' .0 0 0 50.0 0 10 100.0 0 13 150.0 0 14 200,0 0 13 VERT VERT DEPTH SECTION ft ft CLOSURE DISTANCE BEARING ft deg min N 0 0 E .00 .0 .0 .0 N 0 0 E GYRODATA SURVEY RUN IN 34" CASING TO 430' M.D. SURVEY COORDINATES REF. TO POOL #422 R.K.B. DIST. TO MSL 161 S 16 51 E .33 50.0 .0 .1 S 16 51 E S 16 59 W .24 100.0 .1 .2 S 5 4 E S 19 42 W .04 150.0 .2 .4 S 5 36 W S 14 46 W .04 200.0 .3 .6 $ 9 21 W 250.0 0 9 S 62 4 W .33 250.0 .5 .8 S 15 8 W 300.0 0 14 S 2 25 W .41 300.0 .6 .9 S 18 6 W 350.0 0 20 S 27 20 W .32 350.0 .7 1.2 S 17 24 W 400.0 0 11 S 13 59 W .33 400.0 .9 1.4 $ 17 57 W 430.0 0 14 S 15 11 W .16 430.0 1.0 1.5 S 17 42 W 480.0 0 14 S 13 27 W PROJECTED SURVEY AT 480' MEASURED DEPTH .02 480.0 1.1 1.7 S 17 17 W HORIZONTAL COORDINATES feet .00 N .00 E .07 S .02 E .23 S .02 E .42 S .04 W .61 S .10 W .73 S .20 W .86 S .28 W 1.11 S .35 W 1.32 S .43 W 1.43 S .46 W 1.63 S .51 W Final Station Closure: 1.7 feet South 17 deg 17 min 10 sec West HOUSTOH INST RUMEN ~' ~$r~ TJX'~ CHART NO I0 Unocal North Americ3r"'"- Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITTAL December 8, 1989 HAND DELIVERED TO: Oohn Boyle FROM: R.C. Warthen K. D. Kiloh LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Trad~qg Bay Unit, McArthur River Field~ Steelhead M-13 i blueline and I sepia of logs: Formation Evaluation Log Array Sonic/SDT Rrocessed Array Sonic Waveform Cement Bond Log Cement Evaluation Log True Vertical Depth FDC/CNL True Vertical Depth DIL/SFL/SR Stratigraphic Dipmeter (SHDT) Cement Volume Log 2" & 5" Lithodensity/Compensated Neutron 2" & 5" Dual Induction-SFL 2 copies of survey 1 magnetic tape w/listing PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT OCT 14 '8~ 06:BB STEELHE~D-DRILLIMg POOL ARCTIC ALASKA BOPE Inspection Report, Location: Sec T R M Pool Arctic Alaska Rig # .......... ~.~L..~ ............ Location, General Well Sign General Housekeeping ~.a~/' Rig ... ., Reserve Pi t -,,.~.~..~?---.~-~_.~- :~ ........ l] 1 ii I ir Mud S.ystems ...........V.iSU~_I ............. Audi_o- ............ .¢/ / Trip Tank · Pit Gauge Flow Monitor Gas Detectors ~Qg.E__S..ta c k Test Pressure Annular Prevente r._.~~.. Pipe Rams ~~ B1 i nd Rams_..~/~.~.~ Choke C~ne Check Valve._.~g~. ~. ~. ~.~. ~~.= ............ .......... Test Results: Failure~ ~o~~ ..... . . . Repair or Repl~cemen~ ttve/ Cmission office noti'fid. Remrks: ~= ............... , ........ ,,,, Representative Pemit # i i i i i i i i i i ...... c Casing Set @ ft. Representative A_C_CU UkATOB...S_Y_S_T..EM Full Charge Pressure ......... ................. psig.~ Pressure After Closure psig. Pump incr clos pres 200 psig:._ .......... min ....sec Full Charge Pressure Attained: min....... sec N2,' psig Control s: Master ~/~.~ ............ ............ Remote / Blinds switch cover v'~. KELLEY AND FLOOR SAFETY VALVES /' Upper Kelly_Z.__Test PressurejLis~/~,-~' ,-~""~.,. Lower KellY / Test Pressure~/,~~ Ball Type ~ Test Pressu. r_e~i~.._~Z~_.~_~ Inside BOP Test Pressure~a:r2~//_.~.~ Choke Mnfold' Test Pressure~~~ No. val yes /, ~ ............ . ..... No. Flanges ...... _~_~'. ......... _ Adjustable Chokes Hy, dr, au,],i ca,t ,ly. qpera,te,,,d,,, choke Test Time.L.'. '~ hrs. ~' min. ' be made within days and Repres.enta- ., . FORMS1: 20001 Operator Represe~a t ive '"~'-~ ~~~. ~ 9/15/88 LER L' '; SEP M EMORAN Dc, M State of Alaska A~SKA OIL AIqD GAS COiqSERVATION COr~I~SION ~< August 14, 1989 TO: Lonnie C. Smi DATE: Commissioner ? : FILE NO: D .BDF. 081 THRU: FROM: TELEPHONE NO: ~-tichael T. l~inder ~~-~, SUBJECT.' Sr. Petroleuat Engineer Bobby D. Foster ~ ?etroleu~.. Inspector BOP Test Marathon TBU-M- 13 Permit No. 89-49 Tr~adi~g~'~y Oil Pool.5 Tuesday, Augus~ 1, 1989, The BOP test began at 10:30 am and was ~-0qtCi6d~d::a(~ 4?00 pm. ~s the attached BOP test form shows there were no failures. The only problem was the sTr~ of chicksan in the kill line. I requested this be corrected as soon as replacement equipment could be obtained. in sum~tary, i witnessed the BOP test on Marathon's M-13. Attachment D. BDF. 08la Page 2 August 14, 1989 ?,,farathon TBU M- ! 3 ~[r. Thompson, ~arathon Rep. had the driller close the blind ram;~ and an attempt was made to pressure test the casing. After pumpi~g 7~ bbls of =' ' ~r~a~ ~-~ . '_e the crew was looking ,. ..~,iuzd no pressure was ....... c=~ed !~H~i~ for leaks one of them noticed a small gas ]~eak at the point wh~.re the cap fits between the 30" and 20" conduc~o-~..rs were o~oined- ' ..... ~'= TI)e va].ve was A hose was instaz.~ed and the pressure was b!e~~ o.,=.. closed and the pressure built up to °5 ~'- ~..~ ..... ..... ~ pszg i~m~edia~e~,~ and to ~5 in 6 minutes. The valve vgas opened and the pressure was b!e~ off and after 30 minutes the valve was closed off and the pressure gauge was monitored. The pressure built slowly from 0 to 140 psig in I 45 minutes. The b,r..~ssu~e~ between the 20" a~d 16" casing maintained r~ cons~an~ psig dur~_,~ the duratio~t o: the test ~o attempt was made to this pressure off. STATE OF ALASKA , ' ALASKA OIL & CAS CONSERVATION COfffilSSION , B.O.P.E. Inspection Report -. '8- '" ' - ~4~ l~ ..' ~o~,~o~ s~. ~. ~ B~ U~ . . _ C,,~s s,~ s, _ ' ~. ' - Loca~ion, Ceneral ~ ~ell Sign~ ACg~LATOR SYST~ ' ~eneral Ilousekeep~ng ~ RiS ~ ._ Full Charge Pressure~~ ' 'psig. , .. Hud Systems V.isual · Trip Tank Flow ltonitor Annular Preventer · : .. Pipe Rams · · Blind Rams Audio Pump incr. clos. pzes. 20,0 psig --~ miCa_sec. Ful1 Charge Pressure At~ained: .~. ¥_~:.~ ~~~ :~. ~.~... , .... Conc~ols:,~as~er ~.~ Ramoce~~Blinds s~i~ch cover~~ [~1!y and Floor Safe~y Valves Lover Kellr.. /' Test P~:essure~ Ball Type, ,, /'." 'Test Pressure~ Inside'BOP / Test Choke Line Valves //~.- .O ' .Choke Hanifold~, ~Tes~ P~essure~ ' ~~',tm~ KiI1 Lin~ ~alves ' ~o flanges , .... - · , , ' / Ch~k ~alw ~ , Ad~usCabl~ Chokes~ , . , ~es~ ~es~l~sl ~a~lu~es ~ ~esc ~a~~ h~s, · RePair o~ Replacement of ~ailed equip~en~ ~o ba ~ade vichin ~- day~ and In~pec~o.~/ . . Co~tssion. office notified. '. Remarks g ' · · Orig. - AO&GCC . CC -.Operator .c~o~ ~~~~~~ .cc - Supervisor Inspe ...-- , · , 3L Unocal Oil & Gas Di'~"~n Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District August 2, 1989 C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Hr. Chatterton: Enclosed for your file is a survey report on Well M-13, Steelhead Platform, run on Ouly 25, 1989. Please contact me if you desire additional copies of this survey. Very truly yours, , Candace Lockwood Environmental Analyst Attachment CC' Don Wotrlng ARCO Alaska, Inc. Anchorage CWL: klb O013n/?l Alask& ulion Domest,c Production Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 April 27, 1989 Hr. llike Iiinder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mi ke- Attached are schematics of the diverter system, choke manifold, and mud system that will be used on Well M-13, Trading Bay Unit, Steelhead Platform. Sincerely, Well M-13 will not interfere with any existing wells drilled from the Grayl lng Platform. G. R. Whitlock Drill lng Superintendent GRW/aem\DOCS\DD9 Attachment RE£EJVED Alaska Oi~ & Gas Cons. Cc~mi~s~o~ ~nchorage A subsidiary of USX Corporation to Flare to Flare ,I 3' Cameron 5000~ Valve 2' Cameron 5000~ Valve 3' Damco 2" Cameron 5000~ Valve :6-5/8°i OD 2' Cameron 5000~. Valve 2° Plug Pressure Gauge Cameron 5000,* Valve 2' Cameron 5000~ Valve Cameron 5000~ Valve Cameron 5000.f. Valve ManUalI Choke ~', Rig F~loor Super Choke Needle Valves × ,,I I To Gas Buster !--~-.. Pressure :~, Sensor for~ Super Choke 2' Cameron 5000~, Valve 3' Cross Over 50OO~ Steelhead Platform -- Pool Rig ~422 Choke Manifold Plan View STEELHEAD PLATFORM DIVERTER SYSTEM Rig Substructure Rig Substructure I Ceramite filled ~,~ ~ Sleeies~ / 20' Diverter Lines ~X, 20' Ball Valves Ceramite filled Sleeves Section View 29-1/2° 500 MSP Annular IJ 29-112' 500 psi Flange .. ', !~ ,%1 .~. :.~:: ' !! '" ~4 tw --/,3 'i'0 ~SIN$ FILL LINE BELL NIPPLE RIG ~22 SUBSTRUCTURE MUD SYSTEM SCHEMATIC BY-PASS DITCH SWACO VACUUM DEC.,ASS~ TRIP TANK 90BBL TRIP TANK PUMP DEOA~ER TANK 125BBL DE(}ASSER EDUCTOR PUMP ~TIVE TANK 125BBL MUD RETURN LINE T° PITS IN MUD MODULE CENTRIFUGE PIT lOO Bbls Cap 0.99 Bbls/in - 0 MUD CLEANER PIT lO5 Bbls Cap 1.03 Bbls/in SUCTION PIT ~2 320 Bbls Cap 3.05 Bbls/in DESANDER PIT 13 Bbls Cap 1.11 Bbls/in , ................ © MUD RETURN DITCH -- EQUALIZE R - AGITATOR MUD GUN REsERvE PIT 509 Bbls Cap 4.97 Bbls~'in I . MIX PIT 82 Bbls Cap 0.77 Bbls/in N PILL PIT DESANDER PIT 113 Bbls Cap 1.11 Bbls/in MUD CLEANER PIT lO5 Bbls Cap 1.03 Bbls/in CENTRIFUGE PIT 100 Bbls Cap 0.99 Bbls/in .0 80 Bbls Cap 0.75 Bbls/in SUCTION PIT ~1 -0 320 Bbls Cap 3.05 Bbls/in Mud Return Line From Substructure Mud System STEELHEAD PLATFORM MUD PIT LAYOUT Charge Pumps I Mud Pump Mud Pump May 3, 1989 Telecopy: (907)276-7542 Mr. Roy D. Roberts Environmental Engineer Union Oil Company of California P. O. Box 190247 Anchorage, Alaska 99502 Re: Trading Bay Unit M-13 Union Oil ComPany of California Permit No. 89-49 Sur. Loc. 1048'FNL, 453'F%~L, Sec. 33, T9N, R13W, SM Btmhole Loc. 2257'FNL, 2424'FEL, Sec. 32, TgN, R13W, SM Dear Mr. Roberts Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting detez"minations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very trulM~yours, ~C. V. ~:~r'to Chai~an o f Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COmmISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux STATE OF ALASKA ALASKA u~L AND GAS CONSERVATION CL~vlMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen Service [] Developement Gas ~ Single Zone [] Multiple Zone , 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNOCAL (Marathon Oil Company, Sub-Operator) 152' KB above MSL feet McArthur River Field 3. Address 6. Property Designation Grayling Gas Sands P. O. Box 190247 Anchorage, AK 99519-0247 ADL-17594 Pool 4. Location of well at surface 7. Unit or property Name 11. Type Burial(see 20AAC 25,025) 1048' FNL, 453' FWL, Sec 33, T9N, R13W, S.M. Trading Bay Unit At top of productive interval 8. Well nurpber Number 5194234 1101' FNL, 323' FWL, Sec 33, T9N, R13W, S.M.~' M-13 Equitable At total depth 9. Approximate spud date Amount $200,000 U.S. 2257' FNL, 2424' FEL, Sec 32, T9N, R13W, S.M. June 7, 1989 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property' 15. Proposed depth(MOa.dTVD) property line 7461' MI) 2424' from ADL18730feet 95.4 feet 5116.00 acres 6552' TVD feet ,,, 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 800 feet Maximum hole angle~0' 0°8 aaximu,~ surface 2633 psig At total depth ('I'VD) 2749 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 34" 407 ' 73 73 480 ' 480 ' Driven 26" 20" 94#(-56 RL-4C 877' 73 73 950' 950' 1500 sx ** 16,, 75#K_55 Buttres. 1377' 73 73 .1463' 1450'* 1500 ~x ~..~ *** /3-3/8" 61# K-55 Buttres~ 2827' 73 73 !3012' 2700' 1350 sx ~,~ 12-1/4" /0-3/4" 55.5# N-80 Buttres~ 427' 73 73 500' 500' 1315 sx 9-5/8" 43.5# N-80 Buttres~ 5300' 500 500 5800' 4970' 47.0# N-80 Buttres~ 1676' 5800 i4970 7461' 6552' * Top of AC-1 sand at 1492' T.V.D. This is the highest known gas. ** Hole size- 17-1/2" UR 20" , *** Hole size- 14-3/4", UR 17-1/2".RECEIVED APR 1 7' Alaska .0il & Gas Cons, C0mmissi0. ': Anchorage 20. Attachments Filing fee ~ Property plat-k-t BOP Sketch [] Diverter Sketch [] Drilling program Drilling fluid program g~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~:~/1¢,,,~,~~ (~t~¢-~ Title EnvSronmental Engin¢¢~ Date4/14/89 Ro~ b. Re;Der. ts l~tommission Use Only Permit Number , APInumber IApprovaldate ISeecoverletter ! 5°-?.¢Z" ?'o705/02/89 for other requirements Conditions of apProval Samples requ, ired [] Yes ,~"No Mud log required L-] Yes ~'No Hydrogen sulfide measures [] Yes ,~_No Di,rect~onal survey required ,,~ Yes [] NO Required workin~sure,for BOPE~ IDEM; ~ 3,M; [] 5M; [] 10M; [] 15M Other: (.~~7 (./.~_./~ .... ' -- by order of Approved by Commissioner the commission Date DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: M-13 FIELD: LEG: a-1 AFE No.: SLOT: I TYPE: Trading Bay Unit, Steelhead Platform 8333-9 Dual gas producer REVISION NO.: I DATE: 04/14/89 SURFACE LOCATION 1048'FNL, 453'FWL, Sec.33, T9N, R13W, S.M. BOTTOMHOLE LOCATION: 2257'FNL, 2424'FEL, Sec.32, T9N, R13W, S.M. KB ELEVATION: 152 ft. GL ELEVATION: FORMATION ESTIMATED FORMATION TOPS: DEPTH(MD) DEPTH(TVD) AC-1 1519 1502 A-1 2974 2752 B-1 3627 3252 C-1 4683 3952 D-1 5110 4352 E-1 7354 6452 CASING PROGRAM TYPE SIZE WT. GRADE THREAD CONDUCTOR: 20 94 X-56 RL-4C AUXILIARY: 16 75 K-55 BTC SURFACE: 13.375 61 K-55 BTC wi PRODUCTION: SET FROM Surf Surf Surf POTENTIAL CONTENT gas/water gas/water gas/water gas/water gas/water gas/water SET TO 950' 1463' 3012' 10.75 55.5 N-80 BTC Surf 500' 9.625 43.5 N-80 BTC 500' 5800 9.625 47.0 N-80 BTC 5800' 7461' HOLE SIZE 26" 17-1/2" U/R to 20" 14-3/4" U/R to 17-112" 12-1/4" DIVERTER SYSTEM The diverter system will consist of a 29-1/2" x 500 psi annular preventer, two 20" diverter lines each equipped with a 20" hydraulically actuated full- opening ballvalve and a 30" x 500 psi riser. A preselected diverter valve will open when the annular is closed. The direction of flow can be changed without opening the annular. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 16-3/4" x 5000psi Hydril type GK annular preventer, a 16-3/4" x 10000 psi Hydril double gate ram type preventer outfitted with pipe rams in the bottom and blind rams in the top, a 16-3/" x 10000 psi drilling spool (mud cross) equipped with a 4-1/16" x 10000 psi outlet and a 3-1/16" x 10000 psi outlet. The riser will be rated for 16-3/4" x 5000 psi. The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. The blowout preventers, choke manifold and associated equipment will be pressure tested to 250 psi and to 3000 psi with the exception of the annular which will be tested to 250 psi and to 2000 psi. MUD EQUIPMENT The solids control equipment consists of an Oiltools dual tandem shale shaker, a I~randt 2-cone desander, a I~randt mudcleaner, and a I~randt centrifuge. RECEIVED Alaska Oil & ~;as Cons. Commission Anchorage CEMENTING PROGRAM CONDUCTOR: 20" @ 950' MD LEAD SLURRY TYPE Premium cement w/15 Ib/sk Thix Lite 373 WEIGHT: 12.8 ppg. YIELD: 2.17 cu. ft./sk WATER REQ.: 11.9 gal/sk PUMPING TIME: 6:00+ hrs:min EXCESS (%): 100 % ESTIMATED VOLUME (Gauge hole): 1100 sx TAIL SLURRY TYPE: Premium cement w/3% CaCI2 WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: 5 gal/sk PUMPING TIME: 6:00+ hrs:min EXCESS (%): 100 % ESTIMATED VOLUME (Gauge hole): 400 sx AUXILIARY: 16" @ 1463' MD LEAD SLURRY TYPE Premium cement wi 15 Ib/sk Thix Lite 373 WEIGHT: 13.6 ppg. YIELD: 2.17 cu. ft./sk WATER REQ.: 11.9 gal/sk PUMPING TIME: 6:00+ hrs:min EXCESS (%): 100 % ESTIMATED VOLUME (Gauge hole): 1100 sx TAIL SLURRY TYPE: Premium cement w/3% CaCI2 WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: 5 gal/sk PUMPING TIME: 6:00+ hrs:min EXCESS (%): 100 % ESTIMATED VOLUME (Gauge hole): 400 sx RECIE: VED Oil & Gas Co~s. Oornmissior~ Ar~chorage SURFACE: 13-3/8" @ 3012' LEAD SLURRY TYPE Premium cement w/8% ge1,.25% CFR-3,.5°/o Halad-344 2% Calcium Chloride WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): 13.2 ppg. 1.89 cu. ft./sk 10.2 gal/sk 9:40 hrs:min 50 % ESTIMATED VOLUME (Gauge hole): 200 sx INTERMEDIATE SLURRY TYPE: Premium cement w/4% ge1,.25% CFR-3, .5% Halad-344, 2% Calcium chloride WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): 14.7 ppg. 1.52 cu. ft./sk 7.6 gal/sk 6:50 hrs:min 50 % ESTIMATED VOLUME (Gauge hole): 750 sx TAIL SLURRY TYPE: Premium cement w/.25% CFR-3,1% Calcium chloride WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: 5 gal/sk PUMPING TIME: 6:00+ hrs:min EXCESS (%): 50 % ESTIMATED VOLUME (Gauge hole): 400 sx PRODUCTION: 9-5/8" and 10-3/4" @ 7461' LEAD SLURRY TYPE Premium cement w/6% gel, .25% CFR-3, .4% Halad-344, .1% LWL WEIGHT: 13.6 ppg. YIELD: 1.71 cu. ft./sk WATER REQ.: 8.9 gal/sk PUMPING TIME: 3:25 hrs:min EXCESS (%): 30 % ESTIMATED VOLUME (Gauge hole): 540 sx TAIL SLURRY TYPE: Premium cement w/.25% CFR-3, .5% Halad -344,. 1% LWL WEIGHT: 15.6 ppg. YIELD: 1.18 cu. ft./sk WATER REQ.: 5.2 gal/sk PUMPING TIME: 3:30 hrs:min EXCESS (%): 30 % ESTIMATED VOLUME (Gauge hole): 775 sx MUD PROGRAM DEPTH DEPTH WEIGHT VISC. WATER MUD TYPE FROM TO ppg sec/qt LOSS Surf 950' 8.8-9.2 60-80 <30cc's Spud 950' 1450' 9.0-9.2 60-80 <30cc's Spud 1450' 2900' 9.2-9.4 40-50 <20cc's Gel/Benex 2900' 7461' 9.2-9.4 40-50 <10cc's 1% KCI/Polymer SPECIAL CONSIDERATIONS: per EPA requirements. Mud discharges will be monitored and reported DIRECTIONAL PLAN NORTH EAST DESC MD TVD INCL AZIM COORD COORD SECTION RKB 0 0 0 N0.0W 0.00N 0.00E 0 Kickoff 800 800 0 S67,42W 0.00N 0.00E 0 End of build 2136.26 2029,87 40.08 S67.42W 170.30S 415.13W 448.69 Drop pt. 4279.01 3669.2 40.08 S67.42W 694.02S 1691.73W 1828.49 End of drop 5607.37 4812.3 20.18 S66.04W 951.90S 2303.00W 2491.94 T.D. 7461.15 6552.3 20.18 S66.04W 1211.60S 2887.33W 3131.24 Note: M-25 is the only existing well within 100 ft. of planned wellpath of M-13. Distance between well paths is 95' from surface to 800' TVD where the wellpaths diverge, CONDUCTOR: LOGGING No logging is planned for this interval. AUXILIARY: No logging is planned for this interval. SURFACE: GR/Cal/DIL/BHC-Sonic from 2900' to 1450'. GR from 2900'-surface. PRODUCTION: GR/SP/Cal/DIL/LSS from 7461' to 2900'. FDC/CNL/Cal/GR from 7461' to 2900'. Dipmeter from 7461' to 2900'. 25 to 50 pressure recordings will be taken with an RFT at intervals to be determined. COMPLETION: A Cement Bond Log (CBL/GR) and a directional gyro- survey will be run prior to perforating. No coring is planned for this well. CORING PROGRAM TESTING PROGRAM No open hole tests are planned for this well. DRILLING PROGRAM CONDUCTOR: Nipple up diverter and pressure test to 500 psi. Drill a 26" hole to 975' KB. Run and cement 20" conductor with 1500 sx of cement. WOC. Perform top job if necessary. Cutoff conductor. AUXILIARY: Nipple up diverter and pressure test to 500 psi. All personnel not required for drilling and production operations will be removed at this time. Drill a 17-1/2" hole to 1450' KB per the directional program. program. Underream the 17-1/2" hole to 22" from 950' to 1450'. Run and cement 16" auxiliary casing. WOC. Set slips and nipple up BOPE. Test BOPE, choke manifold, and casing to 2500 psi. SURFACE: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill 14-3/4" hole from 1450' to 2900' per the directional program. Reconstruction activities will resume at this time. Underream the 14-3/4" hole to 17_1/2" from 1450' to 2900'. Run and cement 13-3/8" casing with 1350 sx. WOC. Set slips and nipple up BOPE. Test BOPE, choke manifold, and casing to 2800 psi. PRODUCTION: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill 12-1/4" hole from 2900' to 7461' per the directional program. Run and cement 9-5/8" casing with 1315 sx. WOC. Set slips and nipple up BOPE. Test BOPE, choke manifold, and casing to 3000 psi. COMPLETION: Cleanout casing to PBTD. Run gyro and CBL. Perforate and flowtest the D-16A and D-16BC sand with TCP guns. Kill well, POOH. Set permanent production packer with plug above perfs. Perforate and flowtest the D-3A, D-3B, and D-4 sands with TCP guns. Kill well, POOH. Retrieve packer plug. Run dual strings of 3-1/2" tubing and dual packer. Land tubing. Nipple down BOPE. Nipple up tree. Unload tubing with CTU and nitrogen. '1 15 ~ 151 °~2L~,~a 11 Kill Line Fillup Line Flow Line L I Hydril l 16-314' 5000 psi Type GK Annular \ ° r-------- Blind Rams Pipe Rams I ~ Coflexip Hose [' 'i ! ' i Gate Valve HCR Valve 'Pipe Rams 16-3/4' 10,000 psi Singlegate · ~ I I 16-314° 10,000 psi Doublegate Check Valve Gate Valve Gat® Valve STEELHEAD PLATFORM Steelhead Blowout Preventer Schematic 16-314' 5000 psi Riser J Ball Valve lhead To Gas Buster to Flare to Flare I, 2' Cameron 3' Cameron ,._ 5000~, Valve ~ooo. ~ I /, .--.~ · OD~ ~ 2" Cameron 5000~ Valve ~5000~ Valve 2' Cameron 5000- Valve Union to Shake Shakers ~ ! 3' Plug 2' Cameron 5000~. Valve Cameron 5000~ Valve 2"' Cameron 5000~ Valve Manual Rig Floor Un, Super Choke Needle Valves Preseure Gauge. L 2' Cameron 5000~ Valve ti¸ Choke Pressure Sensor for Super Choke Cameron 6000~ Valve I 3' Cross Over 5000. Steelhead Platform Pool Rig ,f, 422 Choke Manifold Plan View STEELHEAD PLATFORM DIVERTER SYSTEM Rig Substructure I29-112' 50O MSP Annular Rig Substructure [ Ceramite filled ,~ ~1 20' Diverter Lines ~ 20' Ball Valves Ceramite filled Sleeves Section View Riser' 29-1/2' 500 psi Flange HORIZONTAL PROJECTION SCALE 1 IN. '" 1000 FEET IIARATHON OIL COIIPANY Leo Al, Slot 1, Well No' M-13 Propoaed STEELHEAD Platform' Cool( Inlet, Alaeke z o TD LOCAT I ON ' 2260' FNL. 2434' FEL SEC. 32. TgN. R I3W 1000 m 1 000 _ 2000 _ 3000 _ WEST-EAST 4000 3000 2000 1 000 I I i 0 1 000 I I SURFACE LOCATION, 1048' FNL. 453' FWL SEC. 33. TgN. R13W TARGET #1 TVD=4812 THD=SSOZ DEP-2492 SOUTH 952 WEST 2303 TARGET #1 LOCATION, 2000' FNL. 1850' FEL SEC. 32. TgN. R13W TARGET #2 TVD=6152 TND=Z035 DEP-2984 SOUTH 1152 WEST 2753 TARGET #2 LOCATION, 2200' FNL. 2300' FEL SEC. 32. TgN. R13W S 67 DEG 14 MI N W 3151' (TO TD) HARATHON OIL COHPANY Leg Al, Slot 1 Well NoS STEELHEAD Platform' Oook M-13 Inlet, Propoeed Aleeka 0 _ RKB ELEVAT[ON~ 152' ~0 C~ 1000_ 2000 _ :3000 _ 4000 _ 5000 _ 6000 _ 7000, KOP i$ 21 27' 3g EOB TVD=800 THD=800 DEP=O BUILD 3 DEG PER 100 FT TVD=2030 TMD=21:36 DEP=449 MAXIMUM AN GLE 40 DEO 5 MI N BEOIN ANOLE DROP 39 4.5 TVD=3669 TMD=4279 DEP=I 828 36 45 33 30 4,' DROP I .5 DEO 27' 45 PER !00 FT 24 45 21 45 TAROET #1 TVD=4812 TMD=5607 DEP--2492 (END ANOLE DROP) TARGET 20 DEG ANGLE 11 MIN TAROET #2 TVD=6152 TMD=7035 DEP=2984 TD TVD'--6552 THD=,7461 DEP=313;1 I I I 1 000 2000 3000 VERTICAL SECTION I 4000 .=, t ,:, 't n a.m e : ..- A 1 -' ]. D Cz t e : -' 0 6-A P R-.:3 9 Rev:i.s. ion no :- 2 Pr'.e~.a.r-ed. b'-,.' :- T 0 u r. r- e .F : .... F ~.. ~..) 4.::,.::, :, ()M A EASTMAN CHRISTEN:~:EN~ A,",chor-~_~e, A],-~$k~ 06-APR-8? ~. All depths ~J-.e irJ t:eet ,-~r,d ,.zr'-e RKB. ~. · ~. A1 1 dis'L'~nces ~r.e in t:eet . .~ Opi~in Point of loc,~1 coopdin,~tes i5 slot. ~ :x- V~,p'~ic~l section is c,~]cu!,~ted on the ~l,~.ne oF -~. ~- S67 14W (247.24 de~) ~nd is r.e-¢er, enced fr'.om .~. ~ ~1 or. '~- .P~Se 2 We i 1 P r- o .F i 1 e :"-;Y r, o ~ s i s E. AS'I'MAr.4 CFiR i STENSEN, Me~sur. ed Tpue Ver-e. De Pt h De Pt h I r, ,: 1 i r,. A z i m u t h Be ~ r. i r, ~ [le~ Min De~r. ees De~ Mir, 06- AF::'R-- 8'.'T.' Rect~nMul ~r. C,:, o r-d i n~te s Vet. tics1 Se c t i ,:, r, 0.00 0.C) 0 0 0 0.00 N 0 OE 0.00hl 0.00E 0.00 FiC~L..D 8 0 0.0 0 8 0 0.0("~ 0 0 0.0 0 N 0 0 E 0.00 N 0.00 E 0.00 BUILD -. BUII....B RATE = :3,,C) ODEG / 100FT. :2:1 ............ c: F., 26 2029 :=: 7 4 C) 5 247 ,'~, 9 '-'=,,:/,-/ 42 W. 170 :'30 S 4 1 ._. 1:3 W 44. 8 6'P H 0 L D DROP &. TURN .... DLS = 1.50DEG / 100F'F. 4 2 7 9.0:1. :.::' 6/-, 9 .2 0 4. 0 ._=; 2 4. 7.6 9 '~".=,/'..::, -'/ 4. 2 W T~RE. iET 5607:37 4812 :'::('~ 20:1. 1 94 F., 04 S/.":,/-, .-. W H 0 L D ,, _ / =~'-' 24,6 $66 '7.4. 6 J 1 .=, c,._, ..... ... ,, 30 20 I :1, .0.4 2 W Nell F'r-c,~:~le _.HR I .=,TbN.::,EN, EAF-;TMAN ~ .... - ..... -' , An,- I-~c,r.~_qe, A1 Me~sur-ed True Vert Ir, clin. Azimuth Be~r. in.~ DePth DePth De~ Min De~r. ees De~ Min 06-APR-89 Rec t a.r', ~ u 1 ~r. Ve r-t i ,:;~ 1 C o o r- d i n,a t e s S e c t i o n KICK OFF POINT 0.00 0.00 0 0 0.00 N 0 OE O. OON O.00E 0.00 500.00 500.00 0 0 0.00 N 0 OE 0.00N O.OOE 0.00 800.00 800.00 0 0 0.00 N 0 OE O.00N O.OOE 0.00 900,00 899,95 3 0 247,69 S67 42W 0.99S 2.4.2W 2,62 1000.00 9'29.6:3 6 0 247.69 S67 42W :B. 9'78 9.68W 10. 4~ ..... . ....... :, ::,7 42 W 8.92'.:; . ~9 . ._ i 100.00 109:::. 77 9 0 247./',9 '"" ¢~ . . _ 21 7._ W 2:3 ~ 1 1200.00 1197.08 12 0 247.69 S67 42W 15.848 :38.61W 41.7:3 1300,00 1294.31 15 0 247.69 S67 42W 24,708 60.21W 65.07 1400.00 1:390.18 18 0 247.69 S67 42W :35,488 86.48W 93.47 '-' I 48 1 ~c' .~,/. ,:,~ 1500.00 1484.4 :B 2 :L 0 247. A 9 S 67 4. ~ W 1 17 :B 6 W 1 = _, 160(3. O0 1576.81 .24 0 247.6'.,} S6'7 42W 62. 678 152,, 76W 165.11 17(}0,,00 1667.06 27 0 247.69 S67 42W 79.018 192.57W 208.16 180().00 1754.93 30 0 247.69 S67 42W 97. 128 236~73W - 255~86 .... :, .)o. I 1 19 (') 0 (') 0 _1. 840 1 ':' '":'":'0 .................... =, ::, 7 42 W 116 9.4. S ~.,_,._ . ¢:,,(", W 200C,. OC, 1 'i;'22.59 :36 0 247.69 S67 42W 13:3.44. S 3:37.46W 364.74 4000 ,, O0 3455 ,, 74 40 5 247.69 :36'7 42W 625.82'S 1525.50W 164.8.8:3 427'.-.? ,, 01 3669.2.0 40 5 247.69 S6,,7 4.2W 694. 028 !/.i:,91.73W 1828.49 4:30 C). 00 :3,685, :30 :3 ,:.-v 4. 6 2. 4-'7,68 S 67 41 W 69':.';' ,, 1:3 'S 1704.1 ':.-.' W 1841.9 '7 44 () 0 (') (') "::' '''?,./.. '":' ':::' '-':' ':"':' 2..,.1. 7. 'S 67 72. :3 r ,-,,'-. . '-' I '.:.:' 0-'I- 9 :'2: ......... , _, .......... : ...... 16 6 t ::: 7 W . J,'",.::, 1762 4. ~: W 1 . 4500.0() :384:;:2.29 34:-., 4/:, 24'7, 5:3 S67:32N 74,./:,, :328 1818.72W 1 '~65.83 4600. ()0 392:3,, 17 :35 17 24'7 ,, 45 S67 27W '768. 838 1873.06W 2024.64 4700. O0 40()5.55 3:3 47 :2:47.3/:, S67 22W 770./:,08 :1. 925. :38W 2(}81.3]:' 4 :::: ("~(') () 0 408'ii'.' :=: 9 .:,.-, .-, ~. --. c, 7 'S 67 '""-' ..... :.. 17 ~:. ,./, ~. 1,6 W '=' I 1 6 ~'..=, 1975 /':, 7 W 21 ':' ~ o--, 490(),, 0() 4.174, 63 30 47 247. 16 S.,...,7 1 OW 831. 878 2(32:3. 881,,.t 2188. 11 ..-,, !:::;00(') ..................... O0 4261 "::'0 29 1'7 °47,:. C).~";...F;¢.!:,7 .::,N ':'/P~" '~T"ll/':~:""~ '~z'~2:~ ~~tl~[~~'~'~ ~'~'--'''-''-~ ~' , . \ \' Nell Pro~:i~e EASTMAN CHR'[S"FENSEN, Ai-,,-h,:,r.,.~se, A],-~sk,=z ( ,-_ o r, t ± n u e d ) Memsur-ed Tr-ue Ver. t DePth DePth I ncl in. Azirr, uth De~ Min Deq- r. ees 5100. O0 4:349.06 27 47 5200.00 44,38. 13 26 17 5300.00 4528.36 24 47 5400.00 4619.67 23 17 5500.00 4712.05 ;21 47 !5600.00 4805.38 20 17 5607. :37 4:312.30 20 t 1 60('D0.0(} 518('.'). 83 20 11 6500, O0 5650. 14 20 11 7 0 0 0.0() 61 19.4 6 2.0 1 1 0/_-,-A P R ...-8':? Be~r-in~ Re,ztar,~ul ~r- Ver-t ica1 De ~ M i n C o ,:, r- d i n a t e s S e c t i ,:, n 246. ':.-'~3 S66 56W 870. OOS 2113.94W 2285.91 246.79 S66 47W 887.86S 2 '_i, 55.73W 2331.36 246.64 S66 38W 904.90S 21'75. :32W 2374.46 246.47 S66 28W '.-721.10S 2232.68W 2415.18 246 27 '='!-./- 16W 9:36 46S 2267 79W ..'.4 .... :,..~r. .... 246.05 '.=;66 3W 950.97S 2300.63W 2489.39 :.246, (.'.)4 S66 2W '.~51. '~0S 2303.00W 24'.-? 1. '.-74. 246,, 04 S66 2W 1006,, 'F.¢0S 2426.76W 2627.34 246.04 S66 2W :1. 076.95S 2584.37W 27'.~9.77 246 04 ' '-'/'./. '?'"':' 72 '-' '~ .........-. .... =, 2W 1147. ¢)0S 2741 97W · .zc 70:34. '79 615'2. :30 2(:) 11 246. (:)4 S66 2W 1151. '.:¢0S 275:3. OOW 2?84.27 ,, .:::,,.::, 6 '""t ,, "'" ''"''"''' ¢. ~,:' .-, .-, -) 2 4/_-, 0 4 "'/' ¢_!. rD c. ..:,:.,,=, 7 .... ' :2:1 ,, '7461.. 15 ,.: ...... _, ~ .:, t 20 I 1 . ~ W 1211 ......... :,..:,W :31 24 Eastn . n -,-',, ~itb.~li Llbl ~Uit NbW WkLL F~.RMI'f'S ITEM Fee 1. APPROVE DATE (2 thru 8) (3) Admin · (4) Casg (5) BOPE (8) ~9 -thru 13)' - 10. (10 and 13) 12. 13. (14 thru 22) (23 thru 28) Company ~/A]o~-~/ ( ./7_~O~ ~'~-/O~o~.~) Lease&YES WellNoNO. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. ~ 3. Is we~] located proper distance from property line .................. ~ 4. Is we~~,[ located proper distance from other wells ................ ' ... '~ 5. Is suz~icient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the Only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... ~. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ · . 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ .,, Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on I0-403 ............ Is adequate wellbore separation proposed ............................ ~-~ .,, Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached.~. Does BOPE have sufficient pressure rating - Test to~~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. 'Is the presence of H2S gas probable ................................. (6) OTHER (29 thru 31) (6) Add: ~/.~, 5-/-,89 Geology: Engi;~eering :/' rev: 01/30/89 6.011 Fo r 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented-- Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: o Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. C,~LU~ERG~R ~L~'S~ C~N~UTiNG CEqT~ DATE : 89/10/17 ~RIGIN : FLIC. REEL ~E · 7~58~ CONTinUATION ~ : PREVIOUS RE~L COMMENT FILl N&~E : EDIT .C3i S~RV!CE : =tic V E R S l ON O0 CAT~E : ~9/13/'17 MAX R C SZ '~c ' ~524 FILE TYPE LAST FILE ~C~RTHU~R ~IV"-'P. TEU ~-13,~ APl ~ 5 O - ? 3~.:~ - 2 t,' 4 0 7~' ~ 53 - 733- 2 0.40 7 CHLUM~ERGER ~LASKA C~M~UT'ZNG CEN~E~ OAT~ LG:SG~:D RUN NUNBER: TO DR ILL:R.: TO LOGG:R: Ol.-OCT-gg CASING I: i7 1t2" CAS'TNG 2: J~ SI',:" ~ D~::LL:x OE:~T,: . ~ 936 :NG LO'Gg:ER O:P'TH g:: 2928 B'IT SIZe: Z: !2 !/4" 'TYPG ~LU:i.D IN HOLE: P~SLY PLUS D:NSZTY: 9.5 P:H: 8.6 VISr~ .. ,, MUD :RESIST.IVITY' 2.2 FiLTRITE 2:Si :TIV:ZT¥: 2.9 ,. S ~STZV~T¥ 2.:~ S 74 T.Z~G CiRCUL.ATIO'4 FNDEO: 13:04 OI-3CT TZMiF LGSGER ON ~3~3TTSM (3'Ti:/SDT P.A.SS): 00:33 O2-DCT 'TINE. LC~G ~:R g?'4 ~r'TT:]~. ~ (LD ~/rNL: ~ P~ SS) '". 08:05 O2-Orv,~, MAXiMUN T':MP REC. G~'O5~ (3'T~/:SDT P~SS): 133 TOOL NUM~SRS' CPj AAA 1~ '$~ K ,6'3":' BIC ;~R 35 CNC HA 125.~ 0:~5 :~ Z9,3'1 PGD G 2723 SLS V3 10 ~ZS ~C tB9 NSC D I ~6 9~W L :97S G SR J 7371 F:ELD REMARKS: .3~ 3" ST/INDSO:FS ~UN Stj ~rTE. 6, 3" ST6Ng-SFmS RUN ON SCT. ~C<-UP ~3T FZL:E 17 ASC=~LI , :~4i:¢00, WAGC=C. ISA, wG~i:4)O. CCUL~ N~V CLE~q-U LOT/CNL RUN ~.~LL V~2Y ~3UGP fi. 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