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208-162
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ 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 9,930 feet 7,100 feet true vertical 4,310 feet N/A feet Effective Depth measured 5,971 feet See schematic feet true vertical 2,526 feet See schematic feet Perforation depth Measured depth 5,347 - 7,060 feet True Vertical depth 2,244 - 3,017 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 5,142 MD 2,152 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: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 7,240psi Daniel E. Marlowe Operations Manager Burst Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 2,260psi5,020psi 907 777-8376 6,870psi 401 1,384 2,594 3,612 401 1,443 Conductor Surface 5,410psi 4,760psi 28" 13-3/8" 6,120 Size 160 Production Casing Structural Liner 3,830 Length Intermediate N/A Junk 5. Permit to Drill Number: 1,195 McArthur River Field / Middle Kenai Gas PoolN/A measured 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 101 N/A Oil-Bbl 341 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-413 120 Authorized Signature with date: Authorized Name: 0 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-162 50-733-20583-00-00 Plugs ADL0017594 / ADL0018730 Trading Bay Unit M-18 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 490 Casing Pressure 7" 6,120 MD 401 1,443 8,375 TVD measured true vertical Packer 9-5/8" Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:39 am, Nov 09, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.11.06 14:46:31 -09'00' Dan Marlowe (1267) Perforate DSR-11/10/2020 SFD 11/9/2020gls 11/16/20 RBDMS HEW 11/9/2020 Updated by: JLL 11/05/20 Steelhead Platform Well: M-18 Last Completed: 07/16/2009 API: 50-733-20583-00 PTD: 208-162 SCHEMATIC CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID in TOP MD rkb TOP TVD rkb BTM MD rkb BTM TVD rkb 28” X-56 27 Surface Surface 401’ 401’ 13-3/8” 68 L-80 BTC 12.406 Surface Surface 1,443 1384’ 9-5/8” 47 L-80 BTC-M 8.688 Surface Surface 6,120’ 2,593’ 7” 26 L-80 DWCSR 6.276 4,545’ 1,976’ 7,100’ 3,035’ 7” EZSV 7,100’ 3,035’ 7” 26 L-80 DWCSR 6.276 7,100’ 3,035’ 8,375 3,611’ Tubing 3-1/2” 9.2 L-80 Hydril 503 2.992 Surface Surface 5,142’ 3,186’ RKB to TBG Head = 78.75’ 13 3/8’ Shoe @ 1,443’ 7” Liner Shoe @ 8,375’ Hydraulic Stage Collar @ 469’ 28” Conductor @ 401’ Cement to ML @ 385’ 9 5/8 Hydraulic Stage Collar @ 2,552’ MD 9 5/8” x 7” Liner Hanger @ 4,545’ (Unset) EZSV @ 7,100’ Middle SC-1 Packer @ 5,975’ Lower SC-1 Packer @ 6,744’ F-1 Sump Packer @ 7,070’ TD 8 ½ Hole @ 9,930’ Upper SC-1 Packer @ 5,142’ @, 9 5/8” Shoe @ 6,120’ MAX HOLE ANGLE = 89.3q @ 3,533’ MD SZ 20 Perforation Detail MD (rkb) TVD (rkb) Zone SPF Notes 5,347’ - 5,476’ 2,244’ - 2,303’ SZ-19 12 4-5/8” Millennium Chrg 5,537’ - 5,555’ 2,330’ - 2,339’ SZ-20 6 10/28/20 / 15Gram Razor Gun 5,600’ - 5,665’ 2,358’ - 2,388’ SZ-21 12 4-5/8” Millennium Chrg 5,790’ - 5,900’ 2,444’ - 2,494’ SZ-22 12 4-5/8” Millennium Chrg 5,945’ - 5,960’ 2,514’ - 2,521’ SZ-23 12 4-5/8” Millennium Chrg 6,370’ - 6,395’ 2,706’ - 2,717’ A-2A 14 4-5/8” Big Hole Chrg 6,440’ - 6,580’ 2,737’ - 2,800’ A-2B 14 4-5/8” Big Hole Chrg 6,712’ - 6,730’ 2,859’ - 2,868’ A-3 14 4-5/8” Big Hole Chrg 7,028’ - 7,060’ 3,002’ - 3,017’ A-5 14 4-5/8” Big Hole Chrg Cementing Information Description Volume (bbls) Density (ppg) Yield (ft3/sx)Notes Surface Csg. 1st Stage 231.0 13.0 1.47 LiteCrete to 469’ Surface Csg. 2nd Stage 259.0 13.0 1.47 Lite Crete. Stage Collar at 469’ Some cement to surface 12 bbls before landing plug. Intermediate Csg. 1st Stage 131.0 13.0 1.47 Lite Crete. Planned TOC is 4404’ Intermediate Csg. 2nd Stage 145.0 13.0 1.47 Lite Crete. Planned TOC @ 385’ ML Production Liner 70.0 13.0 1.47 Pumped 65 bbls 13.0 ppg Lite Crete through perfs. Maintained good returns through most of the job. Lost approximately 6 bbls cement near the end of displacement Jewelry Detail Item MD (rkb) TVD (rkb) OD ID Model TE-5 SSSV 463’ 462’ 5.4” 2.813” Gas Lift Mandrel 1,602’ 1,507’ 5.27” 2.992” Gas Lift Mandrel 3783’ 1,932’ 5.27” 2.992” ZXP Liner Top Packer 4,530’ 1,973’ Gas Lift Mandrel 5,061’ 2,118’ 5.27” 2.992” SC-1 GP Packer 5,142’ 2,152’ 6.0” 4.0” SC-1 GP Packer 5,975’ 2,528’ 6.0” 4.0” SC-1 GP Packer 6,744’ 2,874’ 6.0” 4.0” Model F-1 Sump Packer 7,070’ 3,021’ 5.85” 4.0” Tag 5,971 ELM 10/28/20 NOTE: could not perf SZ-24 sands. Note: Tagged at 5971 ft with tractor new perfsSZ 20S 5 () () 5,347’ - 5,476’ 2,244’ - 2,303’ SZ-19 12 4-5/8” Millennium Chrg 5,537’ - 5,555’ 2,330’ - 2,339’ SZ-20 6 10/28/20 / 15Gram Razor Gun ( b) ( b) o e S otes 5 tagged high Well Name Rig API Number Well Permit Number Start Date End Date M-18 Eline 50-733-20583-00-00 208-162 10/28/2020 10/28/2020 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary 10/28/2020 - Wednesday Arrive on Steelhead. PJSM & Permits. Remove hatch covers, place bridge in place over M-18, secure open hole on drill deck. Spot ELU, tool shack, gun rack in place. Continue MIRU. Make up GR/CCL, WellTec Tractor. Test wire and connections. Good test. Pu riser. Make up Gun #1 18', 2.375", 6 spf, 60* phase 15gram razor gun. Stab on well. PT WLV/Lub low/high 250/1500. Good test. Open well. Swab 20 3/4 turns, WHP 33, IA 120. RIH, Tag @ 5141', shut tractor off, pu hole to 5050'. RBIH tag again at same.PUH try again tag same. Slack some wire off at tag, turn tractor off and on 6 times. On the 6th try we made it by tight spot at 5141'. CTRIH to 5800', pull log up to 5200'. Send log to town Engineers for Apporval to shoot SZ-20 5537'-5500'. Decision was made to try and pull a log from 6400'-5700' before shooting. RIH to 6400', tagged at 5971'. PU manipulate wire alternating turning tractor off and on trying to get down. Picked up to 5200' tried to get a run at it, still not getting past 5971', shut well in trying to change DH dynamics still not able to get past 5,971'. Decision made to PU hole to shoot SZ-20 5537'-5555'. Got approval from Geologist. Get on depth, park at CCL Depth 5,522', CCL t/top shot 15', CCL t/bottom shot 33'. Shoot SZ-20 sands 5537'-5555', ITP 292, FTP 390, log up 200' POOH. Hung up at 5141'. Work wire up and down couple hundred feet multiple times before popping through. COOH. Tagged up, swab shut, bleed down, pop off well. All shots fired, dry gun. Rig down gun, tractor and riser. SDFN. Tagged at 5971 with Tractor . Perf SZ-20 zone 5537-5555' t SZ-20 5537'-5555' Engineers for Apporval to shoot SZ-20 5537'-5500' 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): 9,930'N/A Casing Collapse Structural Conductor Surface 2,260 psi Intermediate Production 4,760 psi Liner 5,410 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:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 7,100' COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017594 / ADL0018730 208-162 50-733-20583-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-18 CO 228A 9.2 / L-80 TVD Burst 5,142' 6,870 psi 7,240 psi Tubing Size: MD 5,020 psi 401' 1,384' 401' 1,443' 28" 13-3/8" 401' 1,443' 6,120' Perforation Depth MD (ft): 5,347 - 7,060 6,120' See schematic Tubing Grade:Tubing MD (ft): 2,244 - 3,017 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. 10/20/2020 3-1/2" Daniel E. Marlowe See schematic 4,310'7,100'3,035'~990psi 2,555'7" 2,594'9-5/8" 7,100'3,035' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:04 am, Oct 05, 2020 320-413 Daniel Marlowe I am approving this document 2020.10.02 15:54:36 -08'00' Daniel Marlowe gls 10/6/20 DSR-10/12/2020 X DLB10/05/2020 Perforate 10-404 Comm. pq 10/13/2020 dts 10/12/2020 JLC 10/13/2020 RBDMS HEW 11/3/2020 Well Work Prognosis Well Name:Trading Bay Unit M-18 API Number: 50-733-20583-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:10/20/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:208-162 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Office: 907-777-8384 Cell: 907-570-1801 Current Bottom Hole Pressure: 567 psi @ 2,630’ TVD 0.216 psi/ft Maximum Expected BHP:1,100 psi @ 2,580’ TVD 0.426 psi/ft Max. Allowable Surface Pressure (Perf Job):~990 psi using 0.1 psi/ft Brief Well Summary: Well M-18 is a gas well currently completed in the SZ and A sands. The objective of this program is add perforations into the SZ20 and SZ24 sands. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line and perforate per the program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic he objective of this program is add perforations into the SZ20 and SZ24 sands. DRAWN BY: JAR Revised CVK 8/14/09 Steelhead Platform Well: M-18 Last Completed: 07/16/2009 API: 50-733-20583-00 PTD: 208-162 SCHEMATIC CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID in TOP MD rkb TOP TVD rkb BTM MD rkb BTM TVD rkb 28” X-56 27 Surface Surface 401’ 401’ 13-3/8” 68 L-80 BTC 12.406 Surface Surface 1,443 1384’ 9-5/8” 47 L-80 BTC-M 8.688 Surface Surface 6,120’ 2,593’ 7” 26 L-80 DWCSR 6.276 4,545’ 1,976’ 7,100’ 3,035’ 7” EZSV 7,100’ 3,035’ 7” 26 L-80 DWCSR 6.276 7,100’ 3,035’ 8,375 3,611’ Tubing 3-1/2” 9.2 L-80 Hydril 503 2.992 Surface Surface 5,142’ 3,186’ RKB to TBG Head = 78.75’ 13 3/8’ Shoe @ 1,443’ 7” Liner Shoe @ 8,375’ Hydraulic Stage Collar @ 469’ 28” Conductor @ 401’ Cement to ML @ 385’ 9 5/8 Hydraulic Stage Collar @ 2,552’ MD 9 5/8” x 7” Liner Hanger @ 4,545’ (Unset) EZSV @ 7,100’ Middle SC-1 Packer @ 5,975’ Lower SC-1 Packer @ 6,744’ F-1 Sump Packer @ 7,070’ TD 8 ½ Hole @ 9,930’ Upper SC-1 Packer @ 5,142’ 9 5/8” Shoe @ 6,120’ MAX HOLE ANGLE = 89.3q @ 3,533’ MD Perforation Detail MD (rkb) TVD (rkb) Zone Density (SPF)Notes 5,347’ - 5,476’ 2,244’ - 2,303’ SZ-19 12 4-5/8” Millennium Chrg 5,600’ - 5,665’ 2,358’ - 2,388’ SZ-21 12 4-5/8” Millennium Chrg 5,790’ - 5,900’ 2,444’ - 2,494’ SZ-22 12 4-5/8” Millennium Chrg 5,945’ - 5,960’ 2,514’ - 2,521’ SZ-23 12 4-5/8” Millennium Chrg 6,370’ - 6,395’ 2,706’ - 2,717’ A-2A 14 4-5/8” Big Hole Chrg 6,440’ - 6,580’ 2,737’ - 2,800’ A-2B 14 4-5/8” Big Hole Chrg 6,712’ - 6,730’ 2,859’ - 2,868’ A-3 14 4-5/8” Big Hole Chrg 7,028’ - 7,060’ 3,002’ - 3,017’ A-5 14 4-5/8” Big Hole Chrg Cementing Information Description Volume (bbls) Density (ppg) Yield (ft3/sx)Notes Surface Csg. 1st Stage 231.0 13.0 1.47 LiteCrete to 469’ Surface Csg. 2nd Stage 259.0 13.0 1.47 Lite Crete. Stage Collar at 469’ Some cement to surface 12 bbls before landing plug. Intermediate Csg. 1st Stage 131.0 13.0 1.47 Lite Crete. Planned TOC is 4404’ Intermediate Csg. 2nd Stage 145.0 13.0 1.47 Lite Crete. Planned TOC @ 385’ ML Production Liner 70.0 13.0 1.47 Pumped 65 bbls 13.0 ppg Lite Crete through perfs. Maintained good returns through most of the job. Lost approximately 6 bbls cement near the end of displacement Jewelry Detail Item MD (rkb) TVD (rkb) OD ID Model TE-5 SSSV 463’ 462’ 5.4” 2.813” Gas Lift Mandrel 1,602’ 1,507’ 5.27” 2.992” Gas Lift Mandrel 3783’ 1,932’ 5.27” 2.992” ZXP Liner Top Packer 4,530’ 1,973’ Gas Lift Mandrel 5,061’ 2,118’ 5.27” 2.992” SC-1 GP Packer 5,142’ 2,152’ 6.0” 4.0” SC-1 GP Packer 5,975’ 2,528’ 6.0” 4.0” SC-1 GP Packer 6,744’ 2,874’ 6.0” 4.0” Model F-1 Sump Packer 7,070’ 3,021’ 5.85” 4.0” Updated by: JLL 10/01/20 Steelhead Platform Well: M-18 Last Completed: 07/16/2009 API: 50-733-20583-00 PTD: 208-162 PROPOSED CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID in TOP MD rkb TOP TVD rkb BTM MD rkb BTM TVD rkb 28” X-56 27 Surface Surface 401’ 401’ 13-3/8” 68 L-80 BTC 12.406 Surface Surface 1,443 1384’ 9-5/8” 47 L-80 BTC-M 8.688 Surface Surface 6,120’ 2,593’ 7” 26 L-80 DWCSR 6.276 4,545’ 1,976’ 7,100’ 3,035’ 7” EZSV 7,100’ 3,035’ 7” 26 L-80 DWCSR 6.276 7,100’ 3,035’ 8,375 3,611’ Tubing 3-1/2” 9.2 L-80 Hydril 503 2.992 Surface Surface 5,142’ 3,186’ RKB to TBG Head = 78.75’ 13 3/8’ Shoe @ 1,443’ 7” Liner Shoe @ 8,375’ Hydraulic Stage Collar @ 469’ 28” Conductor @ 401’ Cement to ML @ 385’ 9 5/8 Hydraulic Stage Collar @ 2,552’ MD 9 5/8” x 7” Liner Hanger @ 4,545’ (Unset) EZSV @ 7,100’ Middle SC-1 Packer @ 5,975’ Lower SC-1 Packer @ 6,744’ F-1 Sump Packer @ 7,070’ TD 8 ½ Hole @ 9,930’ Upper SC-1 Packer @ 5,142’ @, 9 5/8” Shoe @ 6,120’ MAX HOLE ANGLE = 89.3q @ 3,533’ MD SZ 20 SZ 24B Perforation Detail MD (rkb) TVD (rkb) Zone SPF Notes 5,347’ - 5,476’ 2,244’ - 2,303’ SZ-19 12 4-5/8” Millennium Chrg ±5,537’ - ±5,555’ ±2,330’ - ±2,339’ SZ-20 Future/Proposed 5,600’ - 5,665’ 2,358’ - 2,388’ SZ-21 12 4-5/8” Millennium Chrg 5,790’ - 5,900’ 2,444’ - 2,494’ SZ-22 12 4-5/8” Millennium Chrg 5,945’ - 5,960’ 2,514’ - 2,521’ SZ-23 12 4-5/8” Millennium Chrg ±6,000’ - ±6,240’ ±2,539’ - ±2,648’ SZ-24B Future/Proposed 6,370’ - 6,395’ 2,706’ - 2,717’ A-2A 14 4-5/8” Big Hole Chrg 6,440’ - 6,580’ 2,737’ - 2,800’ A-2B 14 4-5/8” Big Hole Chrg 6,712’ - 6,730’ 2,859’ - 2,868’ A-3 14 4-5/8” Big Hole Chrg 7,028’ - 7,060’ 3,002’ - 3,017’ A-5 14 4-5/8” Big Hole Chrg Cementing Information Description Volume (bbls) Density (ppg) Yield (ft3/sx)Notes Surface Csg. 1st Stage 231.0 13.0 1.47 LiteCrete to 469’ Surface Csg. 2nd Stage 259.0 13.0 1.47 Lite Crete. Stage Collar at 469’ Some cement to surface 12 bbls before landing plug. Intermediate Csg. 1st Stage 131.0 13.0 1.47 Lite Crete. Planned TOC is 4404’ Intermediate Csg. 2nd Stage 145.0 13.0 1.47 Lite Crete. Planned TOC @ 385’ ML Production Liner 70.0 13.0 1.47 Pumped 65 bbls 13.0 ppg Lite Crete through perfs. Maintained good returns through most of the job. Lost approximately 6 bbls cement near the end of displacement Jewelry Detail Item MD (rkb) TVD (rkb) OD ID Model TE-5 SSSV 463’ 462’ 5.4” 2.813” Gas Lift Mandrel 1,602’ 1,507’ 5.27” 2.992” Gas Lift Mandrel 3783’ 1,932’ 5.27” 2.992” ZXP Liner Top Packer 4,530’ 1,973’ Gas Lift Mandrel 5,061’ 2,118’ 5.27” 2.992” SC-1 GP Packer 5,142’ 2,152’ 6.0” 4.0” SC-1 GP Packer 5,975’ 2,528’ 6.0” 4.0” SC-1 GP Packer 6,744’ 2,874’ 6.0” 4.0” Model F-1 Sump Packer 7,070’ 3,021’ 5.85” 4.0” SZ 20S SZ 24B DATA SUBMITTAL COMPLIANCE REPORT 4/25/2011 Permit to Drill 2081620 Well Name /No. TRADING BAY UNIT M -18 Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20583 -00 -00 MD 9930 TVD 4310 Completion Date 7/16/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION . Mud Log No Samples No Directional Survey Yes, — -- -- DATA INFORMATION Types Electric or Other Logs Run: GR, RES, NEUT, DENS (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr III Data. Digital Dataset Log Log Run Interval OH / T :e Med /Frmt Number Name Scale Media No Start Stop CH Received Comments ED C Las 17597 nduction /Resistivity 400 9930 Open 2/20/2009 GR, RPC, RPT, Dens, NPSFM, Temp Log Induction /Resistivity 2 Col 480 9930 Open 2/20/2009 TVD MPR, CNP, CDP, j GR, Mem Log 10- Jan -2009 i Log Induction /Resistivity 5 Col 480 9930 Open 2/20/2009 MD MPR, CNP, CDP, GR, Mem Log 10- Jan -2009 "Log Gamma Ray 5 Col 480 9930 Open 2/20/2009 MD GR, MPR Mem Log 10- Jan -2009 ,Log Gamma Ray 2 Col 480 9930 Open 2/20/2009 TVD GR, MPR Mem Log i" j 10- Jan -2009 {D C Las 19812 Induction /Resistivity 400 9931 Open 6/29/2010 Final OH data, Survey in LAS, PDS and DLIS graphics Well Cores /Samples Information: • Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /API Daily History Received? / N Chips Received? Formation Tops Y /N Analysis ,Y6-Pb- Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 4/25/2011 Permit to Drill 2081620 Well Name /No. TRADING BAY UNIT M -18 Operator UNION OIL CO OF CALIFORNIA API No. 50 -733- 20583 -00 -00 MD 9930 TVD 4310 Completion Date 7/16/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N Compliance Reviewed By: .� _ f_ Date: 25 r/ _ iF_ • 111 Chevron Francisco Castro Chevron North America Exploration and Production w - Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE June 28, 2010 il To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 ; Alaskl al a DATA TRANSMITTAL Transmitted herewith is one DVD containing the following data. • D -48L1 b > L./ • Formation evaluation logs - LAS P59 -0-? / • Gamma ray logs - LAS • , K -12RD2 0 65L1 / : -666 • K- 12RD2Final_Survey.xls • K- 12RD2_ _Tops.xlsx out _b 1 6 • MPR -Gamma ray logs - LAS, CGM, PDF • K -18RD ),l - /l') / • K- 18RD_Final_Survey.doc • Density Neutron logs - LAS 06/ / 9 &d Z • K- 18RDPB1 • UBI log - LAS, PDS, DLIS 00°5 41 y 97)O • survey.xls / • K -24RD2 �6 3 — /tSa • Density Neutron logs - LAS • Final Mudlog Report - LAS, DOC CO2 -f9 6 / 9 1/ , • M -06 • Final logs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS • M -10 c90.- /(oa ``� /0 • M- 10Tops.xlsx • USIT log - PDS ' 069 -03 /9 -/ 3 • Final logs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS • M -10PB1 • Final logs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS • M -16RD /`9 — 6"9.0 / 9 c • M- 16RD_Tops.xlsx • Final logs; Cement Bond Log, Completion Record -PDS • M -17 • M- 17_Tops.xlsx • M17_MWD_Survey.pdf • Final Mudlog Report - LAS, DOC, DBF, MDX, PDF, DAT • Final logs; Depth, Formation Evaluation, Cement Bond, Plug Setting, Perforation - LAS, PDS, DLIS, TIFF Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: ig • STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. Test: U Initial LJ Annual U Special lb. Type Test: U Stabilized 11 Non Stabilized U Multipoint ❑ Constant Time ❑ Isochronal ❑ Other 2. Operator Name: 5. Date Completed: 11. Permit to Drill Number: Union Oil Company of California 7/18/2009 208 -162 3. Address: 6. Date TD Reached: 12. API Number: PO Box 196247, Anchorage, AK 99519 January 9, 2009 50- 733 - 20583 -00 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): 13. Well Name and Number: Surface: 1040' FNL 605' FWL, SEC 33 T9N, R13W, SM 160' Steelhead M -18 Top of Productive Horizon: 8. Plug Back Depth(MD +TVD): 14. Field /Pool(s): 630' FNL, 855' FWL, Sec 33, T9N, R13W, SM 7,100' MD (3,035' TVD) McArthur River Field Total Depth: 9. Total Depth (MD + TVD): Middle Kenia Gas Pool 1,172' FSL, 1,810' FWL, Sec 21, T9N, R13W, SM 9930' MD (4,311' TVD) 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 214222.01 v- 2499459.53 Zone- 4 N/A ADL- 17594, ADL 18730 TPI: x- 214481.35 y- 2499863.61 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 217255.82 y- 2506880.80 Zone- 4 perforated casing with gravel pack 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 7" 26 6.276 8375 7028 -7060, 6370 -6395, 6440 -6580 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. 6712 -6730, 5347 -5476, 5600 -5665 3 -1/2" 9.2 2.992 5142 5790 -5900, 5945 -5960 20. Packer set at ft: 21. GOR cf /bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): 5142 NA NA NA 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): El Tubing ❑ Casing 63 F° 850.7 psia @ Datum 1861 TVDSS 14.7 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO % N % H Prover: Meter Run: Taps: NA NA 0.57 0 0 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F psig F psig F Hr. Size (in.) Size (in.) 1. X 794 68 0 NA 0 2. X 665 56 0 NA 6 3. X 511 52.6 0 NA 6 4. X 349 50 0 NA 6 5. X 250 42 0 NA 6 Basic Coefficient Flow Temp. Super Comp. No. (24 -Hour) h Pressure Gravity Factor Rate of Flow Pm Factor Fg Q Mcfd Fb or Fp Ft g Fpv 1. _ 0 2 6000 3 9000 4 10900 5. 11920 Temperature for Separator for Flowing No. Pr T Tr z Gas Fluid Gg G 1. 523 1.524781 0.89 2. 1.088985594 523 1.524781 0.902 3. 0.845888355 523 1.524781 0.911 Critical Pressure 666.4 4. 0.592286915 523 1.524781 0.921 Critical Temperature 343 5. 0.43622449 523 1.524781 0.927 �(�( / Form 10 -421 Revised 1/2004 CONTINUED ON REVERSE SID R 'LS C , ' " .Submit in Duplicate Pc 808.4 pct 653510.56 • 860.7 pf 740804.49 No. Pt Pt Pct -Pt2 Pw Pw Pc Ps Ps Pf -Ps 1. 2. 680 462400 191110.6 45.7 2088.49 651422.07 725.7 526640.5 214164 3. 526 276676 376834.6 37.7 1421.29 652089.27 563.7 317757.7 423046.8 4. 364 132496 521014.6 30.7 942.49 652568.07 394.7 155788.1 585016.4 5. 265 70225 583285.6 25.7 660.49 652850.07 290.7 84506.49 656298 25. AOF (Mcfd) 13 n 0.606201 Remarks: I hereby certify that he foregoing is true and correct to the best of my knowledge. Signed;�'!� Title Petroleum Engineer Date 9/15/2009 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd / 4 hwPm Fp Basic critical flow prover or positive choke factor Mcfd /psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= 4712 dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air = 1.000), dimensionless Gg Specific gravity of separator gas (air = 1.00), dimensionless GOR Gas -oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back - pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut -in wellhead pressure, psia Pf Shut -in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells , Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 1/2004 Side 2 • Page 1 of 1 Fleckenstein, Robert J (DOA) From: Rose, Jim [Contractor] [RoseJi ©chevron.com] Sent: Thursday, August 20, 2009 2:37 PM To: Fleckenstein, Robert J (DOA) Subject: FW: Governmental Coordinates APD 208 -162 Bob there was a typo but the numbers from a different program are very similar. please compare and let me know how they look Jim This is the correct info: surface - 1040' FNL, 605' FWL, Sec 33, T9N, R13W, S TPI - 630' FNL, 855' FWL, Sec 33, T9N, R13W, S TD - 1172' FSL, 1823' FE L, Sec 21, T9N, R13W, S 8/24/2009 R E .I STATE OF ALASKA • 11,1itesogt ALAS OIL AND GAS CONSERVATION COMMISSION 406 1 7 ZuO WELL COMPLETION OR RECOMPLETION REPORT AND LOG > Irt P Cons Commission 1 a. Well Status: Oil ❑ Gas Ei . Plugged ❑ Abandoned ❑ Suspended ❑ 1 b. Well Class ,.4 20AAC 25.105 20AAC 25.110 Development El • L Iti`r.. ^ 1 GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other❑ No. of Completions: Service ❑ Stratigraphic Test❑ 2. Operator Name: 5. Date Comp l , S sp., or 12. Permit to Drill Number: /.. Union Oil Company of California Aband 7 A, 208 -162 • a p 97" ' -7 7 3. Address: 6. Date Spud ed: 17.;10. 13. API Number: PO Box 196247, Anchorage, AK 99519 12/15/2008 • 50- 733 - 20583 -00 • 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1,040' FNL 605' FWL, SEC 33, T9N, R13W, SM • 1/9/2009 • Trading Bay Unit M -18 , Top of Productive Horizon: 8. KB (ft above MSL): 160 15. Field /Pool(s): 630' FNL 855' FWL, SEC 33, T9N, R13W, SM Ground (ft MSL): McArthur River Field Total Depth: / L gPC. 81,94 V 79 9. Plug Back Depth(MD+TVD): 1,172' FSL 1,41:f FA., SEC 21, T9N, R13W, M 7,100' MD (3,035' TVD) Middle Kenai Gas Pool • 4b. Location of Well (State Base Plane Coordinates, NAD 27): • 10. Total Depth (MD + TVD): 16. Property Desigrtion: /11P L. /137 , Surface: x- 214222.01 • y- 2499459.53 • Zone- 4 • • 9,930' MD (4,311' TVD) • ADL017594 Platform] TPI: x- 214481.35 y- 2499863.61 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 217255.82 y- 2506880.80 • Zone- 4 446' MD (445' TVD) N/A 18. Directional Survey: Yes [ No ❑ 19. Water De th, if Off ,ore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed in rri per 20 AAC 25.050) ' 5 / ft MIS-L.)6' 1 ' 8 ' N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR, RES, NEUT, DENS 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 28" X -56 Surface 401' Surface 401' Driven 13 -3/8" 68# L -80 Surface 1,443' Surface 1,384' 17 -1/2" / 510bb1 13.Oppg LiteCrete cement in two stages 9 -5/8" 47# L -80 Surface 6,120' Surface 2,593' 12 -1/4" 7 276bb1 13.Oppg LiteCrete cement in two stages 70bbl 13.0ppg LiteCrete 7" 26# L -80 4,545' 8,375' 1,976' 3,611' 8 -1/2" cement 23. Open to production or injection? Yes isi • No ❑ If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 4 -5/8" guns, .91 ", 14spfA -5 7,028'- 7,060'MD (TVD) 3 1/2" 5142' 5,142', 5,975', 6,744', & , 4 -5/8" guns, .91 ", 14spf A -2A 6,370'-6,395'MD (TVD) 7,070' 4 -5/8" guns, .91 ", 14spf A -2B 6,440'- 6,580'MD (TVD) 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4-5/8" guns, .91 ", 14spf A -3 6,712' MD (TVD) DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4 -5/8" guns, .38 ", 12spf SZ -19 5,347'-5,476'MD (TVD) 4 -5/8" guns, .38 ", 12spf SZ -21 5,600'- 5,665'MD (TVD) 7,028' 7,060' Gravel Pack of 3,7651bs 20 -40 sand at 5bpm 4 -5/8" guns, .38 ", 12spf SZ -22 5,790'- 5,900'MD (TVD) 4,000psi max rate 4 -5/8" guns, .38 ", 12spf SZ -23 5,945'- 5,960'MD (TVD) 6,370' - 6,395' & 6,440' - 6,580' Gravel Pack of 8,1281bs 20 -40 sand at 5bpm & 6,712' - 6,730' 5,125psi max rate 5,347'- 5,476' &5,600'- 5,665' Gravel Pack of 9,8901bs 20 -40 sand at 7.3bprr & 5,790'- 5,900' & 5,945'- 4,150psi max rate 5,960' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 7/17/2009 Flowing Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 8/9/2009 24 Test Period — 0 11,030 0 N/A N/A Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 349psi 625 psi 24 -Hour Rate �■ 0 11,030 • 0 N/A 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ig • Sidewall Cores Acquired? Yes ❑ No 0 - If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per , ' ' COMPLE 1t8 1. DATE ,. RBoms tart. i AUG 1 2009 •1l Form 10 -407 Revised 2/2007 CONTINUED ON REVERSE 18z3q • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes In No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base See Attached Formation Top ✓ information. Formation at total depth: /-S) / rq 30. List of Attachments: Operations Summary, Directional Survey, Welibore Schematic, Mud Weight Report, Formation Tops 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Rose 263 -7637 Printed Name Timothy C. Brandenburg Title: Drilling Manager Signature: ` /�' • �j J7 Phone: 276 -7600 Date: 8/14/2009 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for / njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 Trading Bay Unit M -18 Formation Tops Chevron API No: 50- 733 - 20583 -00 ItIO APD: 208 -162 %10 Well Surface ft MDbrf ft TVDbrf ft TVDss Well Surface ft MDbrf ft TVDbrf ft TVDss M -18 28 in Shoe 487.00 487 -327 M -18 SZ19CB 5492.05 2310 -2150 M -18 SZ6CT 1203.52 1177 -1017 M -18 SZ2OST 5531.02 2328 -2167 M -18 SZ7CT 1261.33 1229 -1069 M -18 SZ2OCT 5566.72 2344 -2184 M -18 SZ8ST 1283.55 1249 -1088 M -18 SZ2OCB 5580.00 2350 -2190 M -18 SZ8CT 1337.56 1296 -1135 M -18 SZ21ST 5593.81 2356 -2196 M -18 SZ8CB 1348.87 1305 -1145 M -18 SZ21 SB 5675.82 2393 -2233 M -18 13.375 in Shoe 1442.37 1383 -1223 M -18 SZ21 CT 5726.53 2416 -2256 M -18 17.5 in TD 1448.60 1389 -1228 M -18 SZ21CB 5762.53 2432 -2272 M -18 SZ10CT 1489.98 1421 -1261 M -18 SZ22ST 5789.35 2444 -2284 • M -18 SZ10CB 1499.92 1429 -1269 M -18 SZ22SB 5901.46 2495 -2335 M -18 SZ11 BST 1571.90 1485 -1325 M -18 SZ22CT 5903.45 2496 -2336 M -18 SZ11CT 1712.11 1587 -1427 M -18 SZ22CB 5940.42 2512 -2352 M -18 SZ11CB 1734.29 1603 -1442 M -18 SZ23ST 5945.80 2515 -2355 M -18 SZ12ST 1747.92 1612 -1451 M -18 SZ23SB 5960.16 2521 -2361 M -18 SZ12SB 1799.15 1645 -1485 M -18 SZ23CT 5969.60 2526 -2365 M -18 SZ12CT 1832.72 1665 -1505 M -18 SZ23CB 5978.63 2530 -2370 M -18 SZ12CB 1861.40 1682 -1522 M -18 SZ23ASB 6043.53 2559 -2399 M -18 SZ13ST 1881.70 1694 -1534 M -18 SZ23BST 6070.26 2571 -2411 M -18 SZ13CT 1970.80 1742 -1582 M -18 SZ23BSB 6116.54 2592 -2432 M -18 SZ13CB 1977.57 1746 -1585 M -18 9.625 in Shoe 6118.92 2593 -2433 M -18 SZ14ST 1999.73 1757 -1597 M -18 12.25 in TD 6129.48 2598 -2438 M -18 SZ14CT 2089.57 1799 -1639 M -18 ACT 6202.45 2631 -2471 M -18 SZ14CB 2103.73 1804 -1644 M -18 ACB 6238.44 2647 -2487 M -18 SZ15ST 2179.88 1833 -1673 M -18 A1CT 6320.22 2684 -2524 M -18 SZ15CT 2267.04 1860 -1700 M -18 A1CB 6326.58 2687 -2527 • M -18 SZ15CB 2273.09 1862 -1702 M -18 A2ST 6344.65 2695 -2535 M -18 SZ16ST 2293.49 1867 -1706 M -18 A2ST 6345.47 2695 -2535 M -18 SZ16SB 4681.57 2001 -1841 M -18 A2SB 6581.65 2801 -2641 M -18 SZ16CT 4703.31 2006 -1846 M -18 A2CT 6584.04 2802 -2642 M -18 SZ16CB 4741.50 2015 -1855 M -18 A2CB 6628.62 2822 -2662 M -18 SZ17ST 4911.22 2064 -1903 M -18 A2AST 6651.19 2833 -2672 M -18 SZ17CT 5021.64 2103 -1942 M -18 A2ACT 6659.61 2836 -2676 M -18 SZ17CB 5034.86 2108 -1947 M -18 A3CT 6683.08 2847 -2687 M -18 SZ18CT 5264.92 2208 -2047 M -18 A3ST 6710.19 2859 -2699 M -18 SZ18CB 5295.21 2221 -2061 M -18 A3SB 6749.95 2877 -2717 M -18 SZ19ST 5343.04 2243 -2083 M -18 A4ST 6761.38 2882 -2722 M -18 SZ19CT 5476.09 2303 -2143 M -18 A4SB 6780.66 2891 -2731 Page 1 of 2 Trading Bay Unit M -18 Formation Tops Chevro API No: 50- 733 - 20583 -00 %110 APD: 208 -162 1110 Well Surface ft MDbrf ft TVDbrf ft TVDss Well Surface ft MDbrf ft TVDbrf ft TVDss M -18 A4CT 6863.70 2928 -2768 M -18 B3CB 8320.29 3587 -3427 M -18 A5ST 6892.32 2941 -2781 M -18 B5ST 8384.17 3616 -3455 M -18 A5BST 6949.73 2967 -2807 M -18 B5SB 8450.13 3645 -3485 M -18 A5CST 7027.42 3002 -2842 M -18 B4CT 8466.68 3653 -3493 M -18 A5CT 7129.18 3048 -2888 M -18 B4CB 8495.68 3666 -3506 M -18 A5CB 7160.32 3063 -2902 M -18 B6ST 8546.18 3689 -3528 M -18 A6ST 7357.56 3152 -2992 M -18 B6AST 8644.55 3733 -3573 M -18 A6SB 7415.17 3178 -3018 M -18 B6SB 8711.74 3763 -3603 M -18 A6SB 7415.24 3178 -3018 M -18 B5CT 8724.98 3769 -3609 • M -18 BCT 7470.39 3203 -3043 M -18 B5CB 8753.76 3782 -3622 M -18 BCT 7479.64 3207 -3047 M -18 CCT 8945.11 3868 -3708 M -18 BCB 7536.33 3233 -3073 M -18 CCB 8981.60 3885 -3724 M -18 B1 ST 7565.44 3246 -3086 M -18 C1 ST 8996.02 3891 -3731 M -18 B1 ST 7566.76 3247 -3087 M -18 C1SB 9139.86 3956 -3796 M -18 B1 SB 7613.96 3268 -3108 M -18 C2ST 9194.50 3980 -3820 M -18 B1SB 7663.44 3291 -3130 M -18 C2SB 9204.72 3985 -3825 M -18 B2ST 7667.04 3292 -3132 M -18 C1CT 9331.18 4042 -3882 M -18 B2ST 7669.50 3293 -3133 M -18 C1CB 9338.46 4045 -3885 M -18 B2SB 7758.35 3334 -3173 M -18 C2CT 9347.98 4050 -3889 M -18 B2SB 7759.66 3334 -3174 M -18 C2CB 9354.06 4052 -3892 M -18 B1CT 7768.64 3338 -3178 M -18 C3ST 9375.96 4062 -3902 M -18 B1CT 7769.10 3339 -3178 M -18 C3SB 9487.13 4112 -3952 M -18 B1CB 7791.83 3349 -3189 M -18 C4ST 9562.58 4146 -3986 M -18 B1CB 7793.18 3349 -3189 M -18 C4SB 9642.57 4182 -4022 M -18 B3ST 7946.83 3419 -3259 M -18 C3CT 9659.28 4190 -4029 • M -18 B3SB 7968.47 3429 -3268 M -18 C3CB 9676.72 4198 -4037 M -18 B3ST 7987.01 3437 -3277 M -18 C5ST 9710.58 4213 -4053 M -18 B4ST 8044.78 3463 -3303 M -18 C5SB 9747.90 4230 -4069 M -18 B4ST 8045.53 3463 -3303 M -18 C6ST 9753.92 4232 -4072 M -18 B4SB 8119.32 3496 -3336 M -18 C6SB 9792.43 4250 -4089 M -18 B4SB 8119.81 3497 -3336 M -18 DCT 9819.40 4262 -4101 M -18 B2CT 8224.39 3544 -3384 M -18 DCB 9860.31 4280 -4120 M -18 B2CB 8257.74 3559 -3399 M -18 D1ST 9875.92 4287 -4127 M -18 B3CT 8263.75 3562 -3401 M -18 8 -1/2 in TD 9930.00 4311 -4151 Page 2of2 Chevron • •elhead Platform :: Well M -18 %. Completed 7/16/09 CASING AND TUBING DETAIL RKB to TBG Head = 78.75' TOP TOP BTM BTM SIZE WT GRADE CONN ID MIN n MD TVD MD TVD rkb rkb rkb rkb Cement to 28" X -56 27 Surface Surface 401' 401' ML @ 385' 13 -3/8" 68 L -80 u 12.406 Surface Surface 1,443 1384' 28" 9 -5/8" 47 L -80 BTC -M 8.688 Surface Surface 6,120' 2,593' Conductor 7" 26 L -80 DWCSR 6.276 4,545' 1,976' 7,100' 3,035' ' 0 401' 7" EZSV 7,100' 3,035' Hydraulic 7" 26 L -80 DWCSR 6.276 7,100' 3,035' 8,375 3,611' Stage Collar Tubing @469' 3 -1/2" 9.2 L -80 Hydril 2.992 Surface Surface 5,142' 3,186' 503 Perforation Detail MD (rkb) TVD (rkb) Zone Densit Notes 5,347' - 5,476' 2,244' - 2,303' SZ -19 12 4 -5/8" Millennium Chrg 13 3/8' Shoe @ 1,443' 5,600' - 5,665' 2,358' - 2,388' SZ -21 12 4 -5/8" Millennium Chrg ydraulic 5,790' - 5,900' 2,444' - 2,494' SZ -22 12 4 -5/8" Millennium Chrg 9 5/8 H Stage ydra@ 5,945' - 5,960' 2,514' - 2,521' SZ -23 12 4 -5/8" Millennium Chrg 2,552 MD 6,370' - 6,395' 2,706' - 2,717' A -2A 14 4 -5/8" Big Hole Chrg 6,440' - 6,580' 2,737' - 2,800' A -2B 14 4 -5/8" Big Hole Chrg 6,712' - 6,730' 2,859' - 2,868' A -3 14 4 -5/8" Big Hole Chrg 7,028' - 7,060' 3,002' - 3,017' A -5 14 4 -5/8" Big Hole Chrg Completion Equipment Informtion Item MD (rkb) TVD (rkb) OD ID 9 5/8" x 7" Liner Model TE -5 SSSV 446' 445' 5.4" 2.813" Hanger @ 4,545' Gas Lift Mandrel 1,602' 1,507' 5.27" 2.992" II IncPt1 Gas Lift Mandrel 3783' 1,932' 5.27" 2.992" IN ZXP Liner Top Packer 4,530' 1,973' Gas Lift Mandrel 5,061' 2,118' 5.27" 2.992" SC -1 GP Packer 5,142' 2,152' 6.0" 4.0" SC -1 GP Packer 5,975' 2,528' 6.0" 4.0" SC -1 GP Packer 6,744' 2,874' 6.0" 4.0" • 0 0 Upper SC - Packer @ Model F -1 Sump Packer 7,070' 3,021' 5.85" 4.0" . 5,133' i 9 5/8" Shoe @ 6,120' Cementing Information k Volume Density Yield Description bbls .) (ft3 /sx) Notes • Middle SC - Packer @ Surface Csg. 1 Stage 231.0 13.0 1.47 LiteCrete to 469' ► • 5,970' Lite Crete. Stage Collar at 469' Some 1 i Surface Csg. 2 Stage 259.0 13.0 1.47 cement to surface 12 Lower SC - Packer @ bbls before landing 6,741' plug. ' 0 C Intermediate Csg. 1 Stage 131.0 13.0 1.47 Lite Crete. Planned • • TOC is 4404' •: F - Sump Packer @ Intermediate Csg. 2 Stage 145.0 13.0 1.47 Lite Crete. Planned c ' l 7,064' TOC @ 385' ML EZSV @ 7,100' Pumped 65 bbls 13.0 ppg Lite Crete 4 I. 7" Liner Shoe @ 8,375' through perfs. Maintained good Production Liner 70.0 13.0 1.47 returns through most of the job. Lost aooroximately 6 bbls TD 8'/ Hole @ 9,930' IAX HOLE ANGLE = 88.3° @ 3,533' MD Well Detail DRAWN BY: JAR Revised CVK 8/14/09 • • Trading Bay Unit M -18 Mud Weight -vs- Depth APD 208 -162 Mud Weight (ppg) 8 8.2 8.4 8.6 8.8 9 9.2 9.4 9.6 9.8 10 0 Measured Depth True Vertical Depth 2000 4000 w 6000 a d • Partial Lost Returns @ 8190' - 8000 MD (just above the B2 coal) 10000 - -- I 1 12000 - Actual Wellpath Geo • raphic Report Report Generated 8/14/2009 at 2:50:13 PM Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet • Operator Chevron North Reference True ° Area Cook Inlet, Alaska (Offshore) Scale 0.999993 Field McArthur River Field Horizontal Reference Point Slot Facility STEELHEAD Platform Vertical Reference Point Actual Datum (RKB) Slot slot #82 -2 MD Reference Point Actual Datum (RKB) Well M -18 • Field Vertical Reference mean sea level Wellbore M -18 Actual Datum (RKB) to Faculty Vertical Datum 160.25 ft • Wellpath SDI Gyro <129 - 992' >SDI MWD<1067- 1450'>ATK- OnTrak MWD<1448- 9930'> Actual Datum (RKB) to mean sea level 160.25 ft Wellbore Last Revised 01/28/2009 Facility Vertical Datum to Mud Line (Facilit ) 0.00 ft Sidetrack from (none) Section Origin X E 0.00 ft User Ulricard Section Origin Y N 0.00 ft Calculation method Minimum curvature Section Azimuth 20.77° Local North Local East Grid East Grid North Latitude Longitude [ft] [ft] [USft) [USft[ Slot Location - 1040.02 , 606.93 214222.01 2499459.54 60 °49'54.561 "N 151 °36'05.775 "W Facility Reference Pt 213640.71 2500514.08 60 °50'04.803 "N 151 °36'18.018 "W Field Reference Pt 213640.71 2500514.08 60 °50'04.803 "N 151 °36'18.018 "W TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments [ft] [1 (1 [ft] [ft] [ft] [ft] [sry ft] [sry ft] [°llooft] [1 [°I1ooft] [°I1o0ft] [ft] 0.00 0.00 133.59 0.00 - 160.25 0.00 0.00 214222.01 • 2499459.53• 60 °49'54.561 "N 151 ° 36'05.775'W 0.00 133.59 0.00 0.00 0.00 129.00 0.09 133.59 129.00 -31.25 -0.07 0.07 214222.09 2499459.46 60°49'54.561"N 151°36'05.773'W 0.07 91.72 0.07 0.00 -0.04 _ 179.00 0.09 137.02 179.00 18.75 -0.13 0.13 214222.14 2499459.41 60 °49'54.560 "N 151'38'05.772' W 0.01 - 104.99 0.00 6.86 -0.07 229.00 0.09 107.05 229.00 68.75 -0.17 0.19 214222.20 2499459.36 60 °49'54.560"N 151 °36'05.771'W 0.09 77.27 0.00 -59.94 -0.09 279.00 0.18 155.13 279.00 118.75 -0.25 0.26 214222.27 2499459.28 60 °49'54.559 "N 151 °36'05.769'W 0.27 -92.55 0.18 96.16 -0.14 329.00 0.18 150.03 329.00 168.75 -0.39 0.34 214222.34 2499459.14 60'49'54.558 "N 151 °36'05.768'W 0.03 97.38 0.00 -10.20 -0.24 379.00 0.18 164.79 379.00 218.75 -0.53 0.40 214222.40 2499458.99 60 °49'54.556 "N 151 °36'05.767'W 0.09 108.15 0.00 29.52 -0.36 429.00 0.18 201.09 429.00 268.75 -0.68 0.39 214222.39 _ 2499458.84 60 °49'54.555 "N 151 °36'05.767'W 0.22 -13.60 0.00 72.60 -0.50 479.00 0.44 193.01 479.00 318.75 -0.94 0.32 214222.31 2499458 59 60 °49'54.552"N 151 °36'05.768'W 0.53 - 148.00 0.52 -16.16 -0.77 527.00 0.88 60.38 527.00 366.75 -0.94 0.60 214222.59 2499458 58 60 °49'54.552 "N 151 °36'05.763'W 2.55 -1.75 0.92 - 276.31 -0.67 571.00 3.61 59.06 570.96 410.71 -0.06 2.08 214224.09 2499459 60 °49'54.561 "N 151 °36'05.733'W 6.21 -1.81 6.20 -3.00 0.68 630.00 7.65 58.10 629.66 469.41 2.97 7.01 214229.09 2499462.34_ 60 °4954.591 "N 151 °36'05.633'W 6.85 22.48 6.85 -1.63 5.26 671.00 9.41 62.49 670.21 509.96 5.96 12.30 214234.45 2499465.20 60'49'54.620"N 151 °36'05.527"W 4.57 10.28 4.29 10.71 9.94 720.00 11.09 64.07 718.42 558.17 9.87 20.09 214242.34 2499468.92 60 °49'54.659 "N 151 °36'05.370"W 3.48 16.76 3.43 3.22 16.36 767.00 12.49 66.01 764.43 604.18 13.92 28.80 214251.14 2499472.74 60'49'54.698 "N 151 °36'05.194'W 3.10 -42.77 2.98 4.13 23.23 810.00 13.81 61.08 806.30 646.05 18.29 37.54 214259.99 2499476.90 60 °49'54.742 "N 151 °36'05.018'W 4.03 -19.52 3.07 -11.47 30.41 855.00 15.40 58.97 849.85 689.60 23.97 47.36 214269.94 2499482.34 60 °49'54.797 "N 151 °36'04.819'W 3.73 -52.37 3.53 - 4.69 39.21 901.00 16.89 52.73 894.04 733.79 31.16 57.91 214280.67 2499489.28 60 °49'54.868 "N 151 °36'04.607"W 4.97 -46.65 3.24 -13.57 49.68 942.00 18.48 47.64 933.10 772.85 39.15 67.46 214290.40 2499497.03 60 °49'54.947 "N 151 °36'04.414'W 5.41 -29.20 3.88 - 12.41 60.53 992.00 19.71 45.62 980.35 820.10 50.39 79.34 214302.56 2499507.97 60 °49'55.058 "N 151 °36'04.174'W 2.79 -81.29 2.46 -4.04 75.25 1067.00 20.76 33.74 1050.75 890.50 70.29 95.77 214319.47 2499527.47 60 °49'55.254 "N 151 °36'03.843'W 5.64 -87.60 1.40 - 15.84 99.69 1109.00 20.88 29.39 1090.01 929.76 83.01 103.57 214327.58 2499539.99 60 °49'55.379 "N 151 °3603.685'W 3.69 -31.96 0.29 -10.36 114.35 1163.00 22.88 26.23 1140.12 979.87 100.81 112.94 214337.38 2499557.56 60 °49'55.554 "N 151 °36'03.497'W 4.30 -18.98 3.70 -5.85 134.31 1208.00 24.91 24.58 1181.26 1021.01 117.28 120.75 214345.59 2499573.83 60 °49'55.716 "N 151 °36'03.339"W 4.75 -2.07 4.51 -3.67 152.48 1258.00 27.05 24.41 1226.20 1065.95 137.21 129.83 214355.15 2499593.53 60'49'55.913 "N 151 °36'03.156'W 4.28 -13.98 4.28 -0.34 174.34 1303.00 29.19 23.32 1265.89 110564 156.61 138.40 214364.19 2499612.71 60 °49'56.104 "N 151 °36'02.983'W 4.89 -9.58 4.76 -2.42 195.51 1353.00 31.55 22.56 1309.03 1148.78 179.89 148.25 214374.61 2499635.75 60 °49'56.333 "N 151 °36'02.784'W 4.78 18.91 4.72 -1.52 220.77 - . 1385.00 33.37 23.69 1336.03 1175.78 195.68 155.00 214381.74 2499651.37 60 °49'56.488 "N 151•36'02.648'W 5.99 -3.83 5.69 3.53 237.93 1448.00 35.18 23.48 1388.08 1227.83 228.19 169.19 214396.72 2499683.53 60 °49'56.809 "N 151 °36'02.362'W 2.88 5.57 2.87 -0.33 273.37 1543.00 39.49 24.14 1463.60 1303.35 280.88 192.46 214421.27 2499735.63 60 °49'57.327 "N 151 °36'01.892'W 4.56 -5.47 4.54 0.69 330.88 1638.00 43.37 23.60 1534.82 1374.57 338.36 217.88 214448.09 2499792.48 60 °49'57.893 "N 151 °36'01.379'W 4.10 1.23 4.08 -0.57 393.64 1732.00 47.12 23.71 1600.99 1440.74 399.49 244.66 214476.35 2499852.93 60 °49'58.495 "N 151 °36'00.839'W 3.99 -2.13 3.99 0.12 460.30 1748.00 47.81 23.68 1611.80 1451.55 410.29 249.40 214481.35 2499863.61 60 °49'58.602 "N 151 °36'00.744'W 4.32 -2.10 4.31 -0.22 472.07 Interpolated Point 1799.00 50.01 23.57 1645.32 1485.07 445.50 264.80 214497.61 2499898.44 60 °49'58.948 "N 151 °36'00.433'W 4.32 -3.86 4.31 -0.21 510.46 1891.00 57.12 23.00 1699.93 1539.68 513.45 294.02 214528.48 2499965.66 60 °49'59.618 "N 151 °35'59.843'W 7.74 -10.09 7.73 -0.62 584.36 i 1989.00 59.00 22.61 1751.77 1591.52 590.11 326.25 214562.57 2500041.51 60 °50'00.372 "N 151 °3559.193'W 1.95 -27.37 1.92 -0.40 667.47 2083.00 64.28 19.60 1796.41 1636.16 667.26 355.97 214594.16 2500117.90 60 °50'01.132 "N 151 °35'58.594'W 6.28 -8.08 5.62 - 750.14 2178.00 70.96 18.60 1832.56 1672.31 750.23 384.68 214624.89 2500200.14 60 °50'01.949 "N 151 °35'58.014'W 7.10 -4.48 7.03 -1.05 837.90 2272.00 73.16 18.42 1861.51 1701.26 835.03 413.07 214655.34 2500284.22 60 °50'02.784 "N 151 °35'57.442'W 2.35 7.60 2.34 -0.19 927.25 2396.00 78.76 1918 1891.59 1731.34 948.86 451.83 214696.87 2500397.07 60 °50'03.905 "N 151 °35'56.660'W 4.56 4.70 4.52 0.61 1047.43 2491.00 83.85 19.60 1905.94 1745.69 1037.41 483.00 214730.19 2500484.84 60 °50'04.777 "N 151 °35'56.031'W 5.38 2.67 5.36 0.44 1141.28 2586.00 88.14 19.80 1912.58 1752.33 1126.61 514.94 214764.29 2500573.23 60 °50'05.655 "N 151 °3555.386'W 4.52 -76.80 4.52 0.21 1236.00 2681.00 88.53 18.14 1915.34 1755.09 1216.41 545.81 214797.34 2500662.25 60 °50'06.540 "N 151 °3554.763'W 1.79 -99.88 0.41 -1.75 1330.91 2774.00 88.20 16.24 1917.99 1757.74 1305.21 573.28 214826.98 2500750.35 60 °50'07.414 "N 151 °35'54.209'W 2.07 -58.80 -0.35 -2.04 1423.69 2869.00 89.23 14.54 1920.12 1759.87 1396.78 598.48 214854.41 2500841.28 60 °5008.316 "N 151 °35'53.701'W 2.09 -89.46 1.08 -1.79 1518.24 2964.00 89.24 13.50 1921.39 1761.14 1488.94 621.50 214879.66 2500932.85 60 °50'09.223 "N _ 151°35'53.236'W 1.09 -90.00 0.01 -1.09 1612.57 3060.00 89.24 13.41 1922.66 1762.41 1582.30 643.83 214904.27 2501025.63 60 °50'10.143 "N 151'35'52.785'W 0.09 -93.90 0.00 -0.09 1707.78 3154.00 89.21 12.97 1923.93 1763.68 1673.81 665.28 214927.94 2501116.59 60'50'11.044 "N 151 °35'52.353"W 0.47 65.22 -0.03 -0.47 1800.95 3249.00 89.27 13.10 1925.19 1764.94 1766.35 686.70 214951.62 2501208.58 60 °5011.955 "N 151 °35'51.920'W 0.15 -95.53 0.06 0.14 1895.08 3344.00 89.24 12.79 1926.43 1766.18 1858.93 707.98 214975.15 2501300.61 60 °5012.867 "N 151 °35'51.491 "W 0.33 79.38 -0.03 -0.33 1989.18 3438.00 89.27 12.95 1927.65 1767.40 1950.56 728.92 214998.32 2501391.70 . 60 °50'13.769 "N 151 °35'51.068 "W. 0.17 -85.24 0.03 0.17 1 2082.28 Page 1 of 2 ° ND from MD Inclination Azimuth ND Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rat( Turn Rate Vert Sect Comments [ft] [1 [1 [ft] [ft] [ft] [ft] [sry ft] [sry ft] [°/100ft] [°] [°/100ft] [° /100ft] [ft] 3533.00 89.30 12.59 1928.84 1768.59 2043.20 749.92 215021.57 2501483.81 60 °50'14.681 "N 151 °3550.645W 0.38 - 106.70 0.03 -0.38 2176.35 3628.00 89.27 12.49 1930.02 1769.77 2135.93 770.54 215044.45 2501576.00 60 °5015.594 "N 151 °35'50.228'W 0.11 - 151.39 -0.03 -0.11 2270.36 3722.00 88.94 12.31 1931.49 1771.24 2227.73 790.72 215066.87 2501667.28 60 °5016.498 "N 151 °3549.821'W 0.40 91.98 -0.35 -0.19 2363.35 3817.00 88.93 12.60 1933.26 1773.01 2320.47 811.21 215089.61 2501759.50 60 °5017.412"N 151 °3549.405W 0.31 127.00 -0.01 0.31 2457.33 3910.00 88.32 13.41 1935.49 1775.24 2411.06 832.13 215112.74 2501849.55 60 °5018.304"N 151 °3548.985W 1.09 113.42 -0.66 0.87 2549.45 4006.00 87.65 14.96 1938.86 1778.61 2504.07 855.64 215138.51 2501941.95 60 °5019.220 "N 151 °3548.511'W 1.76 101.32 -0.70 1.61 2644.76 4100.00 87.61 15.16 1942.75 1782.50 2594.77 880.04 215165.12 2502032.03 60 °50'20.113 "N 151 °35'48.018'W 0.22 -90.00 -0.04 0.21 2738.21 4196.00 87.61 15.13 1946.75 1786.50 2687.35 905.10 215192.43 2502123.97 60 °5021.024 "N 151 °35'47.513'W 0.03 85.50 0.00 -0.03 2833.66 4291.00 87.67 15.89 1950.67 1790.42 2778.81 930.49 215220.04 2502214.78 60 °5021.925 "N 151 °3547.000'W 0.80 155.84 0.06 0.80 2928.18 4385.00 85.47 16.88 1956.29 1796.04 2868.83 956.95 215248.69 2502304.13 60 °5022.811 "N 151 °35'46.466'W 2.57 172.24 -2.34 1.05 3021.73 4481.00 82.63 17.27 1966.24 1805.99 2960.09 984.98 215278.94 2502394.68 60 °5023.710"N 151 °3545.900'W 2.99 165.08 -2.96 0.41 3117.00 4549.00 80.94 17.73 1975.95 1815.70 3024.28 1005.22 215300.74 2502458.35 60 °50'24.342"N 151 °35'45.492'W 2.57 165.01 -2.48 0.67 3184.19 7" Liner Top 4575.00 80.30 17.90 1980.19 1819.94 3048.70 1013.06 215309.18 2502482.57 60 °50'24.583" 151 °35'45.334'W 2.57 162.71 -2.48 0.67 3209.81 4670.00 77.57 18.77 1998.42 1838.17 3137.19 1042.39 215340.65 2502570.32 60 °50'25.454" 151 °35'44.742'W 3.01 174.02 -2.87 0.92 3302.95 4764.00 ' 75.08 19.04 2020.64 1860.39 3223.60 1071.98 215372.34 2502655.98 60 °50'26.305" 151°35'44.145'W 2.66 168.70 -2.65 0.29 3394.23 4860.00 72.88 19.50 2047.14 1886.89 3310.69 1102.42 215404.91 2502742.30 60 °50'27.163" 151 °35'43.530'W 2.34 170.41 -2.29 0.48 3486.48 4954.00 69.66 20.08 2077.32 1917.07 3394.45 1132.56 215437.07 2502825.30 60 °50'27.987" 151 °35'42.922'W 3.47 - 179.20 -3.43 0.62 3575.46 5050.00 66.37 20.03 2113.25 1953.00 3478.06 1163.08 21546983 2502908.14 60 °50'28.811" 151 °35'42.306'W 3.43 169.15 -3.43 -0.05 3664.46 5144.00 63.34 20.68 2153.19 1992.94 3557.83 1192.67 215501.15 2502987.16 60 °50'29.596" 151 °35'41.709'W 3.28 111.89 -3.22 0.69 3749.54 5239.00 63.19 21.10 2195.92 2035.67 3637.10 1222.92 215533.33 2503065.67 60 °50'30.377'N 151 °35'41.098'W 0.43 89.46 -0.16 0.44 3834.38 5333.00 63.20 21.97 2238.31 2078.06 3715.14 1253.72 215566.02 2503142.93 60 °50'31.145 "N 151 °35'40.476'W 0.83 - 126.79 0.01 0.93 3918.28 5428.00 63.12 21.85 2281.21 2120.96 3793.78 1285.35 215599.56 2503220.78 60 °50'31.919 "N 151 °35'39.835W 0.14 81.37 -0.08 -0.13 4003.02 5521.00 63.19 22.36 2323.20 2162.95 3870.66 1316.57 215632.66 2503296.87 60 °50'32.677" 151 °35'39.208'W 0.50 92.34 0.08 0.55 4085.98 5617.00 63.16 23.26 2366.53 2206.28 3949.63 1349.78 215667.78 2503375.00 60 °50'33.454" 151 °35'38.537'W 0.84 88.16 -0.03 0.94 4171.59 5712.00 63.19 24.20 2409.40 2249.15 4027.23 1383.90 215703.78 2503451.76 60 °50'34.218" 151 °35'37.849'W 0.88 88.93 0.03 0.99 4256.26 5806.00 63.20 24.74 2451.79 2291.54 4103.60 1418.65 215740.39 2503527.25 60 °50'34.970" 151 °35'37.147'W 0.51 100.69 0.01 0.57 4339.98 5902.00 63.12 25.22 2495.13 2334.88 4181.24 1454.83 215778.45 2503603.98 60 °50'35.735 "N 151 °35'36.417'W 0.45 73.03 -0.08 0.50 4425.41 5995.00 63.15 25.33 2537.16 2376.91 4256.26 1490.25 215815.69 2503678.12 60 °50'36.474 "N 151 °35'35.702'W 0.11 -90.02 0.03 0.12 4508.11 6089.00 63.15 25.25 2579.61 2419.36 4332.09 1526.08 215853.36 2503753.05 60 °50'37.220 "N 151 °35'34.979'W 0.08 155.97 0.00 -0.09 4591.72 6144.00 63.11 25.27 2604.47 2444.22 4376.46 1547.01 215875.37 2503796.89 60 °50'37.657 "N4 151 °35'34.556'W 0.08 -82.86 -0.07 0.04 4640.63 6238.00 63.21 24.40 2646.91 2486.66 4452.58 1582.24 215912.44 2503872.13 60 °50'38.407 "Ni 151 °35'33.845'W 0.83 -74.02 0.11 -0.93 4724.29 6334.00 63.30 24.05 2690.12 2529.87 4530.76 1617.41 215949.52 2503949.43 60 °50'39.176 "N, 151 °35'33.135W 0.34 -88.44 0.09 -0.36 4809.87 6430.00 63.31 23.66 2733.24 2572.99 4609.20 1652.10 215986.11 2504026.99 60 °50'39.949 "Ni 151 °35'32.435W 0.36 -91.16 0.01 -0.41 4895.51 6524.00 63.30 23.03 2775.47 2615.22 4686.30 1685.38 216021.26 2504103.26 60 °50'40.708 "N 151'35'31.763'W 0.60 -91.90 -0.01 -0.67 4979.41 6618.00 63.28 22.29 2817.72 2657.47 4763.79 1717.73 216055.49 2504179.94 60°50'41.471"N' 151'35'31.110"W 0.70 -85.49 -0.02 -0.79 5063.33 6711.00 63.30 22.01 2859.52 2699.27 4840.74 1749.05 216088.68 2504256.09 60 °50'42.229 "N 151'35'30.478'W 0.27 -90.06 0.02 -0.30 5146.38 6808.00 63.30 21.75 2903.11 2742.86 4921.15 1781.35 216122.93 2504335.70 60 °50'43.020 "N 151 °35'29.826"W 0.24 - 153.67 0.00 -0.27 5233.02 6903.00 63.03 21.60 2945.99 2785.74 4999.93 1812.65 216156.15 2504413.68 60 °50'43.796 "N 151°3529.194"W 0.32 71.94 -0.28 -0.16 5317.78 6998.00 63.10 21.84 2989.03 2828.78 5078.61 1844.00 216189.40 2504491.58 60 °50'44.571 "N 151 °35'28.561'W 0.24 - 101.39 0.07 0.25 5402.46 7092.00 63.05 21.56 3031.59 2871.34 5156.48 1874.99 216222.28 2504568.67 60 °50'45.338 "N 151 °35'27.935"W 0.27 92.97 -0.05 -0.30 5486.26 7186.00 63.04 21.78 3074.20 2913.95 5234.34 1905.93 216255.11 2504645.75 60 °50'46.104 "N1 151 °3527.311'W 0.21 88.29 -0.01 0.23 5570.04 7282.00 63.06 22.47 3117.71 2957.46 5313.62 1938.16 216289.27 2504724.22 60 °50'48.885 "N 151 °35'26.660'W 0.64 - 110.54 0.02 0.72 5655.59 7376.00 63.01 22.32 3160.33 3000.08 5391.08 1970.08 216323.07 2504800.87 60 °50'47.648 "N 151 °35'26.016'W 0.15 -98.38 -0.05 -0.16 5739.34 7469.00 62.98 22.09 3202.56 3042.31 5467.79 2001.39 216356.24 2504876.80 60 °50'48.403 "N 151 °35'25.383'W 0.22 -75.14 -0.03 -0.25 5822.17 7565.00 63.08 21.67 3246.10 3085.85 5547.19 2033.27 216390.06 2504955.39 60 °50'49.185 "N 151 °35'24.740'W 0.40 -97.06 0.10 -0.44 5907.72 7659.00 63.03 21.21 3288.70 3128.45 5625.19 2063.90 216422.58 2505032.62 60 °50'49.953 "N 151 °35'24.121'W 0.44 80.91 -0.05 -0.49 5991.51 7754.00 63.04 21.28 3331.77 3171.52 5704.10 2094.59 216455.18 2505110.76 60 °50'50.730 "N 151 °35'23.502'W 0.07 74.72 0.01 0.07 6076.17 7851.00 63.20 21.93 3375.63 3215.38 5784.54 2126.44 216488.99 2505190.40 60 °50'51.522 "N 151 °35'22.859'W 0.62 -63.58 0.16 0.67 6162.68 ' 7944.00 63.28 21.75 3417.50 3257.25 5861.62 2157.33 216521.75 2505266.70 60 °50'52.281 "N 151 °35'22.235'W 0.19 97.35 0.09 -0.19 6245.71 8039.00 63.23 22.19 3460.26 3300.01 5940.30 2189.07 216555.40 2505344.58 60 °50'53.056 "N 151 °35'21.594 "V✓ 0.42 -99.17 -0.05 0.46 6330.53 8130.00 63.18 21.84 3501.28 3341.03 6015.61 2219.52 216587.68 2505419.12 60 °50'53.797 "N 151 °35'20.979'W 0.35 66.50 -0.05 -0.38 6411.74 8298.00 63.25 22.02 3576.99 3416.74 6154.73 2275.53 216647.07 2505556.83 60 °50'55.167 "N 151 °35'19.848"W 0.10 85.52 0.04 0.11 6561.68 I 8391.00 63.28 22.44 3618.82 3458.57 6231.61 2306.96 216680.36 2505632.93 60 °50'55.924 "N 151 °3519.214'W 0.40 - 105.69 0.03 0.45 6644.71 8486.00 63.22 22.20 3661.58 3501.33 6310.09 2339.17 216714.48 2505710.59 60 °50'56.697 "N 151 °35'18.563'W 0.23 87.32 -0.06 -0.25 6729.51 8581.00 63.24 22.66 3704.37 3544.12 6388.49 2371.54 216748.75 2505788.18 60 °50'57.469 "N 151 °35'17.910'W 0.43 77.42 0.02 0.48 6814.30 8675.00 63.28 22.86 3746.67 3586.42 6465.90 2404.01 216783.11 2505864.77 60 °50'58.231 "N 151 °3517.254 "W 0.19 90.83 0.04 0.21 689819 8771.00 63.27 23.96 3789.84 3629.59 6544.59 2438.08 216819.08 2505942.60 60 °50'59.006 "N 151 °35'16.566'W 1.02 96.18 -0.01 1.15 6983.85' 8864.00 63.23 24.38 3831.70 3671.45 6620.35 2472.08 216854.92 2506017.52 60 °50'59.752 "N 151 °35'15.879'W 0.41 -92.84 -0.04 0.45 7066.75 8959.00 63.22 24.15 3874.50 3714.25 6697.67 2506.94 216891.66 2506093.96 60 °51'00.513 "N 151 °3515.175'W 0.22 83.16 -0.01 -0.24 7151.40 9053.00 63.27 24.61 3916.81 3756.56 6774.12 2541.59 216928.16 2506169.55 60 °51'01.266 "N 151 °3514.476'W 0.44 -84.01 0.05 0.49 _ 7235.17 9148.00 63.31 24.19 3959.51 3799.26 6851.41 2576.64 216965.09 2506245.95 60 °51'02.027 "N 151 °35'13.768'W 0.40 - 110.09 0.04 -0.44 7319.87 9244.00 63.18 23.79 4002.73 3842.48 6929.72 2611.50 217001.85 2506323.39 60 °51'02.798 "N 151 °35'13.064'W 0.40 8.46 -0.14 -0.42 7405.45 9339.00 63.24 23.80 4045.55 3885.30 7007.32 2645.71 217037.94 2506400.13 60 °51'03.562 "N 151 °35'12.373'W 0.06 -94.67 0.06 0.01 7490.14 9433.00 63.19 23.09 4087.91 3927.66 7084.30 2679.10 217073.20 2506476.27 60 °51'04.320 "N 151 °3511.699'W 0.68 -41.79 -0.05 -0.76 7573.96 9529.00 63.31 22.97 4131.12 3970.87 7163.20 2712.63 217108.65 2506554.33 60 °51'05.097 "N 151 °35'11.022'W 0.17 - 146.19 0.12 -0.13 7659.62 9623.00 63.27 22.94 4173.37 4013.12 7240.52 2745.38 217143.28 2506630.82 60 °51'05.858 "N 151 °35'10.360'W 0.05 90.02 -0.04 -0.03 7743.53 9717.00 63.27 23.01 4215.65 4055.40 7317.81 2778.15 217177.92 2506707.29 60 °51'06.619 "N 151 °35'09.698'W 0.07 -97.13 0.00 0.07 7827.42 9812.00 63.25 22.83 4258.39 4098.14 7395.96 2811.19 217212.86 2506784.61 60 °51'07.389 "N� 151°35'09.031"W 0.17 -97.42 -0.02 -0.19 7912.20 N � 9898.00 63.22 22.57 4297.12 4136.87 7466.79 2840.83 217244.21 2506854.70 60 °51'08.086" 151 °35'08.433'W 0.27 0.00 -0.03 -0.30 7988.94 ° 9930.00 63.22 22.57 • 4311.54 4151.29 7493.17 2851.79 • 217255.82 • 2506880.80 60°51'08.346"N 151°35'08.211'W 0.00 0.00 0.00 0.00 8017.50 Projected Data - NO SURVEY; 8.5" Open Hole TD Page 2 of 2 • • Chevron • %O. Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -18 TRADING BAY UNIT M -18 ADL017594 5073320583 LK7620 160.00 185.00 �'"4.4e 1 a, .�. �:.. . < "' r 'r Primary Job Type Job Category Objective Actual Start Date Actual End Date Drill and Complete Drill and 12/4/2008 Complete Primary Wellbore Affected Wellbore UWI Well Permit Number M -18 5073320583 -00 2081620 alTIErt 12/412008 06:00 - 12/5/2008 00:00 Operations Summary Skidding rig from M -32RD. Rigging up. 12/5/2008 00:00 - 12/6/2008 00:00 Operations Summary Rigging up. 12/6/2008 00:00 -1217/2008 00 :00 Operations Summary Rigging up. 110/2008 00:00 - 12/8/2008 00:00 Operations Summary Begin NU of 20 -3/4" BOPE. 12/8/2008 00:00 1240008 00:00 Operations Summary Rigging up 20 -3/4" BOPE. 12/9/2008 00 :00 - 12/10/2008 00 :00 Operations Summary Rigging up 20 -3/4" BOPE. .12/10/2008 00:00 -12/11 /2008 00:00 Operations Summary Rigging up 12/.14/2008 00:00 - 12/12/2006`00 :00 Operations Summary Rigging up 12112/200660:00 12/13/2008 00:00 Operations Summary Continue to rig up. Perform Diverter test, witnessed by AOGCC Jeff Jones. 12/13/2008 00 :00 12114/it 0; 00 00 Operations Summary Continue rigging up. 't/14/200800:00 .12/15/2008 00:00 Operations Summary Continue to rig up. PU BHA. Tag mudline at 442'. 12/15/2008 00:00. 12116/2008 00 :00 Operations Summary Drill directionally 17 -1/2" hole to 1180' MD. ' 12/184008 00 :00 -12/17/2008 00:00 Operations Summary Drill directionally 17 -1/2" hole to section TD @ 1450' MD. TOOH and LD BHA. 12/17/2008 00010'4 12/1812008 00:00 'I'll,: 4 Operations Summary Wash out conductor. Make wiper trip to 1450'MD OK. TOOH, begin running 13 3/8" 68# L -80 surface casing. 12/18 /2008 00:00 12/19/2008 00 :00 t, r, Operations Summary Continue to run 13 3/8 surface casing. Condition mud for cement while rigging up cementers. 149 12008 00100 - :12120/2008 00:00 Operations Summary Finish conditioning mud for cement. Cement 13 3/8 casing to surface in 2 stages. Stage one of 234bb1 13.0ppg LiteCrete cement, bumped plug at 700psi, floats held. Pressured up to open DV collar at 469' w/ 2200psi. Stage two of 276bb1 13.0ppg LiteCrete cement, bumped lug & closed DV collar w/ 1100psi. Start wellhead installation. Notice given to AOGCC for upcoming BOP test. Cpl to c u + 7 *1400008 00:00 - 12/21/2008 00:00 Operations Summary Finish installing wellhead. Test BOPs to 250psi low /3000psi high, charted and witnessed by AOGCC Jeff Jones. 12121/2008 00:00 - 12/22/2000:00100 r . tom^ Operations Summary Pickup Cleanout BHA, Run in hole to 409' MD, wash to 455' MD and tagged hard cement. Drill cement and DVT to 495' MD. Continued to drill cement stringers to 1337' MD. CBU. Performed Casing test to 1500 psi for 30 minutes. Wash and ream cement to 1356' MD. Drill cement from 1356' to 1397' MD. Change mud over to 9.1 ppg. POOH for Directional BHA. Start to pick up Directional BHA. • Chevron 1 %1 0/ Chevron - Alaska 1 %. Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -18 TRADING BAY UNIT M -18 ADL017594 5073320583 LK7620 160.00 185.00 12/22/2008 00 :00 12/2312008 00:00 Operations Summary Continue to pick up Directional BHA. Run in hole w/ 12 -1/4" bit to 1394' MD. Wash from 1394' to 1450' MD. Drill from 1450' to 1470' MD. Perform FIT to 12.8 ppg equipvalent. Continue drilling from 1470' to 1532' MD. Lost pulse on MWD tool. POOH. Lay down BHA. Start to pick up new Directional BHA. 12/23/2008 00:00 - 12/24/2008 00 :00 Operations Summary Continue picking up directional BHA. Run in hole to 1532' MD. Drill from 1532' to 1820' MD. POOH to pick up motor for correction run. Start to pick up Mud Motor BHA. 121241. 008 00:00 - 12/2512008 00:00 Operations Summary Trip in hole with motor directional assy. Slide and rotary drill 1820'- 2380'. 12125 /2008 00x00. 1212612008 00 :00,.• Operations Summary Slide and rotary drill 2380'- 2390'. TOOH. Lay down motory assy and MU rotary steerable assy. TIH. Drill 2390' -2520' w/ rotary steerable. 17,126/2006 00:00 - 12/27/2008 00:00 _. . Operations Summary Drill with rotary steerable assy 2520'- 3938'. 12/27/2008 00:00 = 12/2812008 00 :00 1,7f4f Operations Summary Drill with rotary steerable 3938'- 5180'. 12128/2008 00 :00 - 12/29/2008 00:00 Operations Summary Drill with rotary steerable 5180' to section TD at 6126'. CBU. Start to backream out of hole. 42129/2008 00 :00 - 12/30/2008 00:00 Operations Summary Back ream out of hole. MAD pass 2372'- 1799'. Finish backreaming out of hole. LD BHA. Wash out wellhead and prep to test land hanger. 12/30/ 2008 00j00 12/Att2008 00:00 zz ; - 1A4 Operations Summary Wash out wellhead. RU to run casing. Run 9 5/8 ", 47 ppf, L -80, BTC -M to 1508'. /2/3112008 00:00 - /1/2009 00:00 Operations Summary Finish running 9 5/8 ", 47 ppf, L -80, BTC -M to 6028' Prep to land casing hanger. . 00 :00 - 1/2/2009 00:00 Operations Summary Land 9 5/8" casign hanger. Cement 9 5/8" casing in 2 stages. Stage one 131bbI 13.0ppg LiteCrete cement, bumped plug at 1250psi, good returns throughout, opended DV collar w/ 2150 psi, stage two of 145bb1 13.Oppg LiteCrete cement, bumped & shifted DV tool closed w/ 2000psi. Wash out stack and install pack off bushing in wellhead. Notice given to AOGCC for upcoming BOP test. _ 1/2/2009 00:00` - 1/3/2009 00 :00 Operations Summary Finish testing voids in wellhead. Test BOP's 250/2000/3000. BOP test witness waived by Jeff Jones of AOGCC. 113/2009 00:00;- i141e2009 00:00 Operations Summary Make up rotary steerable BHA and TIH. Drill out stage tool. TIH. Test 9 5/8" casing to 3000 psi ok. 1/4/2009 00:00.1/8/2009,00 :00 Operations Summary Drill out 9 5/8" casing w/ 8 -1/2" bit. Perfrom FIT test at 6146' to 12.8ppg EMW. Drill ahead with rotary steerable to 7138 collecting 1 pressure sample. //512009 00 :00'- 1/6/2009 00:00 Operations Summary Drill 7138' -8164' with rotary steerable. TOOH to repair IBOP and install TQ reduction tools. 1/6/2009 00:00,1`1000:00 Operations Summary TOOH back reaming as necessary. Repair IBOP while installing torque reduction tools on DP. Lay down TesTrak tool from BHA. 1/7/2009.0000 - 1/8/2009 00:00' Operations Summary TIH. Drill 8164'- 8231'. Partial lost returns at 8190'. Pick up and spot 3 lost circulation pills. Losses slowed from 12 to 20 BPH. Drill 8231' -8520' back reaming and circulating sweeps as necessary to clean hole. 1/8/2009 00:00 ,.. ,, Operations Summary Drill with rotary steerable 8520'- 9712'. 1/912009 00:00 - 1/10/2009 00:00 , Operations Summary Drill 9712' to TD @ 9930'. Circulate and condition hole for liner. Start back reaming out of hole 1/10/2009 00:0'0 1i11l'12_009 09:00 ..,. Operations Summary Finish back reaming out of hole. Spotted 35bb1 LCM pill at 6120' on way out. LD BHA. Chevron • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -18 TRADING BAY UNIT M -18 ADL017594 5073320583 LK7620 160.00 185.00 1/1112009 00:00 - 1/12/2009 00 :00 r. Operations Summary RU to run liner. TIH with 7 ", 26 ppf, L -80 Liner. 1/12/2009 00:00.1/43/2009 00:00 Operations Summary Run 7 ", 26 ppf, L -80 liner to 8276'. Liner started taking weight and packing off at 8276. Work pipe and circulate. 1/13/2009 00:00 - 1/14/2009 00:00 „ Operations Summary Work tight hole with 7" liner 8223'- 8303'. Could not work deeper. TOOH w/ DP. Notify AOGCC of upcoming BOP test - waived by Jim Regg. LD liner hanger. Continue to TOOH and lay down liner. 11141200900 :00 - 1/1512009 00:00 Operations Summary Finish laying down 7" liner. Start testing BOP's 250psi low / 3,000psi high, witness waived by AOGCC Jim Regg. 1145/2009 00.00 , r`1,116/2009'00:00 Operations Summary Finish testing BOP's. TIH to 1400' and start to repair top drive. jh1612009 =4141/200900:00 Operations Summary Finish top drive repairs and test. TIH to 8990' washing and reaming tight spots as necessary. 1/17/2009 00:00 - 1/1812009 00,00 . . Operations Summary Wash and ream 8952'- 9836'. Pump several high vis sweeps and TOOH. Work several tight spots without circulating on trip out. 1/18/2009 00:00 - 1/19/2009 00:00 Operations Summary Finish TOOH with clean out assy. Run 7" 26# L -80 liner. MU liner hanger. TIH to 6190'. Circ and condition mud. 1/49/2009[06:00 - :1/2012009 00:00 Operations Summary TIH with 7" liner 6019' to 8420' working through tight spots. Liner running tool released while rotating at 8375'. TOOH with running tool. Prep to install 3 1/2" rams in BOP. 4/20 /2009 00:00 - 1/21/2009 00:00 Operations Summary Finish testing rams in BOP's to 250psi low /3000psi high. MU 7" EZSV c/w perf gun on 3 1/2 DP. TIH picking up 3 1/2 DP and then 5" DP out of derrick. 1121/2009 00 :00» 4/22/2009'0M00 Operations Summary TIH with EZSV and perf gun. Set EZSV@ 7100'. Perforate 7" liner from 7102' -7104' and circulate freely. Pump 70 bbls 13.0 ppg LiteCrete. Place approximately 65 bbls cement behind pipe with good returns. Returns diminished at end of job resulting in a loss of approximately 6 bbls cement. Sting out of EZSV and circulate clean. TOOH. 1/22/2009 00:00 - 1/23/2009 00:00 Operations Summary TIH with polish mill. Polish tie back receptacle. TOOH. TIH with ZXP liner top packer and set. TOL at 4545'. TOOH removing DP torque tools. 1/23/2009 00:00 - 1/24/2009 00:00 ,,,..; .. _ f rh•r , Operations Summary TOOH with ZXP packer setting tool. Test casing to 3000 psi ok. TIH and tag EZSV at 7100'. Start cleaning pits and displacing wellbore to FIW. 1/24/2009 00:00'''4/2t12009 00:00 Operations Summary s Continue to clean pits and displace wellbore to FIW. 1/25/2009 00:00 - 1/26/2009 00 :00,• Operations Summary POOH standing back 5" DP. LD 3 1/2 DP. TIH with 3 1/2" 9.2# L -80 tubing kill string to 3157'. Land tubing hanger and test voids ok. V 1/26/2009 00:00 - 1/27/2009 00:00 Operations Summary ND BOP's. Land dry hole tree and test voids ok. Prep to warm stack rig 4/27/2009"60:00::.'1126/20400:00 Operations Summary Continue to warm stack rig. 1/28/2009 00:00 4/29x2009 00100"7r,,,' Operations Summary Continue deactivation and warm stacking rig. 1/29/2000 - 1130/2009 00:00. Operations Summary Continue deactivation and warm stack the rig. 4/30/2009`o0:00 - 1/31/2009 00 :00 , ,„4,11 .0 ,';1 ` v° tar Operations Summary Continue deactivation and warm stack rig. 1/31/2009 00 :00 211/2009 00 :00'' Operations Summary Continue deactiviation and warm stack rig Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -18 TRADING BAY UNIT M -18 ADL017594 5073320583 LK7620 160.00 185.00 2/112009 00:00 - 2/2/2009 00 :00 Operations Summary Finish deactivation and warm stacking rig. Final report. 313/2009 00 :00= 314/2009 00:00 . Operations Summary NU tree, set BPV, and test tree to 250 psi low / 5,000psi high, for flowline installation. turn well back over to production. Rig still deactivated. 6117/2009 00:00 - 6/18/2009 00 :00 Operations Summary Personnel arrived on platform. 6/18/2009 00:00.6/19/2009 00:00 Operations Summary Began re- activation of Steelhead Rig -51, skidded and secured rig over M -18. Mobe equipment to platform. 6/19/2009 00:00 - 6/20/2009 00:00 Operations Summary Continued mobe of equipment to platform, reactivating rig. 6/20/2009 00:00 - 6/21/2009.00:00 Operations Summary Continue rig reactivation, spot vendor equipment, performed derrick inspection. Move HWDP 5" in derrick. 4/21/2009 00:00 - 6/22/2009 00 :00 Operations Summary Moved 5" DP in derrick for M -18 operations. Continue rig prep. Confirmed BPV previously set in Tree, ND tree and installed VETCO test dart. N/U riser and BOPs to M -18. 6 /22/2009 00 :00 - 6/23/2009 00:00 Operations Summary Continue NU BOPE and related equipment. Installed 5" RAMs in upper double gate and 3 1/2" RAMs in lower single gate. R/U test pump and filled riser and BOP with water. Leak on air boot flange connection. Pulled flow nipple and air boot x flange assembly and siliconed ring groove before re- installing. Refilled flow nipple with water no leaks. Made up 3 1/2" test assembly. Made up test manifold and purged air from lines. Closed annular preventer. 6/23/2009 00:00 6/24/2009 00:00 Operations Summary � Problem testing annular on 3 -1/2" test joint, good test of annular on 5" test joint. Troubleshoot and remedy problem testing 3 -1/2 ". Began testing BOPE 250psi low /3,000, Annular to 250psi low /1,000psi high on 3 -1/2" & 5 ". BOP test witnessed by Lou Grimaldi of AOGCC. 6/24/2009 00:00 - 6/25/2009 00:00 Operations Summary Continue testing BOPs, replaced choke line and HCR valve. Conducted pre- operations meeting with rig crew. Flushed all low and high pressure surface lines with caustic. Neutralized caustic and prepared Baraclean surfactant pill. Continued with derrick inspection. 6/28/2009 00 :00 - 6/26/2009 00:00 Operations Summary Completed derrick inspection, flushed low and high pressure lines with Baraklean and returned dirty fluid to pits for disposal in the production system. Flushed all lines with FIW. Rinsed the active pits and took on 1000 bbls of FIW for mixing completion brine. Unseated tubing hanger and pulled 3 1/2" kill string and stood back in derrick. 6/26/2009 00:00 - 6/27/2009 00:00 Operations Summary Finished TOOH with 3 1/2" kill string. Installed 7" blanking sleeve and tested same. Installed 9" x 13 3/8" wear ring. P/U 7" wellbore cleaning tool assemblies. TIH to 4087' w/ 3 1/2" DP and 7" WCT assemblies. Mixed and filtered 1000 bbls of 6% KCI brine. Final NTU= 25, Solids= 25ppm. 6/27/2009 00:00 - 6/28/2009 00 :00 . • Operations Summary R/U Pit management valve at shaker pit dump. Drifted 3 1/2" DP to 4534'. Rotated through liner top, P/U 9 5/8" cleaning assemblies on 5" DP and TIH to tag EZSV @ 7097'. Pumped sweeps, 55 bbls of caustic, 55 bbls of Baraclean and 40 bbls of N -Vis. Short tripped and TIH to tag EZSV again @ 7097' 6/28/2009 00:00 - 6/29/2009 00:00 Operations Summary Continue to pump and dump FIW in order to achieve <500 ppm solids while rotating and reciprocating. Pumped 40 bbls of N -Vis and displaced well with 6% KCI completion fluid. R/U DE filter press in a closed loop circuit and continued to circulate and filter wellbore fluid. Cleaned DE press twice. 6/29(2009 00:00 - 6/30/2009 00:00 m " Operations Summary POOH w/ cleaning tools, M/U sump packer and and setting tool. TIH @ 2 min/ stand to 4951'. RA tags on stands #1, #7 and #12. P/U 5" DP and continued to TIH. Tagged EZSV @ 7097'. spaced out packer to 7075' DPM. R/U a -line and prepared to pump down gamma ray tool for depth correlation. 6130/2009.00:00 - 7/1/2009 00:00 <..` s�} Operations Summary Correlated sump packer on depth w/ GR @ 7070'. Pumped packer setting ball and set sump packer. Pumped 40 bbl sweep of Baraclean and continued to circulate and filter wellbore fluids. Added Inflo -250 to wellbore fluids and continued to filter. Final solids loading 125 ppm . POOH and LD RA subs and setting tool. Began testing BOPs (witnessing waived by Chuck Scheve AOGCC), annular 250 low/ 1000 high. tested upper rams, safety valve, IBOP, upper TD valve, outside kill valve and choke manifold valve #s 1,2,3,4,5,6,12 & 13 to 250 low/ 3000 high. All tests held for 5 mins. Chevron • %. Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -18 TRADING BAY UNIT M -18 ADL017594 5073320583 LK7620 160.00 185.00 Daily ©peratlons 7/1/2009 00 :00 - 7/2/2009 00:00 Operations Summary Continue testing BOP equipment to 250 psi low / 3000 psi high. Lower TD (top drive) valve failed. Performed cummy pre- charge test. Pulled 5" test jt. and tested blind rams to 250 psi low /3000 psi high. Good test. M/U 3 1/2" test jt. Tested annular to 250 psi low /1000 psi high. Good test. Tested lower. pipe rams, safety valve and IBOP to 250 psi low /3000 high. All good tests. changed lower TD valve and tested same. good test. M/U and P/U TCP assembly and TIH to 5334' by midnight. 7/212000 00 :00 - 7/3/2009 00:00 Operations Summary TIH w/ TCP string from 5330' to sump packer @ 7070'. Snap in and out of packer. Correlate guns on depth, space out and set champ packer. Tested backside to 500 psi.R/U surface lines and PT same. Opened bypass and displaced 60.2 bbls of completion fluid to the trip tank. Shut bypass and pressured up DP to 3300 psi to fire guns @ 7028' -7060' (A5 sand). Observed pressure decline. bullheaded 88 bbls down DP to overdispiace N2 into the formation. Opened bypass and observed losses, 4 BPH. Circulated N2 out of the well. Unset Champ packer and flow tested well and continued to circulate 400 bbls @ 7 BPM and 1400 psi (no losses observed) POOH w/ TCP string and LD same. M/U cleanout assembly. 7/3/2009 00:00 - 7/4/2009 00 :00 ,,, '. . , Operations Summary TIH w/ cleanout assembly. tagged out 38' below the TOL @ 4572'. Worked pipe w/ no success. dropped ball to deactivate the Ridge Back Burr Mill (RBBM). Rotated pipe and tried to pass restriction w / no success. POOH, and M/U cleanout assembly #2 replaced RBBM with a 6" OD watermelon mill and TIH to TOL © 4534'. Broke circulation and worked through tight spot © 4572' w/o problem. TIH to sump packer @7078' DPM. Circulated two hole volumes. Final return sample had 50 ppm and 194 NTUs. Rabbit DP POOH, LD assembly, magnets were completely packed off with pert debris. ,71412009 00 :00 - 7/5/2009 00:00 Operations Summary M/U GP assembly #1, TIH on 3 1/2" DP. Reduce TIH speed to 3 min /std in 7" liner. Spaced out, change out bails and R/U surface lines. Drop packer setting ball and pumped to seat. Set SC -1 packer @ 6744' and tested annulus to 1000 psi. Released setting tool w/ 2500 psi on annulus. Located circulating and reverse positions and marked pipe. Moved to reverse position and begin to circulate setting ball back to surface. 7/5/2009 00 :00- 7/6/2009 00 :00 Operations Summary Reverse out setting ball @ 9 BPM and recovered at surfac. Pickled DP w/ 6.5 bbis of 10% HCI and reversed back to slop tank. Neutralized acid to a pH of 7. Performed DP friction test. Moved to circulating position and performed step rate inj. test. Frac extension pressure = 844 psi (surface) @ 1.47 BPM. Peformed a HRWP on the A -5 sand. Pumped @ 5 BPM w/ 2.5 BPM return rate. Pumped 113 bbis of completion fluid and 4329 Ibs of 20-40 sand. Achieved sand out pressure of 4000 psi after overdisplacing x -over port by 20 bbis. Reversed out excess sand and restressed pack to 4060 psi © 0.9 BPM indicating 18' of blank covered. Total sand place in formation 3765 lbs = to 118 lb/ft of perfs. Performed soft closure pulling out of KOIV. Had to pump down to close KOIV. Dropped rabbits while P0011 w/ service assembly and LD same. M/U TCP assembly #2 w/ SB packer plug. P/U and begin TIH. 710/2009 00:00 - 7/7/2009 00:00 ` Operations Summary TIH w/ TCP assembly #2 and position gun 5578' -6743' DPM. R/U e-line to correlate guns. Space out and latch packer plug and shear off same. Test WL SES to 250 psi low and 2500 psi high, Good test. TIH and correlate guns on depth. POOH and R/D a -line. 7/7/2009 00:00 - 7/8/2009 00 :00 Operations Summary Made several attemps to set Champ packer w/ no success. POOH w/ TCP assembly and change out packer. TIH w/ TCP assembly. Space out and set Champ packer @ 6195' DPM and test same. Good Test. P/T surface lines, displace 49 bbis of DP fluid with N2. Shut bypass and pressure up string to 2900 psi. Guns fired. Perfs shot: A2A (6370- 6395'), A2B ( 6440'- 6580') , A -3 (6712'- 6730'). Monitor prssure, stabilized @ 470 psi. Displace N2 with completion fluid, monitored losses. Circulated 2 bottoms up. Final solids 250 ppm with 160 NTUs. POOH w/ TCP assembly #2 7/8/2009 00 :00 - 7/9/2009 00:00 Operations Summary POOH w/ TCP assembly #2 and LD same. All shots fired P/U cleaning tool and overshot and TIH. Circulate and filter 3 hole volumes © 7 BPM, final NTUs 180 w/ 300 ppm solids. TIH above SB packer plug and reverse circulate 2 bottoms up @ 4.5 BPM. S/O and latched SB plug. POOH w/ BHA and SB packer plug to 1025' 7/9/2009 00 :00 - 7/10/2009 00:00 �. Operations Summary Continue POOH w/ cleanout BHA. Recovered SB packer plug and LD same. M/U middle GP assembly and TIH to 6750' DPM. R/U surface lines and PIT same to 6000 psi. Pump packer setting ball and set SC -1 packer © 5975' (IES). Pull test packer and test annulus to 1000 psi. Increase pressure to 2500 psi to activate hydraulic release, locate and mark; circulating and reverse positions. Close pipe rams and reverse ball to surface. Recover ball and re -test lines to 6000 psi. 7/10/200900 :00 - 7/11 /2009 00 :00 Operations Summary Pickle pipe w/ 6 bbis of 10% HCI and 9 bbls of 5% HCI. Reversed out acid and neutralized in slop tank. Continued reversing to pits until fluid specs achieved 145 NTUs and <500 ppm solids. Performed DP friction and step rate injection test. Frac extension pressure = 844 psi (surface) © 1.89 BPM. Pumped HRWP @ 5 BPM w/ 2.5 BPM returns and 1 ppa gravel. Rapid sand out to 5125 psi. P/U reversed out sand w/ rig. Dumped seals and restressed pack w/ .49 BPM and 800 psi. Final results 8128 Ibs of gravel below x -over, 25 Ibs /ft of perfs and 9' of blank covered. Performed soft closure proceedure for KOIV valve but valve did not close, even after several attempts to pump it closed. Static losses were 12 BPH. Decision made to POOH. POOH w/ GP service assembly and LD same. P/U and begin TIH w/ 3d TCP assembly to 2659'. Hole losses @ 10 BPH. Total losses per day 306 bbis. Chevron • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -18 TRADING BAY UNIT M -18 ADL017594 5073320583 LK7620 160.00 185.00 f . 7/11 /2009'00 :00 - 7/12/2009 00:00 Operations Summary TIH w/ TCP assembly #3 to 5959'. P/U 135K and S/O 90K. M/U W/L SES. P/U space out and TIH to latch SB plug in packer and shear off. Hole losses stopped. R/U a -line equipment and P/T same to 250 psi low/ 2500 psi high. RIH w/ GR CCL and pump down tool. Begin pumping tool down 3 1/2" DP @ 1 bpm -250 psi. Increased rate to 2 BPM -450 psi when tool string pumped of e-line. Mechanical weak point released. R/D a -line and POOH with 5" DP and 3 stands of 3 1/2" DP. Recovered W/L string. TIH w/ TCP assembly to 5971'. R/U e-line equipment and retest to 250 psi low/ 2500 psi high. RIH w/ WL tools and pump down 3 1/2" @ 2.5 BPM - 150 psi to 5100'. Begin correlating guns on depth. 7/12/2009 00:00.7/13/2009 00:00 Operations Summary Correlate guns on depth. P/U 6' to position top shot @ 5347' and bottom shot © 5960'. Brent Voorhees - Geologist confirmed correlation. POOH and R/D E -line tools. Set Champ packer and opened by -pass. R/U N2 lines and P/T same to 4000 psi w/ N2. Displace DP to 4700' w/ N2, recovered 39 bbls. Closed by -pass and pressured up DP to 2920 psi, guns fired within 4 mins. Perforated for production: SZ -19 (5347'- 5476'), SZ -21 (5600'- 5665'), SZ -22 (5790'- 5900'). SZ -23 (5945'- 5960'). Monitored pressure decline. Displaced N2 into the formation w/ 56 bbls of brine. Opened by -pass and circulated 2 bottoms up. Monitored losses - 8 BPH. POOH and UD TCP assembly and guns. All shots fired. Start to P/U cleanout assembly #3. 7/13/2009 00:00 - 7/14/2009 00100 Operations Summary RIH w/ cleanout assembly & magnets to 5,965', circulated hole clean with filtered KCL to 95 NTUs/ <400ppm solids. Engaged and released SB packer plug at 5,975'. POOH w/ plug monitoring well. RIH w/ GP screens, blank pipe, and SC -1 Packer assembly. 7/14/200900:00 - 7/15/2009 00:00 Operations Summary RIH w/ gravel pack assembly on DP. Sting into SC -1 packer at 5,975'. Drop ball and set Baker SC -1 Packer at 5,142'. Test backside of paker to 2500psi, & hydraulically release from packer. Reversed out setting ball. Performed gravel pack on upper zone at 7.3 bpm, max pressure at sandout 4,150 psi, 57 Ibs sand in annulus, 4150 lbs in perfs. Reversed out excess. POOH w/ GP service tool and wash pipe. Notified AOGCC Jeff Jones of upcoming , BOP test. 7/15/20090(00 - 7/16/2009 00 :00 Operations Summary UD GP assembly, pull wear bushing, drain stack and flush well head. P/U snap latch seal assembly and attempt to drift tubing in derrick w/o success. P/U and TIH w/ tubing from deck to 1266'. R/D BJ lines and equipment and prepare to back load. Off load new 3 1/2" tbg from boat, P/U and TIH w/ completion string including gas lift valves © 5084', 3811' and 1626'. P/U SSSV and function test same. TIH to position @ 475'. Snap in and out of SC -1 packer @ 5142', space out and install space out pups. 7/1612009 00:00 - 7/17/2009 00:00 Operations Summary UD scaled up 3 1/2" Tbg. from derrick, M/U landing joint to hanger, Connect SSSV control line to hanger and test same to 5000 psi. Continue RIH w/ completion string to 5120' and displace well with packer fluid. Sting into SC -1 packer and land tubing hanger with tubing in neutral position.. Pressure test void to 250 psi low and 5000 psi high. Connect lines and P/T production seals to 300 psi. ND BOPs and NU tree. Test bonnet void to 250 psi low and 5000 psi high. Pull BPV, install test dart and P/T tree to 250 psi low and 5000 psi high. Turn well over to production. Trouble shoot TDS (top drive) , problems. 7/17/2009 00:00 - 7118/2009 00:00 Operations Summary Continue to R/D and off load equipment from M -18 operations. Perform rig maintenance in preperation to skid rig over M -6 7/18/2009 00 :00 - 7/19/2009 00:00 Operations Summary Continue to R/D from M -18 operations and prepare to skid rig to M -6. Final report for M -18 operation. • • t L � fit k 4 4 y / SARAH PALIN, GOVERNOR SSA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMAIISSION / PHONE 907A 9501 -3539 279-1433 Timothy Brandenburg s FAX (907) 276 -7542 Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, M -18 Sundry Number: 309 -197 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 17 day of June, 2009 Encl. Dot -tom • b . 11 STATE OF ALASKA I�; WG* /IZ / 2ooq ALASKA OIL AND GAS CONSERVATION COMM ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Waiver ❑ . Other S Alter casing Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Restart Operations Change approved program Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development a . Exploratory ❑ 208 -162 . 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20583 -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 El Trading Bay Unit M -18 • 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): wiz& , 7 , 4 , t l g, ADL 17594, ADL 18730 [Steelhead Platform] 160 AMSL McArthur River Field/ Gang- Gas-Sarnls , L: IC 6fr 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): 9,930' 4,311' 8,375' 3,610' 7,100' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 401' 28 -32" 480' 480' Surface 1,362' 13 -3/8" 1,441' 1,382' 5,020 psi 2,270 psi Intermediate 6,041' 9 -5/8" 6,120' 2,593' 6,870 psi 4,760 psi Production Liner 3,830' 7" 4,545' (4_ ) 1,975' 7,240 psi 5,410 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,102'- 7,104' 3,034'- 3,035' 3 -1/2" DP S -135 2,768' Packers and SSSV Type: Packers and SSSV MD (ft): None N/A 13. Attachments: Description Summary of Proposal 151 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch CI Exploratory ❑ Development El • Service ❑ 15. Estimated Date for 6/17/2009 16. Well Status after proposed work: Commencing Operations: Oil ❑ Gas 0 ` 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 Jim Rose, 907 - 263 -7637 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature / 907 - 276 -7600 Date 6/11/2009 4101 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ., L C/ Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance ❑ Other: Per 20M-C. 2S. OSS (■,)(l) , goPE test Varg' && c is AfproVt i RECEIVED A. it ®t.„,,. Pr® z.og - l 6, 2 s 19(4.1a_t o fp! i JUN 1 2 Uo9 Subsequent Form Required: (0 _ 40 ! Apo o ( 1 mapl '�, • Alogica Oil & (has Cons. Cnnlr, jp 1 `^ nr charm APPROVED BY Approved by: �� COMMISSIONER THE COMMISSION Date: 61 / 7 / r —v, . , , ! Form 10 -403 Rev * r =: � ( ' \ ( t i / L_ Submit in Duplicate • Chevron • Steelhead Platform Well # M -18 6/11/09 OBJECTIVE: • Complete well with triple stack gravel pack. PROCEDURE SUMMARY: 1. ND Tree and NU BOPE, shell test BOP's, POOH with 3 %" Hydril 503 tbg. kill string and stand back same. 2. Perform a full function BOP test as per the permit to drill # 208 -162 , witnessed by the AOGCC 3. PU an assembly of wellbore cleaning tools including scrapers and brushes, and RIH establish circulation with FIW, rotate and reciprocate. 4. Pump cleaning pills and circulate with FIW until a solids content of 500 ppm or less is achieved. 5. Circulate and filter well w/ 6% KCI completion brine. 6. PU sump packer on DP and RIH, R/U E -line and use a pump down gamma ray tool to correlate, set packer on DP @ 7,064' MD ( +/ -), POOH & RD E -line. 7. RIH w/ TCP assembly, R/U E -line and use a pump down gamma ray tool to correlate to perforate the A -5 sand, POOH & RD E -line. Set Champ packer and open bypass. 8. R/U N2 unit and displace completion fluid with N2 to thf Champ packer. Close the bypass and pipe rams pressure up the DP to an extreme overbalance pressure of 3,294 psi ( + / -) at surface and perforate the A -5 sand from , f29.' ( + / -)- 7,060' ( + / -) i POOH. 9. P/U BHA with string magnets, Burr mill and mule shoe and RIH to clean out debris, POOH. 10. PU lower GP assembly, RIH and latch into sump packer, set lower GP packer @ 6,741' MD ( + / -), establish circulation, perform step rate injection test, perform high rate water pack on lower interval, POOH. 11. RIH w/ TCP assembly with SB packer plug and setting tool. Latch packer plug into lower GP packer and shear off. R/U E- line and use a pump down gamma ray tool to correlate guns on depth to perforate the A -2, A -3 sands, POOH & RD E -line. Set Champ packer and open bypass. 12. R/U N2 unit and displace completion fluid with N2 to the Champ packer. Close the bypass and hydril and pressure up the DP to an extreme overbalance pressure of 3,042 psi ( + / -) at surface to perforate the A -3 sand from 6,712' ( + / -)- 6,730' ( + / -) and A -2 sands from 6,440' ( + / -)- 6,580' ( + / -) & 6,370' ( + / -)- 6,395' ( + / -). 13. P/U overshot with string magnets and Burr mill and RIH clean out perf debris and retrieve packer plug, POOH. 14. RIH w/ middle GP assembly and latch into lower GP packer, set middle GP packer @ 5,970' MD ( + / -), establish circulation, perform step rate injection test, perform high rate water pack on middle interval, POOH. 15. RIH w/ TCP assembly with SB packer plug and setting tool. Latch packer plug into middle GP packer and shear off. R/U E- line and use a pump down gamma ray tool to correlate guns to perforate the SZ -19 -23 sands, POOH & RD E -line. Set Champ packer and open bypass. 16. R/U N2 unit and displace completion fluid with N2 to the Champ packer. Close the bypass and hydril and pressure up the DP 3 to an extreme overbalance pressure of 2,785 psi ( + / -) at surface and perforate the SZ -19 -23 sand from 5,945' ( + / -)- 5,960' ( + / -) & 5,790' ( +0- 5,900' ( + / -) & 5,600' ( +/- )- 5,665' ( + / -) & 5,347' ( +/- )- 5,476' ( + / -). 17. P/U overshot with string magnets and Burr mill and RIH clean out perf debris and retrieve packer plug, POOH 18. RIH w/ upper GP assembly and latch into middle GP packer, set upper GP packer @ 5,133' MD ( +/ -), establish circulation, perform step rate injection test, perform high rate water pack on upper interval, POOH. 19. P/U 3 1/2" tubing with S2 snap latch seal assembly and ratchet M /S, gas lift mandrels and SSSV, RIH, space out tubing, make up landing joint, splice SSSV control line, circulate packer fluid into annulus and land tubing in hanger. 20. Release rig, turn well over to production 21. R/U coiled tubing, test BOPE, and RIH to brea KOI , POOH , 22. RIH w/ CT to drift KOIVs, POOH Turn well over to production M -18 REVISED BY: CVK 6 -11 -09 Chevron S •teelhead Platform 1 %0 -7 Well M- —%0 As- spen 1/25/09 CASING AND TUBING DETAIL RKB to TBG Head = 78'.75 SIZE WT GRADE CONN MIN TOP TOP BTM BTM ID in MD rkb TVD rkb MD rkb TVD rkb Cement to ML " Structural 27 Surface Surface 480' 480' �- @ 385' 13 -3/8" 68 L -80 BTC 12.415 Surface Surface 1441' 1382' 9 -5/8" 47 L -80 BTC -M 8.681 Surface Surface 6120' 2593' 28" Conductor 28 7" 26 L -80 DWCSR 6.276 4545' 1975' 8375' 3 ® @ass Kill e String 13 3/8 Stage Collar 3 -1/2" 9.2 L -80 HSO3 Surface Surface 3157 1924 @ 469 Tbg Logging Detail Hole LWD /MWD Wire Line Mud Logging Notes Section 17' 'A" GR/Res Gas Detection, Consulting Geologist Mud Logging 13 3/8 in 17''A" Hole 12 /d' GR/Res/ Dens- Gas Detection, Consulting Geologist 9 5/8 Hydraulic Stage Neut Mud Logging Collar @ 2552 8 %" GR/Res/ Dens- Gas Detection, Consulting Geologist Neut Mud Logging Perforation Detail MD Zone Density (SPF) Notes 7102 -7104 A5 6SPF Perfs for cementation of 7" liner 1 7" Liner Top @ 4545' Miscellaneous Equipment Informtion Item Depth OD ID Notes L , 9 5/8" Casing in 12'/" Hole CMT Nor @7100 Cementing Information sQz peas @71oz -71oa, 6SPF Description Volume Density Yield Notes (bbls) (ppg) (ft3 /sx) 7" shoe @ 8375 13 3/8 Stage 1 234 13.0 1.46 LiteCrete 13 3/8 Stage 2 276 13.0 1.46 Lite Crete. Stage Collar at 469' Some cement to surface 12 bbls before landing plug. Planned TOC is 9 5/8 Stage 1 131 13.0 1.48 Lite Crete. 4404' J 9 5/8 stage 2 145 13.0 1.48 Lite Crete. Planned TOC @ TD 8 %Hole @ 9930 385' ML 7" Liner 65 13.0 1.48 Pumped 65 bbls 13.0 ppg Lite Perforated and cemented Crete through perfs. from 7102' Maintained good returns through most of the job. Lost approximately 6 bbls cement near the end of displacement MAX HOLE ANGLE = 89.3 @ 3533' MD Well Detail DRAWN BY: JAR I lhevron 1 •teelhead Platform Well M -18 1%. Proposed 01/09 V.11 CASING AND TUBING DETAIL RKB to TBG Head = 78.75' TOP TOP BTM BTM $ SIZE WT GRADE CONN I p I 1 n MD TVD MD TVD rkb rkb rkb rkb � Cement to 28" X -56 27 Surface Surface 401' 401' 4 ML @ 385 13-3/8" 68 L -80 BTC 12.406 Surface Surface 1,443 1384' Conductor 9 -5/8" 47 L -80 BTC -M 8.688 Surface Surface 6,1 s' 2,593' 7" 26 L -80 DWCSR 6.276 4,545' 1,976' ,10S' 3,035' 1' ��� 4Y� 7" EZSV 7,100' 3,035' 7" 26 L -80 DWCSR 6.276 7,100' 3,035' 8,375'' 3,611' SC Tubing Stage Collar g (cuss' 3-1/2" 9.2 L -80 HSO3i1 2.992 Surface Surface 5,133' 3,186' Perforation Detail I MD (rkb) TVD (rkb) Zone Density Notes t , 13 3/8 Shoe @ 1,443' 5,347 - 5,476' 2,244' - 2,303' SZ -19 12 4 -5/8" Millennium Chrg 9 5/8 Hydraulic 5,600' - 5,665' 2,358' - 2,388' SZ -21 12 4 -5/8" Millennium Chrg 5,790' - 5,900' 2,444' - 2,494' SZ -22 12 4 -5/8" Millennium Chrg ®r Stage Collar @ J 2,552' MD 5,945' - 5,960' 2,514' - 2,521' SZ -23 12 4 -5/8" Millennium Chrg 6,370' - 6,395' 2,706' - 2,717' A -2A 14 4 -5/8" Big Hole Chrg 6,440' - 6,580' 2,737' - 2,800' A -2B 14 4 -5/8" Big Hole Chrg 6,712' - 6,730' 2,859' - 2,868' A -3 14 4 -5/8" Big Hole Chrg 7,028' - 7,060' 3,002' - 3,017' A -5 14 4 -5/8" Big Hole Chrg Completion Equipment Informtion 9 5/8" x 7" Liner Hanger @ 4,545' Item MD (rkb) TVD (rkb) Notes A Incatl Model TE -5 SSSV 431' 430' Gas Lift Mandrel Gas Lift Mandrel SC -1 GP Packer 5,133' 2,148' SC -1 GP Packer 5,970' 2,526' 0 e upper SC - Packer @ SC -1 GP Packer 6,741' 2,873 II . 5,133' Model F -1 Sump Packer 7,064 3,018 i. Cementing Information i' 9 5/8" Shoe @ 6,120' Volume Density Yield Description (bbls) (ppg) (ft3 /sx) Notes 0 0 Middle SC - Packer @ Surface Csg. 1 Stage 231.0 13.0 1.47 LiteCrete to 469' . 5,970' Lite Crete. Stage Collar at 469' Some Surface Csg. 2 "d Stage 259.0 13.0 1.47 cement to surface 12 Lower SC - Packer @ bbls before landing 6 plug. 0 Intermediate Csg. 1 Stage 131.0 13.0 1.47 Lite Crete. Planned TOC is 4404' F - Sump Packer @ nd Lite Crete. Planned Intermediate Csg. 2 Stage 145.0 13.0 1 1,1 1,1 7,064' TOC @ 385' ML ±� EZSV @ 7,100 Pumped 65 bbls 13.0 ppg Lite Crete A I. 7" Liner Shoe @ 8,375' / through perfs. Maintained good Production Liner 70.0 13.0 1.47 returns through most of the job. Lost aooroximately 6 bbls TD 8'/: Hole @ 9,930' IAX HOLE ANGLE = 88.3° @ 3,533' MD Well Detail DRAWN BY: JAR 1 7 Ilk M -18 20 3/4" BOP / Diverter Stack up 21 114" 2M Hydril Annular 4.22' 1 1 HUB CLAMP 20 3/4" 3 M Hydril DBL Gate Pipe Rams d 71' 20 3/4" 3M Blind Rams HUB CLAMP LcZCI , e Mud Cross HCR 2.00' I HUB CLAMP 20 3/4" 3M Single Gate Pipe Rams 2.71' HUB CLAMP 8" Ansi 600 Diverter Valves }'� 0 20 3/4 3M 2 NT Connec r XO l Diverter �k � S poo l 3.00' no _ 20 3/4 3M NT2 Connector 20 3/4" 3M Riser • 20 3/4" 3M Riser VETCO 20 3/4" NT2 Connector VETCO NT2 HEAD 6" ANSI 600 RTJ • ■ Steelhead M -18 BOP test variance Page 1 of 2 Aubert, Winton G (DOA) ` 0 1 1 — 16. From: Aubert, Winton G (DOA) Sent Wednesday, June 10, 2009 1:22 PM To: 'Ross, David A. [Petro Technical Resources of AKI' Cc: Regg, James B (DOA); DOA AA�Op6 GCC Prudhoe Bay Subject: Trading Bay Unit M-18 (PTD 182) AO' ... . ?, j 1 .. ...J I �t p�._v� 33 tact I i t" _ z .1,esc .oe ..J v iv 0 2_..J ,. ' ;:e I_..i s .... 12-403 J1n _ '.';'._j t. , e .. The T3L 'i- 3 e _ J .1. .� _ r r. '.-,r BORE n a} an i pe zi , e . • es oo 1 • : J t•tv. :i! have J r.f'''s "JJ � : "�.; i `�I,t y- Thank yon,, Winton Aubert AOGCC 793-1231 From: Ross, David A. [Petro Technical Resources of AK] [mailto:nossda @chevron.com] Sent: Wednesday, June 10, 2009 12:13 PM To: Aubert, Winton G (DOA) Cc: Moore, Roger; Vaussine, Ray J. (rajv) (RayVaussim); Nienhaus, Doug R Subject Steelhead M -18 BOP test variance Winton, As discussed on the phone we are planning to re -start operations on the Steelhead after a six month delay waiting on a new work boat. M has been in an operational shut down status since January with a 3 1/2" kill string hung off. The well has not yet been perforated and thus we are seeking a variance which would allow us to perform an initial shell test on the BOP stack prior to pulling the kin string. After pulling the kill string a full function BOP test would be performed prior to running in the hole with the welbore cleaning tools. By performing a shell test instead of a full function test would erate having to test against a tubing hanger instead of a BOP test plug. Performing the full function BOP test after the kill string has been pulled would also reduce the operational logistics involved by eliminating the crossovers from 3 1/2" tubing back to 31/2" DP and 5" DP for the required pipe ram tests. Based on the fact the well is fined with kill weight fluid and has yet to be perforated, we do not feel there is an inherent risk with our proposed procedure. Please contact me at your earliest convenience if you require any additional information pertaining to this variance request. Regards, Steelhead M -18 BOP test varian Page 2 of 2 • David Ross '° Alaska Wellbore Maintenance Team Chevron North America Exploration & Production (MCA) Office: (907) 263 -7696 Cell: (907) 9034555 Fax: (866) 244-1439 Email: rossda@chevron.com 6/10/2009 0 46 el -AN Chevron BAKER li t. Chevron NV6MEs L Cook Inlet, Alaska (Offshore) Slot: slot #B2 -2 NTEQ lit. Field: McArthur River Field Well: M -18 Facility: STEELHEAD Platform Wellbore: M -18 ^ . s . •.. a „ .,.M. �w M RKKB —_... _ _ •as x.o2Y,.M..w SMt PM .=on.4twun. Usr..r C.oreinans are in r..r,.Mrzn..ero SM Created by unu■L on 10/27/2008 Scat. 11.M•700 R Easting (ft) 0 350 700 1050 1400 1750 2 100 2450 2 800 3150 3500 3850 31� 7700 7700 99°° 0 4 9 00° 4300 Gner 7350 7350 A 00° 4p0 7000 A �0 ° 4100 7000 I I 4 00 0 A2° 30 6650 6650 30 00 X 00 A 6300 6300 3 64,E 5950 350 5950 34 00 5600 3 . 3 00 5600 320 5250 3 70 0 5250 Z G.2^ 300 0 m Y m• L 49 29, 4900 c t o Z 28p0 375 Radius circle around 95/8 Shoe 4550 2,000 )? 4550 m 5i 2 00 625'4 C° /4 9 m ^, 4200 a a M o y 4200 ,, vv -_0 25p, Q m r 151 0, 240 I c D 3850 - w > N °w o° ° o o 4 G -18DPN 3850 w w m o m 0 � o e ° ° o p w N ,, -. o o J° 5 ° o ° 0 3 ° e v v o . 7, m Ea 0 0 ° o ___.,.......0001•7'T. � ,. a ,t, mu 'Si °' $ '/6i 3500 3500 _ _ a • o 0 3900 _ N _ g� 1 ,0 0 N l.;/ - o CC 4 , 76 0 0 °1` 68 OJ T e { g e 3 c0. 3 ; °° o n 20 4 6� 3 00 ej 3 4 ) 3150 Li 3 60 0 4600 3 C.00 .. $ 0 q3 2 ° . ° o 4/pp ° o 0 40° 4 • of Perf set 2 s•,, 0 2800 m l7 , M ° ° D q 4 0 0 d : 4600 1,00 4700 4 3 0 0° ' o , f q . o v s 2 , _ p0 3,.,00 .° °4`so v F v' ro o° 2450 4f�' 4g 4800 000 37 7j h �ei ° v r y7 4700 c; %0 900 3B 0 0 0 ® 0j O 7 48 00 0 00 2100 2100 / %r V. 4 504 . 3 04 0 00 ` rri 0 6 ..`. -. 4 •4 ^4 1060 1400 . ' 0 175 2100 2450 2800 3150 3500 3850 Scale i inc.•YMO^ Easting (ft) • • Chevron Timothy C Brandenburg Union OiI Company of California 140 Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 IMO Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt @chevron.com Feb 18, 2009 R FEB 1 9 2009 Commi Alaska Oil & Gas Cons. Commission Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue Anchorage Anchorage, Alaska 99501 Re: Trading Bay Unit M -18, PTD 208 -162 Dear Commissioner, On January 26, 2009, Union Oil Company of California received Sundry Approval 309 -024 to suspend the drilling and completion operations of the above referenced well. Attached you will find the drilling data required by 20 AAC 25.072 for the above referenced well. The open hole log data has been previously submitted. Please contact Jim Rose at 907 - 263 -7637 if you have any questions. Sincerely, Timothy C. - •enburg Drilling Manager TCB: sk Attachments: Form 10-404 Well Sketch Formation Tops Daily Rig Activity Summary Plot of Mud Density -vs- Depth Welibore Survey Cc: File Union OiI Company of California / A Chevron Company Page 1 of 1 a REGtIV w ., `� ALAS AND GAS CONSERVATION COMMIIO 1 9 2009 ago -G'9 ry , '� REPORT OF SUNDRY WELL OPEli IICASr,�as Cons. Comm pnchor 1. Operations Abandon [_1 Repair Well [J Plug Perforations Li StimulateL Other U Data Submittal Performed: Alter Casing p Pull Tubing Perforate New Pool ❑ Waiver Time Extension❑ Change Approved Program ❑ Operat. Shutdown 0 - Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Co of California 4. Well Class Before ork 5. Permit to Drill Number: Name: Development [+l Exploratory❑ 208 -162 3. Address: 3800 Centerpoint Dr, Anchorage, AK 99503 Stratigraphic, - Service❑ 6. API Number: 50- 7333 - 20583 -00 - 7. KB Elevation (ft): 9. Well Name and Number: 160' AMSL Trading Bay Unit, M -18 - 8. Property Designation: 10. Field /Pool(s): , ADL -17594 rADL 18730 r McArthur River Field, Grayling Gas Sands 11. Present Well Condition Summary: Total Depth measured 9930 - feet Plugs (measured) 7100 true vertical 4311 - feet Junk (measured) NA Effective Depth measured 8375 feet true vertical 3610 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 401 28 -32 480 480 Surface 1362 13 3/8 1441 1382 5020 2270 Intermediate 6041 9 5/8 6120 2593 6870 4760 Production Liner 3830 7 8375 3610 7240 5410 Perforation depth: Measured depth: 7102 -7104 True Vertical depth: 3034 -3035 Tubing: (size, grade, and measured depth) 3 1/2, 9.2 PPF, L -80, H563, Kill String @ 3157' MD Packers and SSSV (type and measured depth) NA 12. Stimulation or cement squeeze summary: 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: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Previously Submitted Exploratory❑ Development 0 , Service ❑ Daily Report of Well Operations Attached 16. Well Status after work: Oil❑ Gas 0' 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: 309 -024 Contact Jim Rose, 907 - 263 -7637 Printed Name Timothy Brandenburg Title Drilling Manager Signature ..A M._ — -- Phone 907 - 276 -7600 Date 2/16/2009 Form 10 -404 Revised 04,�100t#.. i r Submit Original Only i Chevron • •eelhead Platform %. Well M -18 As- Suspended 1/25/09 —1%0 CASING AND TUBING DETAIL RKB to TBG Head = 78'.75 SIZE WT GRADE CONN MIN TOP TOP BTM BTM ID in MD rkb TVD rkb MD rkb TVD rkb Ce ment to ML 28" Structural 27 Surface Surface 480' 480' 4-- @ a ss' 13 -3/8" 68 L -80 BTC 12.415 Surface Surface 1441' 1382' 9 -5/8" 47 L -80 BTC -M 8.681 Surface Surface 6120' 2593' 28" Conductor 7" 26 L -80 DWCSR 6.276 4545' 1975' 8375' 3 @4ss Kill p String 13 3/8 Stage Collar 3 -1/2" 9.2 L -80 HSO3 Surface Surface 3157 1924 @ 469 Tbg Logging Detail Hole LWD /MWD Wire Line Mud Logging Notes Section 17 %" GR/Res Gas Detection, Consulting Geologist I Mud Logging �' 13 3/8 in 17'''A" Hole 12 ' /4" GR/Res/ Dens- Gas Detection, Consulting Geologist 9 5/8 Hydraulic Stage Neut Mud Logging Collar @ 2552 8 IA" GR/Res/ Dens- Gas Detection, Consulting Geologist Id Neut Mud Logging Perforation Detail MD Zone Density (SPF) Notes 7102 -7104 A5 6SPF Perfs for cementation of 7" liner 1 7" Liner Top @ 4545' Miscellaneous Equipment Informtion Item Depth OD ID Notes I. i 95/8" Casing in 12'/" Hole cn4T Raw @7100 Cementing Information SQZ peels @ 7102 -7104, 6SPF Description Volume Density Yield Notes (bbls) (ppg) (ft3 /sx) 7" shoe @ 8375 13 3/8 Stage 1 234 13.0 1.46 LiteCrete 13 3/8 Stage 2 276 13.0 1.46 Lite Crete. Stage Collar at 469' Some cement to surface 12 bbls before landing plug. 9 5/8 Stage 1 131 13.0 1.48 Lite Crete. Planned TOC is 4404' 9 5/8 stage 2 145 13.0 1.48 Lite Crete. Planned TOC @ T178' /: :Hole @9330 385' ML 7" Liner 65 13.0 1.48 Pumped 65 bbls 13.0 ppg Lite Perforated and cemented Crete through perfs. from 7102' Maintained good returns through most of the job. Lost approximately 6 bbls cement near the end of displacement MAX HOLE ANGLE = 89.3° @ 3533' MD Well Detail DRAWN BY: JAR Trading Bay Unit M -18 Formation Tops Chevron API No: 50- 733 - 20583 -00 %O. APD: 208 -162 %. Well Surface ft MDbrf ft TVDbrf ft TVDss Well Surface ft MDbrf ft TVDbrf ft TVDss M -18 28 in Shoe 487.00 487 -327 M -18 SZ19CB 5492.05 2310 -2150 M -18 SZ6CT 1203.52 1177 -1017 M -18 SZ2OST 5531.02 2328 -2167 M -18 SZ7CT 1261.33 1229 -1069 M -18 SZ20CT 5566.72 2344 -2184 M -18 SZ8ST 1283.55 1249 -1088 M -18 SZ20CB 5580.00 2350 -2190 M -18 SZ8CT 1337.56 1296 -1135 M -18 SZ21ST 5593.81 2356 -2196 M -18 SZ8CB 1348.87 1305 -1145 M -18 SZ21SB 5675.82 2393 -2233 M -18 13.375 in Shoe 1442.37 1383 -1223 M -18 SZ21 CT 5726.53 2416 -2256 • M -18 17.5 in TD 1448.60 1389 -1228 M -18 SZ21 CB 5762.53 2432 -2272 M -18 SZ1OCT 1489.98 1421 -1261 M -18 SZ22ST 5789.35 2444 -2284 M -18 SZ10CB 1499.92 1429 -1269 M -18 SZ22SB 5901.46 2495 -2335 M -18 SZ11 BST 1571.90 1485 -1325 M -18 SZ22CT 5903.45 2496 -2336 M -18 SZ11 CT 1712.11 1587 -1427 M -18 SZ22CB 5940.42 2512 -2352 M -18 SZ11 CB 1734.29 1603 -1442 M -18 SZ23ST 5945.80 2515 -2355 M -18 SZ12ST 1747.92 1612 -1451 M -18 SZ23SB 5960.16 2521 -2361 M -18 SZ12SB 1799.15 1645 -1485 M -18 SZ23CT 5969.60 2526 -2365 M -18 SZ12CT 1832.72 1665 -1505 M -18 SZ23CB 5978.63 2530 -2370 M -18 SZ12CB 1861.40 1682 -1522 M -18 SZ23ASB 6043.53 2559 -2399 M -18 SZ13ST 1881.70 1694 -1534 M -18 SZ23BST 6070.26 2571 -2411 M -18 SZ13CT 1970.80 1742 -1582 M -18 SZ23BSB 6116.54 2592 -2432 M -18 SZ13CB 1977.57 1746 -1585 M -18 9.625 in Shoe 6118.92 2593 -2433 M -18 SZ14ST 1999.73 1757 -1597 M -18 12.25 in TD 6129.48 2598 -2438 M -18 SZ14CT 2089.57 1799 -1639 M -18 ACT 6202.45 2631 -2471 M -18 SZ14CB 2103.73 1804 -1644 M -18 ACB 6238.44 2647 -2487 • M -18 SZ15ST 2179.88 1833 -1673 M -18 Al CT 6320.22 2684 -2524 M -18 SZ15CT 2267.04 1860 -1700 M -18 Al CB 6326.58 2687 -2527 M -18 SZ15CB 2273.09 1862 -1702 M -18 A2ST 6344.65 2695 -2535 M -18 SZ16ST 2293.49 1867 -1706 M -18 A2ST 6345.47 2695 -2535 M -18 SZ16SB 4681.57 2001 -1841 M -18 A2SB 6581.65 2801 -2641 M -18 SZ16CT 4703.31 2006 -1846 M -18 A2CT 6584.04 2802 -2642 M -18 SZ16CB 4741.50 2015 -1855 M -18 A2CB 6628.62 2822 -2662 M -18 SZ17ST 4911.22 2064 -1903 M -18 A2AST 6651.19 2833 -2672 M -18 SZ17CT 5021.64 2103 -1942 M -18 A2ACT 6659.61 2836 -2676 M -18 SZ17CB 5034.86 2108 -1947 M -18 A3CT 6683.08 2847 -2687 M -18 SZ18CT 5264.92 2208 -2047 M -18 A3ST 6710.19 2859 -2699 M -18 SZ18CB 5295.21 2221 -2061 M -18 A3SB 6749.95 2877 -2717 M -18 SZ19ST 5343.04 2243 -2083 M -18 A4ST 6761.38 2882 -2722 M -18 SZ19CT 5476.09 2303 -2143 M -18 A4SB 6780.66 2891 -2731 Page 1 of 2 ` Trading Bay Unit M -18 Formation Tops Chevron API No: 50- 733 - 20583 -00 %./ APD: 208 -162 %10 Well Surface ft MDbrf ft TVDbrf ft TVDss Well Surface ft MDbrf ft TVDbrf ft TVDss M -18 A4CT 6863.70 2928 -2768 M -18 B3CB 8320.29 3587 -3427 M -18 A5ST 6892.32 2941 -2781 M -18 B5ST 8384.17 3616 -3455 M -18 A5BST 6949.73 2967 -2807 M -18 B5SB 8450.13 3645 -3485 M -18 A5CST 7027.42 3002 -2842 M -18 B4CT 8466.68 3653 -3493 M -18 A5CT 7129.18 3048 -2888 M -18 B4CB 8495.68 3666 -3506 M -18 A5CB 7160.32 3063 -2902 M -18 B6ST 8546.18 3689 -3528 M -18 A6ST 7357.56 3152 -2992 M -18 B6AST 8644.55 3733 -3573 • M -18 A6SB 7415.17 3178 -3018 M -18 B6SB 8711.74 3763 -3603 M -18 A6SB 7415.24 3178 -3018 M -18 B5CT 8724.98 3769 -3609 M -18 BCT 7470.39 3203 -3043 M -18 B5CB 8753.76 3782 -3622 M -18 BCT 7479.64 3207 -3047 M -18 CCT 8945.11 3868 -3708 M -18 BCB 7536.33 3233 -3073 M -18 CCB 8981.60 3885 -3724 M -18 B1ST 7565.44 3246 -3086 M -18 C1 ST 8996.02 3891 -3731 M -18 B1ST 7566.76 3247 -3087 M -18 C1SB 9139.86 3956 -3796 M -18 B1SB 7613.96 3268 -3108 M -18 C2ST 9194.50 3980 -3820 M -18 B1SB 7663.44 3291 -3130 M -18 C2SB 9204.72 3985 -3825 M -18 B2ST 7667.04 3292 -3132 M -18 C1CT 9331.18 4042 -3882 M -18 B2ST 7669.50 3293 -3133 M -18 C1CB 9338.46 4045 -3885 M -18 B2SB 7758.35 3334 -3173 M -18 C2CT 9347.98 4050 -3889 M -18 B2SB 7759.66 3334 -3174 M -18 C2CB 9354.06 4052 -3892 M -18 B1CT 7768.64 3338 -3178 M -18 C3ST 9375.96 4062 -3902 M -18 B1CT 7769.10 3339 -3178 M -18 C3SB 9487.13 4112 -3952 M -18 B1 CB 7791.83 3349 -3189 M -18 C4ST 9562.58 4146 -3986 • M -18 B1 CB 7793.18 3349 -3189 M -18 C4SB 9642.57 4182 -4022 M -18 B3ST 7946.83 3419 -3259 M -18 C3CT 9659.28 4190 -4029 M -18 B3SB 7968.47 3429 -3268 M -18 C3CB 9676.72 4198 -4037 M -18 B3ST 7987.01 3437 -3277 M -18 C5ST 9710.58 4213 -4053 M -18 B4ST 8044.78 3463 -3303 M -18 C5SB 9747.90 4230 -4069 M -18 B4ST 8045.53 3463 -3303 M -18 C6ST 9753.92 4232 -4072 M -18 B4SB 8119.32 3496 -3336 M -18 C6SB 9792.43 4250 -4089 M -18 B4SB 8119.81 3497 -3336 M -18 DCT 9819.40 4262 -4101 M -18 B2CT 8224.39 3544 -3384 M -18 DCB 9860.31 4280 -4120 M -18 B2CB 8257.74 3559 -3399 M -18 DIST 9875.92 4287 -4127 M -18 B3CT 8263.75 3562 -3401 M -18 8 -1/2 in TD 9930.00 4311 -4151 Page 2 of 2 ` ` Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -18 TRADING BAY UNIT M -18 ADL017594 5073320583 LK7620 160.00 185.00 Primary Job Type Job Category Objective Actual Start Date Actual End Date Drill and Complete Drill and 12/4/2008 Complete Primary Wellbore Affected Wellbore UWI Well Permit Number M -18 5073320583 -00 2081620 Dal d + =xtt = 12/412008 06:00 -12/5/2008 00:00 Operations Summary Skidding rig from M -32RD. Rigging up. 12/5/2008 00 :00 -12/6/2008.00:00 Operations Summary Rigging up. 12/612008.0:00 1217/200800 :00 Operations Summary Rigging up. 121712008 00 :00 - 12/812008 00:00 `. " , Operations Summary Begin NU of 20 -3/4" BOPE. '12/8/2008 00:00 /9/2008 00:00 Operations Summary Rigging up 20 -3/4" BOPE. 12(912000;00:00 - 12/10/2008 00:00 Operations Summary Rigging up 20 -3/4" BOPE. 12/10/2008 00:00 - 12/1112008 00:00 „- Operations Summary Rigging up 12/11/2008 Operations Summary Rigging up 1 12I4088 (00100 = 12/13/201 8 Operations Summary Continue to rig up. Perform Diverter test. 42113/2008 00 :00 - 12/1 4 /2008 00:00 Operations Summary Continue rigging up. 1211412008 00 :00 - 12/16/2008 Operations Summary Continue to rig up. PU BHA. Tag ML at 442'. 12/ 15/2008 00 :00 12/16/200000:00 . - Operations Summary Drill directionally 17 -1/2" hole to 1180' MD. 12/18/2008 00:00i,44,24 00;00 Operations Summary Drill directionally 17 -1/2" hole to section TD @ 1450' MD. TOOH and LD BHA. 0l 00 = 12/18/2008 :00 ti. Operations Summary Wash out conductor. Make wiper trip to 1450'MD OK. TOOH for 13 3/8" surface casing. ;12118/2008 00:00 - 12/1$002008 00:00 ` '''• n u` Operations Summary Continue to run 13 3/8 surface casing. Condition mud for cement while rigging up cementers. 12/19f20O8 O(tt00 :'/2'!2012008' 00:00 , `` ` ` F 1511 ;_;,. u�a.��� Operations Summary Finish conditioning mud for cement. Cement 13 3/8 casing to surface in 2 stages. Start wellhead installation. 42120/2008 00:00 - 12/21/2008 00:00 ; . , `; , Operations Summary Finish installing wellhead. Test BOPS , 17J21/204 00J -0.0: ;4212212008 00:0044.44.3, . k x Operations Summary Pickup Cleanout BHA, Run in hole to 409' MD, wash to 455' MD and tagged hard cement. Drill cement and DVT to 495' MD. Continued to drill cement stringers to 1337' MD. CBU. Performed Casing test to 1500 psi for 30 minutes. Wash and ream cement to 1356' MD. Drill cement from 1356' to 1397' MD. Change mud over to 9.1 ppg. POOH for Directional BHA. Start to pick up Directional BHA. 12122 120Oitib0k.42/2n00#0 a �' _... , }` Operations Summary Continue to pick up Directional BHA. Run in hole to 1394' MD. Wash from 1394' to 1450' MD. Drill from 1450' to 1470' MD. Perform FIT to 12.8 ppg equipvalent. Continue drilling from 1470' to 1532' MD. Lost pulse on MWD tool. POOH. Lay down BHA. Start to pick up new Directional BHA. Chevron • • 1%0 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -18 TRADING BAY UNIT M -18 ADL017594 5073320583 LK7620 160.00 185.00 12/2212008.00:00 - 12124/2008 00:00 Operations Summary Continue picking up directional BHA. Run in hole to 1532' MD. Drill from 1532' to 1820' MD. POOH to pick up motor for correction run. Start to pick up Mud Motor BHA. 12/24/2008 00:00 - 12/25/2008, 00;00 Operations Summary Trip in hole with motor directional assy. Slide and rotary drill 1820 -2380. 12/25/2008- 00:00 - 12/26/2008 00 :00 x ' ' ' " Operations Summary Slide and rotary drill 2380 -2390. TOOH. Lay down motory assy and MU rotary steerable assy. TIH. Drill 2390 -2520 w/ rotary steerable. 1 2 6/2009°00:00 - 42/2712008`00:00 Operations Summary Drill with rotary steerable assy 2520 - 3938'. 12/27/2008 00:00 - 12128/2008'00:00 Operations Summary Drill with rotary steerable 3938 -5180. 12/28/2008 00:00 Operations Summary Drill with rotary steerable 5180 to section TD at 6126. CBU. Start to backream out of hole. 12129/2008. :00 - 12/30/2008,00:00 Operations Summary Back ream out of hole. MAD pass 2372 -1799. Finish backreaming out of hole. LD BHA. Wash out wellhead and prep to test land hanger. 12/30/2008 00:00 - 12/31/2008 00:0 Operations Summary Wash out wellhead. RU to run casing. Run 9 5/8, 47 ppf, L -80, BTC -M to 1508. 12/31/2008 100:00`4441 009'0 0t .T'. Operations Summary Finish running 9 5/8, 47 ppf, L -80, BTC -M to 6028' Prep to land casing hanger. t`700Oi10mt009 00;00 P ' " ry Y Operations Summary Land 9 5/8 casign hanger. Cement 9 5/8 casing in 2 stages. Wash out stack and install pack off bushing in wellhead. X2/2009 00:001/3/200 Operations Summary Finish testing voids in wellhead. Test BOP's 250/2000/3000. Test witness waived b Jeff Jones of AOGCC. 1/3/200900 :00 - 1/4/2008 00:00 - Operations Summary Make up rotary steerable BHA and TIH. Drill out stage tool. TIH. Test 9 5/8 casing to 3000 psi ok. 4144008 00 :0,0 1/5/2009 00:00 _ m. Operations Summary Drill out 9 5/8 casing. Perfrom FIT test at 6146 to 12.8 EMW. Drill ahead with rotary steerable to 7138 collecting 1 pressure sample. 1/5/2009 00:00 - 1/6/2000 00:00, �,� 4;1'1, ..: mi=xr Operations Summary Drill 7138 -8164 with rotary steerable. TOOH to repair IBOP and install TQ reduction tools. 1/6/2009 00:00.1 . � 00 O , t,.,, " .... Operations Summary TOOH back reaming as necessary. Repair IBOP while installing torque reduction tools on DP. Lay down TesTrak tool from BHA. 7%7/2009 00:00- '1/8/200900 :00 ; x ; Operations Summary TIH. Drill 8164 -8231. Partial lost returns at 8190. Pick up and spot 3 lost circulation pills., Losses slowed to 12 -2- BPH. Drill 8231 -8520 back reaming and circulating sweeps as necessary to clean hole. 4 1/8/2000"OO 00,- :1/9/2009 00:00 Operations Summary Drill with rotary steerable 8520 -9712. 4/9 009 00:00 - 1/10/2009 00 :00 .. ,� �s �rzz�v.. Operations Summary Drill 9712 to TD @ 9930. Circulate and condition hole for liner. Start back reaming out of hole. 10/2009:.00:00 - 1/11/2009 (10 0 <::. / Operations Summary Finish back reaming out of hole. Spotted LCM pill at 6120 on way out. LD BHA. 1/11/2009 00:00` '712/2009 00 :00 a' . - , 59 Operations Summary RU to run liner. TIH with 7 ", 26 ppf, L -80 Liner. ; /12/2009 00:00 Operations Summary Run 7 ", 26 ppf, L -80 liner to 8276. Liner started taking weight and packing off at 8276. Work pipe and circulate. • • "' Chevron • 1110 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -18 TRADING BAY UNIT M - ADL017594 5073320583 LK7620 160.00 185.00 f/4312009'00:00 00 :00 Operations Summary Work tight hole with 7" liner 8223 -8303. Could not work deeper. TOOH w/ DP. Notify AOGCC of upcoming BOP test - waived by Jim Regg. LD liner hanger. Continue to TOOH and lay down liner. 1/14/2009 00:00 - 1/15/009=00:00 Operations Summary Finish laying down 7" liner. Start testing BOP's 250psi low/ 3,000psi high. '17 h5/2009 00 :00 -1/16/2090t091.00- .;. �. , . Operations Summary Finish testing BOP's. TIH to 1400' and start to repair top drive. 1"140/2009`00:00 - 1117/2009:.000 Operations Summary Finish top drive repairs and test. TIH to 8990 washing and reaming tight spots as necessary. 1j11/2O09 .0000'k.1118/2009 00:00 Operations Summary Wash and ream 8952 -9836. Pump several high vis sweeps and TOOH. Work several tight spots without circulating on trip out. N µ_ X6/2009 00:06. 1/19/2009 00:61 Operations Summary Finish TOOH with clean out assy. Run 7" liner. MU liner hanger. TIH to 6190. Circ and condition mud. 4/19 /2009 00 :00 -1/20/2009 00 :00 Operations Summary TIH with 7" liner 6019 to 8420 working through tight spots. Liner running tool released while rotating at 8375.. TOOH with running tool. Prep to install 3 1/2" rams in BOP. 1/20/2009 00 :00 - 1/21/2009 00 :00 Operations Summary Finish testing BOP's. MU 7" EZSV c/w perf gun on 3 1/2 DP. TIH picking up 3 1/2 DP and then 5" DP out of derrick. 4/21/2009 00 :00 - 1/22/2009 00:00 Operations Summary TIH with EZSV and perf gun. Set EZSV .) 7100. Perforate 7" liner and circulate freel . Pum • 70 bbls 13.0 • • • LiteCrete. Place a • • roximatel 65 • • cem -n • - hin• .i• - wi • •od returns. Returnsdimini h -• -tend •f'•• r- u in•' - I. • • -•• •.'u • •• - u - • . '•• • • Z -n• circulate clean. TOOH. 1/22/2009 00: :00.1/23/200900:00 Operations Summary TIH with polish mill. Polish tie back receptacle. TOOH. TIH with ZXP liner top packer and set. TOOH removing DP torque tools. 1/2312009 00 :00 112412019 00:00 -- Operations Summary TOOH with ZXP packer setting tool. Test casing to 3000 psi ok. TIH and tag EZSV at 7100. Start cleaning pits and displacing wellbore to FIW. 1/2 f4 /10:00£ - 1/2151 09 00:00 Operations Summary Continue to clean pits and displace wellbore to FIW. 1 120:60, 97.9:0J2009 00:00 Operations Summary POOH standing back 5" DP. LD 3 1/2 DP. TIH with 3 1/2 tubing kill string to 3157'. Land tubing hanger and test voids ok. 4 /26/2009200:A F /2 /20/k 00. 't,. o- ; , . . ., - Operations Summary ND BOP's. Land dry hole tree and test voids ok. Prep to warm stack rig ` %009 000{x 1128/2009k 00:04.. Operations Summary Continue to warm stack rig. 1/28/2109 oo f 0« -Ii 4'12009` Operations Summary Continue deactivation and warm stacking rig. :1129/2009 00:00 - 1/30/2009 00:00 .. ,..'• ' -'. Operations Summary Continue deactivation and warm stack the rig. 1/30/2009 "00.1/31/200900:00 Operations Summary Continue deactivation and warm stack rig. 1`/211200 811:00 211/2009 00 :00 ' * s. Operations Summary Continue deactiviation and warm stack rig 1264 x00p t}]r' 1 ..','00: n ,* x _ -. " ...' . ,. .Hti;a° ., Operations Summary Finish deactivation and warm stacking rig. Final report. • Trading Bay Unit M -18 Mud Weight -vs- Depth APD 208 -162 Mud Weight (ppg) 8 8.2 8.4 8.6 8.8 9 9.2 9.4 9.6 9.8 10 0 - t Measured Depth True Vertical Depth 2000 4000 a 6000 -- 0 Partial Lost Returns @ 8190' 8000 - MD (just above the B2 coal) 7 10000 12000 t- . Actual Well • ath Geo • raphic Re • ort Report Generated 14- Jan -09 at 07:45:51 Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Operator Chevron North Reference - True Area Cook Inlet, Alaska (Offshore) Scale 0.999993 Field McArthur River Field Horizontal Reference Point Slot Facility STEELHEAD Platform Vertical Reference Point Actual Datum (RKB) Slot slot #132-2 ! MD Reference Point Actual Datum (RKB) Well M -18 Field Vertical Reference mean sea level Wellbore M -18 Actual Datum (RKB) to Facility Vertical Datum 160.25 ft Wellpath SDI Gyro <129 - 992' >SDI MWD <1067- 1450' >ATK- OnTrak MWD <1448- 9930'> Actual Datum (RKB) to mean sea level 160.25 ft Wellbore Last Revised 01/12/2009 Facility Vertical Datum to Mud Line (Facility) 0.00 ft Sidetrack from (none) Section Origin X E 0.00 ft User Jonethoh Section Origin Y N 0.00 ft Calculation method Minimum curvature I Section Azimuth 20.77° MM Local North Local East Grid East Grid North Latitude Longitude [1t] [ft] [USft] [USft] Slot Location - 1040.02 606.93 214222.01 2499459.54 60 °49'54.561 "N 151 °36'05.775 "W Facility Reference Pt 213640.71 2500514.08 60 °50'04.803 "N 151 °36'18.018 "W FI ^'d Reference Pt 213640.71 2500514.08 60 °50'04.803 "N 151 °3618.018 "W I I 1 TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments [ft] [°] [°] [ft] [ft] [ft] [ft] [sry ft] [sry ft] [ °I100ft] (°] [° /100ft] [ °I100ft] [ft] 0.00 0.00 133.59 0.00 - 160.25 0.00 0.00 214222.01 2499459.53 60 °49'54.561 "N 151 ° 36'05.775 "W 0.00 133.59 0.00 0.00 0.00 129.00 0.09 133.59 129.00 -31.25 -0.07 0.07 214222.09 2499459.46 60 °49'54.561 "N 151 ° 36'05.773 "W 0.07 91.72 0.07 0.00 -0.04 179.00 0.09 137.02 179.00 18.75 -0.13 0.13 214222.14 2499459.41 60 °49'54.560 "N 151 °36'05.772 0.01 - 104.99 0.00 6.86 -0.07 229.00 0.09 107.05 229.00 68.75 -0.17 0.19 214222.20 2499459.36 60 °49'54.560 "N 151 ° 36'05.771 0.09 77.27 0.00 -59.94 -0.09 279.00 0.18 155.13 279.00 118.75 -0.25 0.26 214222.27 2499459.28 60 °49'54.559 "N 151 ° 36'05.7' 0.27 -92.55 0.18 96.16 -0.14 329.00 0.18 150.03 329.00 168.75 -0.39 0.34 214222.34 2499459.14 60 °49'54.558 "N 151 ° 36'05.768 "W 0.03 97.38 0.00 -10.20 -0.24 379.00 0.18 164.79 379.00 218.75 -0.53 0.40 214222.40 2499458.99 60 °49'54.556 "N 151 °36'05.767"W 0.09 108.15 0.00 29.52 -0.36 429.00 0.18 201.09 429.00 268.75 -0.68 0.39 214222.39 2499458.84 60 °49'54.555 "N 151 °36'05.767"0. 0.22 -13.60 0.00 72.60 -0.50 479.00 0.44 193.01 479.00 318.75 -0.94 0.32 214222.31 2499458.59 60°49'54.552 "N 151 °36'05.768' 0.53 - 148.00 0.52 -16.16 -0.77 527.00 0.88 60.38 527.00 366.75 -0.94 0.60 214222.59 2499458.58 60 °49'54.552 "N 151 °36'05.763"0. 2.55 -1.75 0.92 - 276.31 -0.67 571.00 3.61 59.06 570.96 410.71 -0.06 2.08 214224.09 2499459.42 60 °49'54.561 "N 151 °3695.73310. 6.21 -1.81 6.20 -3.00 0.68 630.00 7.65 58.10 629.66 469.41 2.97 7.01 214229.09 2499462.34 60°49'54.591"N 151°36'05.633"W 6.85 22.48 6.85 -1.63 5.26 671.00 9.41 62.49 670.21 509.96 5.96 12.30 214234.45 2499465.20 60 °49'54.620 "N 151°36'05.527'M 4.57 10.28 4.29 10.71 9.94 720.00 11.09 64.07 718.42 558.17 9.87 20.09 214242.34 2499468.92 60 °49'54.659 "N 151°36'05.370"A 3.48 16.76 3.43 3.22 16.36 767.00 12.49 66.01 764.43 604.18 13.92 28.80 214251.14 2499472.74 60 °49'54.698 "N 151°36'05.194 mom -42.77 2.98 4.13 23.23 810.00 13.81 61.08 806.30 646.05 18.29 37.54 214259.99 2499476.90 60 °49'54.742 "N 151°36'05.018 ' -19.52 3.07 -11.47 30.41 855.00 15.40 58.97 849.85 689.60 23.97 47.36 214269.94 2499482.34 60 °4954.797 "N 151 °3604.81910.® -52.37 3.53 -4.69 39.21 901.00 16.89 52.73 894.04 733.79 31.16 57.91 214280.67 2499489.28 60 °49'54.868 "N 151 °36'04.607 4.97 -46.65 3.24 -13.57 49.68 942.00 18.48 47.64 933.10 772.85 39.15 67.46 214290.40 2499497.03 60 °49'54.947 "N 151°3604.414"W 5.41 -29.20 3.88 -12.41 60.53 992.00 19.71 45.62 980.35 820.10 50.39 79.34 214302.56 2499507.97 60 °49'55.058 "N 151 °36'04.174" 2.79 -81.29 2.46 -4.04 75.25 1067.00 20.76 33.74 1050.75 890.50 70.29 95.77 214319.47 2499527.47 60 °49'55.254 "N 151 °36'03.8431A 5.64 -87.60 1.40 -15.84 99.69 09.00 20.88 29.39 1090.01 929.76 83.01 103.57 214327.58 2499539.99 60 °49'55.379 "N 151 °36'03.685 3.69 -31.96 0.29 -10.36 114.35 :3.00 _ 22.88 26.23 1140.12 979.87 100.81 112.94 214337.38 2499557.56 60 °49'55.554 "N 151 °36'03.497 4.30 -18.98 3.70 -5.85 134.31 08.00 24.91 24.58 1181.26 1021.01 117.28 120.75 214345.59 2499573.83 60 °49'55.716 "N 151 °36'03.33' 4.75 -2.07 4.51 -3.67 152.48 1258.00 27.05 24.41 1226.20 1065.95 137.21 129.83 214355.15 2499593.53 60 °49'55.913 "N 151 °36'03.156" 4.28 -13.98 4.28 -0.34 174.34 1303.00 29.19 23.32 1265.89 1105.64 156.61 138.40 214364.19 2499612.71 60 °49'56.104 "N 151 °36'02.983 "W 4.89 -9.58 4.76 -2.42 195.51 1353.00 31.55 22.56 1309.03 1148.78 179.89 148.25 214374.61 2499635.75 60 °49'56.333 "N 151 °36'02.78410. 4.78 18.91 4.72 -1.52 220.77 1385.00 33.37 23.69 1336.03 1175.78 195.68 155.00 214381.74 2499651.37 60 °49'56.488 "N 151 °36'02.648 "1/v 5.99 -3.83 5.69 3.53 237.93 1448.00 35.18 23.48 1388.08 1227.83 228.19 169.19 214396.72 2499683.53 60 °49'56.809 "N 151 °36'02.362 "W 2.88 5.57 2.87 -0.33 273.37' 1543.00 39.49 24.14 1463.60 1303.35 280.88 192.46 214421.27 2499735.63 60 °49'57.327 "N 151 °36'01.892 "W 4.56 -5.47 4.54 0.69 330.88 1638.00 43.37 23.60 1534.82 1374.57 338.36 217.88 214448.09 2499792.48 60 °49'57.893 "N 151 °36'01.37910. 4.10 1.23 4.08 -0.57 393.64 1732.00 47.12 23.71 1600.99 1440.74 399.49 244.66 214476.35 2499852.93 60 °49'58.495 "N 151 °36'00.839 "W 3.99 -2.13 3.99 0.12 460.30 1799.00 50.01 23.57 1645.32 1485.07 445.50 264.80 214497.61 2499898.44 60 °49'58.948"N 151 °36'00.433"0. 4.32 -3.86 4.31 -0.21 510.46 1891.00 57.12 23.00 1699.93 1539.68 513.45 294.02 214528.48 2499965.66 60 °49'59.618 "N 151 °35'89.84310. 7.74 -10.09 7.73 -0.62 584.36 1989.00 59.00 22.61 1751.77 1591.52 590.11 326.25 214562.57 2500041.51 60 °50'00.372 "N 151 °35'59.193"W 1.95 -27.37 1.92 -0.40 667.47 2083.00 64.28 19.60 1796.41 1636.16 667.28 355.97 214594.16 2500117.90 60 °5091.132 "N 151 ° 35'58.594"W 6.28 -8.08 5.62 -3.20 750.14 2178.00 70.96 18.60 1832.56 1672.31 750.23 384.68 214624.89 2500200.14 60 °50'01.949 "N 151 ° 35'58.014'1 /V 7.10 -4.48 7.03 -1.05 837.90 2272.00 73.16 18.42 1861.51 1701.26 835.03 413.07 214655.34 2500284.22 60 °50'02.784 "N 151 °3557.442 "W 2.35 7.60 2.34 -0.19 927.25 2396.00 78.76 19.18 1891.59 1731.34 948.86 451.83 214696.87 2500397.07 60 °50'03.905 "N 151 ° 35'56.660"W 4.56 4.70 4.52 0.61 1047.43 2491.00 83.85 19.60 1905.94 1745.69 1037.41 483.00 214730.19 2500484.84 60 °50'04.777 "N 151 °35'56.031"Wl 5.38 2.67 5.36 0.44 1141.28 2586.00 88.14 19.80 1912.58 1752.33 1126.61 514.94 214764.29 2500573.23 60 °50'05.655 "N 151°35'55.386"W 4.52 -76.80 4.52 0.21 1236.00 2681.00 88.53 18.14 1915.34 1755.09 1216.41 545.81 214797.34 2500662.25 60 °50'06.540 "N 151°35'54.763"W 1.79 -99.88 0.41 -1.75 1330.91 2774.00 88.20 16.24 1917.99 1757.74 1305.21 573.28 214826.98 2500750.35 60 °50'07.414 "N 151 °35'54.209"0. 2.07 -58.80 -0.35 -2.04 1423.69 2869.00 89.23 14.54 1920.12 1759.87 1396.78 598.48 214854.41 2500841.28 60 °50'08.316 "N 151 °35'53.701"W 2.09 -89.46 1.08 -1.79 1518.24 2964.00 89.24 13.50 1921.39 1761.14 1488.94 621.50 214879.66 2500932.85 60 °50'09.223 "N 151 °35'53.236"W 1.09 -90.00 0.01 -1.09 1612.57 3060.00 89.24 13.41 1922.66 1762.41 1582.30 643.83 214904.27 2501025.63 60 °50'10.143 "N 151 °35'52.785"0. 0.09 -93.90 0.00 -0.09 1707.78 Page 1 of 3 .- TVD from MD Inclination Azimuth TVD Rd Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments [ft] [1 [1 [ft] [ft] [ft] [ft] [sry ft] [sry ft] r /100ft] (1 [ °I100ft] [ °1100ft] [ft] .3154.00 89.21 1 12.97 1923.93 1763.68 1673.81 665.28 214927.94 2501116.59 60 °50'11.044 1 151 °3652.353 0.47 65.22 -0.03 -0.47 1800.95 3249.00 89.27 13.10 1925.19 1764.94 1766.35 686.70 214951.62 2501208.58 60 °50'11.955 "tt 151 °35'51.921 0.15 -95.53 0.06 0.14 1895.08 3344.00 89.24 12.79 1926.43 1766.18 1858.93 707.98 214975.15 2501300.61 60 "50'12.867 "l 151 °35'51.491' MEEMMEMMEMZEMMEM 1989.18 3438.00 89.27 12.95 1927.65 1767.40 1950.56 728.92 214998.32 2501391.70 60 °50'13.769'F 151 °35'51.068' .131.11=IMMEMMMM 2082.28 3533.00 89.30 12.59 1928.84 1768.59 2043.20 749.92 215021.57 2501483.81 60 °50'14.681" 151 °35'50.645 M - 106.70 MIEMMEMMICEI 3628.00 89.27 12.49 1930.02 1769.77 2135.93 770.54 215044.45 2501576.00 60 °50'15.594 "tt 151 °35'50.228' EffiammEM 1 1 =M11MME3 3722.00 88.94 12.31 1931.49 1771.24 2227.73 790.72 215066.87 2501667.28 60 °50'16.498" 151 °35'49.821 MIEM. 91.98 ®' ®' ' 3817.00 88.93 12.60 1933.26 1773.01 2320.47 811.21 215089.61 2501759.50 60 °50'17.412" 151 °3649.408 31.11.MIBEIMIIIMMIIMMEI 3910.00 88.32 13.41 1935.49 1775.24 2411.06 832.13 215112.74 2501849.55 60 °50'18.304" 151 °3648.985 1.09 113.42 -0.66 0.87 2549.45 4006.00 87.65 14.96 1938.86 1778.61 2504.07 855.64 215138.51 2501941.95 60 °50'19.220" 151 °3648.511 1.76 101.32 -0.70 1.61 2644.76 4100.00 87.61 15.16 1942.75 1782.50 2594.77 880.04 215165.12 2502032.03 60 °5020.113" 151 °3648.018 0.22 -90.00 -0.04 0.21 2738.21 4196.00 87.61 15.13 1946.75 1786.50 2687.35 905.10 215192.43 2502123.97 60 °50'21.024" 151°35'47.513 0.03 85.50 0.00 -0.03 2833.66 4291.00 87.67 15.89 1950.67 1790.42 2778.81 930.49 215220.04 2502214.78 60 °5021.925" 151 °3647.000" 0.80 155.84 0.06 0.80 2928.18 4385.00 85.47 16.88 1956.29 1796.04 2868.83 956.95 215248.69 2502304.13 60 °5022.811" 151 °35'46.466 2.57 172.24 -2.34 1.05 3021.73 4481.00 82.63 17.27 1966.24 1805.99 2960.09 984.98 215278.94 2502394.68 60 °5023.710" 151 °35'45.900' 2.99 165.08 -2.96 0.41 3117.00 4575.00 80.30 17.90 1980.19 1819.94 3048.70 1013.06 215309.18 2502482.57 60 °5024.583" 151 °35'45.334 2.57 162.71 -2.48 0.67 3209.81 4670.00 77.57 18.77 1998.42 1838.17 3137.19 1042.39 215340.65 2502570.32 60 °50'25.454" 151°3644.742 3.01 174.02 -2.87 0.92 3302.95 4764.00 75.08 19.04 2020.64 1860.39 3223.60 1071.98 215372.34 2502655.98 60 °5026.305" 151 °3644.145 2.66 168.70 -2.65 0.29 3394.23 4860.00 72.88 19.50 2047.14 1886.89 3310.69 1102.42 215404.91 2502742.30 60 °50'27.163" 151 °3643.530 2.34 170.41 -2.29 0.48 3486.46 4954.00 69.66 20.08 2077.32 1917.07 3394.45 1132.56 215437.07 2502825.30 60 °50'27.987" 151 °3642.922 3.47 - 179.20 -3.43 0.62 3575.46 0.00 66.37 20.03 2113.25 1953.00 3478.06 1163.08 215469.63 2502908.14 60 °50'28.811" 151 °3642.306 3.43 169.15 -3.43 -0.05 3664.46 .00 63.34 20.68 2153.19 1992.94 3557.83 1192.67 215501.15 2502987.16 60 °50'29.596" 151 °35'41.71' 3.28 111.89 -3.22 0.69 3749.54 9.00 63.19 21.10 2195.92 2035.67 3637.10 1222.92 215533.33 2503065.67 60 °5630.377" 151 °35'41.1' 0.43 89.46 -0.16 0.44 3834.38 5333.00 63.20 21.97 2238.31 2078.06 3715.14 1253.72 215566.02 2503142.93 60 °50'31.145" 151 °35'40.476 0.83 - 126.79 0.01 0.93 3918.28 5428.00 63.12 21.85 2281.21 2120.96 3793.78 1285.35 215599.56 2503220.78 60 °50'31.919" 151 °3639.838 0.14 81.37 -0.08 -0.13 4003.02 5521.00 63.19 22.36 2323.20 2162.95 3870.66 1316.57 215632.66 2503296.87 60 °50'32.677" 151 °35'39.208 0.50 92.34 0.08 0.55 4085.98 5617.00 63.16 23.26 2366.53 2206.28 3949.63 1349.78 215667.78 2503375.00 60 °50'33.454" 151 °3638.537 0.84 88.16 -0.03 0.94 4171.59 5712.00 63.19 24.20 2409.40 2249.15 4027.23 1383.90 215703.78 2503451.76 60 °50'34.218" 151 °3637.849 0.88 88.93 0.03 0.99 4256.26 5806.00 63.20 24.74 2451.79 2291.54 4103.60 1418.65 215740.39 2503527.25 60 °50'34.970" 151 °35'37.147' 0.51 100.69 0.01 0.57 4339.98 5902.00 63.12 25.22 2495.13 2334.88 4181.24 1454.83 215778.45 2503603.98 60 °50'35.735" 151 °3636.417 WZMIME11. -0.08 MEM.MEII 5995.00 63.15 25.33 2537.16 2376.91 4256.26 1490.25 215815.69 2503678.12 60 °50'36.474" 151 ° 35'35.702 MI. -90.02 6089.00 63.15 25.25 2579.61 2419.36 4332.09 1526.08 215853.36 2503753.05 60 °50'37.220" 151 ° 3634.979 0.08 MIMI 0.00 -0.09 MOM 6144.00 63.11 25.27 2604.47 24.44.22 4376.46 1547.01 215875.37 2503796.89_ 60 °50'37.657" 151 °35'34.556 0.08 ElelniMMIIMEr. 4640.63 6238.00 63.21 24.40 2646.91 2486.66 4452.58 1582.24 215912.44 2503872 13 MgMEMMEM:E...3111M:MMIMIEMMEMI 6334.00 63.30 24.05 2690.12 2529.87 4530.76 1617.41 215949.52 2503949.43 60 °50'39.176" 151°35'33.135 MIKOMMEI 0.09 6430.00 63.31 23.66 2733.24 2572.99 4609.20 1652.10 215986.11 2504026.99', 60 °50'39.949" 151 ° 3632.435 "1A 0.36 MZIKEIME.MXIMEMEM 6524.00 63.30 23.03 2775.47 2615.22 4686.30 1685.38 216021.26 2504103.26' 60 °50'40.708" 151 ° 3631.7631A 0.60 -91.90 MCMIMEEEMMEIMI 6618.00 63.28 22.29 2817.72 2657.47 4763.79 1717.73 216055.49 2504179.94 60 °50'41.471" 151 °35'31.110' 0.70 • • M '®' 6711.00 63.30 22.01 2859.52 2699.27 4840.74 1749.05 216088.68 2504256.09 60 °5642.229" 151 °35'30.478" V� 0.27 -90.06 =MEMMICENIIESEIE3 6808.00 63.30 21.75 2903.11 2742.86 4921.15 1781.35 216122.93 2504335.70 60 °5643.020" 151°3529.8261N 0.24 1.12M1 0.00 MUM.2M33 6903.00 63.03 21.60 2945.99 2785.74 4999.93 1812.65 216156.15 2504413.68 60 °50'43.796" 151°3629.1941A 0.32 IMIIMMEMMEMMIHNI 6998.00 63.10 21.84 2989.03 2828.78 5078.61 1844.00 216189.40 2504491.58 60 °50'44.571" 151 °3528.5611A 0.24 11 7092.00 63.05 21.56 3031.59 2871.34 5156.48 1874.99 216222.28 2504568.67 60 °50'45.338" 151 °3527.935" 0.27 MEEMIMIMMEM 5486.26 7186.00 63.04 21.78 3074.20 2913.95 5234.34 1905.93 216255.11 2504645.75 60 °50'46.104" 151 °3627.311' 0.21 88.29 -0.01 0.23 5570.04 7282.00 63.06 22.47 3117.71 2957.46 5313.62 1938.16 216289.27 2504724.22 60 °50'46.885" 151 °35'26.660' 0.64 - 110.54 0.02 0.72 5655.59 7376.00 63.01 22.32 3160.33 3000.08 5391.08 1970.08 216323.07 2504800.87 60 °50'47.648" 151 °3626.016' MM. -98.38 MIIMEMMEMMEI 9.00 62.98 22.09 3202.56 3042.31 5467.79 2001.39 216356.24 2504876.80 60 °50'48.403 "IKEENIEMI • • EIMIEEMI 5.00 63.08 21.67 3246.10 3085.85 5547.19 2033.27 216390.06 2504955.39 60 °50'49.185" 151 °3624.740' II.M. -97.06 MIEMMEMCIEI 59.00 63.03 21.21 3288.70 3128.45 5625.19 2063.90 216422.58 2505032.62 60 °50'49.953" 151 °35'24.121' MM. 80.91 11111.MIEMMEM 7754.00 63.04 21.28 3331.77 3171.52 5704.10 2094.59 216455.18 2505110.76 60 °50'50.730" 151 °3623.502' 0.07 74.72 0.01 0.07 6076.17 7851.00 63.20 21.93 3375.63 3215.38 5784.54 2126.44 216488.99 2505190.40 60 °50'51.522" 151 °3622.859 0.62 -63.58 0.16 0.67 6162.68 7944.00 63.28 21.75 3417.50 3257.25 5861.62 2157.33 216521.75 2505266.70 60 °50'52.281" 151 °3622.235' 1.12.MEEM 0.09 ®' t 8039.00 63.23 22.19 3460.26 3300.01 5940.30 2189.07 216555.40 2505344.58 60 °50'53.056 "MEMIMEME • • EKEIMMEED 8130.00 63.18 21.84 3501.28 3341.03 6015.61 2219.52 216587.68 2505419.12 60 °50'53.797" 151 °35'20.979 11132. 66.50 -0.05 ®1 8298.00 63.25 22.02 3576.99 3416.74 6154.73 2275.53 216647.07 2505556.83 60 °50'55.167" IEN=231.31[1:EMEEM 0.04 11.111M. 6561.68 8391.00 63.28 22.44 3618.82 3458.57 6231.61 2306.96 216680.36 2505632.93 60 °50'55.924" 151 °3619.214 MEM - 105.69 0.03 8486.00 63.22 22.20 3661.58 3501.33 6310.09 2339.17 216714.48 2505710.59 60 °50'56.697" 151 °35'18.563' WEIMMEREEM -0.06 IMICESMEMI 8581.00 63.24 22.66 3704.37 3544.12 6388.49 2371.54 216748.75 2505788.18 60 °50'57.469 "ECKEEMOZEI • • 6814.30 8675.00 63.28 22.86 3746.67 3586.42 6465.90 2404.01 216783.11 2505864.77 60 °50'58.231" IREIREEMIEM 90.83 MIZMMEN. 6898.19 8771.00 63.27 23.96 3789.84 3629.59 6544.59 2438.08 216819.08 2505942.60 60 °50'59.006" 151 °35'16. :• 1.02 96.18 -0.01 1.15 6983.85 8864.00 63.23 24.38 3831.70 3671.45 6620.35 2472.08 216854.92 2506017.52 60 °50'59.752" 151 °35'15.879 0.41 -92.84 -0.04 0.45 7066.75 8959.00 63.22 24.15 3874.50 3714.25 6697.67 2506.94 216891.66 2506093.96 60 °51'00.513" 151 °35'15.175' 0.22 83.16 -0.01 -0.24 7151.40 9053.00 63.27 24.61 3916.81 3756.56 6774.12 2541.59 216928.16 2506169.55 60 °51'01.266" 151 °3614.476 0.44 -84.01 0.05 0.49 7235.17 9148.00 63.31 24.19 3959.51 3799.26 6851.41 2576.64 216965.09 2506245.95 60 °51'02.027" 151 °3613.768 0.40 - 110.09 0.04 -0.44 7319.87 9244.00 63.18 23.79 4002.73 3842.48 6929.72 2611.50 217001.85 2506323.39 60 °51'02.798" 151°35'13.064 0.40 8.46 -0.14 -0.42 7405.45 9339.00 63.24 23.80 4045.55 3885.30 7007.32 2645.71 217037.94 2506400.13 60 °51'03.562" MBEIMMEE 0.06 MUM 0.06 MM. 9433.00 63.19 23.09 4087.91 3927.66 7084.30 2679.10 1 217073.20 2506476.27 60 °51'04.320" 151°3611.699 IIMEMMEEIMIIMMEMEran 9529.00 63.31 22.97 4131.12 3970.87 7163.20 2712.63 217108.65 2506554.33 60 °51'05.097" 151 °35'11.022" IMNIMME3Th °®MII3EEM 7659.62 9623.00 63.27 22.94 4173.37 4013.12 7240.52 2745.38 217143.28 2506630.82 60 °51'05.858" 151 °35'10.360 1 • 90.02 MaIMMIEEMINEEMEI 9717.00 63.27 23.01 4215.65 4055.40 7317.81 2778.15 217177.92 2506707.291 60 °51'06.619" 151 °35'09.698 =IIMMENER 0.00 MICEMIEEM 9812.00 63.25 22.83 4258.39 4098.14 7395.96 2811.19 217212.86 2506784.611 60 °51'07.389" 151 °3609.031 0.17 -97.42 -0.02 -0.19 7912.20 Page 2 of 3 TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rat( Vert Sect Comments [ft] [°] [°] [ft] [ft] [ft] [ft] [sry ft] (sry ft] (° /100ft] [1 [°/100ft] [0/100ft] [ft] 9898.00 63.22 22.57 4297.12 4136.87 7466.79 2840.83 217244.21 2506854.70 60 °51'08.086" 151 °35'08.433" 0.27 0.00 -0.03 -0.30 7988.94 9930.00 ®MEIMIIIIMCIMMIMMITIMIZEITI 2506880.80 60 °51'08.346" lialiMEN 0.00 0.00 0.00 0.00 8017.50 Pro ected Data - NO SURVEY • • Page 3 of 3 10.16A— , 1/2.1 woi • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISb ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 11 Repair Well 11 Plug Perforations T j Stirrulatell Other LI Data Submittal Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver El Time Extension0 Change Approved Program 0 Operat. Shutdown!!! Perforate 0 Re-enter Suspended Well 2, Operator Union Oil Co of California 4, Well Class Before Work: 5. Permit to Drill Number Name: Development 0 ExploratoryEl 208-162 Address: 3800 Centerpoint Dr, Anchorage, AK 99503 Stratigraphic El ServiceE 6. API Number: 50-7333-20583-00 7. KB Elevation (ft): 9, Well Name and Number: 160' AMSL Trading Bay Unit, M-18 8. Property Designation: 10. Field/Pool(s): ADL-17594, ADL 18730 McArthur River Field, Grayling Gas Sands 11. Present Well Condition Summary: Total Depth measured 9930 feet Plugs (measured) 7100 true vertical 4311 feet Junk (measured) NA Effective Depth measured 8375 feet true vertical 3610 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 401 28-32 480 480 Surface 1362 133/8 1441 1382 5020 2270 Intermediate 6041 9 5/8 6120 2593 6870 4760 Production Liner 3830 7 8375 3610 7240 5410 Perforation depth: Measured depth: 7102-7104 True Vertical depth: 3034-3035 Tubing: (size, grade, and measured depth) 3 1/2, 9.2 PPF, L-80, H563, Kill String rit? 3157' MD Packers and SSSV (type and measured depth) NA 12. Stimulation or cement squeeze summary: 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: Subsequent to operation: 14. Attachments 15. Well Class after work: Copies of Logs and Surveys Run Previously Submitted Exploratory0 Development b Service 0 Daily Report of Well Operations Attached 16. Well Status after work: OHO Gas el WAG L GINJ D WINJ LI WOSPL 111 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 309-024 Contact Jim Rose, 907-263-7637 Printed Name Timothy Brandenburg Title Drilling Manager • Signature Phone 907-276-7600 Date 2/16/2009 )8 p, ieb ; - Form 10-404 Revised 04/2006 ' Submit Original Only , . Chevron 0 •mead Platform Well M-18 As-Suspended 1/25/09 CASING AND TUBING DETAIL RKI3 to TI3G Head = 78%75 SIZE WT GRADE f'ONN NIIN t TOP TOP BTNI BTM m in MD rkb 'IND rkb NID rkb TVD rkb cement to mi., 1 ' ' ,_____ 0385' ., 28" Conductor 26 L-80 DWCSR CSR 1975' 8375' 3610' - iii ' ilik A mr Kill Tbg Strillg ° i 1 {13 485 l 313 Slap Collar 2 713 :1' 318, 68 S 12.415 Surface 5cce Surface 1 e4 41 80' , 1 4 3 8 8 0 2 ' 4 , 9-5/8" 47 L-80 BTC-M , 8.681 Surface Surface 6120' 2593' 3-1/2" 9.2 L-80 HSO3 Logging De Surface Surface 3157 1924 11 1 /2" GR/Res Notes Section Gas Detection, Consulting Geologist Mud Logging 133/8" in 17 55" Holt 12 1/4" GR/Res/ Dens- Gas Detection, Consulting Geologist Neut Mud Logging 9 5/3 Hydraulic Slaw -, Collar 552 8 'A" GR/Res/ Dens- Gas Detection, Consulting Geologist , A ,... C4 2 'I 1 ar Neut Mud Logging Perforation Detail MD Zone Density (SPE) , Notes 7102-7104 A5 6SPF Perfs for cementmiottof 7" liner 0 o r L.65445'6, 4545' Miscellaneous Equipment Informtion, Item Depth OD ID Notes 4. 9 5/8" Casing in 12 Sa" Huta . — SQZ 6SPF ----- ' 44 r shot P6 6155 / 1 _ 13 3/8 Stage 1 023b4 13,0 1.46 h) Cemen . Description Volume Density Vicki Notes LiteCrete I 13 3/8 Stage 2 276 13.0 1,46 Lite Crete. Stage Collar at 469' Some cement to surface 12 bbls before landing plug. 9 5/8 Stage 1 131 13.0 1.48 Lite Crete. Planned TOC is U 4404' 95/8 stage 2 145 13.0 148 Lite Crete, Planned TOC @ ms , Aniaottvor 385' ML 7" Liner 65 13.0 1.48 Pumped 65 bbls 13.0 ppg Lite Perforated and cemented Crete through perfs. from 7102' Maintained good returns through most of the job. Lost approximately 6 bbls cement near the end of displacement MAX HOLE ANGLE =,-- 89.3 @ 3533' MD Well Detail DRAWN BY: JAR Trading Bay Unit M -18 Formation Tops Chevron API No: 50- 733 - 20583 -00 APD: 208 -162 Wen Surface ft MDbrf ft TVDbrf ft TVDss Well Surface ft 'MDbrf ft TVDbrf ft TVDes M -18 28 in Shoe 487.00 487 -327 M -18 SZ19C6 5492.05 2310 -2150 M -18 SZ6CT 1203.52 1177 -1017 M -18 SZ2OST 5531.02 2328 -2167 M -18 SZ7CT 1261.33 1229 -1069 M-18 SZ2OCT 5566.72 2344 -2184 M -18 SZ8ST 1283.55 1249 -1088 M -18 SZ2003 5580.00 2350 -2190 M -18 SZ8CT 1337.56 1296 -1135 M -18 SZ21 ST 5593.81 2356 -2196 M -18 SZ8CB 1348.87 1305 -1145 M -18 SZ21 SB 5675.82 2393 -2233 M -18 13,375 in Shoe 1442.37 1383 -1223 M -18 SZ21CT 5726.53 2416 -2256 • M -18 17,5 in TD 1448.60 1389 -1228 M -18 SZ21 CB 5762.53 2432 -2272 M -18 SZ10CT 1489:98 1421 -1261 M -18 SZ22ST 5789.35 2444 -2284 M -18 SZ1OCB 1499,92' 1429 -1269 M -18 SZ22SB 5901.46 2495 -2335 M-18 SZI I BST 1571.90 1485 -1325 M -18 SZ22CT 5903.45 2496 -2336 M -18 SZ11CT 1712.11 1587 -1427 M -18 SZ22CB 5940.42 2512 -2352 M -18 SZ11 C8 1734.29 1603 -1442 M -18 SZ23ST 5945.80 2515 -2355 M -18 SZI2ST 1747.92 1612 -1451 M -18 SZ23SB 5960.16 2521 -2361 M -18 SZ12SB 1799.15 1645 -1485 M -18 SZ23CT 5969.60 2526 -2365 M -18 SZ12CT 1832.72 1665 -1505 M -18 SZ23CB 5978.63 2530 -2370 M -18 SZ12CB 1861.40 1682 -1522 M -18 SZ23ASB 6043.53 2559 -2399 M -18 SZ13ST 1881.70 1694 -1534 M -18 SZ23BST 6070.26 2571 -2411 M -18 SZ13CT 1970.80 1742 -1582 M -18 SZ23BSB 6116,54 2592 -2432 M -18 SZI3CB 1977.57 1746 -1585 M -18 9.625 in Shoe 6118.92 2593 -2433 M -18 SZ14ST 1999.73 1757 -1597 M -18 12.25 in TD 6129.48 2598 -2438 M -18 SZ14CT 2089.57 1799 -1639 M -18 ACT 6202.45 2631 -2471 M -18 SZ14CB 2103.73 1804 -1644 M -18 ACB 6238.44 2647 -2487 io M -18 SZ15ST 2179.88 1833 -1673 M -18 Al CT 6320,22 2684 -2524 M -18 SZI5CT 2267.04 1860 -1700 M -18 A1CB 6326.58 2687 -2527 M -18 SZ15CB 2273.09 1862 -1702 M -18 A2ST 6344.65 2695 -2535 M -18 SZI6ST 2293.49 1867 -1706 M -18 A2ST 6345.47 2695 -2535 M -18 SZ16SB 4681,57 2001 -1841 M -18 A2SB 6581.65 2801 -2641 M -18 SZ16CT 4703.31 2006 -1846 M -18 A2CT 6584,04 2802 -2642 M -18 SZ16CB 4741.50 2015 -1855 M -18 A2CB 6628.62 2822 -2662 M -18 SZ17ST 4911.22 2064 -1903 M -18 A2AST 6651.19 2833 - 2672 M -18 SZ17CT 5021.64 2103 -1942 M -18 A2ACT 6659,61 2836 -2676 M -18 SZ17CB 5034.86 2108 - 1947 M -18 A3CT 6683.08 2847 -2687 M -18 SZ18CT 5264.92 2208 -2047 M -18 A3ST 6710.19 2859 -2699 M -18 SZ18CB 5295.21 2221 -2061 M -18 A3SB 6749.95 2877 -2717 M -18 SZI9ST 5343.04 2243 -2083 M -18 A4ST 6761.38 2882 -2722 M -18 SZ19CT 5476.09 2303 - 2143 M-18 A4SB 6780.66 2891 -2731 Page 1 of 2 Trading Bay Unit M-18 Formation Tops Chevron API No: 50-733-20583-00 APD: 208-162 Well Surface ft MDbrf ft TVDbrf ft 'Mee Well Surface ft MDbrf ft TVObrf ft TVDes M-18 A4CT 6863.70 2928 -2768 M-18 B3CB 8320.29 3587 -3427 M-18 A5ST 6892.32 2941 -2781 M-18 B5ST 8384.17 3616 -3455 M-18 A5BST 6949.73 2967 -2807 M-18 85SB 8450.13 3645 -3485 M-18 A5CST 7027.42 3002 -2842 M-18 B4CT 8466.68 3653 -3493 M-18 A5CT 7129.18 3048 -2888 M-18 B4CB 8495.68 3666 -3506 M-18 A5CB 7160.32 3063 -2902 M-18 B6ST 8546.18 3689 -3528 M-18 A6ST 7357.56 3152 -2992 M-18 B6AST 8644.55 3733 -3573 40 M-18 A6SB 7415.17 3178 -3018 M-18 B6SB 8711.74 3763 -3603 M-18 A6SB 7415.24 3178 -3018 M-18 B5CT 8724.98 3769 -3609 M-18 BCT 7470.39 3203 -3043 M-18 B5C8 8753.76 3782 -3622 M-18 BCT 7479.64 3207 -3047 M-18 CCT 8945.11 3868 -3708 M-18 BCB 7536.33 3233 -3073 M-18 CCB 8981.60 3885 -3724 M-18 B1ST 7565.44 3246 -3086 M-18 C1ST 8996.02 3891 -3731 M-18 B1ST 7566.76 3247 -3087 M-18 C1SB 9139.86 3956 -3796 M-18 B1SB 7613.96 3268 -3108 M-18 C2ST 9194.50 3980 -3820 M-18 B1SB 7663.44 3291 -3130 M-18 C2SB 9204.72 3985 -3825 M-18 B2ST 7667.04 3292 -3132 M-18 C1CT 9331.18 4042 -3882 M-18 B2ST 7669.50 3293 -3133 M-18 C1CB 9338.46 4045 -3885 M-18 B2SB 7758.35 3334 -3173 M-18 C2CT 9347.98 4050 -3889 M-18 82S8 7759.66 3334 -3174 M-18 C2CB 9354.06 4052 -3892 M-18 B1CT 7768.64 3338 -3178 M-18 C3ST 9375.96 4062 -3902 M-18 B1CT 7769.10 3339 -3178 M-18 C3SB 9487.13 4112 -3952 M-18 131C8 7791.83 3349 -3189 M-18 C4ST 9562.58 4146 -3986 0 M-18 B1CB 7793.18 3349 -3189 M-18 C4S8 9642,57 4182 -4022 M-18 B3ST 7946.83 3419 -3259 M-18 C3CT 9659.28 4190 -4029 M-18 B3SB 7968.47 3429 -3268 M-18 C3CB 9676.72 4198 -4037 M-18 B3ST 7987.01 3437 -3277 M-18 C5ST 9710.58 4213 -4053 M-18 84ST 8044.78 3463 -3303 M-18 C5SB 9747.90 4230 -4069 M-18 B4ST 8045.53 3463 -3303 M-18 C6ST 9753.92 4232 -4072 M-18 B4SB 8119.32 3496 -3336 M-18 C6SB 9792.43 4250 -4089 M-18 B4SB 8119.81 3497 -3336 M-18 DCT 9819.40 4262 -4101 M-18 B2CT 8224.39 3544 -3384 M-18 DCB 9860.31 4280 -4120 M-18 B2CB 8257.74 3559 -3399 M-18 D1ST 9875.92 4287 -4127 M-18 B3CT 8263.75 3562 -3401 M-18 8-1/2 in TD 9930.00 4311 -4151 Page 2 of 2 • • Trading Bay Unit M -18 Mud Weight -vs- Depth APD 208 -162 Mud Weight (ppg) 8 8.2 8.4 8.6 8.8 9 9.2 9A 9.6 9.8 10 0 —+— Measured Depth - —True Vertical Depth 2000 ""—�: 4000 4 1r-- 6000 �� . At Partial Lost Returns (a 8190 FF 8000 MD (just above the B2 coal) gimp 10000 12000 Actual Well • ath Ge©• ray • hic Re 0 ort Report Generated 14- Jan -09 at 02:45:51 Protection System _ s :. - ..1 a r . Operator Chevron North Reference Area ; Cook Inlet Alaska (Offshore) Scale 0. 999993 Field McArthur River Field Horizontal Reference Point Slot Facility STEELHEAD Platform Vertical Reference Point Actual Datum (RKB) Slot slot #B2 -2 MD Reference Point Actual Datum (RKB) Well M -18 Field Vertical Reference mean sea level ''. Welihore M -18 Actual Datum (RKB) to Facility Vertical Datum 160.25 ft Wellpath SDI Gyro <1294997 >SDI MWD< 1087- 14505ATK- OnTrek MWD <1448- 9930> Actual Datum (RKB) to mean sea level 160.2511 Wellbore Last Revised 01/12/2009 ! Facility Vertical Datum to Mud Line (Facility) 0.00 ft Sidetrack from (none) Section Origin X E 0.006 j User Jonethoh Section Origin Y N 0.00 ft , Calculation method Minimum curvature Section Azimuth 20.77 Local North Local East Grid East Grid North Latitude Longitude (ft] (ft] [US ft] (USft] Slot Location - 1040,02 ; 1 2499459.54 60'49'54.561 18 Facility Reference Pt MIIIIIIIIIIIIIIIIIIMIIIIIIIIIIIIIIIIIIIMIMIIIIINIIIIIIIIIIIIEEIMEBIIIIIIIIIII 2500514.08 60°5004,803 N 151'3818,011W Reference Pt 11.111.1111110111MBINIMMINNININIMIMINMEEZ3a0111110 2500514.08 60'50'04.801'N TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments ( (l 11 (ft] (if; (ft] (ft] law ft) (srrft] (' /100ft]r (°) I ( (ft) 0.00 0.00 133,59 __, 0.00_ _._ -160.25 _' 0.00 0.00 214222.01 2499459,53 60°4054561"N 151`36'05.775\11 0_00_ 133.59 0.00 __. 000 0LL00 • 129.07 0.09 133.58 129.00 -31.25 - 0.07 107 21422209 2499459.46 80°49'54.561 151'36057731 0.07 91..72 0.07 0.00 -0.04 179.00 _ 0.09 137.02 179,00 18.75 -0.13 0.13 214222.14 2499459.41 80 49'54.560°N 151 0.01 -104.99 0.00 686 -107 _ 229.00 0.09 107.05 229.00 68.75 -0,17 0.19 214222.20 2499459.36 60 °49`54.560 "N 151 0.09 77 27 0.00 . :5994 -0.09 279.00 118 155.13 279.00 118.75 -0125 0.26: 21422227 2499459.28 60 °49'54.5599 N 151 °36 W 0.27 9255 0.18 9616 -0.14 329.00 018 150.03 329,00 16875 -0.39 __ 0.34 214222,34 2499459.14 60'4154.558"N 151 °360578$° 0.03 97,38 0.00 -10.20 -0.24 37900 . _. 018 184.79 379.00 21875 - 053.: 0,40 2142222,40 2499458.99 60'4954.556'N 151 0.09 108.15 0.00 29.52 =0.36 429.00 0.18 201.09 42900 26875 -0.68 Q 3�9 214222 39 249945484 60•49'54.555N 151'2695.76M 022 -13.60 0.00 72.60 .0,50 _47 0.44 193.01 - 479.00 - 318.75 -094 Q 32 214222 31 2499458 59 ' 60 49 54 552 N 151'3695,768"" - - 0 - 148.06 0.52 -16.16 -3.77 527.0X! 0.88 6_0.38 527.00 368 75 -0394 0.60 214222.59 „ 2499458.58 60'49`54.552`N 151 °3605.783"" 2.55 -1.75 0.92 _ -_ -276.31 -__ 0 .6 7 .__.__. 571.00 3.61 5996 570.96 41071 -0.06 2.08 214224.09 2499459.42 60' 49'54.561 'N 151 ° 30'05.733 N 6.21 -1.81 6.20 -3.00 0.68 630.00 7.65 58.10 629.66 469.41 2.97 ...... 7.01 _214229.09 2499462.34 60°41591 54:_ N 151_3605.633"W _ .. 6 85 22,48 6.85 .1.63 5 . 2 6 671.00 9.41 62.49 670.21 50996 5.96 12.34 214234.45 2499465.20 60 °49'54,620 151 ° 36'05.5271N 4.57 10.28' 4.29 10.71 99 720.00 11.09 84.07 718 42 558 17 _ 9,87 20.09 214242.34 2499468.92 80 49'54.859 "N 151 _ 3.48 16.78 . _3.43 3,22 _16.36 767.0 12.49_ 58.01 764.43 ,., 60418 04 18 .. 13.92 28.80 214251.14 2499472.74 60 49'54.698 "N 151'38`05.194'W 3.10 -42,77 2.98 4;43 23.23 810,00 13.81 81.08 806.30 646.05 18.29_ 37.54 21425999 2499476,90 60 °49'54.742 "N 151°36'05,018 -V, 4.03 -19.52 3.07 -11.47 30.41 855.00 15:40 5897 84985 68960 . -. 23 97 �� 47.36 21426994 24 99482 34- 80 151'3894.81(7W 313 -52.37 3,53 - 469 3/21 „_ 901.00 _ 18889 . 52 73 894.04 733.79 31.18 57.91 214280,87 249 9.28 80 "49'54:868 "N 151 ° 36'04.807"W 4.97 - 46-95 3.24 -13 .57 49=88 942.00 1848 47.64 933.10 LL „_, 772.85 39.15 67.48 214290.40 2499497.03 8049`64.947"N 151'3604.414Wi 5.41 - 29.20 3.88 -12.41 60.53 992.00 19.71 45;62 98935 82110 5039 7934 214302.58 249950797 80'4055.0547N 151 ° 3004.174' 2,79 46129 2:46 -404 75:25 1067.00 20.76 3374 1050,75 -- _890_50 ; _. 70.29 95.77 214319.47 249962747, 60'4155.254'N 151 5,64 - 87.60 140 -15.84 9969 109.00 , 20.88 29.39 109001 929.78 : 83,01 103.57 214327.58 2499539.99 80 °49'55 .379 "N 151'3603,6851 N 3:69 - 31.96^ 0,29 -10.36 114.35 13.00 22.88 26.23 1140.12 979.87 10181 112.94 214337.38 2499557:56 80'49'51554N 151°3693.4971N 4.30} -18,98, 3.70 -585 134:31 1 8.00 24.91 24.58 1181 26 1021_01 _ 1 17:28 120.7 } 214345,59 2499573.83 6049'55.716 "N 151'36'03,339'W 4.75 -2.07 4.51 3:67 152.48 1258 c0 _ m 279,5 24.41___ 1226.20 106595 13721 129.83 21435515 2499593.534 60°4955913"N 151'3603.156"1! , 4,28 -13:98 4.28 -0.34 17434 1303.00 2+J 19 23.32 1265.89 1105.64 156.61 138.40 214384.19 „, 2499612.71 60'49'54104"N 151 °3602.983'W .. 4,89 -9.58 4.78 -2.42 195.51 1353,00 31.55 22.56 1309.03 1148.78 179,89 148.25 214374.61 2499635.75 ' 60 °4056.333 "N 151°3602.7841W 4778 18.91 4.72 -1.52 220.77 138500 33,37 23.69 133103 1175.78 19168 155.00 214381,74 249965137 60' 4956.488 "N', 151 °3692.648" 5.99 -3,83 . 5.69 3.53 237.93 1448.00 35.18 23.48 138808 1227,83 228.19 169,19 _ 214396.72 X 2499683.53 60'4956.80914 151'3402.36M; 2 5,57 2.87 -0.33 273.37 0 1543 3949 24.14 1463.60. 1303.35 280.88 192.46 214421,27 .2499735,8 60 °49'57.327 "N 151 °3691.8921M 458 -5.47 4.54 0.69 330.88 1638.00 4337 2180 1534,82 1374.57 33836 217.88 214448.09 2499792.48 60'49'57.893"N 151.3601,379 Va 410 1.23 4.08 -0.57 393.64 1732.00 47.12 2371 4 1800.99 1440.74 ! 399.49 LL 244.66 214478.35 2499852.93 60'49'58.495 "N 151 °3600.839"04 3.99 2.13 3.99 112 460.30 17994 50.01 23.57 1645.32 1485.07 445.50 284.80 214447.61 _ 2499898.44 613'49'58.948 "N 151 °3690.433® 432 ^ f -188 4.31 -0,21 510.46 1891,00 57.12 151 °35'58914 23.00 169993 1539.68 513.45 294.02 214528, 2499965.66_ , 60°49 58.618 N 151'35'59,843 Vn 7,74 1009 7,73 _ -0 584.36 1989,00 59.00 22;61 1751.77 1591 52 - 590,11: 326.25 21458287 2500041,51 80'5('00.372 "N 151 °35'59.193"11 1.95 -27.37 1 92 -0.40 667.47 2083.00 083.00 64,28 - 19.60 1796 41 1638.16 667.26 35597 214594.16 2500117 60°50'01 .132 N 151 ° °35'58_594'W 6.28 -8.08 5.62 3.20 750.14 2 . 70.96 . 18.60 1832.58 1872.31 750.23 38 : 4.68 � 2500200,14 60 °50'01.949 "N "W 7.10 -4.48 703 -1.05 637.90, --- - --- 2272,00 73,18 18.42 1861 170! 26 835.03 413.07 214655.34 .2500284.22 80 ° 50'02.784 "N 151 °35'57.442"W 2.35 7.60 2.34 -0.19 92725 239600 78.78 19.18 1891.59 X 1731.34 948.86 451,83 214696.87 ; 2500397.07 60 "5803.905 "N 151'35'58:860"1 4.56 4. 4.52 0. 1047,43 ._, m,.._ .....__.__ - 2491.00 83.85 1990 1905.94 1745.69 1037.41 483.00 214730.19 2503484,84 60'50 '04.777 "N' 151'35'56.031°W 5.38 2,67 5.36 0.44 1141.28 2586.00 88.14 10.80 1912.58 1752.33 1126.61 . 51494_ 214764.29 2500673.23'6050'0S.65511 151 4,52 -78.80 4,52 021 1236.00_ , 268190 88„53 18.14 191534 . ___1755 09 1216. 5 4561 214797.54 250086225 - 80110'06.540 "N 151'35'54783" 1,79 -99 0 41 -1.75 133091 r 2774.00 88.20 16.24 1917.99 1757.741305.21 573 28 21482698 250075035 80'50'07.414 N 151'35'54.209"W 2.07 - 58.80 035 -2.04 1423.89 14.5 -1.79 1518.24 2889,00 89,23 14.54 1920.12 1759.87 1396 78 598 48 214854 d9 2500841 28 60 °50'0$.316 "N 151 "35'53,70!"V4 2.03? 89.48 1.08 2984.00 89.24 13.50 62 0 1921.39 1781,14 148894 1.50_, 2/487986 250093285 80'50'09.223 "N 151'35'53,238'W 1.00 -90.00 0.01 -199 1612.57 306030 89.24 13.41 1922.88 1762.41 1582.30 643.83 214904.27 250102563 60 °50'10.14311 151°35"52,785 Vv 0.09 - 93.90 0.00 -0.09 170 .78 Page 1 of 3 TVD from Inel]oatlon ' Azimuth TVD rid Rr:1 North East Grid Bast Grid North Latitude Longitude DLS TooItaLe Build Rani Turn Rat( Vert Sett Comments [n] ['1 CI (ft] [it] Ltl (ft1 (sr-4 tt) [sty ft[ 1'1100ft1 Pl (ilooft) (t100ft1 (ft) 3154.00 8911 12:97 192303 1763.68 167181 ! 66128 214927.94 2501116,59 603011,044 "N 151'3552.353% 0.47 6512 -103 0.47 1800,95 - 3249.00 89:27 13,10 1925 19 176494 176835 686.70 214951.62 2501208.58 80'50'11.955 "N 151'3551.920% 0,15 -95.53 0.06 0- 14 1895.08 - -- .,r . - �_ -... 3344,00 89.24 _ 12,79 _ _,_ 1926,43 1766.18 1858,93 707.98 214975.15 250130061 80'501188M 151`3551.491"41 0.33 0.03 -0:33 1989.18 3438.00 69.27 _ .12.95 1927.65 1767.40 195 728.9 214998 32 2501391.70 _ 60'5013.765'4 151'35'51.066% 0.17 -85.24 0.03 0.17 2082.28 3533.00 __ 89,30 12.59 1928.84 1768,59 2043.20 749.92 215021.57 2501483:81 603014,681"N 151'3550845% 038 -10670 0,03 -0.38 2178.35 3828.00 8121 _ _ _, 12.49 1930.02 1769.77 2135,93' 770:54 21504445 2501576.00' 60 °50'15,594"N 151•35'50.2281. 0.11 •151:39 - 0.03` 0.11 2270:36 3722.00,_ 88_94 12,31 1931.49 177124 2227.73 790.72 215066.87 25 0166728 - 60'5016.498"N 151'3549.8211. 0.40 91.98 -0.35 -0:19 2363.35' 3817.00 88.93 _ 12.60 1933,26' 177301 2320.47 811,21 215089.61 2501750.50 60 151`35'49.408% 0.31 127.00 -0.01 0.31 2457_33 3910.00 88,32 13.41 1935.49 177524: 2411.06 832.13 215112.74 2501849.55 60'50'18.304 "N 151'3548985.. 1.09 113.42 -0.66 0.87 2549,45 400690 67.65 14,96 1 938.86 1778.81 2504c07 _- _ 855.64 215138.51 2501941.95 60'50'19220"N 151'3548.511% 1 78 101.32 -0.70 1.61 2644.76 41 00.00 ; 87.61 _ 15.16 _ 1942.75 178250 2594 77 880.04 _ 215165.12 2502032.03 ' 803020.113"N 1513548,018 % 0.22 - 90:00 LL -0.04 0.21 2738.21 4196:00 , 87.61 15,13 19405" 1786.50 ..._._ 2687.35 905,10. 215192 43 2502123 97 60 5021,024'N 151`3547.513Vr 0.03. 85.50 100 -0,03 2833.66 4291,00 8707 15.89 1950.67 1790.42 2778.81 930,49 21522004 2502214,78 60 °50'21.925 "N 151'3547.0001 0.80 155,84 0 :06 _ 0.80 2928.18 4385_00 85,47 1188 1956.29 1796.04 2888.83 956,95 215248 69 2502304.13 60'50'22,811"N 15115'46,4661 2,57 - 172.24 -2.34 1,05 302173 4481.00 82.63 17.27 196124 1805,99 2960,09 98498 21527694 2502394.68 60'50'23.710"N 151'3545.900°% 2.99 165.08 .236 0.41 3117.00 4575,00 80.30 1790 1980.19 181194 3048,70 101106 215309.18 250248157 "8 2.57 162.71 -2.48_ 0.67 3209.81 i 4670.00 77.57 18.77 1998.42 1838.17 3137.19 1042.39 215340.65 2502570.32 603025.454"N 151'35'44.742% 3.01 174,02 287 0.92 3302.95 4764:00 755508 19:04 2029.84 1860.39 322380 1071.98 215372.34 2502855.98' 60'5028.305 "N 151'3544.1451N 2.66 168.70 -2.65 0,29 3394.23 4860.00 72.88 1950 204714 188689 3310.69 1102.42 215404.91 2502742.30 805027.163N 151'35'43.530% 2.34 170,41 -2.29 0.48 348648 7 � - 4954.00 69,86 20.08 2077.32 1917.0i ^ 3394.45 1132.56 215437 07 2502825 30 _ 60'5027 .907"4 151'35'42322% 3.47 179,20 -3,43 0.62 3575.48 0.00 " 66.37 20.03 2113,25 1953,00 3478.06 1163,08 215489.83 2502908,14 6L/60 151'3542.306% % 3.3 189.15 -3.43 0.05_ 3684.48 .00 63.34 20.68 2153.19 1992.94 3557,83 ' 119287_ 215501 15 2502987.16 603039.596"N 151'3541 7091 3.28 111 -3.22 0.89 39.00 ' 63.19 21,10 2195.92 2035.67 3837,10 1222.92 21553333 250306567 60 5030.377"N 151'3541098'1% 0.43 89.48 -0,16 0.44 3834.38 5333.00 ' 63.20 21.97 _` 212096 3793.78 1285.35 2 2238.31 2078,06 3715.14 ' 1253.72 R 215566.03 - 2503142.93 60'5031.145 "N 151'3640.476% 0:83 -126.79 0.01_ -� 0 0,93 391828 5428.00 - ' _ 63.12 _. 21.85 2281 21 78 60'51731.919"N V - - ,..._ 15599.56 ' 2508220:7151'3539.6381. 0.14 81.37 -0 .08 :13 4003A2 5521.00 63.19 22.36 2323 20 2162.95 387086 13 'S 18,57 215632.66 2503296.87 60032.677N 151'35'39.208"V 0.50 82.34 008 D 55 408598 5617.00 _ 83.16 23,26 2366.53 2206.28 3949.63 1349.78 215667,78 2503375.00 60°5033.454 "N 151'3538.537"% 0.84 8816 -0.03 0.94 , 4171.59 5712.00 63.19 2451.79 229154 9 24.20 ' 2409.40 2249.15 4027.23 1383.90 215703.78 2503451.78 8030'34.216W 151'35'37.849Yu 0.86 88,93 0.03 0.99 4256.26 580@,00 63,20 24,74 245 � 418:65 1 215740 39 2503527 25 4 60'5034.970"N 151'35'37 147'% 0 51 100,69 0.57 4 1036 0 . 0,01 0.57 4339,98 - 590200 63.12 25.22 ' 2495,13 2334.88 4181.24 1454,83 215778 45 2503803.98 80'5035.735"N 151'35'16.417"W 0.45 73.03 -008 0.50 4425,41 16 - 8100 --- 63.15 25.33 2537.16 2376.91 4256.26 1490.25 215815.89 2503878:12 80'5018.474"N 151 3535 7 021 0.11 -90:02 0.03 0.12 4506,11 608900 63.15 25,25 2579.61 2419.36 4332.09 1526.08 215853.36 , 2503753.05 605037 220N 151'35'34.9791;4 0.08 155.97 0.00 •0:09 4599:72 4:00 614 63.11 25.27 2604.47 2444,22 4376,46 1547.01 215875.37 250379689 60'5037.8574 151'35'34.556M 008 -82.86 -0.07 0,04 4840.63 6238,00 63.21 24.40 2646.91 2486.66 4452.58 1582.24 215912.44 2503872,13 80'5038.407"N 151'35'33.84611 0.83 -74.02 0,11 -0.93 4724.29 6334.00 63.30 24,05 2690.12 2529.87 4530,78 1617.41 - 215949 52 2503949 43 605039.176 "61 151'3533.135% 0,34 -8844 0.09 -0.38 480987 6430.00 63.31 23.66 2733/4 2572.99 4609.20 1652.10 215986.11 250402899' 6030'39,946'N 151'35'32,435' 0.36 -91 18 0,01 T -0.41 4895.51 6524,00 63.30 23.03 2775.47 2615 22 4888,30 1885.38 216021 26 2504103 26 60'50'40.708 "N 151'35'31 763"% 0.60 .91.90 -0.01 0,67 4979:41 6618 :00 63:28 22.29 2817.72 2657,47 4763.79 1717.73 21805549 2504179.94 60'50`41.471 N 151'35311901. 0,70 -85.49 -0.02 -0.79 5063.33 -. - gym.. 8711.00 63.30 22,01 2859.52 2699 27 4840,74 1749,05 216088.68 2504256.09 60'50'42.229' N 151'3530 478'% 027 -90,08 0.02 030 5146.38 6608.00 63.30 21.75 2903,11 2742.88 4921.15 1781.35 216122.93 2504335,70 603043.020'N 151'3529826'% 024 -153.67 0,00 -0.27 5233.02 6903,00 63,03 21 294599 2785 74 4999,93 , 181265 216156.15 2504413.66' 6030'43,7981T 0.32 71.94 -028 -0.16 5317.78 6998,00 6310 21.84 2989.03 2828.78 5078.61 1844.00 216189.40 2504491.58 603044.571"N 151'3628.5611N 0.24 -101.39 0.07 0.25 5402.46 7092.00 63.05 21.58 303159 2871,34 515548 1674:99 216222.28 2504568 67 803045.338"N N 151'3527.935"% 0.27 92 :87 -0;05 -0.30 5488.26 7186.00 63,04 21.78 , 3074.20 , 2913,96 5234.34 µ 190593 - 216255.11 250464535' 151'3527.3111A 0.21 88.29 -0.01 0.23 5570.04 7282.00 _6306 22,47 € 311771. `2957.46 5313.62 - _ 1338 16 216289 27 2504724.22 6050'48.885 "N 151•3528.880% 0:64 -110.54 0.02 4 0.72 5655.59 .01 7378,00 63 22.32 3160,33 3000.08 5391.08 97 10.08 216323.07 _ 2504800,87' 80'5047,648'N 151'3526,0161 0.15 -98.38_ -0.05 -0.16 5739.34 469.00 62.98 22,09 3202.58 , 3042.31 ' 5467.79 2001.39 216356,24 2504876.80 60'5(748.403"N 151'3525,3839. 0.22 -75.14 -0.03 -0.25 5822.17 .00 63.08 - 21.67 3246.10 3085.85 5547.19 2033.27 216390.06 2504955 39 60'5049.185 "N 151'35'24.740% 040 -97.06 010 -0.44 5907.72 , " x.00 63.03 21.21 3288.70 3128.45 562519 2063,96 216422,58 2505032.62 60.50.49. 151'3524.121% 0.44 80.91 -0.05 •0:49 5991.51 75400 6304 21.28 333177 _ 3171,52 5704, 10 2094.59 216455.18 2505110.76 _ 80 5050.730'N 151 °3523502% 007 74,72 0.01 0.07 8076,17_, - Fr , ^ 785100 83.20 21.93 3375.83 3215 38 576454 216.44 218488.99 2505190,40' 60'5051.5224 151'35'22,8591 0 62 83 58 0.16 0.67 8162.68 -`_ ___. 794400 63.28 21.75 3417.50. 3257 25 5881 62 2157.33 - 216521 75 2505266.70' 6030'52.281"N 151'35'22,235"% 0,19 97.35 0.09 -0,19 6245.71 803900 63.23 22.19 348028 3300.01 5940.30 2189,07 216555,40 2505344,51 6030'53.056"N951 0.42 99.17 -0;05 0.46 6330.53 813000 63.18 21,84 3501,28 3341.03 6015,61 2219,52 216587.68 2505419.12 6050'53:797'N 151•3520979'% 0.35 66.50 -0.05 -0.38 8411.74 829800 8325 2202 3576,99 3416 74 6154 73 ' 2275.53 216647,67 2505558.83 8050 55.167N 151 °3519.848"% 0 10 85.52 0;04 011 6561.88: 8391 .00 63.28 22.44 3618.82 3458.57 8231.81 2308.96 216680,36 2505632.93. 6050'55.92414 151'35'19.214% 040 105 69 0.03 045 664471 848800 63.22 22.20 3661.58' 350133 8310.09 2339.17 216714,48 2505710.59 60'50'56.697"4151 °3518,563"% 0.23 87.32 - 0.06 -125 8729,51 1661.00 63.24 22.66 3704,37 354412 r 6388.49 2371.54 216748,75 2505788,18 60'50'57.489 "N 151'35'170i 0.43 77.42 0.02 0.48 8814.30 6675.00 83.28 22.86 3746,67 3586,42 648590 2404,01 216783.11 2505864.77 605058.231 "N 1513517.254% 019 90.83 004 0.21 689819 . , 8771.00 6327 23.96 3789.84 3_629.59%` 8544.59 2438.08 216819.08 2505942.80 60.50'59,006 151'35'16:566% 1.02 96.18 _ -0.01 1,15 6983.85 888400 63;23 2438 3831,70' 3671,45 662035 247208 218854,92 2506017,52 60°5059.752 "N 151'3515,8791 0,41 9284 -0,04 0,45 706675 8959 00 _ 63.22 24.15 3874.50 3714.25 " 6617.67 2506,94 216891 66 2506093.96 603100.51314 151"3515195% 0.22 8316 -0.01 -0.24 7151.40 9053:00 63.27 24,61 3918,81 3756.56 ! 6774,12 2541.59 216928,16 2508169.55 6031' 01266 "N 151°3514.476% -8401 0.05 0.49 7235.17 9148,00 83;31 24,19: 3959.51 3799.26 6851:41 2578.64 216985.09 2506245.95 60'51'02,027 N_ 151 °3513768% 0.40 11009 0.04 -0.44 7319.87 9244.00 63.18 23:79 4002.73 ' 3842,48 8929.72 ' - 2811 50 211 "2506323.39 80°51'02.798 N 151`35'13.0641 0,40 8.46 -114 -0,42 7405,45 _ _ -__ 9339.00 63,24 23.80 4045.55 3885,30 7007.32! 2645.71 21703794 2506400:13 60'51'03062'N 151 °3512.37316 0.08__ -94.67 006 0.01 7490.14 _ ___,_ 9433.00 63.19 23.09 4087.91 3927.66 -0 13 7859 62 7084.30_ 2679,10 21707320 250647617' 80'51'04.320 N 151'35'11.699% 0.68 41,79 -0.05 -0,76 7573,96 u 66119 012 9529:00 6331 22.97 4131.12 3970.87 7183,20 2712:83 217108 85 2506554 33 80 51'05.097 "t� 151'35'11.0221 019 14 9623.00 63,27 22.94 4173.37 4013.12 7240 -52 2745.38 217143,28 2506630.82' 60'51'0_5.858 "N 151'3510.360% 0.05 9002( -0.04 -0.03 7743.53 9717.00 63.21 23,01 4215,65 4055_40 7317.81 2778.15 217177.92 2508707.29 60°51'06.619'N 151'35'09,698% 097 - 97:13 0.00 -- 0.07 9812.00 63,25 22.83 425639 4098.14 7395.96 2811.19 217212.86 , 2506784.81, 60'51'07,389'N 151'35'09.031'% 0.17 97.42 -102 -0.19 7912.20 Page 2of3 TVD from f1D # InCOnation Azimuth TVD Etd Ref North East Grid East Grid North LatltudC Longitude DLS Too;face Build Rate Turn Ratc Vert Sect Comments jft] [`] ['] [tt[ [ft] [ft] [ft] [env ft] [cry ft] f °f100ft] r [ °] ' [°Li00Rl [It100ft] [ft] 9898.00 63.22 22.57 4297.12 4136.87 ' 7468.79 ' 2840.83 217244 21 2506654 70 60'51'08.088"N 151'35'08.4331h t 0.27 0 00 -0.03 -0.30 7088.94 993000 63.22 22.57 4311.54 .415129 7493.17 2651_79 217255.82 2506880,80 60 °51'06.345 14 151 °3508.211 "W 0.00 0.04 0.00 000 8017.50 Projected Data- NO SURVEY • • Rage 3 of 3 • • Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email branderiburgttilchevron.corn Feb 18, 2009 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue Anchorage, Alaska 99501 Re: Trading Bay Unit M-18, PTO 208-162 Dear Commissioner, On January 26, 2009, Union Oil Company of California received Sundry Approval 309-024 to uspencl the drilling and completion operations of the above referenced well. Attached you will find the drilling data required by 20 MC 25.072 for the above referenced well. The open hole log data has been previously submitted. Please contact Jim Rose at 907-263-7637 if you have any questions. Sincerely, 7 Timothy C. "eriburg -- Drilling Manager TCB: sk Attachments: Form 10-404 Well Sketch Formation Tops Daily Rig Activity Summary Plot of Mud Density -vs- Depth Wellbore Survey Cc: File Union Oil Company of California / A Chevron Company Page 1 of I Z33, Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 4110. Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE February 15, 2009 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste #100 Anchorage, AK 99501 DATA TRANSMITTAL 2 < s z i s s } a : , ,r o m +. :: s � ' a '; , y a., - w. " o 2 o : i S t; '' ;4 t �� 4,a '* a 3, a 4 °'-_, 4n 'as.';a"ri N' ' „t� *' 'z�` I:44 7U% 4tz, , u i it AtiAt �5 - C - � WELL a=f � SCALE L+ Q iE RliN w tee GAMM RAY IMAGE MULTIPLE CGM, PROPAGATION RESISTIVITY PDF, LAS, TBU M -18 GAMMA RAY -- MD 5" 10Jan09 1420 -6120 2 -6 1 1 DLIS GAMM RAY IMAGE MULTIPLE CGM, PROPAGATION RESISTIVITY PDF, LAS, TBU M -18 GAMMA RAY -- TVD 5" 10Jan09 1350 -2625 2 -6 1 1 DLIS MULTIPLE PROPAGATION RESISTIVITY COMPENSATED NEUTRON POROSITY CGM, COMPENSATED DESITY PDF, LAS, TBU M -18 POROSITY GAMMA RAY 5" 10Jan09 480 -9912 1 -7 1 1 DLIS MULTIPLE PROPAGATION RESISTIVITY COMPENSATED NEUTRON POROSITY CGM, COMPENSATED DESITY PDF, LAS, TBU M -18 POROSITY GAMMA RAY -- TVD 5" 10Jan09 480 -9912 1 -7 1 1 DLIS MULTIPLE PROPAGATION RESISTIVITY COMPENSATED NEUTRON POROSITY CGM, COMPENSATED DESITY PDF, LAS, TBU M -18 POROSITY GAMMA RAY -- MD 5" I 10Jan09 480 -9912 1 -7 1 1 DLIS Please acknowledge receipt by signing and returning one copy of this tray s,F1'}ittal ar FAX_ 907 263 7828. Received By: j j Date: J / 1 • I SARAH PALIN, 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 Evan Harness Drilling Superintendent Union Oil Company of California 3800 Centerpoint Drive Anchorage, Alaska 99503 Re: McArthur River Field, Mid Kenai Gas Pool, Trading Bay Unit M -18 Sundry Number: 309 -024 Dear Mr. Harness : 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this `L' day of January, 2009 End. 0011-1(0P .61 i STATE OF ALASKA 9 CEIVED t i � ALASKA OIL AND GAS CONSERVATION COMMIS 3 ,in, Ck APPLICATION FOR SUNDRY APPRO 20 AAC 25.280 _Alaska Oil & (;as Cons. Commission 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown Perforate chorage Waiver ❑ Other I=1 Alter casing Repair well El Plug Perforations ❑ Stimulate E Time Extension ❑ Change approved program❑ Pull Tubing Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 . Exploratory ❑ 208 -162 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 3800 Centerpoint Dr, Anchorage AK 99503 50- 7333 - 20583 -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 -18 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): /W!d kGhiari- 645 "Pse ADL 17594, ADL 18730 160 AMSL' McArthur River Field, Graving- GesSands 41 y•c9 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 9930 4311 8375 3610 7100 NA Casing Length Size MD TVD Burst Collapse Structural Conductor 401 28 -32 480 480 Surface 1362 13 3/8 1441 1382 5020 2270 Intermediate 6041 9 5/8 6120 2593 6870 4760 Production Liner 3830 7 4545 1975 7240 5410 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7102 -7104 3034 -3035 3 1/2 DP S -135 -2768 Packers and SSSV Type: Packers and SSSV MD (ft): None NA 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 ' Service El 15. Estimated Date for 15- Apr -09 16. Well Status after proposed work: Commencing Operations: Oil ❑ Gas 0 • Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: 111 W WAG ❑ GINJ ❑ WINJ DSPL CI Commission Representative: ( =FC9E 0.1e /' 1`1 k ID. 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jim Rose, 907 - 263 -7637 Printed Name Evan Harness Title Drlg Supt Signature,, i Phone 907 - 276 -7600 Date 1/23/2008 ✓ 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30 q • C3o2- 4 / Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location \\ Clearance El v� k_ c ` QC ^ h`,. C`A� vc:� cc��tioh p� \tom T ko v SV q"`�. QQc _ 1Qf\-�. Subsequent Form Required: LA0L c1 c��is., s- p C...a- ,C0t g4) APPROVED BY , 7 V Approved by COMMISSIONER THE COMMISSION Date: I "' ))) .. L JAN272000 .�°m /.24,,c9 Form 10 -403 Revised 06/2006 i L ! . ` i '4 /\ Submit ,J.l I' tg, v ,/�'` /7.20,/,-9 • Chevron Timothy C Brandenburg Union Oil Company of California %10 Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 Tel 907 263 7657 Fax 907 263 78888 4 Email brandenburgt @chevron.com Jan 23, 2009 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue Anchorage, Alaska 99501 Re: Trading Bay Unit M -18, PTD 208 -162 Dear Commissioner, Union Oil Company of California requests sundry approval to suspend drilling and completion operations on the above referenced well. Safe and efficient operations are no longer possible due to the hazardous ice conditions in Cook Inlet and the loss of the MV Monarch support vessel. Union Oil Company plans to resume operations approximately April 15, 2009 pending progress on • other work and the location of a suitable support vessel. We will file the required well records within 30 days pursuant to 20 AAC 25.072. The proposed configuration of the wellbore can be seen on the attached wellbore sketch. The 9 5/8" casing x 7" liner was jug tested to 3000 psi for 30 min on 1/23/09. The well bore is planned to be displaced to seawater and a kill string run to approximately 2768' within the next 72 hrs. A tree will be installed and the wellbore will be made secure until operations resume. Attached please find a basic procedure, well sketch, and form 10-403 in duplicate. Please review and approve at your first convenience. If you have any questions, please contact Jim Rose at 907 -263- 7637. Sincerely, G� 9 �fVan? ! 1. rn Timothy C. Brandenburg Drilling Manager TCB: sk Attachment: Form 10 -403, Well sketch, Brief Procedure Cc: File Union Oil Company of California / A Chevron Company Page 1 of 1 Chevron 0 •eelhead Platform Well M -18 , -MO Proposed 1/20/09 —I-11W CASING AND TUBING DETAIL RKB to TBG Head = 78'.75 SIZE WT GRADE CONN MIN TOP TOP BTM BTM ID in MD rkb TVD rkb MD rkb TVD rkb Cement to Ml 28" Structural 27 Surface Surface 485' 485' .4-- @ 385' 13 -3/8" 68 L -80 BTC 12.415 Surface Surface 1441' 1382' 9 -5/8" 47 L -80 BTC -M 8.681 Surface Surface 6120' 2593' 28" Conductor 7" 26 L -80 DWCSR 6.276 4545' 1975' 8375' 3610' @ 485 I{ill -- D String 13 3/8 Stage Collar 3 -1/2" S -135 3 ' /z" IF Surface Surface 2768 1916 @ 469 DP Logging Detail Hole LWD /MWD Wire Line Mud Logging Notes Section 17' h" GR/Res Gas Detection, Consulting Geologist Mud Logging 13 3/8" in 17' /z" Hole 12'/4" GR/Res/ Dens- Gas Detection, Consulting Geologist Neut Mud Logging 9 5/8 Hydraulic Stage ' Collar @ 2552 8 '' /2" GR/Res/ Dens- Gas Detection, Consulting Geologist ® Neut Mud Logging Perforation Detail MD Zone Density (SPF) Notes 7102 - 7104 A5 6SPF Perfs for cementation of 7" liner a - 7" Liner Top @4545' Miscellaneous Equipment Informtion Item Depth OD ID Notes i 9 5/8' Casing in 12'/14" Hole CMTRtnr @71oo Cementing Information sQz pens @noz -71oa, 6SPF Description Volume Yield Notes 4 (bbls) (ppg) Density (ft3 /sx) 7" shoe @ 8375 13 3/8 Stage 1 234 13.0 1.46 LiteCrete 13 3/8 Stage 2 276 13.0 1.46 Lite Crete. Stage Collar at 469' Some cement to surface 12 bbls before landing plug. 9 5/8 Stage 1 131 13.0 1.48 Lite Crete. Planned TOC is ) 4404' 9 5/8 stage 2 145 13.0 1.48 Lite Crete. Planned TOC @ TD S' /,Hole @ 9330 385' ML 7" Liner 65 13.0 1.48 Pumped 65 bbls 13.0 ppg Lite Perforated and cemented Crete through perfs. from 7102' Maintained good returns through most of the job. Lost approximately 6 bbls cement near the end of displacement MAX HOLE ANGLE = 89.3° @ 3533' MD Well Detail DRAWN BY: JAR • • 'Chevron I Steelhead M -18 Suspension of Operations Procedure 1/23/09 1. Jug test the 9 5/8" casing and 7" liner to 3000 psi on chart for 30 min. 2. TIH OE to 7100' and displace wellbore to FIW until clean. 3. TOOH standing back 5" DP 4. MU tubing hanger and 3'h H563 x 3 % /z" IF XO. 5. Land hanger and hang off 2768' of 3'/2" DP for a kill string. 6. Test hanger void seals per Vetco standards. 7. Install BPV. 8. Break BOP stack and stump back 9. Install dry hole tree and test voids per Vetco standards JAR Steelhead M -18 Drilling Program Page 1 of 1 Suspension of operations, TB4-18, PTD 208 -162 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, January 23, 2009 4:13 PM To: 'Rose, Jim [Contractor]' Cc: Bonnett, Nigel (Nigel.Bonnett); Nienhaus, Doug R; Harness, Evan Subject: RE: Suspension of operations, TBU M -18, PTD 208 -162 Jim, et al, We have received the sundry notice; however it will not be possible to get it out today. I have apprised Commissioner Foerster of your request and she has given her oral approval. Call or message with any questions. Tom Maunder, PE AOGCC From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Friday, January 23, 2009 12:37 PM To: Maunder, Thomas E (DOA) Cc: Bonnett, Nigel (Nigel.Bonnett); Nienhaus, Doug R; Harness, Evan Subject: Suspension of operations, TBU M -18, PTD 208 -162 Tom, We are seeking sundry approval to suspend operations pending better ice conditions in the Inlet and better work boat support. I am delivering a 10 -403 sundry app today and would like approval if possible. We plan to continue operations through the weekend and may wrap up in 2 or 3 days. «TBU M -18 Suspension of Operations .pdf» Attached you will find a digital copy of the documents that will be delivered today. Please feel free to call with questions 263 -7637. Thanks, Jim 1/23/2009 Steelhead M -18, PTD 208 -16* • Page 1 of 4 Maunder, Thomas E (DOA) From: Bonnett, Nigel (Nigel. Bonnett) [Nigel.Bonnett@chevron.com] Sent: Thursday, January 22, 2009 9:34 AM 4 -°- To: Maunder, Thomas E (DOA) Cc: Rose, Jim [Contractor]; Brandenburg, Tim C; Harness, Evan; Orr, Gary A. Subject: RE: Steelhead M -18, PTD 208 -162 Tom, Mud weight of the water based system was a 9.3 ppg. Coals were already unstable and at an inclination of - 60 degrees, borehole collapse can be expected with the passage of time. Regards, Nigel From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, January 22, 2009 9:19 AM To: Bonnett, Nigel (Nigel.Bonnett) Cc: Rose, Jim [Contractor]; Brandenburg, Tim C; Harness, Evan; Orr, Gary A. Subject: RE: Steelhead M -18, PTD 208 -162 Thanks Nigel. Following up on my message of last night, is it expected that the lost hole section will collapse? What was the mud weight in use? Thanks in advance. Tom Maunder, PE AOGCC From: Bonnett, Nigel (Nigel.Bonnett) [mailto:Nigel.Bonnett@chevron.com] Sent: Thursday, January 22, 2009 9:08 AM To: Maunder, Thomas E (DOA) Cc: Rose, Jim [Contractor]; Brandenburg, Tim C; Harness, Evan; Orr, Gary A. Subject: RE: Steelhead M -18, PTD 208 -162 Morning Tom, The remedial cementation on the 7" liner appeared to go well - we estimate 59 bbls behind pipe - we believe we lost 6 bbls towards the end of the job. Job was planned on 30% OH excess and in fact we pumped a few barrels more (70 bbls pumped). The only cement we saw came from the residual cement purposely left in the stinger - no cement above the lengthy liner lap (top at 4550 ft MD • 9 -5/8" shoe at 6120 ft MD). This leads us to believe we have got a pretty reasonable job, no doubt aided by liner being centralised and we obtained an unhindered circulating rate of 5 BPM @ 870 psi after perforating liner below cement retainer set at 7100 ft MD. Forward path is polish the PBR - currently in hole doing this. Then separate trip to set the ZXP liner top packer. Then test cased wellbore against cement retainer to 3000 psi. Regards, Nigel From: Maunder, Thomas E (DOA) [mailto:tom.maunder @ alaska.gov] Sent: Wednesday, January 21, 2009 4:54 PM 1/26/2009 Steelhead M -18, PTD 208 -16• • Page 2 of 4 To: Bonnett, Nigel (Nigel.Bonnett) Subject: RE: Steelhead M -18, PTD 208 -162 Nigel, So this doesn't catch you and your colleagues unaware, we may be asking for some validation that reserves are not being risked by not doing any work below the 7" shoe. I have passed this note on to my geological and reservoir colleagues responsible for the Inlet. It is unfortunate that the liner got stuck high and Unocal /Chevron has made good faith attempts to get the pipe to the desired depth. However, the resource must be considered in the path forward. What is the present schedule on the well work? I likely won't be in the office much longer today, but will check email from home and you can also reach me on my cell at 529 -1645. Tom Maunder, PE AOGCC From: Bonnett, Nigel ( Nigel.Bonnett) [mailto:Nigel.Bonnett@chevron.com] Sent: Wednesday, January 21, 2009 4:38 PM To: Maunder, Thomas E (DOA); Rose, Jim [Contractor] Cc: Nienhaus, Doug R; Brandenburg, Tim C; Harness, Evan; Orr, Gary A. Subject: RE: Steelhead M -18, PTD 208 -162 Afternoon Tom, With reference to your question on drilled reservoir that we will not be capturing, in completing well M -18 after the liner running tool failure. The C3 appears to be the best pay left below the 7" shoe. The B5, B4, and B1 are also present below the 7" shoe, but not as promising. Unfortunately due to sticking problems we had to eliminate gathering reservoir pressures in the 8 -1/2" hole section, after almost getting stuck with the TesTrak on our first pressure point in the A2 sand. The A2 sand pressure was very close to the pressure data point that was recorded in Well M -17. Based on the poor mud log shows in the A2 sand and all the other sands below the 7" shoe with the exception of the C -3 sand, we are assuming these sands have seen significant depletion from other wells completed in these zones. There is the potential for crossflow and it was a point of consideration in our decision. However if crossflow were to occur it would be going into gas zones that are currently being produced in existing gas wells and the gas theoretically would be recovered. I hope the above addresses your queries. Regards, Nigel From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, January 21, 2009 8:14 AM To: Rose, Jim [Contractor] Cc: Bonnett, Nigel (Nigel.Bonnett); Nienhaus, Doug R; Brandenburg, Tim C; Harness, Evan Subject: RE: Steelhead M -18, PTD 208 -162 Jim, et al, Sorry I was not able to get back to you last evening. Prior to leaving the office I did apprise Commissioner Foerster of the situation and she gave her oral approval for you to proceed with the cementing operation. You indicate that the C3 sand is potential pay but now lies 1000' below the 7" shoe. Are there other potential pays in the interval below the 7" shoe? Is there any chance of cross flow between intervals? I look forward to your reply. Tom Maunder, PE AOGCC From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Tuesday, January 20, 2009 7:00 PM 1/26/2009 Steelhead M -18, PTD 208 -1620 • Page 3 of 4 To: Maunder, Thomas E (DOA) Cc: Bonnett, Nigel (Nigel.Bonnett); Nienhaus, Doug R; Brandenburg, Tim C; Harness, Evan Subject: Steelhead M -18, PTD 208 -162 Mr. Maunder, «M -18 AsBuilt.doc» «TBU- M18 » _ Surveys TD.xls» «Quick Plot for V8c 5.75 build.pdf Per our conversation earlier today, ram seeking approval to cement the production liner of the M -18 well 1555' off bottom. A brief well history follows: • The well was drilled and cased to 1441 with 13 3/8 surface casing. The casing was cemented successfully in 2 stages. • The well was then drilled to 89 deg and back to 63 deg where the 9 5/8 intermediate casing was cemented to 6120. The casing was cemented successfully in 2 stages. • Drilling of the 8 1/2 section was completed to 9930' MD @ 63 deg. Hole conditions were questionable at the completion of drilling operations. Losses were noted at 8190' The BHA was backreamed all the way back to the 9 5/8 shoe. • A 7" liner was run to the B2/B3 coal at 8303 but could not be worked deeper. • The liner was pulled and a clean out run made. Packing off of the drill string was evident but eventually cleaned up. • A 2nd attempt was made to run the liner with rotary capability. The liner was worked with difficulty past the B2/B3 coal and to 8420' but was packing off and could not be worked deeper. It was worked back to 8375 where the liner running tool failed. This left the liner top @ 4545 and the shoe at 8375. • Evaluation of the logs indicates substantial pay behind the 7" liner and 9 5/8 casing. The C3 sand, which was potential pay is left at 9400' (below the 7" shoe). • After many hours of evaluation, we conclude that the best option is to cement the liner in place and continue with completion operations. Hole conditions deteriorate below the B coal at 7500' and the shoe is likely packed off completely at this point. Therefore we would like to cement the liner from 7100' which gives us the best chance of covering pay and not packing off during cementation. The procedure forward would be as follows: • Run and set 7" retainer at 7100. This tool has a small perforating gun below it. Set retainer and fire gun. • Establish circulation past liner hanger. • Cement liner with 64 bbls slurry. (30% OH excess and 1375' of lap) • Circulate clean • Run polish mill and polish tie back sleeve. • Run and set ZXP liner top packer • Test casing and liner to 3000 psi. • Swap the wellbore to completion brine. • Proceed with GP completions Attached you will find a proposed wellbore sketch. Some of the completion details are not yet determined but the pertinent information for the issue at hand is noted on the drawing. Also attached is a copy of the unregistered well survey and planned trajectory. Please indicate you concurrence with the proposed plan by return email if you find it acceptable. If you have any questions, please call me at 306 -1945 Thanks, 1/26/2009 Chevron tteelhead Platform IN. Well M -18 —1%011 Proposed 1/20/09 CASING AND TUBING DETAIL RKB to TBG Head = to TBG SIZE WT GRADE CONN MIN TOP TOP BTM BTM -le d = nut 1 o like w nirrp ID in MD rkb TVD rkb MD rkb TAD rkb 1 Can pr to oc 1. e h: 28" Structural 27 Surface Surface 485' 485' e•It du.; re n - Cement to ML g g Jul I ul @ 385' 13 -3/8" 68 L -80 BTC 12.415 Surface Surface 1441' 1382' u er lur N, .Cat He 9 -5/8" 47 L -80 BTC -M 8.681 Surface Surface 6120' 2593' t 13oks , e'a that ' ° 7" 26 L -80 DWCSR 6.276 4545' 1975' 8375' 8383' 28 ;a pn vide ` cal. e @ 485 Conductor Tubing grit du' g re 3 -1/2" 9.2 L -80 Hydril 2.992 Surface Surface TBD u er lur N S78 . to T 13 3/8 Stage Collar 503 I,y d = nut s like ,Ittor @ 469 th. 1 Can pr a to . We .,...,. stn gent du g re i . 'lnents w e.r ,ur N r1 75 Logging Detail 1 Hole LWD/MWD Wire Line Mud Logging Notes Section 17 '2" GR/Res Gas Detection, Consulting Geologist . Mud Logging r 133/8" in 17'/" Hole 12 '/" GR/Res/ Dens- Gas Detection, Consulting Geologist 9 5/8 Hydraulic Stage Neut Mud Logging Collar @ 2552 8 '/2" GR/Res/ Dens- Gas Detection, Consulting Geologist Neut Mud Logging Perforation Detail MD Zone Density (SPE) Notes TBD _- T Liner Top d 4545' 0 GP #3@ Miscellaneous Equipment Informtion Item Depth OD ID Notes 9 5/8" Casing in 12 '/" 0 0 Hole 1 1 GP #2@ GP #1 I i Cmt Rtnr and perfs .O, 7100' lop Cemented with 64 bbls. Cementing Information Includes 30% excess in OH and P. 1375' of liner lap. Planned Description Volume Density Yield Notes TOC is 200' below liner hanger (bbls) (ppg) (ft3 /sx) r shoe a 8375 13 3/8 Stage 1 234 13.0 1.46 LiteCrete 13 3/8 Stage 2 276 13.0 1.46 Lite Crete. Stage Collar at 469' Some cement to surface 12 bbls before landing plug. 9 5/8 Stage 1 131 13.0 1.48 Lite Crete. Planned TOC is 4404' 9 5/8 stage 2 145 13.0 1.48 Lite Crete. Planned TOC @ TD 2; 9 33o 385' ML 7" TBD TBD TBD TBD MAX HOLE ANGLE = 89.3° @ 3533' MD Well Detail DRAWN BY: JAR Rot feel.. is Male ProlaauN3 - -� Well Profile Data TO venial depdn are referenced to Actual D.lum (RKB) Grid SyWm: NA027 / TM Maths Slate Plane, Zone • (5004). US Mt Measured depths am e,er,M.dto Actual oat.(RKB) run„Ra„rence Use north Design Comment MD (ft) Inc ( °) Az ( °) TVD (ft) Local N (ft) Local E (ft) DLS (°/100ft) _ VS (ft) Ache/ Datum (RKS) to mean.aa level. 160.25 NM Sale: True distance Tie On 1732.00 47.120 23.710 1800.99 399.49 244.66 0.00 460.36 mean sea evel to Mud line (P.cly STEELHEAD Puawlm): o wet Depths are in feat End of Build 1819.72 50.710 23.710 1858.62 480.02 271.24 4.09 528.38 Coordmtea are in tan referenced to Slot Created w: dream on 12/3,20011 End of 3D Arc 2482.77 88.000 15.000 1888.69 1036.41 467.47 5.75 1134.88 End of Tangent 4300.00 _88.000 15.000 1952.11 2790.65 937.51 0.00 2941.66 End of 3D Arc 5162.63 63.198 22.700 2165.28 3575.55 1202.15 3.00 3769.38 End of Tangent 9970.51 63.198 22.700 4333.19 7534.51 2858.22 0.00 8058.43 i i -500 - • 0-y 500 ■ i I\ 28in Conductor 1000- n x ` 13.375in Casing Intermediate - 1500 D c 0 c� 0 O \ A o e o 0 2000 - •�� o a a c '� • I - w m pa g �\� te PO 2500 - A. ■ 9 6�' • • (s. 42 ti 3000 - 3500 - M18 Tgt to avoid K -20 4000 - �, 7in Lner O no of Tangent 78 4500 - 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 Vertical Section (ft) $Le 1 mcn - 1ooc" Azimuth 20.81° with reference 0.00 N, 0.00 E M -18 FIT 1 • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, December 19, 2008 1:46 PM To: Rose, Jim [Contractor] Cc: Regg, James B (DOA) Subject: RE: M -18 (208 -162) FIT Good news. Jim Regg informed me that contact had been made with the Inspectors. Best wishes for the holidays. Tom From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Friday, December 19, 2008 1:44 PM To: Maunder, Thomas E (DOA) Subject: RE: M -18 (208 -162) FIT Tom Got the 2nd stage cement in place with cement to surface. With good luck we will be doing the BOP test late tonight or, more likely, tomorrow. Jim From: Maunder, Thomas E (DOA) [mailto:tom.maunder @ alaska.gov] Sent: Friday, December 19, 2008 8:50 AM To: Rose, Jim [Contractor] Cc: Bonnett, Nigel (Nigel.Bonnett) Subject: RE: M -18 (208 -162) FIT Thanks as well Jim. What is the current status of operations? When will the BOP test be accomplished? Tom From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Friday, December 19, 2008 8:47 AM To: Maunder, Thomas E (DOA) Cc: Bonnett, Nigel ( Nigel.Bonnett) Subject: RE: M -18 (208 -162) FIT Tom, Ok, will do. Will change our procedure. Thanks for the consideration. Jim From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, December 19, 2008 8:41 AM To: Rose, Jim [Contractor] Cc: DOA AOGCC Prudhoe Bay Subject: RE: M -18 (208 -162) FIT 1/26/2009 • 0 M -18 FIT Pa ge2of3 Jim, Sorry I did not get a reply to you yesterday. You are correct about casing effect, however I still believe it appropriate to comply with the regulations for 20' — 50' of new hole. Best regards for the operations. It is nice to see new drilling underway. Tom Maunder, PE AOGCC From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Thursday, December 18, 2008 1:16 PM To: Maunder, Thomas E (DOA) Subject: RE: M -18 (208 -162) FIT Tom, 'Will, of course, do as you wish. However, the omission of the casing string is not relevant to this issue. We are setting pipe at the location of the 2nd string per the old regs. Once it is cemented, we are in the same situation as we have always been...Cemented pipe and BOP's in place. dont personally see this as a large request. Have I changed your mind any? Jim From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, December 18, 2008 1:03 PM To: Rose, Jim [Contractor] Subject: RE: M -18 (208 -162) FIT Is it possible to do 2 FITs, one at 5' out and the other beyond 20' out? Not trying to "make work ", but since this is the first well without the additional casing as allowed by the Administrative Approval, I think it is important to honor the requirements of the regulations. I got your other email as well. Tom From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Thursday, December 18, 2008 12:54 PM To: Maunder, Thomas E (DOA) Subject: RE: M -18 FIT Tom The directional BHA wont be in the hole at that point. because we have the stage tool, and the LC, FC, FS of the shoe track, we are planning to drill out with a rotary assy. we would then then smooth out the mud, do the FIT, swap out the mud system to KCL /GEM and then trip for the rotary steerable BHA. I would much prefer to get the FIT before we pick up the smart BHA in the event that it wont test and we need to squeeze or something. attached is the projected trajectory. i think we are about 3 deg behind the curve at casing point...though i dont know if we got anything out of our last slide....heck, it might be a little worse. cant afford to get behind and every foot of TVD counts. Please advise. Jim From: Maunder, Thomas E (DOA) [mailto:tom.maunder @ alaska.gov] Sent: Thursday, December 18, 2008 12:44 PM 1/26/2009 M -18 FIT To: Rose, Jim [Contractor] • Cc: Bonnett, Nigel (Nigel.Bonnett); Nienhaus, Doug R Subject: RE: M -18 FIT Jim, • Is it not possible to drill out, start your kickoff, drill that first joint and conduct the FIT? Tom Maunder, PE AOGCC From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Thursday, December 18, 2008 12:32 PM To: Maunder, Thomas E (DOA) Cc: Bonnett, Nigel (Nigel.Bonnett); Nienhaus, Doug R Subject: M -18 FIT Tom, Page 3 of 3 We are currently running 13 3/8 surface casing on M -18. We TD'd the section at 1450' MD. Projections to the bit indicate we are probably a couple degrees behind the curve. M -18 is a challenging, extended reach well and getting behind will have significant consequences in the tangent section. 20 AAC 25.030 (b)(7)(f) requires us to drill a minimum of 20' of new formation prior to doing the FIT. I am requesting that we be allowed to shorten that to 5' of new formation to allow us to start building angle sooner. Please advise. Thanks, Jim 1/26/2009 I Chevron Chevron �`�`� HUGHES 410 Location: Cook Inlet, Alaska (Offshore) Slot: slot #B2 -2 INTEQ Field: McArthur River Field Well: M -18 Facility: STEELHEAD Platform Wellbore: M -18 Rol reference wellpamI.k16 Verror156 Well Profile Data True vertrcr depths are referenced to Actual Datum (Ft KB) OM System: 640271 TM Alaska State Fiala, Zone 4 (5004), US feel Measured depths are rehr.noed to Actual Datum (12KB) Norm Reference: T. north Design Comment MD (ft) Inc (°) Az ( °) TVD (ft) Local N (ft) Local E (ft) DLS ( ° /100ft) VS (ft) _actual Datum (RKB) to mean se. level: 160.25 hot Scale: True distance Tie On 0.00 0.000 71.565 0.00 0.00 0.00 0.00 0.00 mean sea level to Mud tine (Fawley. STEELHEAD N.tbrm): 0 Mt Depths are in feet End of Tangent 539.97 0.000 71.565 539.97 0.00 0.00 0.00 0.00 ceomin.tee are In het referenced to Slot created by ulnas. on 10/10/2008 End of Build 740.83 9.039 71.565 740.00 5.00 15.00 4.50 10.00 Hole and Casing Sections End of 3D Arc 2542.45 87.974 15.545 1865.26 1118.78 473.56 4.60 1214.04 Start End Sten End Shn Start End End End of Tangent 4247.67 87.974 15.545 1925.55 2760.60 930.26 0.00 2911.00 N.m. MD 637 MD 68 Interval (ro Tor 6q rvD (m Loral N tti Lout E 65) local N (n) Local E (ft) w+bor• End of 3D Arc 5027.84 64.756 18.607 2108.25 3480.61 1150.39 3.00 3682.24 2891 Conductor 0.00 445.00 485.00 0.00 485.00 0.00 0.00 000 0.00 51-19 175in 0p.n Hole 48500 1435.97 950.97 465.00 1375.00 0.00 0.00 220.13 100.36 M-18 End of 3D Arc 5168.57 63.198 22.975 2170.02 3598.81 1195.23 3.00 3788.65 13.37591 Casing Inter rwrah 0.00 143697 143597 000 137600 0.00 0.00 220.12 180.65 81.15 End of Tangent 9043.49 63.198 22.975 3917.25 6783.10 2545.22 0.00 7244.83 12.25910p.1e01e 143597 8250.00 4414.03 1375.00 2567.64 220.12 150.86 4457.49 1571.99 81-10 End of Tangent 9970.51 63.198 22.975 4335.25 7544.89 2868.18 0.00 8071.67 9.6251n Casing 0.00 8250.00 8250.00 0.00 2657.64 0.00 0.00 449749 1571.99 0.00 11 0.591 Open H. 9250.00 997051 3720.51 2657.64 4335.25 4467.49 1571.99 7544.40 2868.10 M-18 79110r1 6050.00 9970.51 3920.51 2567.49 4335.25 4323.14 1502.31 754499 2889.18 M-18 Easting (ft) Scale 1 inch = 2500 5 -2500 -1250 0 1250 2500 3750 5000 , I I I I I I sco - 8750 E,a Of GM (1845.01 2010.0) Dip - 7182° F. 535195 nT r a'?9e Megieuc No500185 6 degrees E Y or True Nwlh(at 12112008) ' / 7500 � i n <ioe7 - 6250 -1250 - In f e al - 5000 O- / \ / 28inConductor� �9�t c f 9 3 End of Tangent A• ^ d 4618 TM 6217CT (8 � i 9 - 3750 End of Build c n • r 1250 - b � 0� ,5 0 0 0 , , � Of3 ° 6c w � N End Of r an9e�f o - 2500 ,�b• Q uo c ' 2500 - g 5't' . !.b 4 E A � 4 ' M 18 Tgt Landing Point F� - 1250 2 � , w n d H 3750 - co a a ° of 3 0 Arc 4 ➢ 73 m ■ M. � slot #B2 -2 1 F 3 js „ c - 0 w F ndo of ew a so9 5000 - o T ao9eOt - -1250 i 0 6250 ., 1 I I I I I I I 1 1 - 2500 -1250 0 1250 2500 3750 5000 6250 7500 8750 Vertical Section (ft) Scale inch =25005 Azimuth 20.81° with reference 0.00 N, 0.00 E Actual curve for M -18 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Rose, Jim [Contractor] [RoseJi @chevron.com] Sent: Thursday, December 18, 2008 1:00 PM To: Maunder, Thomas E (DOA) Subject: Actual curve for M -18 Attachments: M -18 Plan- vs- Actual.pdf «M -18 Plan- vs- Actual.pdf» Tom, Just in....shows the inclination issue Jim I I 1/26/2009 i • 0 Chevron Chevron o t °.,�.,�, � MOP /T s Plane .1,I US fed B L A t� K ii� R lc End Location_ Cook Inlet. Alaska (Offshore) Slot. slot 1082-2 Pia,. Datum t Kai mean ma iw.e ,mnar saga _ _. r11VVNES ww0 rctesae relFCiiy BfEELaE/D P4Gam1'.aM Created Field: McArthur River Field Well. M -18 I NTE mean sea level to Mud Facility: STEELHEA Fie orm Wellbore: M -18 ��rMaam as ��mw, ea,ue Scale 1 inch = 45 ft Easting (ft) -22.5 0.0 22.5 45.0 67.5 90.0 112.5 135.0 157.5 180.0 a m 247.5 ./ 13.375in Casing Planned 225.0 p it i 202.5 , 180.0 c. N M II �: 157.5 L U co 3 135.0 125 — o 5 CO 112.5 250 — 90.0 375 — 675 500 — 28in Conductor 45.0 625 — a ar 0 22.5 750 — / oao° • a s D . 0.0 875 — -22.5 1000 — 1125 — e 6 1250 — 9\ac 4 � `c C 9 1 3. 1375 ■ � �' ._....--- M -18 Actuel • — ..! I I 1 I I �I 1625 -250 -125 0 125 250 375 500 Vertical Section (ft) Scala 1 -.0" Azimuth 20.81 ° with reference 0.00 N, 0.00 E 2-cg — 7( Z---- • McArthur River Field Steelhead Platform M -18 Proposed M -18 Proposed ADL018772 TD X: 217273.5 Y: 2506932 ADL017594 • ADL018730 SZ12ST X: 214483.3 - Y: 2499887 Steelhead Surface Location X: 214222 Y: 2499460 e. N T9N - R13W ADL018729 T8N - R13W ADL017579 0 500 1,000 ID X Y Location I Feet _Surface 214222.00 2499460.00 1040' FNL, 605' FWL, Sec 33, T9N, R13W, S State Plane Alaska SZ12ST 214483.30 2499887.00 606' FNL, 857' FWL, Sec 33, T9N, R13W, S Zone 4 NAD 27 Union Oil Company TD 217273.50 2506932.00 1224' FSL, 1794' FEL, Sec 21, T9N, R13W, S December 8, 2008 of California - AOGCC TBU M -18: Check Coordinate Conversion 3 December 2008 INPUT OUTPUT Geographic, NAD27 State Plane, NAD27 5004 - Alaska 4, U.S. Feet TBU M -18 Slot Location 1/1 Latitude: 60 49 54.561 Northing/Y: 2499459.492 Longitude: 151 36 05.775 Easting/X: 214222.001 Convergence: -1 23 54.94680 Scale Factor: 0.999992931 Remark: Check coordinate conversion on operators planned directional survey - appears okay. SFD 12/3/2008 Corpscon v6.0.1, U.S. Army Corps of Engineers M -18 surface location Page 1 of 2 Davies, Stephen F (DOA) From: Rose, Jim [Contractor] [RoseJi @chevron.com] Sent: Tuesday, December 09, 2008 2:36 PM To: Davies, Stephen F (DOA) Cc: Dial, Amanda [ASRC EPT]; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: M -18 surface location Attachments: RE: Coordinate Help Needed Steve 'Took awhile but I have this issue resolved. Attached you will find a new plat with the correct surface coordinates indicated for Trading Bay Unit M -18, There was a conversion problem within the sofware used by the contractor used by the G &G department. Anyway, if you are interested, I have attached their email concerning the issue. Is there anything else needed from me to wrap this up? 7:1 / ocW Jim V ../- From: Davies, Stephen F (DOA) [mailto:steve.davies @alaska.gov] Sent: Thursday, December 04, 2008 8:58 AM To: Rose, Jim [Contractor] Subject: RE: M -18 surface location Jim, All AOGCC will need for our well record is an email listing the name of the well and the correct coordinates of the surface location (if they were wrong on the application). If they were ok, then just an email saying that AOGCC's calculated coordinates are apparently incorrect. A stat tech brought this surface coordinate discrepancy to my attention yesterday. I initially thought that there might be a problem with AOGCC's coordinate conversion software, so I spent time thoroughly cross - checking our results. After checking our results using two other conversion programs, AOGCC's calculations appear to be correct and consistent. So, I pulled out a 1993 book titled "Platform Information, Cook Inlet, Alaska" by Belmar Engineering. This book has specs on all Cook Inlet platforms, including Steelhead, and it has listings of conductor coordinates in X,Y format. Only a few of these conductors have associated well names, but luckily the conductor B2 -3 is labeled as containing the TBU M -2 well. The surface coordinates for M -2 are 603 FWL and 1043 FNL. So, the X coordinate from the west section line for TBU M- 18 should be more like 607' FWL rather than the 377' FWL value shown on the M -18 permit application. That's why I thought I'd check with you to see if the 377' FWL value might be a typo or cut and paste problem. Thanks for your help, Steve Davies AOGCC From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Thursday, December 04, 2008 6:47 AM To: Davies, Stephen F (DOA) Cc: VOORHEES, BRENT J Subject: M -18 surface location 12/11/2008 M -18 surface location • Page 2 of 2 Steve I received your message and am looking into the coordinate conversion problem. We have software that does the conversion and I really don't know much about how it works. Apparantly it has happened more that once. I will get it resolved. What do you need me to do about once I get it figured out? Jim 12/11/2008 RE: Coordinate Help Needed • Page 1 of 3 • Davies, Stephen F (DOA) From: Hay, Michael L [Resource Data, Inc.] [MHQW @chevron.com] Sent: Monday, December 08, 2008 1:04 PM To: Rose, Jim [Contractor] Subject: RE: Coordinate Help Needed Our calculation relies on finding the vertices at the corners of the section in question. One of the sections was returning a northwest vertex that was not the corner, but was actually east of the corner. This, in effect, moved the western boundary of the section to the east, which shortened the FWL distances. I did a temporary fix by removing that vertex. Now I have to go in and adjust the code to deal with this situation in the future. Sony for the problems. Mike Original Message From: Rose, Jim [Contractor] Sent: Monday, December 08, 2008 12:51 PM To: Hay, Michael L [Resource Data, Inc.] Subject: RE: Coordinate Help Needed So what was causing the problem? Original Message From: Hay, Michael L [Resource Data, Inc.] Sent: Monday, December 08, 2008 12:27 PM To: Rose, Jim [Contractor] Subject: RE: Coordinate Help Needed Attached is a new map with the correct TRS locations. Mike Original Message From: Rose, Jim [Contractor] Sent: Monday, December 08, 2008 11:14 AM To: Hay, Michael L [Resource Data, Inc.] Subject: RE: Coordinate Help Needed Thanks Mike, Whenever you do get it figured out, please fix the attached plat that Damien put together and return it to me. Thanks Jim Original Message From: Hay, Michael L [Resource Data, Inc.] Sent: Monday, December 08, 2008 11:10 AM To: Rose, Jim [Contractor] Cc: 'Ulrich, Carl D'; Kanyer, Christopher V; VOORHEES, BRENT J Subject: RE: Coordinate Help Needed 12/11/2008 RE: Coordinate Help Needed Page 2 of 3 When I manually measure the distances I get about 605 FWL for the Surface, and about 85411L for Top of Prod. The rest of the measurements are correct. Manual measurements are not precise measurements at all, but what that means is the error is in the calculation we use for automated measurements. The numbers from AOGCC and BHI are correct. I'll figure out exactly why our calculations are incorrect and get it fixed. Mike Original Message From: Rose, Jim [Contractor] Sent: Monday, December 08, 2008 10:15 AM To: Hay, Michael L [Resource Data, Inc.] Cc: 'Ulrich, Carl D'; Kanyer, Christopher V; VOORHEES, BRENT J Subject: RE: Coordinate Help Needed Mike Thanks for the help on this but these coordinates are the same as those given previously by Damien. They don't agree with the AOGCC or BHI's conversion to governmental section. I would like you to figure out what is causing the disparity and let me know how to resolve it. Attached is a document from BHI that shows the surface location (slot Location) to be —606 FWL. This is in agreement with the AOGCC coordinates for that location. The AOGCC told me they used 2 different conversion techniques and come up with similar numbers to BHI Carl at BHI can be reached at 267 -6608 and the emial above. I am not sure who is in error but I need resolution to continue forward. Thanks, Jim From: Hay, Michael L [Resource Data, Inc.] Sent: Monday, December 08, 2008 9:53 AM To: Kanyer, Christopher V Cc: Rose, Jim [Contractor]; Flynn, Tim [ASRC] Subject: RE: Coordinate Help Needed Chris, Surface 1040' FNL, 377' FWL, Sec 33, T9N, R13W, S Top of Prod. 606' FNL, 605' FWL, Sec 33, T9N, R13W, S TD 1224' FSL, 1794' FEL, Sec 21, T9N, RI3W, S Let me know if you need anything else. Mike From: Kanyer, Christopher V Sent: Monday, December 08, 2008 9:11 AM To: Hay, Michael L [Resource Data, Inc.] Cc: Rose, Jim [Contractor]; Flynn, Tim [ASRC] 12/11/2008 RE: Coordinate Help Needed • Page 3 of 3 Subject: Coordinate Help Needed Importance: High Can you please help me with the conversion from XY (below) to coordinates NAD 27? We have submitted these incorrectly to the state and they require it asap, as we will begin drilling this well in a couple of days. X Y Location Surface 214222.00 2499460.00 ? FNL, ? FWL, Sec 33 T9N, R13W, S.M. Top of Prod. 214483.30 2499887.00 ? FNL, ? FWL, Sec 33 T9N, R13W, S.M. TD 217273.50 2506932.00 ? FNL, ? FWL, Sec 33 T9N, R13W, S.M. Thank you for your help. Let me know if you need any further information. Chris Kanyer * * Technical Assistant Wellbore Maintenance Team (907) 263 -7831 Chevron North America Exploration and Production Midcontinent /Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 12/11/2008 M -18 name Page 1 of 1 • Davies, Stephen F (DOA) From: Rose, Jim [Contractor] [RoseJi@chevron.com] Sent: Wednesday, December 03, 2008 9:50 AM To: Davies, Stephen F (DOA) Cc: Dial, Amanda [ASRC EPT] Subject: RE: M -18 name Thanks Steve Here forward, we would like to call it: Trading Bay Unit M -18 Jim From: Davies, Stephen F (DOA) [mailto:steve.davies @alaska.gov] Sent: Wednesday, December 03, 2008 9:37 AM To: Rose, Jim [Contractor]; Maunder, Thomas E (DOA) Subject: RE: M -18 name Jim, Your email request (below) is all that is needed. Thanks, Steve Davies AOGCC From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Wednesday, December 03, 2008 9:23 AM To: Maunder, Thomas E (DOA); Davies, Stephen F (DOA) Subject: M -18 name Tom, Steve, I have been advised by Amanda that I put " Steelhead M -18 N in block 11, Well Name and Number of the 10-407 and that is not consistent with the rest of the wells on Steelhead. I would like to change it to "Trading Bay Unit M -18 ". How do I do that? Jim 12/3/2008 M -18 permit Page 1 of 1 4110 1110 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, December 03, 2008 12:36 PM To: 'Rose, Jim [Contractor]' Cc: Flynn, Tim [ASRC]; Nienhaus, Doug R; Bonnett, Nigel (Nigel.Bonnett); Harness, Evan; Hauck, Shane R; Vaussine, Ray J. (rajv) (RayVaussine) Subject: RE: M -18 (208 -162) permit Jim, Reducing the annular test pressure on other than the initial test to 50% of the rating is consistent with the regulations. Please make sure a copy of this message is available on the rig. Tom Maunder, PE AOGCC -- i From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Friday, November 28, 2008 10:54 AM To: Maunder, Thomas E (DOA) Cc: Flynn, Tim [ASRC]; Nienhaus, Doug R; Bonnett, Nigel (Nigel.Bonnett); Harness, Evan; Hauck, Shane R; Vaussine, Ray J. (rajv) (RayVaussine) Subject: M -18 permit Tom, I am in receipt of the M -18 permit. Thanks. The testing requirements are noted as 250/3000 for the rams and 250/2000 for the annular. 18AAC 25.035 (e)(10)(A) indicates a test pressure of 50% of rated working pressure for annular preventers. Though I understand the issue with M -18, I would request that we prove the system by testing the annular to 2000 the first time and then a lower pressure on subsequent tests. A 21 1/4 2M annular is a large preventer and the fatigue caused by regular 2000 psi tests on 5" DP will likely shorten element life considerably. If you are receptive to this, please advise of subsequent test presssure requirements for this annular. Thanks, Jim 12/3/2008 FW: M -18 cement designs Page 1 of 1 I • Maunder, Thomas E (DOA) From: Rose, Jim [Contractor] [RoseJi @chevron.com] Sent: Friday, November 21, 2008 12:03 PM To: Maunder, Thomas E (DOA) Subject: FW: M -18 cement designs Tom, Continued cement work has taken place since the submittal of the M -18 APD. Our cementing goals have not changed but the slurry designs and the excess amounts have been refined. Please keep in mind that isolation of certain formations in the 9 5/8 job are our goals. Those zones may come in substantially different than projected MD because of the shallow trajectory of the wellbore. Therefore actual volumes will will likely change based on where we encounter those zones The following information represents the final planned slurry designs. Proposed cement designs for M -18: 13 3/8 stage 1: 986 sx © 1.46 ft3 /sx, 13.0 ppg LiteCrete, 75% OH excess 13 3/8 stage 2: 927 sx @ 1.46 ft3 /sx, 13.0 ppg LiteCrete, 7% excess (pipe in pipe) 9 5/8 stage 1: 523 sx © 1.45 ft3 /sx, 13.0 ppg LiteCrete, 30% OH excess 9 5/8 stage 2: 703 sx @ 1.45 ft3 /sx, 13.0 ppg LiteCrete, 45% OH excess 7" liner 629 sx © 1.20 ft3 /sx, 15.8 ppg G LXT, 50% OH excess....though I am prepared to pump this much, I would like to reduce this a bit based on drilling results. Let me know if there is anything else you need clarification on. Jim 11/21/2008 M -18 cement designs Page 1 of 1 • • Maunder, Thomas E (DOA) From: Rose, Jim [Contractor] [RoseJi @chevron.com] Sent: Friday, November 21, 2008 9:37 AM To: Maunder, Thomas E (DOA) Subject: M -18 cement designs Tom, Proposed cement designs fro M -18: 13 3/8 stage 1: 986 sx @ 1.46 ft3lsx, 13.0 ppg LiteCrete 13 3/8 stage 2: 927 sx © 1.46 ft3lsx, 13.0 ppg LiteCrete 9 5/8 stage 1: 523 sx © 1.45 ft3 /sx, 13.0 ppg LiteCrete 9 5/8 stage 2: 703 sx @ 1.45 ft3/sx, 13.0 ppg LiteCrete 7" liner 629 sx @ 1.20 ft3 /sx, 15.8 ppg G LXT Jim 11/21/2008 M -18 Page l of 3 • • Maunder, Thomas E (DOA) From: Rose, Jim [Contractor] [RoseJi @chevron.com] Sent: Friday, November 21, 2008 7:04 AM To: Maunder, Thomas E (DOA) Subject: RE: M -18 - AGAIN Attachments: M -18 Basic Drilling Procedure.doc Tom, there was a basic procedure included. i attached it incase it went missing. will forward the cement info shortly From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, November 20, 2008 3:19 PM To: Rose, Jim [Contractor] Subject: RE: M -18 - AGAIN Jim, I am continuing to review the application. You have all the parts here, but I don't find a procedure that ties it all together. Am I missing something? Look forward to your reply. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Thursday, November 20, 2008 2:34 PM To: 'Rose, Jim [Contractor]' Subject: RE: M - 18 Jim, Following on our message trail, I am reviewing the permit application. Could you provide "more" information on the cementing program? In particular, I need the sack count and yields. I fill out a spread sheet and I need those for my inputs. Thanks in advance. Tom Maunder, PE AOGCC From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Tuesday, November 18, 2008 1:39 PM To: Maunder, Thomas E (DOA) Subject: RE: M - 18 not a new stack. used in the inlet before in the same configuration. it had a level 3 inspection and is now going to be used on steelhead. the annular is a 21 1/4 2M BOP while the ram preventers (3 of them) are 20 3/4 3M, the stack is in a 5M configuration. anyway, i thought it might be a good idea to point out 2M / 3M pressure rating issue so i can address it appropriately. seems this was a fairly common manufacturing process in days past. the annular actually appears in theHydril catalouge with a 20 3/4 3M hub though it is a 2M BOP 11/21/2008 M -18 Page 2 of 3 • • Anyway, when you get back to the office, let me know what you want me to do. Thanks Jim From: Maunder, Thomas E (DOA) [ mailto:tom.maunder@alaska.gov] Sent: Tuesday, November 18, 2008 1:19 PM To: Rose, Jim [Contractor] Subject: RE: M - 18 Jim, Is this the new stack? I don't remember having run into this before either. I am not in the office today. I will try to call you later in the week. Tom From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Tue 11/18/2008 11:17 AM To: Maunder, Thomas E (DOA) Subject: RE: M - 18 Tom The proposed BOP stack for steelhead has a 2M annular and a 3M stack. This stack has been used before on Steelhead and I didn't specifically address the pressure rating difference in the APD. This is a bit of an unusual situation, I guess, and I don't think I have had to address it before. Is there anything that needs to be done about it? The MASP for the well is 1119 psi. Jim From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, November 17, 2008 11:55 AM To: Rose, Jim [Contractor] Cc: Davies, Stephen F (DOA) Subject: RE: M -18 Hi Jim, I checked with Steve and I believe all is in order. When is spud planned? Tom From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Monday, November 17, 2008 11:35 AM To: Maunder, Thomas E (DOA) Cc: Davies, Stephen F (DOA) Subject: M - 18 11/21/2008 M -18 Page 3 of 3 • Hey Tom, Hope things are well with you. Ok here. I was wondering how you gents were coming on the M -18 APD? BTW, There was a spacing issue that I hope was resolved by the data I submitted. Please advise if it wasn't. Thanks, Jim 11/21/2008 1 SARAH PALIN, GOVERNOR ALAS OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tim Brandenburg Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, _S_te,elligad M -18 6 " 3 • t.v Unocal $ Permit No: 208 -162 ' `!VG .47. o Surface Location: 1040' FNL, ,3-7-7" SEC. 33, T9N, R13W, SM Bottomhole Location: 124' FSL, 1794' FEL, SEC. 21, T9N, R13W, SM Dear Mr. Brandenburg: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). Sincerely, P L' Cathy . Foerster Commissioner DATED this Z d ay of November, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA ..A OIL AND GAS CONSERVATION COMIC!�SION 4A PERMIT TO DRILL V 20 AAC 25.005 la. Type of Work: lb. Current Well Class: Exploratory ❑ Development Oil ❑ lc. Specify if well is proposed for: Drill 0 Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas 0 Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket • Single Well ❑ 11. Well Name and Number Union Oil Company of California Bond No. 086S103515406BCM Stee - 189 A � 3. Address: 6. Proposed Depth: 12. Field /Pool(s): PO Box 196247, Anchorage, AK 99519 MD: 9970 - TVD: 4335 McArthur River Field ' z -3 4a. Location of Well (Governmental Section): 7. Property Designation: Grayling Gas Sands Surface: 1040' FN�WL, SEC 33 T9N, R13W, SM ' ADL- 17594, ADL 18730 Top of Productive Horiz " A/Zdi'O, 8. Land Use Permit: 13. Approximate Spud Date: 606' FNL, 605 FWL, Sec 33, T9N R13W SM 12/1/2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest 124' FSL, 1794' FEL, Sec 21, T9N, R13W, SM 5116, 3840 Property: >6000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 214222 y- 2499460 Zoi 4 (Height above GL): 160 AMSL feet . Within Pool: 700' 16. Deviated wells: Kickoff depth: 540 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 88 degrees Downhole: 2096 Surface: 1130 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 28 -32 1/2 - 1" WT X -56 Weld 401 0 0 480 480 Driven 17 1/2" 13 3/8" 68 L -80 BTC 1357 0 ' 0 1436 1375 3256 ft3 in 2 stages 12 1/4" 9 5/8" 47 L -80 BTC -M 6171 0 0 6250 , 2658 2177 ft3 in 2 stages 8 1/2" 7" 26 L -80 DWCSR 3920 6050 2567 9970 , 4335 797 ft3 in 1 stage 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural 401.00 28 -32 Driven 480 480 Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch El Drilling Program El Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat 0 Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 10/8/2008 22. I hereby certify that the foregoing is true and correct. Contact Jim Rose, 907 - 263 -7637 Printed Name t CS C c— IL,-)--)ST'S— Title Ott L&..A & G-t %S zfz..1 >J Cs- j\ MJ4 CsZ Signature ---_J 1—t_rfk Phone 10R — 2 CS — 3-$ SS Date 14- be ts 'ZorfC Commission Use Only Permit to Drill API Number: Permit ApproA ar See cover letter for other Number: .2 0. 50- / — 26 583 Date: I I . ..ip . 0g requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales21 Other: " ©�� ` - 1 - .� i &. 000.r;-‘ �h,R,J \,4r .amples req'd: Yes❑ o[✓] Mud log req'd: Yes❑ NoE� a � J ` � � � C H measures: YesZ No❑ Directional svy req'd: YesZ No❑ W � `1 4 aO gP�.a-s ou 5 C <N S) 1 a ' 0 Imo -cc i i (3'` Z\ v Ec - c. r \\ tE. ,1„c..c.Q v.\0 \.z. dp -AAC a-5 , 7 5 C:\N /� ^ . APPROVED BY THE COMMISSION DATE: 11 Zp - 7[/� COMMISSIONER ee Form 10-401 Revised 12/2005 f ) ) 1 Submit in D uplfcatt� / / �9 1 Chevron Timothy C Brandenburg Union Oil Company of California %/0 Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 1%0 Fax 907 263 7657 Fax 907 263 78888 4 Email brandenburgt @chevron.com October 28, 2008 Mr. Stephen Davies Alaska Oil & Gas Conservation Commission OCT Avenue zt 333 W. 7th Alask Anchorage,Alaska 99501 � �° Re: Steelhead M -18 Spacing Exception Dear Mr. Davies, Please find the enclosed spider plot for the above referenced well. All of the intended completion intervals for the M -18 well fall below the 9 5/8 casing shoe. Per your request, I have indicated the producing intervals of the nearest 2 wells that are producing from or are capable of production from the same intervals as the intended completion in the M -18 wellbore. For reference, I also plotted a circle encompassing 10 acres which is the required spacing pursuant to Conservation Order 228. As you can see, K -20 is the only wellbore to fall within the 10 acre spacing along the intended trajectory of M -18. K -20 is incapable of production from equivalent strata. Therefore, a spacing exception should not be necessary to drill M -18. If you have any questions, please don't hesitate to contact myself or Jim Rose at 907 - 263 -7637. Sincerely, Timothy C. Brandenburg Drilling Manager Attachments: Annotated M -18 Spider Plot. Union Oil Company of California / A Chevron Company Page 1 of 1 • • Chevron Timothy C Brandenburg Union Oil Company of California 410 Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 1%0 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt @chevron.com Oct 10, 2007 Commissioner Alaska Oil & Gas Conservation Commission 2flfl8 333 W. 7 Avenue Anchorage, Alaska 99501 Alaska oil 3 f1 S ) rtich{a.air Re: Steelhead M -18 Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the Steelhead M -18 well. Drilling operations are expected to commence approximately December 1, 2008 depending on the progress of other ongoing projects. In accordance with 20 AAC 25.005 (c)(4)(A -C). (A) MASP calculations are attached for review. (B) The Grayling Gas Sands are potentially gas bearing throughout the section. Potential target reservoirs and their predicted pore pressures are indicated in the attached M -18 Well Design Summary. (C) Due to ongoing production operations in this field, sub - normally pressured sands occur in multiple places. Lost circulation and differential sticking are potential problems. Conventional solutions such as LCM and good drilling practice are intended to ameliorate the problems. An exception to 20 AAC 25.035 (c)(1)(B) is requested. The diverter system at Steelhead includes two 16" diameter diverter lines. The surface hole section of M -18 is planned to be drilled with a 17 % /2" bit. Union Oil Company of California / A Chevron Company Page 1 of 2 • • In accordance with 20 AAC 25.050 (b)(2)(B)... Union Oil Company of California is the only operator of wells within 200' of the planned trajectory of M -18. Pursuant to 20 AAC 25.005 (c)(14)... Qualified drilling waste will be discharged in accordance with NPDES permit AKG -31 -5000 which became effective 7/2/2007 and expires 7/2/2012. At this time, Union Oil Company does not intend to apply for annular disposal approval. The remainder of the requirements of 20 AAC 25.005 are attached for review or are on file with the Commission. If you have any questions, please don't hesitate to contact myself or Jim Rose at 907 - 263 -7637. Sincerely, kj ( o Timothy C. Brandenburg W Drilling Manager Attachments: Form 10-401 in Duplicate M -18 Cementing Calculations M -18 Well Design Summary M -18 Casing Design M -18 Summary Drilling Procedure M -18 MASP Calculations M -18 Summary Mud Program M -18 FIT / LOT Procedure M -18 Planned Well Sketch M -18 Spider Plots M -18 Planned Well Trajectory M -18 Combo BOP /Diverter Schematic M -18 Drilling Hazards Notice M -18 Choke Manifold Schematic M -18 Plat Cc: File Union Oil Company of California / A Chevron Company Page 2 of 2 STATE OF ALASKA ALA° . OIL AND GAS CONSERVATION COM /1ION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work: 1b. Current Well Class: Exploratory ❑ Development Oil ❑ lc. Specify if well is proposed for: Drill El Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ISI Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 511 Single Well ❑ 11. Well Name and Number: Union Oil Company of California Bond No. 086S103515406BCM Steelhead M -18 3. Address: 6. Proposed Depth: 12. Field /Pool(s): PO Box 196247, Anchorage, AK 99519 MD: 9970 TVD: 4335 McArthur River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Grayling Gas Sands Surface: 1040' FNL 377' FWL, SEC 33 T9N, R13W, SM ADL- 17594, ADL 18730 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 606' FNL, 605' FWL, Sec 33, T9N R13W SM 19/1/9008 Total Depth: 9. Acres in Property: 14. Distance to Nearest 124' FSL, 1794' FEL, Sec 21, T9N, R13W, SM 5116, 3840 Property: >6000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 214222 y- 2499460 Zoi 4 (Height above GL): 160 AMSL feet Within Pool: 700 16. Deviated wells: Kickoff depth: 540 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 88 degrees Downhole: 2096 Surface: 1130 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 28 -32 1/2 - 1" WT X -56 Weld 401 0 0 480 480 Driven 17 1/2" 13 3/8" 68 L -80 BTC 1357 0 0 1436 1375 3256 ft3 in 2 stages 12 1/4" 9 5/8" 47 L -80 BTC -M 6171 0 0 6250 2658 2177 ft3 in 2 stages 8 1/2" 7" 26 L -80 DWCSR 3920 6050 2567 9970 4335 797 ft3 in 1 stage 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume ? TVD Conductor /Structural 401.00 28 -32 Driven 480 Surface Intermediate 0C^' .. '6 J00 Production AIM ka Oil & 633 Cony. Curlissim, Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Aildrura90 20. Attachments: Filing Fee ❑ BOP Sketch 0 Drilling Program isi Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat 0 Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program ISI 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 10/8/2008 22. I hereby certify that the foregoing is true and correct. Contact Jim Rose, 907-263-7637 Printed Name I g --T Title a t%(t-t../N(s- 7 r.1 - fz/itr.\(r ! \A,.#Ja.L.ct k Signature /" 0 Phone ti, -� - 2 63 —'44( S 3 Date 14 0c_r6;S let Commission Use Only Permit to Drill z�//�� / API Number: P ermit Approval See cover letter for other Number: G-u� �CO Z 50- 7 --26503' Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, ga ydrates, or gas contained in shales:L Other: Samples req'd: Yes No Mud log req'd: Yes No[] H measures: Yes Non Directional svy req'd: YesE Non APPROVED BY THE COMMISSION DATE: , COMMISSIONER Form 10 -401 Revised 12/2005 Submi in Dup alit cat 4* Chevron • %NO Steelhead Platform Well M -18 Well Design Summary M -18 Well Design Summary Steelhead M -18 is a development well drilled in a NNE direction from slot B2- 2. The well penetrates multiple primary and secondary Grayling Gas Sand targets from the SZ11 at 1439' TVD through the C5 at 4251' TVD. • M -18 is designed as an "S" shaped, extended reach well reaching 88 degrees inclination in the tangent section and reaching a total depth of 9970' MD, 4335' TVD. Basic Well Information Platform: Steelhead Well Name: M -18 Estimated Spud Date: 12/1/08 Field: McArthur River Productive Horizon: Grayling Gas Sands - PTD: TBD Total Depth: 9970' MD, 4335' TVD - Slot: Slot B2 -2, NE Leg Surface Location: 1040' FNL, 377' FWL, Sec 33, T9N, R13W, SM X= 214222, Y= 2499460, NAD27, ASP, Zone 4 Planned BHL: 1224'FSL, 1794' FEL, Sec 21, T9N, R13W, SM Original KB Elevation: 160' AMSL ' KB to THF: TBD Casing and Tubing Program Hole Tube Weight Length Top Btm O.D. Grade Conn MD /TVD MD /TVD Size (in) (in) (Ibs / ft) (ft) (ft) (ft) Driven 28 -32 X -56 Weld 401 BF 480 - 17 13 3/8 68 L -80 BTC _ 1357 BF 1436/1375 - 12 9 5/8 47 L -80 BTC -M 6171 BF 6250/2658- 8 1 /2 7 26 L -80 DWCSR 3920 6050/2567 9970/4335 - TBG 3 9.2 L -80 HSO3 TBD THF TBD 10/13/2008 Page 1 of 3 Chevron °kW Steelhead Platform Well M -18 1%0 Well Design Summary Well Control Summary Hole Section Equipment Test Pressure (psi) 17'/2" 21 1/4 2M Diverter c/w 2 ea 16" 600 psi Diverter Function Valves* 21 1/4 2M Annular, 20 3/4 3M Double Gate, 12'/4" 20 3/4 3M Mud Cross, 20 3 /4 3M Single Gate 250/3000 3 1/8 5M Choke Manifold* 21 1/4 2M Annular, 20 3 /4 3M Double Gate, 8'/2" 20 3 /4 3M Mud Cross, 20 3/ 3M Single Gate 250/3000 3 1/8 5M Choke Manifold* Schematics of the well control equipment are attached for reference Anti - Collision Evaluation Summary There are multiple close approach wells. With the exception of M -9, all wells pass major risk criteria. M -9's closest approach is behind the conductor of M -18 and improves with depth below the conductor shoe. Collision risk will be mitigated procedurally by monitoring annular pressures of adjacent wellbores and placing an observer in the wellhead room to listen for indications of a collision. Close Approach M -18 Path Ellipse Separation Diverging From Well (MD ft) (ft) (ft) M -9 415 -0.88 415 M -2 377 0.16 377 M -4 484 0.51 484 M -3 221 0.68 221 10/13/2008 Page 2 of 3 r Chevron ift.1 Steelhead Platform Well M -18 %. Well Design Summary Formation Integrity Testing Test Point, 20' Projected Test Type Projected Test Below... (TVD) (EMW ppg) 13 3/8" Csg Shoe 1375 FIT 12.8 9 5/8" Shoe 2658 FIT 12.8 Mud Program Summary Depth Density Viscosity Section (MD ft) Mud Type (ppg) (sec) PV YP API FL 17 1 /2" Surf. 0 -1436 Pre -Hyd Gel 9.0 -9.3 . 60 -85 10 -28 25 -35 <12 12 Interm. 1436 -6250 KCL /GEM /Pmr 9.1 -9.3 40 -53 6 -15 13 -20 _6 8 1 /2" Prod. 6250 -9970 KCL /GEM /Pmr 9.2 -9.3' 40 -53 6 -15 13 -20 <_6 Cementing Summary See Attachments Formation Markers Target Top TVD /SS Depths Measured Pore Pressure EMW Requirement Depth (RKB) V8 (PSI) (ppg RKB) SZ11 -1299 1547 560 8.4 SZ12 -1444 1763 300 3.6 SZ17 -1924 4969 615 5.7 SZ22 -2314 5844 615 4.8 A2 -2560 6389 510 3.6 B5 -3464 8394 368 2.0 C1 -3758 9045 299 1.5 C5 -4091 9785 995 4.5 10/13/2008 Page 3 of 3 Chevron • Steelhead Platform Well M -18 %MO Basic Drilling Procedure M -18 Basic Drilling Procedure 1. RU Steelhead rig over slot B2 -2. 2. Install A section wellhead and test. 3. Install 21 1 /4 2M /20 3 /4 3M combo diverter/BOP stack and dual 16" diverfer lines. Function test diverter per AOGCC requirements. 4. MU 17 1 /2" bit and clean out conductor to 480'. 5. RU Gyro and survey conductor. 6. MU 17'/2" directional BHA and drill to 1436' taking gyro surveys as necessary. 7. MU jet wash tool and wash out conductor to 480'. 8. Run and cement 13 3/8" casing to surface in 2 stages utilizing an ECP stage collar. 9. Install 13 5/8 multi bowl wellhead system. NU BOP stack. Install blind flanges on diverfer outlets. Install 9 5/8 rams. Test stack to 250/3000. 10. MU 12 1/4" drill out BHA and drill out stage tool. Test casing to 1500 psi. 11. Drill out shoe track and perform FIT to 12.8 ppg EMW. 12. Trip. MU directional BHA. 13. Directionally drill to 6250'. 14. Run and cement 9 5/8 casing to ML in 2 stages. 15. Redress BOP's w/ 7" rams and test 250/3000 psi. Test 9 5/8" casing to 3000 psi 16. MU 8'/2" directional BHA and drill out. Perform FIT to 12.8 ppg EMW. 17. Directionally drill to section TD at 9970. 18. Pull wiper trip. 19. Run 7" Liner, hanger, and liner top packer. Set liner hanger and cement. Set packer. 20. Redress BOP's and test 250/3000. Test 7" liner to 3000 psi. 21. PU clean out string and make bit and scraper runs to PBTD. Displace to completion fluid. 22. RU TCP guns and perforate GGS stage 1. 23. Install stage 1 gravel pack 24. RU TCP guns and perforate GGS stage 2. 25. Install stage 2 gravel pack 26. RU TCP guns and perforate GGS stage 3. 27. Install stage 3 gravel pack 28. Run 3 tubing. Space out and land tubing. Test void. 29. Install BPV and ND BOP. 30. NU tree and test. 31. RU CTU and drill out KOIV valves. RDMO CTU 32. RDMO Steelhead rig. 11/21/2008 Page 1 of 1 • 1 Halliburton BAROID Chevron Mud Program HAP010 (8 _ j'� 11 Chevron Steelhead M -18 Cook Inlet, Alaska Baroid Mud Program Halliburton Baroid Name (Printed) Signature Date Originator Dave Soquet Reviewed by Dave Higbie Customer Approval Jim Rose Version No: Date: 1.0 Aug 25, 2008 M -18 v1.0 1 8/25/08 • • Halliburton BAROID Chevron Mud Program Steelhead Producer Well Specifics: Casing Program MD Footage 17 -1/2" hole (13 -3/8" csg) 1436 951 12 -1/4" hole (9 -5/8" csg) 6250 4814 8 -1/2" Hole (7" liner) 9970 3920 Surface Hole Recommendations - (17 -1/2" hole, 13 -3/8" casing to 1436') Properties: Densi Viscosi Plastic Viscosi Yield Point API FL • H 485' -1436' 9.0 -9.3 60 - 85 10 - 28 25 - 35 <10 8.5 -9.0 System Formulation: pre hydrated gel /produced water spud mud Product Concentration Water 0.905 bbl Soda Ash 0.5 ppb Aquagel 12 -15 ppb Caustic 0.1 ppb (9 pH) Barazan D as needed Baroid as required for 9.2 ppg PAC /Dextrid if required for <10 FL Aldacide G 0.1 ppb Concerns and Contingencies Intermediate Interval - (1,436'MD - 17-1/2" hole, 13 -3/8" casing) Mud Type: Pre - hydrated gel /produced water spud mud 1. Mud weight: Maintain the 9.0 — 9.2 ppg density or as directed. 2. Rheology: Maintain a YP between 25 -35 or as needed to achieve adequate hole cleaning. 3. Filtrate control: Maintain the filtrate <10 using Dextrid and /or Pac L. Additions of Condet may be required to control screen blinding /BHA balling. Losses in this interval can be controlled with additions of 1 -2 ppb BAROFIBRE and 1 -2 ppb of Baracarb 50 or by dedicated LCM pills. Operations Summary: Mix a -50 bbl LCM pill prior to drilling out. The pill formulation will be: 45 bbls base mud, 9 ppb Barofibre, 9 ppb Wallnut F, and 12 ppb of Baracarb 50. Pre - hydrated Aquagel should be used to maintain rheological parameters. Maintain the mud as clean as possible while drilling. Should sweeps be required a high viscosity sweep or Barolift is recommended. Run DFG (Drilling Fluid Graphics) to confirm hole cleaning efficiency based on current rheology, flow rates, angle and cuttings size. Sweep Formulation: 25 bbl of mud with -1 ppb of Barazan D added or 0.25 ppb of Barolift. Dextrid and /or PAC L should be used for filtrate control. While drilling, monitor the torque and drag to determine if liquid lubricant is required. Additions of Condet are recommended to reduce the incidence of bit balling and shaker blinding when penetrating high -clay content sections. Maintain the pH in the 8.5 - 9.0 range with caustic soda. Daily additions of Aldacide G / X -Cide 207 should be made to control bacterial action. M -18 v1.0 2 8/25/08 • • Halliburton BAROID Chevron Mud Program At TD, a Wallnut "flag" (30 bbl pill with 15 ppb of Wallnut Fine) should be pumped to gauge hole washout and to calculate the required cement volume. Spot the above LCM pill in the bottom of the hole. If it has been used, mix a duplicate pill to spot on bottom. The cement will then be pumped and drilling mud will be used to bump the plug. Pretreat this chase mud with 1 ppb Bicarb and 0.5 ppb citric acid. Losses have historically occurred in this interval. Ensure that the mud weight is maintained in the 9.1 -9.2 ppg range through this area. Stress slow pipe movement to the drillers to reduce surge /swab on the zone. Stage pumps on slowly after connections and begin rotation prior to pumping (this will break the gels and reduce the pressure required to break the gels). Spot the above LCM pill in the bottom of the hole. If it has been used, mix a duplicate pill to spot on bottom prior to running casing. Reduce system YP with Barathin as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what yp value they have targeted). Consider spotting a Steelseal LCM pill prior to running the 13 -3/8" casing if losses have been seen in this interval. The plug will again be bumped with mud on the well. This well is a large borehole. Modeling shows that it will become much more difficult to clean if flowrates drop below 1000 gpm. Maintain a minimum 25 YP at all times. Be prepared to increase the YP if hole cleaning becomes an issue. Run DFG (Drilling Fluid Graphics) to confirm hole cleaning efficiency based on current rheology, flow rates and cuttings size. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM-3 600 800 1000 80 rpm 69 92 119 100 rpm 72 96 123 Baroid recommends a flowrate in the 800 gpm range to maximize hole cleaning efficiencies at these higher penetration rates. However if losses occur, the flow rate can be reduced in conjunction with a slower penetration rate which would reduce the ECD /losses. Hazards / Concerns — Surface Interval: • Optimize solids control equipment to maintain density and sand content. • Maintain YP between 25 -35 to optimize hole cleaning and to control ECD. • Pump high viscosity or Barolift sweeps to enhance hole - cleaning efforts. Monitor sweep effectiveness. • Successfully land and cement casing. M -18 v1.0 3 8/25/08 • • Halliburton BAROID Chevron Mud Program Intermediate Hole Section Recommendations Mud Type: 2% KCI, Clayseal, GEM Properties: Densi Viscosi Plastic Viscosi Yield Point API FL • H 1436' -6250' 9.1 -9.3 40 -53 6 - 15 13 - 20 <6 8.5 -9.5 • Additional mud weight may be required for effective coal or shale stabilization. System Formulation: 2% KCI, Clayseal, GEM Product Concentration Water 0.905 bbl KCI 7 ppb (9K chlorides) Caustic 0.2 ppb (9 pH) Barazan D 1.0 ppb (as required 18 YP) Dextrid 1 -2 ppb PAC L 1 ppb Clayseal 4 ppb (initial 1 ppb) Aldacide G 0.1 ppb GEM GP 1.5% by volume Baroid as needed for 9.1 ppg Special Mixing Instructions: • Mix in order as listed • Add polymers slowly to minimize fisheyes. Intermediate Interval (12 -1/4" hole, 9 -5/8" casing to 6250' MD) Mud Type: 9.1 ppg KCl/ ClayseaV GEM System. 1. Mud weight: Maintain the density at 9.1 ppg or as needed; use solids control and whole mud dilution. Increase density as required for hole stability/coal sloughing. Maximize solids control usage. 2. Rheology: Maintain a YP between 13 and 20. Pump high viscosity or Barolift sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation (ideally > 100 RPM). 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. Operations Summary: Mix a -50 bbl LCM pill prior to drilling out. The pill formulation will be the 70 ppb pill from the LCM tree. Mix the recommended LCM material in thinned back base mud. Drill out the cement/casing with the existing mud system. Soda ash and citric acid should be used to pretreat for any negative effects of the cement. After obtaining a leak off, begin drilling ahead displacing to the KCI based fluid. Baracarb 5, 25 and /or 50 should be strung into the system at 4 -8 sx/hr for losses. Barofibre can be added to this mix. The Clayseal concentration should be 1 ppb in the initial mix. As the mud shears, slowly raise the Clayseal concentration to its full 4 ppb concentration. BARAZAN -D should be used to maintain rheological parameters. Maintain the mud as clean as possible while drilling. Should sweeps be required a high viscosity or Barolift sweep is recommended. Sweep Formulation: 50 bbl of mud with -1 ppb of Barazan D added or .25 ppb of Barolift. Dextrid and PAC L should be used for filtrate control (6cc range). Baranex treatments can be made to bring the filtrate down. 2 ppb Barotrol should be added to help control coals and shales. While drilling, M -18 v1.0 4 8/25/08 • • Halliburton BAROID Chevron Mud Program monitor the torque and drag to determine if liquid lubricant is required. If so, approval from town will be required prior to additions of lubricants. Additions of Condet are recommended to reduce the incidence of bit balling and shaker blinding when penetrating high -clay content sections. Maintain the pH in the 8.5 — 9.5 range with caustic soda. Daily additions of Aldacide G / X -Cide 207 should be made to control bacterial action. Maintain Cl- in the 8 -9K range with KCI. Spot the above LCM pill in the bottom of the hole. If it has been used, mix a duplicate pill to spot on bottom. Reduce system YP as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 15 (check with the cementers to see what yp value they have targeted). Consider spotting a Steelseal LCM pill prior to running the casing if losses have been seen in this interval. Suggested Drilling Parameters Pump rate and drill string rotation should be optimized through the real -time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue in this interval. Maximum Acceptable ROP in f 3h at Specified GPM and RPM GPM—) 600 700 800 60 rpm 45 50 52 80 rpm 78 88 97 100 rpm 115 130 151 Rotary speed is the most critical factor in cleaning this highly deviated wellbore. Maximize rpms at all times. ROPs above these levels or with no rotation (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: • extended periods of circulation (with maximum pipe rpm, targeting > 100 rpm) • hole cleaning sweeps (change flow regime of base mud by using fibers, density or rheology for carrying capacity) • connection practices - employing extended gpm, rpm and back reaming during the connection M -18 v1.0 5 8/25/08 • • • Halliburton BAROID Chevron Mud Program 8 -1/2" Hole Recommendations (7" liner) to 9970' Mud Type: 2% KCI, Clayseal, GEM Properties: Densi Viscosi Plastic Viscosi Yield Point API FL • H 6250' — 9970' 9.2 -9.3 40 -53 6 - 15 13 - 20 <5 8.5 -9.5 System Formulation: 2% KCI, Clayseal, GEM Product Concentration Water 0.905 bbl KCI 7 ppb (8 -9 K chlorides) Caustic 0.2 ppb (9 pH) Barazan D 1.0 ppb (as required 18 YP) Dextrid 1 -2 ppb Clayseal 4 ppb Aldacide G 0.1 ppb GEM GP 1.5% by volume Baracarb 50 10 ppb Baroid as needed Mud Type: 9.2 ppg KCI /Clayseal /GEM System. 1. Mud weight: Maintain the density at 9.2 ppg or as directed; use solids control and whole mud dilution. Increase density as required for hole stability/coal sloughing. Maximize solids control usage. 2. Rheology: Maintain a YP between 13 and 20. Pump high viscosity sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation (ideally > 60 RPM). 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. Operations Summary: Mix a -50 bbl LCM pill prior to drilling out. The pill formulation will be the 70 ppb pill from the LCM tree. Mix the recommended LCM material in thinned back base mud. Drill out the cement/casing with the existing mud system. Soda ash and citric acid should be used to pretreat for any negative effects of the cement. BARAZAN -D should be used to maintain rheological parameters. Maintain the mud as clean as possible while drilling. The mud may need centrifuged prior to adding 10 ppb of Baracarb 50 (bridging agent for the "weak" zones). Should sweeps be required a high viscosity sweep or Barolift is recommended. Sweep Formulation: 20 bbl of mud with -1 ppb of Barazan D added or .25 ppb of Barolift. Maintain Clayseal concentrations at 4 ppb and GEM GP at 1.5 -3 %. Dextrid and /or PAC L should be used for filtrate control (5cc range) to TD. While drilling, monitor the torque and drag to determine if liquid lubricant is required. If so, approval from town will be required prior to additions of lubricants. Additions of Condet are recommended to reduce the incidence of bit balling and shaker blinding when penetrating high -clay content sections. Maintain the pH in the 8.5 - 9.5 range with caustic soda. Daily additions of Aldacide G / X -Cide 207 should be made to control bacterial action. The GEM GP can be raised above the 1.5% level to help reduce torque. Do not exceed 3% v/v of GEM GP. Spot the above LCM pill in the bottom of the hole. If it has been used, mix a duplicate pill to spot on bottom. Reduce system YP with Desco as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology M -18 v1.0 6 8/25/08 • • Halliburton BAROID Chevron Mud Program once the casing is landed to a YP < 15 (check with the cementers to see what yp value they have targeted). The plug will be bumped with 3% KCI brine. Suggested Drilling Parameters: Maximum Acceptable ROP in fph at Specified GPM and RPM GPM-* 350 450 550 60 rpm 53 67 81 80 rpm 90 105 138 100 rpm 130 154 176 Production Hole - Hazards / Concerns: • Optimize solids control equipment to minimize colloidal solids build up and dilution requirements. • Maintain flow profile based on PV, YP and tau flow parameters. • Pump sweeps as required to enhance hole - cleaning efforts. Follow the hole cleaning guidelines to assist in drilling parameter selection. Use connections for high RPM and pump rate support when these parameters are limited during drilling operations. • Follow the coal drilling guidelines. Coal Drilling The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The hole stability risks when drilling coal seams are often high, and the fluid design and drilling operations have been optimized to combine reduced risk with reduced costs. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt -type additives to further stabilize coal seams. • Increase fluid density as required to control the running coal. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb BAROTROL pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss (based on ECD values using the DFG software). System density increases can also be employed in increments of 0.5 ppg. Solids Control Equipment Maximize the use of all solids control equipment to ensure that the solids content of the system is kept to a minimum during this interval. 1. Run the shale shakers with as fine a screen size as possible. • Size shakers screens with coarse mesh initially • Adjust screen size as solids loading, mud rheology and flowrates allow • Inspect the shakers frequently, taking time to repair / replace damaged screens 2. Maximize the use of the centrifuge, keeping the fluid as clean as possible. Running Casing / Cementing Preparation Monitor hole fill /returns closely while running the liner to insure losses haven't occurred. Refer to Baroid's DFG+ program if calculated surge /swab values are needed. Condition the mud prior to the cement job. Completion The well will be completed with a 3% KCI brine. If rig ops allow, bump the plug with the brine, then finish displacing the casing after coming off the liner hanger. M -18 v1.0 7 8/25/08 Chevron • •teelhead Platform 4110 Well M -18 %10. Proposed 10/8/08 V8b CASING AND TUBING DETAIL RKB to TBG Head = 78.75' SIZE WT GRADE CONN MIN TOP TOP BTM BTM ID in MD rkb TVD rkb MD rkb TVD rkb Cement to ML 28" Structural 27 Surface Surface 480' 480' @ 385' 13 -3/8" 68 L -80 BTC 12.415 Surface Surface 1436' 1375' 9 -5/8" 47 L -80 BTC -M 8.681 Surface Surface 6250' 2658' z8" Conductor 7" 26 L -80 DWCSR 6.276 6050' 2567' 9970' 4335' Al iii @ 480 Tubing 3 -1/2" 9.2 L -80 HSO3 2.992 Surface Surface TBD TBD ECP Stage Collar Logging Detail H ole LWD /MWD Wire Line Mud Logging Notes Section 17' /x" gMWD /GR Gas Detection, Consulting Geologist Res (Memory Mud Logging i i 13 3/8" in 17 %" Hole only) 12'/d" GR/Res/ Dens- Gas Detection, Consulting Geologist 9 5/8 Hydraulic Stage Neut Mud Lo in Collar @ —2900 (300' gg g Below SZ15 CB 8 '/2" GR/Res/ Dens- Gas Detection, Consulting Geologist Neut, TesTrak Mud Logging TOC @ —4470 (300' above SZ16 CT) 9 5/8" Casing in 12 'A" Hole . ,�► fi V AC r xF . } • A / A 7" Liner in 8 1/2" Hole Well Detail MAX HOLE ANGLE = 88° @ 2542' MD JAR 10/8/08 Chevron nag IWO C hevron BAKER HUGHES ilik. Location: Cook Inlet, Alaska (Offshore) Slot: slot #B2 -2 INTEQ Field: McArthur River Field Well: M -18 Facility: STEELHEAD Platform Wellbore: M -18 Plot reference v°elpath is M -18 Version8BB Well Profile Data True vertical depths are referenced to Actual Datum (R1(5) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feel Measured depths are referenced to Actual Datum(RKB) North Reference: True north Design Comment MD (ft) Inc ( Az ( TVD (ft) Local N (ft) Local E (ft) DLS ( °/100ft) VS (ft) Actual Datum (RKB) to mean sea level: 160.25 feet Scale: True diatance Tie On 0.00 0.000 71.565 0.00 0.00 0.00 0.00 0.00 mean sea level to Mud line (Facility: STEELHEAD Platform) :0 feet Depths are in feet End of Tangent 539.97 0.000 71.565 539.97 0.00 0.00 0.00 0.00 Coordinates are in feet referenced to Slot Created by: railcard on 10/10/2008 End of Build 740.83 9.039 71.565 740.00 5.00 15.00 4.50 10.00 Hole and Casing Sections End of 3D Arc 2542.45 87.974 15.545 1865.26 1118.78 473.56 4.60 1214.04 Start End Start End Start Start End End End of Tangent 4247.67 87.974 15.545 1925.55 2760.60 930.26 0.00 2911.00 NvrrM MD (!) MD m> Interval (ft) 150 (ft) TOO (ft) Loco/ N (ft) Local E)e) Local N (ft) Load E 6u wJSOrs End of 3D Arc 5027.84 64.756 18.607 2108.25 3480.61 1150.39 3.00 3662.24 28in Conductor 0.00 485.00 485.00 0.00 485.00 0.00 0.00 0.00 0.00 M -18 17.5in onar Hale 485.00 1436.97 95097 4e5.00 1376.00 0.00 0.00 200.12 ,60.e6 M-111 End of 3D Arc 5168.57 63.198 22.975 2170.02 3598.81 1195.23 3.00 3788.65 13.375in Casing Intermediate 0.00 1435.97 1435.97 0.00 1375.00 r 0.00 0.00 220.12 160.66 M -16 End of Tangent 9043.49 63.198 22.975 3917.25 6783.10 2545.22 0.00 7244.83 12.25n Open HOW 1435.97 6250.00 4814.03 1375.00 2657.64 220.12 160.66 4407.49 1571.99 1.4-113 End of Tangent 9970.51 63.198 22.975 4335.25 7544.89 2868.18 0.00 8071.67 • 9.625n asap 0.00 6250.00 8250.00 0.00 2857.64 0.00 0.00 4487.49 1571.99 M -18 8.5in Open Hob 6250.00 9970.51 3720.51 2657.644 4335.25 4487.49 1571.99 7544.89 2866.18 M -18 An Liner 6050.00 9970.51 3920.51 2567.46 4335.25 4323.14 1502.31 7544.89 2868.18 14-18 Easting (ft) Scale 1 inch = 2500 8 N -2500 -1250 0 1250 2500 3750 5000 1 8750 Vi 3 E °0 orr B a 18.6 2610.0 a s t 3.62° Field: 55519.5nT Maprcoc ac Norm Nmlh alb fib degrees ev E of True North (at l2llr M6) � y 7500 1 din doer 6250 # -1250 - /∎ �� 5000 �. r 0 28in Conductor � c�0 11001k c 9 625 7n Casin 9 • o M. End of Tangent h - c n M18 Tgt SZ17CT (8- May -08) 3750 m - End of Build 0 Cf` Q o 9 g . - 1250 U � � d rOO a O \ � O o o O Q � c o'°' A • rc L v 0 ., Q 93�y`c Q 4 ' W n ]u �a � 4, End of T an9enr 2500 2500 1 p A Q a1 SP a) a ` �`D ° 4 1;\ C. a) C . o r g M 18 Tgt Landing Point f� 0 3750 co a 3p Are 40 13 s lot #B2 -2 t 3 js; 0 .. y CI. F of .? o i c as7j' 9 5000 3 f tee u c o 9%, c -1250 , 8250 R -2500 -1250 0 1250 2500 3750 5000 6250 7500 8750 Vertical Section (ft) Scale Inch' 2500 Azimuth 20.81 ` with reference 0.00 N, 0.00 E • • Chevron FAR It. Planned Wellpath Report BAKER IMO M -18 Version #8B MYGMES Page 1 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator !Chevron [Slot (slot #B2 -2 Area Cook Inlet, Alaska (Offshore) Well M -18 'Field !McArthur River Field Wellbore FM 18 !Facility 1STEELHEAD Platform 1 REPORT SETUP INFORMATION Projection System r NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet }So ftware System [WellArchitect® 2.0 North Reference True 'User Ulricard 'Report _ .. _._ 1-9/2-5/2008 2 :4 onv .. Scale 0 999993 Re ort Generated at 12 45 PM Convergence at slot 140 West IDatabase /Source file Anchorage/M 18 xml WELLPATH LOCATION r Local coordinates Grid coordinates Geographic coordinates a North[ft] ; East[ft] 1 Easting[USft] Northing[USft] Latitude Longitude !Slot Location j 1040.02 606.93 [ 214222.01 2499459 54 1 60°49'54.561"N 1 151°36'05.775"W [Facility Reference Pt i 213640 71 2500514 08 60 °50'04.803 "N T 151 °36'18.018 "W Field Reference Pt I 1 213640.71 2500514 08 60 °50'04.803 "N 151 °36'18.018 "W WELLPATH DATUM Actual Datum (RKB) to Facility Vertical !Calculation method Minimum curvature i 1160.25ft )Datum r Horizontal Reference Pt Slot 'Actual Datum (RKB) to mean sea level 160.25ft }Vertical Reference Pt Actual Datum (RKB) Facility Vertical Datum to Mud Line (Facility) ,0 00ft Kin Reference Pt ; Actual Datum (RKB) Section Origin IN 0.00, E 0.00 ft "Field Vertical Reference mean sea level Section Azimuth )20.81° • • Chevron Fedi 111 Planned Wellpath Report BAKER INN. M- 18 #8B HUGH Page 2 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator iChevron Slot 'slot #B2 -2 Area Cook Inlet, Alaska (Offshore) Well 1M -18 Feld 'McArthur River Field Wellbore 1M -18 Facility STEELHEAD Platform I WELLPATH DATA (108 stations) f = interpolated /extrapolated station MD Inclination ' Azimuth TVD TVD from , Vert Sect North East Grid East Grid North DLS [ft] 1 0 1 [ ! [ft] Fld Vert Ref [ft] [ft] [ft] [sry ft] Ism ft] [ ° /100ft] - [_ L 0.00 1 , 0.000 71.565 0.00 - 160.25 ; 0.00 0.00 0.00 214222.01 2499459.53 0 0 0 100.00t1 0.000 7 1.565 100.00 - 60.25 0.00 0.00 0.00 214222.01 2499459.53 0.00 L 200.00t 0.0001 7 1.565 200.00 r 39.75 j 0.00 0.00 0.00 1 214222 01 2499459 53 0.00 300.00f 0.000 71.565 300.00 139.75 1 0.00 0.00 0.001 214222 01 i 2499459 53 0.00 k. . 400.00' 0.000 71.565 400.00 239.75 0.00 0.00 0.00 'F` 1 p "' ' 0.00 r 500.00f ; 0.000 71.565 500.00 339.75 0.00 0.00 0.00 214222.01 2499459.53 0.00 F- 539.97 r 0.000 71.565 539.97, 379.72 0.00' 0.00 0.001 214222.01 2499459.53 0.00 600.001 2.702 71.565 599.98 ` 439.73 0.90 0.45 1.34 ' 214223.37 2499459.95 4.50 700.00j'1 7.202 71.565 699.58 539.33 6.35 3.18 9.53 214231.62 2499462.48 4.50 740.8 `.N 9.039 'T1.5. 4 740.00 57935 10.00 5.00 15.00 214237.13 2499464.17 4.50 800.00t1 -- 10.779 `,9.312 798.29 638.04 17.28 9.29 24.17 214246.40 2499468.24 4.60 900.00' 14.422 46 245;. 895.88 735.63 35.85 22.69 41.21 214263.77 I 2499481.21 4.60 � _ 1000.00 18.492 38.58 991.78 831.53 62.21 43.71 60.11 214283.17 2499501.76 4.60 L 1100.00 -- 22.761 33.661' 1085.35 925.10 96.19 72.22 80.73 214304.49 II 2499529 76 f 4.60 , ,, 1 200.00'• 27.136 30.240 1176.00 1015.75 137.57 108.04 102.95 214327.57 " I r 1300.001: 31.571 27.712 1263.15 1102.90 186.09 1 150.94 126.63 j 214352.28 2499607.34 4.60 r 1400.001 36.0451 25.753` 1346.22 I 1185.97 241 42 200.64 , 151.601 214378.46 2499656.42 4.60 1500.00t 40.5451 24.175 1424.681 1264.43 303.21 ' 256.82 r 177.70 1 214405.93 2499711.94 4.60 I 1600.00t 45.063 22.864 1498.04 1337.79 371.06 319.12 204.78 214434.52 2499773.56 4.60 1700.00f 49.593 ` 21.745 1565.80 1405.55 444.54 387.14 232.65 214464.04 2499840.87 4.60 _ 1800.00 f 54.133 20.767 1627.54 1467.29 523.17 460.43 261.14 214494.31 2499913.44 4.60 1900.00 58.680 19.895 1682.85 1522.60 606.44 538.52 290.06 214525.13 2499990.81 4.60 2000.001• 63.232 19.104 1731.39 1571.14 693.82 620.91 1 319.22 214556.29 2500072.46 1 4.60 2100.00t 67.788 18.374 1772.83 1612.58 784.74 707.07 I 348.44 214587.60 2500157.88 4.60 2200.00f 72.348 [7.690 1806.92 1646.67 878.61 796.44 377.52 214618.86 2500246 52 7: 4.60 2300.00t ? 76.909 17.040 1833.42 t 1673.17 974.83 888. 45 406.29 214649.86 2500337.79 , 4.60 1 2400.00f 81.472 16.413 1852.17 16971.92 1072.78 982.49 434.54 ! 214680.40 2500431.12 4.60 2500.00f 86.036 15.802 1863.04 1702.79 1171.83 1077.97 462.11 214710.30 2500525 89 4.60 2542.45 87.974 15.545 1865.26 1705.01 1214.04 1118.78 473.56 214722.74 2500566.41 4.60 2600.001 87.974 15.545 1867.29 1707.04 1271.32 1174.19 488.98 214739.50 2500621.43 0.00 2700.00''1 87.974 15.545 1870.83 1710.58 1370.83 1270.48 515.76. 214768.63 2500717.03 0.00 - -- - -- 2800.00f' 87.974 15.545 1874.37 1714.12 � 1470.35 1366.76 542.54 1 214797.75' 2500812.63 r 0.00I 2900.001' 87.974 15.545 1877.90 1717.65 1569.86 1463.04 569.33 214826.87 2500908.23 0.00 3000.001 87.974 15.545 1881.44 1721.19 1669.38 1559.32 596.11 214856.00 2501003.83 0.00 3100.00f 87.974 15.545 1884.97 1724.72 1768.89 1655.60 622.89 214885.12 2501099.43 0.00 3200.001 87.974 15.545 1888.51 1728.26 1868.41 1751.89 649.67 214914.25 2501195.03 0.00 r 3300.001 87.9743 15.545, 1892.04 1731.79 1967.92 1848.17 676.45 214943.37 2501290.62 0.00 r 3400.001 87.9747 1895.58 1735.33 2067.44 1944.45 703.24 214972.49 2501386.22 _ 0.00 6, 3500.00f 87.974' 15.545 1899.11 1738.86 2166.95 2040.73 730.02 215001 62 72501481 82 0.00 3600.00f 87.974 15.545 1902.65 1742.40 2266.47 2137.01 756.80 215030.74 2501577 42 ; `" 0.00 r 3700.00 87.974; 15.545 1906.19 1745.94 2365.98 2233.30 783.58 215059.87 2501673.02 0.00 3800.00'1 87.974 15.545 1909.72 1749.47 2465.50' 2329.58 1 810.37 215088.99 2501768.62 r 0.00 3900.00ft 87.974; 15.545 1913.26 1753.01 2565.01 2425.86 837.15 215118.11 2501864.22 0.00 4000.001 87.974' 15.545' 1916.79 1756.54 2664.53 2522.14 863.93 215147.24 2501959.82 0.00 4100.00t 87.974 15.545 1920.33 1760.08 2764.04` 2618.42 890.71 , 5176.36 250 K k. ;, ;M e 1- • • Chevron Vail' IOW. Planned Wellpath Report FAKER IMMO M -18 Version #8B HUGHES Page 3 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #B2 -2 [Area 'Cook Inlet, Alaska (Offshore) Well M -18 [Field_ `,McArthur River Field Wellbore 1 M -18 [Facility 1STEELHEAD Platform 1 I WELLPATH DATA (108 stations) 1' = interpolated /extrapolated station MD Inclination Azimuth TVD TVD from Vert Sect ; North East Grid East Grid North DLS [ft] [ I ° ] [ft] Fld Vert Ref [ft] 1 [ft] [ft] [sry ft] Ism ft] [ ° /looft] [ft] 4200.001 87.974 15.545 1923.86 1763.61 1 2863.56 2714.70 917.49 215205.49 ( 2502151.01 0.00 F 87.974 15.545 1925.55 1765.30 5 - 4300.00t 86.416 15.736, 1928.11 1767.86 2963.05 28 944.35 r ------ 215234.68 ? 2502246.56 3.00 4400.001 83.438 16.104' 1936.95 1776.70 3062.28 2906.71 971.67 215264.33 2502341.64 3.00 4500.00t 80.461 16.476 1950.95 1790.70 3160.98 3001.74 999.44f ° • • " , > a 1 I 4600.00t 77.484 16.855 1970.08 1809.83 3258.86 3095.76 1027.58 215324.84 2502529 26 ' 3.00 4700.00t 74.508 17.242: 1994.28 1834.03 3355.67 3188.51 1056.02 215355.541 2502621.29 ; 3.00 4800.00t 71.532 17.641 2023.48 1863.23 3451.13 3279.75 1084.68 215386.42 1 2502711.801 3.00 4900.00t 68.557 18.054 2057.60 1897.35 3544.99 3369.21 1113.49 215417.39 2502800.53 3.00 5000.001 65.583 18.484 2096.56 1936.31 3636.99 3456.66 1142.35 215448.38 2502887.25 3.00 5027.84 64.756 18.607 2108.25 1948.00 3662.24 3480.61 1150.39 215457.00 2502911.00 3.00 5100.001 63.941 20.832 2139.49 1979.24 3727.27 3541.84 1172.33 215480.43 2`02971.67 3.00 5168.57 63.1981 22.975 2170.02 2009.77 3788.65 3598.81 1195.23 215504.71 2503028.07 3.00 5200.00( 63.198 22.975 2184.19 2023.94 3816.68 3624.64 1206.18 r 215516.29 2503053.62 0.00 5300.001 63.198 22.975 2229.28 2069.03 3905.88 3706.81 1241.02 215553.12 2503134.92 0.00 5400.001 63.198 22.975 2274.37 2114.12 3995.07 3788.99 1275.86 215589.96 2` 03216.22 0.00 r 5500.00ti 63.198 22.975 2319.46 2159.21 4084.27 3871.17 I 1310 70 215626.79 2`+03297.52 0.00 5600.001 63.198 22.975 2364.55 2204.30 4173.46 3953.34 7 215663.63 2503378.82 0.00 5700.001 63.198 22.975 2409.64 2249.39 4262.65 4035.52 1380.37 215700.46 2503460.12 0.00 t.' 5800.001 63.198 22.975 2454.73 2294.48 4351.85 4117.70 1415.21 215737.30 2503541.43 0.00 P 00 63.198 22.975; 2499.82 2339.57 4441.04 4199.87 1450.05 215774.13 25"03622.73 0.00 6000. r t 63.1981 22.975 2544.91 2384.66 4530.23 4282.05 1484.89 215810.96 2503704.03 0.00 F 6100.001 63.1981 22.975 2590.00 2429.75 4619.43 4364.23 1519.731 215847.80 2503785.33 0.00 6200.001 63.198 22.975 2635.10 2474.85 4708.62 4446.40 1554.57 215884.63 2503866.63 0.00 6300.00 - 63.198 22.975 2680.19 2519.94 4797.81 4528.58 1589.41 215921.47 2503947.93 0.00 6400.001 { - -- 63.198 22.975 2725.28 2565.03 4887.01 4610.76 1624.25 215958.30 2504029.23 0.00 6500.00t' 63.198 22.975 2770.37 2610.12 4976.20 4692.94 1659.09 215995.14 2504110.54 0.00 6600.001, 63.198 22.975 2815.46 2655.21 5065.39 4775.11 1693.93 216031.97 2504191.84 0.00 6700.00t[ 63.198 22.975 2860.55 2700.30 5154.59 4857.29 1728.77 216068.80 2` 04273.14 0.00 I 6800.004 ' 63.198 22.975 2905.64 2745.39 5243.78 4939.47 1763.61 216105.64 2504354.44 6760 j 6900.001 63.198 22.975 2950.73 2790.48 5332.98 5021.64 1798.44 216142.47 2504435.74 0.00 I 7000.001E 63.1981 22.975 2995.82 2835.57 5422.17 5103.82 1833.28 216179.31 1 2504517.04 0.00 F - 7100.001 63.198 22.975 3040.91 2880.66 5511.36 5186.00 1868.12 216216 14 1 2504598.34 0.00 7200.001 63.198 22.975 3086.00 2925.75 5600.56 5268.17 1902.96 216252.97 2504679.65 0.00 •11 7300.00t 63.198 22.975 3131.09 2970.84 5689.75 5350.35 1937.80 216289.81 2`04760.95 0.00 7400.001 63.198 22.975 3176.19 3015.94 5778.94 5432.53 1972.64 216326.64 2504842.25 0.00 r 7500.001 63.198 22.975 3221.28 3061.03 5868.14 5514.71 1 2007.48 216363 48 j 2504923.55 0.00 _ _ 7600.001 63.1981 22.975 3266.37 3106.12; 5957.33 5596.88 2042.321 216400 31 i 2505004.85 0.00 r 7700.001 63.198 22.975 3311.46 3151.21 [ 6046.52 5679.061 2077.16 216437.15 2505086.15 0.00 ` _ 7800.00t 63.198 22.975 3356.55 3196.30 6135.72 5761.24 2112.0& , a . °2505167.45 ' 0 .00 7900.001 63.198 22.975] 3401.64 3241.39 6224.91 5843.41 2146.84 216510.81 r 2505248.75 0.00 8000.001 63.198: 22.9751 3446.73 3286.48 6314.11 5925.59 2181.67 216547.65 7 2505330.06 0.00 r 8100.001 63.198 22.975r 3491.82 3331.57 6403.30 6007.77 2216.51 216 r 2505411.36 0.00 8200.001 63.198 22.975r 3536.91 3376.66 6492.49 6089.94 2251.35' 216621.32 2505492.66 0.00 8300.001 63.198 22.975' 3582.00 3421.75 6581.69 6172.12 2286.19 216658.15 2■05573.96 0.00 . 0 Chevron Mill ft. Planned Wellpath Report BAKER %WI M -18 Version #8B HUGHES Page 4 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #B2 -2 Area Cook Inlet, Alaska (Offshore) Well M -18 Field McArthur River Field Wellbore 1M -18 Facility STEELHEAD Platform I I WELLPATH DATA (108 stations) 1' = interpolated /extrapolated station MD Inclination Azimuth = TVI) TVD from Vert Sect North East Grid East Grid North DLS [ft] 1 °1 1°1 [ft] Fld Vert Ref [ft] [ft] [ft] [sry ft] [sry ft] [ ° /100ft] lft1 8400.00t 63.198 22.975; 3627.09 3466.84 6670.88 6254.30 2321.03 216694.98 2505655.26 0.00 8500.00t' 63.198 22.975 3672.18 3511.93 6760.07 6336.47 2355.87 216731.82 2505736.56 0.00 L, 8600.00] 63.198 22.9751 3717.28 3557.03 6849.27 6418.65 2390.71 216768.65 , 2505817.861 0.00 8700.00t 63.198 22.975 3762.37 3602.12 6938.46 6500.83 2425.55 216805.49 2505899.17 0.00 8800.00f 63.198 22.975 3807.46 3647.21 7027.65 6583.01 2460.39 216842.32 2505980.47 0.00 L 8900.00t 63.198 22.975 3852.55 3692.30 7116.85 6665.18 2495.23 216879.16 2506061.77 0.00 9000.00t 63.198 22.975 3897.64 3737.39 7206.04 6747.36 2530.07 216915.99 2506143.07 ' 0.00 9043.49 63.198 22.975 3917.25 3757.00 7244.83 6783.10 2545.22 216932.01 2506178.43 0.00 9100.00t 63.198 22.975 3942.73 ; - 3782.48 7295.23 6829.54 2564.91 216952.82 2506224.37 0.00 9200.00t 63.198 22.975 3987.82 3827.57 7384.43 6911.71 2599.74 216989.66 2506305.67 0.00 r 9300.001 63.198 22.975, 4032.91 3872.66 7473.62 6993.89 2634.58 217026.49 2506386.97 0.00 9400.00 63.198 22.975, 4078.00 3917.75 7562.82 7076.07 2669.42 217063.33 2506468.28 0.00 9500.00t 63.198 22.975 4123.09 3962.84 7652.01 7158.24 2704.26 217100.16 2506549.58 0.00 9600.00t' 63.198 22.975 4168.18 4007.93 7741.20 7240.42 2739.10 217137.00 2506630.88 0.00 9700.00t 63.198 22.975 4213.27 4053.02 7830.40 7322.60 2773.94 217 2506712.18 0.00 9800.00j 63.198 22.975 4258.37 4098.12 7919.59 7404.77 2808.78 217210.66 2506793.48 0.00 9900.00t 63.198 22.975 4303.46 4143.21 8008.78 7486.95 2843.62 217247.50 2506874.78 0.00 ' 9970.51 63.198 22.975 4335.25 - 4175.00 8071.67 7544.89 2868.18 217273.47 ! 2506932.11 j 0.00 HOLE & CASING SECTIONS Ref Wellbore: M - 18 Ref Wellpath: M String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W ; End N/S End E/W [ft] [ft] [ft] [ft] [ft] [ft] [ft] i [ft] I [ft] 28in Conductor 0.00 485.00 485.00 0.00 485.00, 0.00' 0.00 0.001 0.00' 17.5in Open Hole 485.00 1435.97 950.97 485.00 1375.007 0.00; 0.001 220.12 160.86 13.375in Casing Intermediate 0.00: 1435.97 1435.97 0.00 1375.00 0.00 j 0.001 220.12 160.86 12.25in Open Hole 1435.97( 6250.00 4814.03 1375.00 2657.64 220.121 160.86 4487.49r 1571.99, 9.625in Casing 0.00 6250.00 6250.00! 0.00 2657.641 0.00 0.001 4487.491 1571.991 8.5in Open Hole 6250.00 9970.51 3720.51 2657.64 4335.25 4487.49 1571.99 7544 89 2868.18 Tin Liner 6050.00 9970 51 3920.51' 2567.463 4335.251 4323.14 1502.31 7544 891 2868.1 Chevron Fail Ill.. Planned Wellpath Report BAKER %ill M -18 Version #8B HUGHES Page 5 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION [Operator (Chevron Slot slot #B2 -2 'Area Cook Inlet, Alaska (Offshore) Well M -18 Field McArthur River Field Wellbore M -18 Facility STEELHEAD Platform F TARGETS t Fsame 1 MD TVD North East Grid East Grid North Latitude Longitude I Shape [ft] [ft] [ft] [ft] [sry ft] [sry ft] 2542.45 1865.26 1118.78 473.56 214722.74 2500566.41 60 °50'05.578 "N 151 ° 35'56.221 "W point 1 ) M18 Tgt Landing Point F F 5 027.84 2108.25 3480.61 1150.39 215457.00 2502911.00 60 °50'28.g1 e 1 7 - 1. �42.562"f oint 2) M18 Tgt SZ17CT (8 May - 08) , p r9043.49 3917.25 6783.10 2545.22 216932.01 2506178.43 60 °51'01.354 "N 151 °35'14.402 "W point 3) M18 Tgt to avoid K -20 SURVEY PROGRAM Ref Wellbore: M -18 Ref Wellpath: M -18 Version #8B Start MD End MD I Positional Uncertainty Model Log Name/Comment Wellbore [ft] [ft] 0.00 485.00 SDI Keeper M -18 485.00 1020.00 SDI Keeper M -18 M -18 1020.00 9970.5 1 OnTrak (SAG, Magcorrl) Steelhead M -18 Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE 17 -1/2" Hole Section • Shallow gas sands will be encountered that have the potential to flow and cause a loss of well control. All operations shall proceed with the necessary precautions to prevent a kick. Special attention is required in the following areas: 1. Monitor trip tank on each trip into and out of the hole. 2. Carefully monitor PVT for gain / loss. 3. Have LCM material onboard and ready for use in the event significant losses occur. 4. Minimize surge and swab pressures while tripping. 5. Review cement spacers and washes to ensure the well is not under balanced at any point during cementing operations. 6. Perform diverter drills until the crews are familiar with the procedure. • M -9, M -2, M -3, M -4 are all critical close approach wells. Record annulus pressures on these wells prior to spud and monitor during the drilling of the surface and 1St intermediate hole sections. 12 - 1/4" Hole Sections • Shallow gas sands will be encountered that have the potential to flow and cause a loss of well control. All operations shall proceed with the necessary precautions to prevent a kick. Special attention is required in the following areas: 1. Monitor trip tank on each trip into and out of the hole. 2. Carefully monitor PVT for gain / loss. 3. Have LCM material onboard and ready for use in the event significant losses occur. 4. Minimize surge and swab pressures while tripping. 5. Review cement spacers and washes to ensure the well is not under balanced at any point during cementing operations. 8 - 1/2" Hole Section • Significantly under pressured reservoir sands will be encountered A heightened awareness of kick detection, pre -job planning and trip tank calibration will be essential while drilling /trip ping the intermediate interval. • Loss circulation is considered to be a major risk due to the depleted reservoir sands which will be encountered. Loss circulation materials will be readily available for adding to the mud system should significant losses be encountered. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures • Differential sticking is a considerable risk while drilling these depleted sands. Keep the drill string moving whenever possible. • Numerous coals will be drilled through. Unocal coal drilling strategy; limiting the amount of coal drilled ( <10') prior to back reaming should be followed. HYDROGEN SULFIDE - H2S • Steelhead is designated as an H2S drill site. Standard Operating Procedures for H2S precautions should be followed at all times. Version 1.0 Rigsite Hazards and Contingencies • McArthur River Field Steelhead Platform , M -18 Proposed ADL018772 M -18 Proposed TD X: 217273.5 Y:2506932 ADL017594 Grayling. ADL018730 SZ12ST — X: 214483.3 Y: 2499887 Steel ead Surface Location X: 214222 Y: 2499460 T9N - R13W T8N - R13W A - ADL018729 ADL017579 L_. Chevron ID X Y Location 0 500 1,000 Surface 214222.00 2499460.00 1040' FNL, 377' FWL, Sec 33, T9N, R13W, S i Feet State Plane Alaska - SZ12ST 214483.30 2499887.00 606' FNL, 605' FWL, Sec 33, T9N, R13W, S Zone4NAD27 Union Oil Company TD 217273.50 2506932.00 1224' FSL, 1794' FEL, Sec 21, T9N, R13W, S Septamber 3, 2008 of California Chevron IOW Steelhead Platform Well M -18 M O O Drilling Program 2008 M -18 Cement Calculations Surface Casing • 13 3/8 ", 68 ppf, Surface Casing in 17 Hole, Stage 1 Cement from section TD at 1436' to the ECP stage tool at 470' OH Volume w/ 100% excess = (1436- 470)*0.1237 *2 = 239.0 bbls Shoe Track Volume = 80 *0.149 = 12.0 bbls Stage 1 Total Volume = 239 +12.0 = 251 bbls of 13.0 ppg LiteCrete Slurry 13 3/8 ", 68 ppf, Surface Casing in 34 OD x Various ID Structural Pile Conductor, Stage 2 Cement from 470' to surface (ECP is 10' long) • Annular Volume = 470 *0.7005 = 329 bbls Stage 2 Total Volume = 329 bbls of 13.0 ppg LiteCrete Slurry Notes: 1 Used 30" ID as average for volumetric calculations. Chevron Steelhead Platform Well M -18 Drilling Program 2008 Intermediate Casing 9 5/8 ", 47 ppf, Intermediate Casing in12 1/4" Hole, Stage 1 Cement from section TD at 6250' to 4470' OH Volume w/75% excess = (6250- 4470) *0.0558 *1.75 = 173.8 bbls Shoe Track Volume = 80 *0.0732 = 5.86 bbls Total Volume, Stage 1 = 173.8 + 5.86 = 179.7 bbls of 12.0 ppg LiteCrete Slurry 9 5/8 ", 47 ppf, Intermediate Casing inl2 /4" Hole, Stage 2 Cement from stage collar at 2900' to ML at 345' OH Volume w/75% excess = (2900 - 1436) *0.0558 *1.75 = 142.9 bbls Cased Hole Volume = (1436- 345) *.0597 = 65.2 bbls Total Volume, Stage 2 = 142.9 + 65.2 bbls = 208.1 bbls of 12.0 ppg LiteCrete Slurry Chevron 11410 Steelhead Platform %OP Well M -18 Drilling Program 2008 Production Liner 7 ", 26 ppf, Production Liner in 8'/2" Hole Cement from section TD at 9970' to 5750' (500' inside the 9 5/8" casing) OH Volume w /50% excess = 9970 - 6250 *0.0226 *1.5 = 126.0 bbls Shoe Track Volume = 80 *0.0383 = 3.1 bbls Cased Hole Annular Volume = 500 *0.0256 = 12.8 bbls Total Cement Volume = 126.0 + 3.1 + 12.8 = 141.9 bbls of 15.8 ppg G LXT Slurry S Chevron 1 Steelhead Platform Well M -18 4.1 , Drilling Program 2008 M -18 Casing Design Tensile Tensile Design Design Design Internal Collapse Strength Strength Safety Safety Safety Size Wt Yield Resistance Body Conn MD TVD Factor Factor Factor (in) (ppf) Grade Conn (psi) (psi) (M Ibs) (M Ibs) (ft RT) (ft RT) T2 B3 C4 28 Structural] 13 3/8 68 L -80 BTC 5020 2270 1556 1478 1436 1375 14.43 13.75 3.41 9 5/8 47 L -80 BTC -M 6870 4760 1086 1031 6250 2658 4.12 6.08 3.70 7 26 L -80 DWCSR 7240 5410 604 573 9970 4335 2.60 6.41 2.58 Notes: I Existing 28 " -32" OD structural pile conductor set in 1986. 2 Tension safety factor is calculated with buoyancy effects. 3 Burst safety factor is based on MASP. 4 Collapse safety factor assumes evacuated casing. • Chevron ONO Steelhead Platform Well M -18 %MO Drilling Program 2008 M -18 Maximum Anticipated Surface Pressure Calculations 17'/2" Surface Hole, 13 3/8 Casing The 17 Y2" surface hole will be drilled to approximately 1436'/1375' MD/TVD under an existing structural pile conductor and will use a diverter system for well control. The diverter system is not designed to shut the well in and contain pressure. Therefore, MASP is 0 psig for this hole section. 12 'I" Intermediate Hole Section, 9 5/8" Casing The 12 '/4" intermediate hole section will be drilled from 1375' TVD to 2658' TVD. MASP will be the lesser of Bottom Hole Pressure ASP from the deepest exposure or Fracture Gradient ASP at the deepest casing shoe. FG ASP Predicted Fracture Gradient = 12.8 ppg 1375 x 12.8 x 0.052 = 915 psig. Correcting for gas gradient -3 915 - (1375 x 0.10) = 778 psig Therefore, FG ASP = 778 psig BHP ASP Depth of next hole section = 2658' TVD. Taking a conservative approach, the maximum predicted mud wt at section TD = 9.3 ppg. The maximum predicted pore pressure at TD = 9.1 ppg. Chevron Steelhead Platform Well M -18 Drilling Program 2008 Pressure of gas column —* 0.7 x 2658 x 0.10 = 186 psig Pressure of mud column — 0.3 x 2658 x 9.3 x 0.052 = 386 psig Pore pressure = 2658 x 9.1 x 0.052 = 1258 psig Therefore, BHP ASP = 1258 - 386 - 186 = 686 psig • MASP = 686 psig 8'/2" Hole Section, 7" Liner The 8 '/2" production hole section will be drilled from 2658' TVD to 4335' TVD. MASP will be the lesser of Bottom Hole Pressure ASP from the deepest exposure or Fracture Gradient ASP at the deepest casing shoe. FG ASP' Predicted Fracture Gradient = 12.8 ppg 2658 x 12.8 x 0.052 = 1769 psig. Correcting for gas gradient —* 1769 - (2658 x 0.10) = 1503 psig Therefore, FG ASP = 1503 psig BHP ASP Depth of next hole section = 4335' TVD. Taking a conservative approach, the maximum predicted mud wt at TD = 9.3 ppg. The maximum predicted pore pressure at TD = 9.1 ppg. Pressure of gas column -* 0.7 x 4335 x 0.10 = 303 psig 49: c „k 5 - 0S p5't ‘ D0 ANC �5 $ 00C DQ \ - X33 =- 1 S y•S\ Chevron %la Steelhead Platform Well M -18 4110 Drilling Program 2008 Pressure of mud column —* 0.3 x 4335 x 9.3 x 0.052 = 629 psig Pore pressure = 4335 x 9.1 x 0.052 = 2051 psig Therefore, BHP ASP = 2051 - 629 - 303 = 1119 psig MASP = 1119 psig • Notes: 1 FG ASP calculations assume an evacuated wellbore. 2 BHP ASP calculations assume a 70% evacuated wellbore and 30% mud column. • • • Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT /LOT results are defined as follows: • Formation Integrity Test (FIT) - Formation is tested to a pre- determined equivalent mud weight. • Leak -Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the leak -off point. • LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak -offs. • Open Hole LOTs (OH LOTs)- Leak -off tests performed with open hole from the casing shoe to some point above the target reservoir. Generally done when leak -off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is required of being able to achieve estimated mud weight. Procedure for FIT: 1. Drill 20' of new hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1 /4 to 1 /2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1- minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre- determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular pumping will be done on a well, the formation below the surface shoe is taken to leak -off. This ensures that future disposal fluids can pumped away without risk of damage to the surface shoe. If two attempts at establishing leak -off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per definition above), then an open -hole LOT is performed. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre- determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Chevron Plot reference wellpath is M -18 Version #88 Mill WI Ch evro n Tree venea deMK are reference to Actual Datum (RPM) God S e m NAM/ „M Alaska State Plane. �e 4 5�� s feet BAKER Measured .M. are referenced to Actual Datum (ROB) actual North Revere stance no. HUGHES W. Location: CooklnletAlaska(Offshore) Slot: slot #B2 -2 m �RKe�,e�... «a�erbso xsree, ea�e:r,�ea�.roze c Field: STEELHEA la Well: M -18 mar,eeaMeenaMwlee Facility: STEELHEADPIatform Wellbore: M -18 ren=eM "r= AORlenemrl.oreet Dept. are in het W' INTEQ Coordinates are In lest referenced to o Slot Slol created . uincerd on 1092008 1 Sak ch , in=15 Easting (ft) -30.0 -225 -15.0 - 75 0.0 7.5 15.0 225 30.0 375 45.0 52.5 60.0 673 75.0 823 90.0 97.5 105.0 I ®� M - 18 `� M_9 • O� 1 675 1 200 900 1 20 0 1 60.0 M' 110 52.5 • N O 70 45.0 I ' 9 .0 X0 0 1 1 000 0 A/C)'' 37.5 30.0 9 00 Z 1 o O o P. : � > 1000 �0� 5 tie 0 00 `' s 223 co 1000 • 1 8 0 $ 0 0 1900 00 �$ 1800 9 00 00 15.0 1700 • 7 00 n ' 1600 /�. �, s X • 0 ak • 0 °0 7.5 , ,4 0`.\ .. , SIOt '-T� • x 0 O •' o o ' - 11 40 " - 0 o slo � „' ° •�� _3 " 600 o 0 700 ep h -7.5 7, o 80. 9.,, 900 -15.0 ® oo MS a -22.5 • • Chevron Fait' Chevron BAKER IWO HUGHES Location: Cook Inlet, Alaska (Offshore) Slot: slot #B2-2 INTEQ Field: McArthur River Field Well: M -18 Facility: STEELHEAD Platform Wellbore: M -18 Plot reference wellpath is M- 18_Version#8B True vertical depths are referenced to Actual Datum (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Actual Datum (RKB) North Reference: True north Actual Datum (RKB) to mean sea level: 16025 feet Scale: True distance mean sea level to Mud line (Facility: STEELHEAD Platform): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by ulricard on 10/9/2008 Scala + inch •1 mn Easting (ft) 85o r 50 100 150 200 250 300 350 400 450 500 550 800 850 700 ® ° °1 ® ac' 850 28 � 800 2 800 'OO 18 00 750 750 2 400 700 2 2■0 20 700 ?8 00 200 850 18 00 850 500 1 2200 60O 550 `'20 550 O 400 18 00 w 5 ' 500 2000 Z C L 450 2800 O 450 Z 18 400 /g � 400 .2, ` 00 B � O 350 180 76 350 300 300 2000 ? - 0 250 ZO M 250 /40 2 00 1100 00 16 00 3 o) Si 200 ,p (x, • i D Cas /0 9 /Ofer N 200 - wet o ° o �- 0 e 150 fr 7200 150 k 1 4, 0 r 0 2Oi O moo rrn �O 1� 100 50 �. 1 ?9, 00 50 100 150 200 Scab l inch .100 ft 250 300 aso 400 450 500 550 600 650 700 Easting (ft) • • Chevron Chevron BAKE Location: Cook Inlet, Alaska (Offshore) Slot: slot #B2 -2 NUGHES 4110 Field: McArthur River Field Well: M -18 INTEQ Facility: STEELHEAD Platform Wellbore: M -18 Plot reference wellpath is M -18 Version #8B True vertical depths are referenced to Actual Datum (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Actual Datum (RKB) North Reference: True north Actual Datum (RKB) to mean sea level: 160.25 feet Scale. True distance mean sea level to Mud line (Facility: STEELHEAD Platform): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by ulrinrd on 10/9/2008 �nb Fasting (ft) 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 3000 !3000 2850 2850 2700 2700 2550 2550 2400 2400 2250 2250 ' ® ,,' 2100 2100 26 00 1950 1950 Z 0 rn s • 2400 4 2 80 c n p 1800 ° 28 00 1800 Z x 26 1650 1650 O� 1500 ® 2600 26 o 1500 2• #0 1350 , 000 1350 I 280 1200 2 800 2 2 40 0 1200 2 p0 M18Tgt : ding • 1050 260 1050 800 6,00 - 1800 2 900 ' X2 0 20„ o 900 2 # 2 . 80 26 0 E 2goo 750 18� 2 ' O 750 I 24, 2n 0 150 2600 300 450 ` 750 900 1050 1200 1350 1500 1650 1800 1950 Scale inch ='°/! Easting (ft) Chevron I F4 Chevron d� Location: Cook Inlet, Alaska (Offshore) Slot: slot #B2 -2 BAKER -. Field: McArthur River Field Well: M -18 HUGHES Facility: STEELHEAD Platform Wellbore: M -18 INTEQ Plot relerett . tt Spath 's M -tS Version9SB True venial Eeptes are mferenced io Actual Datum (RKB) Ond System: MAD27/11,1 Absks State Po, Zone 4 (5004), US feet easur tleptf, are re eren o ua a um (RKB) Hoes 0.01,05.: TNe no/tn Avival Datum ( RKB) to mean sea ive1: 160.35 teal Scai: True Eitanr< mean sae bvel to MS Ane (Facility: STEELHEAD Pi1a^n):0 teal Deplfn en b teal Coordbates are in feet referenKS to Sbl Crealetl by ulrlcnd on 10/9/2001 a,;nen =600K Easting (ft) -600 0 600 1200 1800 2400 3000 7800 7800 0 9 200 7200 .00 7200 40 VP 6600 6600 380 8- 380: do 6000 6000 3 40 0 ' Z O m C 33,0 7- L 6400 5400 O Z t® 3000 ts 480Q. ° 0 4800 ® 2805 , „, 280 ;41 80 4200 4200 1, 240p [� it I N O CCCO00”' IMI ua O y 3600 m 8 c $ a o 4_ 00 g 3600 O O MI es ..'� o $118 r� c7 (8- -� 40 4 061111111111".....— — V n tifill : ° o "O 2p� 48 � pQ O 8 e o ®0 3000 3000 • 3 g00`�' 4 60 0 X 0 0 . . 1'w o 'o M Ca/A -6°0 0 600 M : 1200 1800 2400 3000 5 ° °" Easting (ft) • M -18 20 3/4" BOP / Diverter Stack up • / 21 1/4" 2M Hydril Annular 4.22' I I HUB CLAMP I I 20 3/4" 3 M Hydril DBL Gate Pipe Rams d 71' 20 314" 3M Blind Rams HUB CLAMP 203/4" 3M �� II. Mug Coross , II ii•ii HUB CLAMP III[ 20 3/4" 3M Single Gate 2.71' HUB CLAMP 6" Ansi 600 Diverter Valves 20 314 3M 2.00 NT2 Connector XO f t Diverter [IX 41r Sol 30 20 3/4 3M NT2 Connector 203/4 "3M Riser I 20 3/4" 3M Riser VETCO 20 3/4" Iii NT2 Connector Ng VETCO NT2 HEAD 6" ANSI 600 RTJ L • . CHOKE MANIFOLD • TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS S. A«� 'in ■a i I . in H ' 1 mom aim mum iti . 1 imilini ,. ', * ) : ;-731,..!) ,-:.\ .. ( 44114.: i rn6 • '\ 1/ it /�' ■s . 111 ..................a.........r.. i 1 . i , sub SRI _� 4 �i 11 I . ,. ) �l rem q `� tli r[` # le 1 , \ 1. Imo! j .. +.esw `r '�11��i t ,�r .� • _.. MUM '•?. .Nd,. s . g ill e iliN / i...a � � ,�, 6, ----- 1.., . A i • �:'°:�f f t°il ; 1. r ; lrt .1 n.�t IIIIII I / . t i SWACC! : CHOKE LINE iii , re L A,,..•- SECTION AA * ALL VALVES IN FLOW PATH ARE 3.1/16' 5000 PSI CAMERON GATE TYPE i • TRANSMITTAL LETTER CHECKLIST WELL NAME T v - \'"A PTD# D'O\ \ Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: OAr"\ k ` �OOL: K6) � Y ee' \ Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - . API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool MCARTHUR RIVER, MIDKENAI GAS - 520550 Well Name: TRADING BAY UNIT M -18 Program DEV Well bore seg ❑ PTD#: 2081620 Company UNION OIL CO OF CALIFORNIA Initial Class/Type DEV / PEND GeoArea 820 Unit On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface and top prod interval in ADL 18730; TD in ADL 17594. 3 Unique well name and number Yes 4 Well located in a defined pool Yes MCARTHUR RIVER, MID KENAI GAS - 520550, governed by CO 228. 5 Weil located proper distance from drilling unit boundary Yes Rule 1 of CO 228_ established 10 -acre drilling units for the pool at the D -1 sand, which lies at the vertical 6 Well located proper distance from other wells Yes mid -point of the pool becaues of the lenticular natu of the reservoir sands. 7 Sufficient acreage_ayaiiable in drilling unit Yes 10/21: phoned Jim Rose and requested more information. Received info on 10/28; no exception needed. SEC! _ _ 8 If_deviated, is_wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has_appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Perrnitcan be issued without adrninistrativ_e_approval Yes SFD 11/19/2008 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and_strata authorized by Injection Order # (put IO# in comments) (For NA 15 All wells_within 1 /4_miie areaof review identified ( For service well only) NA 16 Pre- produced injector, duration of pre - production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to A$31.05.03Q0,1.A),(j2.A -D) NA Engineering 18 Conductor string provided Yes 19 Surface casing protects all known USDWS NA All aquifers exempted,_40 CFR147.102 (b)(2)(ii). 20 CMT v_ol adequate to circuiate_on conductor & s urf csg Yes 21 CMT_ v_ol adequate to tie -in long string to surf csg Yes 22 CMT_will coverall known_productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage_ reserve pit Yes Platform rig. Drilling wastes to be discharged in accordance with NPDES. 25 Ifa_re- drill, has_a 10403 for abandonment b een approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Close approaches identified and mitig ation strategies listed. 27 ifdiverter required, does it meet regulations No 16" diverter lines. 17 -1/2" hole planned. This request has been approved pre viously. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum possible formation pressure 9.1 EMW. _MW_planned9 3_ pp9 TEM 11/25/2008 29 BOPEs,_do they meet regulation Yes Stack has 3K rams and a 2K annular. 2K is inexcess of Most conservatively calculated MASP. • • k t� ' n 30 BOPS_ press rating appropriate; test to (put psig in comments) Yes MASP per 20 AAC 25.005 (c)(4)(A) 1618 psi. 3000 psi ram test planned. 2000 psi annular test. w' 31 Choke_ manifold compiles w /API_ RP -53 (May 8 4) Yes 32 Work will occur without oper ation shutdown Yes 33 is presence of H2S gas probable Yes H2S is present in Steelhead oil production. No H28 in gas production, Rig has sensors and alarms. 34 Mechanical_condition of wells within AOR verified (For service well only) NA Geology 35 Permit can be issued w/o hydrogen_ sulfide measures No Steelhead Platform is a designated H2$ site. 36 Data_presented ort potential overpressure zones Yes Expected maximum reservoir pressure is 8,4 pp9 EMW, but many sands will be underpressured as indicated_ in th_ Appr Date 37 Seismicanalysis of shallow gas zones NA Formation Markers table on p. 3 and as discussed in the Summary of Drilling Hazards. SFD 10/21/2008 38 Seabed condition survey (if off- shore) NA 39 Contact name /phone for weekly_progress reports [exploratory only] NA Geologic Engineering , c Commissioner: Date: Commissioner: Date . . „ Date a#.6(10L, //_z4_06, � 4 11 tog
