The URL can be used to link to this page

Home My WebLink About189-1111. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,291 N/A Casing Collapse Structural Conductor Surface 1,020psi Intermediate 1,540psi Production 3,220psi Production 4,760psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng CO 228A Other: CTCO, N2 9/4/2025 7,268'6,732' 4-1/2" 6,496' See schematic See schematic 536' Perforation Depth MD (ft): 2,712' 2,139 - 2,812 536' 9-5/8" 2,131 - 2,730 535'10-3/4" 488' 34" x 28" 20" 16" 937' 13-3/8"2,712' 1,451' MD 3,090psi 2,630psi 936' 1,450' 2,644' 937' 1,451' Length Size Proposed Pools: 488' 488' L-80 TVD Burst 2,466 & 3,085 5,860psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 189-111 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20411-00-00 Hilcorp Alaska, LLC Trading Bay Unit M-03 AOGCC USE ONLY 6,870psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY McArthur River Middle Kenai Gas Same 6,518 3,000 2,888 956psi 3,035 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:29 am, Aug 22, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.08.21 15:39:25 - 08'00' Dan Marlowe (1267) 10-404 MGR05SEP25 A.Dewhurst 27AUG25 * BOPE test to 2500 psi. 48 hour notice for opportunity to witness. DSR-8/26/25 325-502 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.05 09:46:50 -08'00'09/05/25 RBDMS JSB 090925 CT FCO Well: Steelhead M-03 Well Name:M-03 API Number:50-733-20411-00-00 Current Status:Gas Producer Permit to Drill Number:189-111 First Call Engineer:Casey Morse (603) 205-3780 (c)Leg B-2 (NE corner) Second Call Engineer:Eric Dickerman (307) 250-4013 (c) Current BHP: Maximum Expected BHP:1229 psi @ 2,730’ TVD 0.45psi/ft to deepest open perf Max. Potential Surface Pressure: 956 psi Using 0.1 psi/ft Brief Well Summary M-03 is a gas producer on the Steelhead platform with open perforations in the Shallow Zone and A gas sands. It was worked over in October of 2020 and the production rapidly declined from 4.5MMscfs/day to 750mscfs/day. More perforations were added uphole in 2021, and the well saw a short production bump before declining and ultimately getting shut in. Recent slickline tags in the well show the casing & tubing tail are full of water & sand. The goal of this project is to cleanout to TD and return to production. Pertinent wellbore information: - Sail angle / max inclination of 34 degrees from ~2600’ MD to TD - SSSV: TR-SSSV, 3.813” profile at 485’. - Dec-2022 o Numerous bailer runs (1.75” and 2.25”) working down to ±2,165’ KB. - May-2022 o Well shut in, unable to flow - Oct-2020 perf adds o Perf 75’ total A-2 sands o Perf SZ sands: 24B, 24, 23, 22. Significant rate increase. o Tag fill above all open perfs in Feb-2021 o Perf SZ sands: 21, 20, 18A - Aug-2020 o RWO to isolate A-6 through B-8 sands o CIBP set at 3,035’ and dump bail 36’ of cement on top. Coiled Tubing Procedure 1. MIRU Fox Energy offshore Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high. 3. MU FCO BHA 4. RIH and cleanout to PBTD (~3,000’) or as deep as practical a. Working fluid will be water (8.33ppg or greater) Pressure test BOPE to 2500 psi. 48 hour notice to AOGCC for opportunity to witness. CT FCO Well: Steelhead M-03 b. Take returns to surface up the CT x tubing annulus c. Add foam and nitrogen as necessary to carry solids to surface d. Can use GL to assist with hole cleaning 5. RDMO CT Attachments 1. Current Wellbore Schematic 2. CT BOP Drawing (Fox energy) 3. Nitrogen procedure Revised by: JLL 04/04/24 SCHEMATIC Steelhead Platform Well: M-03 Last Completed: 9/08/2020 API: 50-733-20411-00 PTD: 189-111 PBTD =3,000’ TD = 7291’ MAX HOLE ANGLE =33q @ 5002’ RKB to TBG Head = 74.4’ KB to MSL = 160’, RKB to mudline = 345’ 20” 16” 13-3/8” SZ-22 SZ-23 SZ-24 A-2 SZ-18A SZ-20SZ-21 34” Casing patch 2661’-2681’ Tag sand ~3,900’ 05/26/16 Tag @ 4,093’ RKB ELM 10/21/10 B-2 A-6 B-3-B8 C-1 C-2 D-2 XO XO 1 2 4 56 7 8 9 10 11 12 13 14 15 16 17 18 X3 TOC ±3,000’ X Est. TOC 1,950’ CBL 9/6/20 5a Fish 5,376’ 5’± Cut Tbg; “X” Nipple; 7’ 4-1/2” pup jt Casing Detail SIZE WT GRADE CONN ID TOP BTM. 34”x28" Conductor - Driven ~26.5" Surface ~488’ 20”133 X-56 RL45 18.730” Surface 895’ 133 X-56 BTC 18.730” 895’ 937’ 16” 75 K-55 BTC 15.240” Surface 1,451’ 13-3/8”61 K-55 BTC 12.515” Surface 2,453’ 68 K-55 BTC 12.412” 2,453’ 2,712’ 10-3/4”55.5 N-80 BTC 9.760” Surface 153’ 51 L-80 BTC 9.850” 153’ 536’ 9-5/8” 47 N-80 BTC 8.681” 536’ 7,268’ Tubing Detail 4-1/2” 12.6 L-80 IBT 3.958” Surface 2,466’ 4-1/2” 12.6 L-80 AB mod BTC 3.958” 3,035’ 3,085’ JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 74.50’ 74.5’ Hanger, FMC TC-1A-EN 1 485’ 485’ 3.813 5.97 Halliburton TRSV NE-SLIM, PN 478ULXE381004E 2 2,073’ 2,067’ 3.990 8.25 DLH Packer, pinned 58k shear release 3 2,191’ 2,181’ 3.813 5.00 X Nipple 4 2,466’ 2,434’ 3.958 5.00 WLEG 5 3,035’ 2,017’ 9-5/8” CIBP w/ 36’ Cement (TOC ±3,000) 5a 3,035’ 2,017’ Tubing Cut 6 3,044’ 2,925’ 3.813” 5.250” OTIS X Nipple (with PX-plug installed 8/26/2020) 7 3,090’ 2,963’ 6.000” 8.440” Packer – Baker SC-1R w/ locator seal assembly 8 3,099’ 2,971’ 6.380” 8.130” Sliding Sleeve 9 3,124’ 2,992’ 4.950” 7.630” XO 10 3,185’ 3,043’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 11 3,290’ 3,131’ 3.725” 8.440”Packer - Baker SC-1L w/ S-22 snap latch, CAMCO XN Nipple, WLEG 12 3,299’ 3,138’ 6.380” 8.130” Sliding Sleeve 13 3,324’ 3,159’ 4.950” 7.630” XO 14 3,360’ 3,189’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 15 3,462’ 3,275’ 3.000” 8.125” Packer – Baker Model D w/ S-22 snap latch & seals 16 4,156’ 3,860’ TTS umbrella plug w/ cement on top 17 5,032’ 4,595’ 6.00” BWH Packer 18 6,600’ 5,905’ 6.00” BWH Packer Cement Plug: 5,002’ – 6,600’ - 8/6/93 Cement Plug: 7,169’–7,283’ - 8/2/90 OPEN HOLE / CEMENT DETAIL 20"26” Hole: Pumped 2550sxs of cement.Cement assumed to surface. 16”22” hole: Pumped 1066sxs 13.2ppg lightweight lead cement followed by 450 sxs 15.8ppg Class G tail cement. Cement assumed to surface. 13-3/8"17-1/2” Hole: Pumped 1300sxs of cement. Cement assumed to surface. 9-5/8"12-1/2” hole: Pumped 800sxs 13.2ppg lightweight lead cement followed by 860 sxs 15.8ppg Class G tail cement. ToC at 1,950’ MD from 9/6/20 CBL. GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,503’ 1,503’ 3.935 4 1/2" slim hole 1" , running tool 1 5/16 JK, pulling 1 1/4" JDC 20 Dome 823 9/7/2020 2 2,020’ 2,016’ 3.935 4 1/2" slim hole 1" , running tool 1 5/16 JK, pulling 1 1/4" JDC 20 Orifice 9/7/2020 Revised by: JLL 04/04/24 SCHEMATIC Steelhead Platform Well: M-03 Last Completed: 9/08/2020 API: 50-733-20411-00 PTD: 189-111 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet Spf Date Comments SZ-18A 2139’ 2156’ 2131’ 2147’ 17’ 6 02/12/21 Open SZ-20 2357’ 2363’ 2336’ 2341’ 6’ 6 02/12/21 Open SZ-21 2431’ 2450’ 2403’ 2419’ 19’ 6 02/12/21 Open SZ-22 2,490’ 2,518’ 2,455’ 2,479’ 28’ 10/11/20 Open SZ-23 2,537’ 2,545’ 2,496’ 2,502’ 8’ 10/11/20 Open SZ-24 2,555’ 2,560’ 2,511’ 2,515’ 5’ 10/11/20 Open SZ-24B 2,592’ 2,621’ 2,543’ 2,568’ 29’ 10/11/20 Open SZ-24B Stray 2,642’ 2,648’ 2,586’ 2,591’ 6’ 10/11/20 Open Sqz Perfs 2,661’ 2,681’ 2,602’ 2,619’ 20’ Sqz’d Sqz Perfs 2,671’ 2,673’ 2,610’ 2,612’ 2’ Sqz’d SZ-24B Stray 2,674’ 2,680’ 2,613’ 2,618’ 6’ 10/11/20 Open SZ-24B Stray 2,695’ 2,705’ 2,631’ 2,639’ 10’ 10/11/20 Open A-2 2,737’ 2,812’ 2,666’ 2,730’ 75’ 10/3/20-10/4/20 Open A-6 3,202’ 3,278’ 2,753' 2,808' 76’ 12 09/05/20 Isolated B-2 3,370’ 3,430’ 2,874' 2,917' 60’ 12 09/05/20 Isolated B-2 3,440’ 3,450’ 2,925' 2,932' 10’ 12 09/05/20 Isolated B-3 3,499’ 3,555’ 2,967' 3,007' 56’ 5 09/05/20 Isolated B-4 3,564’ 3,592’ 3,013' 3,033' 28’ 6 09/05/20 Isolated B-4 3,610’ 3,624’ 3,046' 3,056' 14’ 6 09/05/20 Isolated B-5 3,780’ 3,850’ 3,169' 3,220' 70’ 6 09/05/20 Isolated B-6 3,895' 3,898' 3,253' 3,255' 3’ 6 09/05/20 Isolated B-6B 3,956' 3,978' 3,298' 3,314' 22’ 6 09/05/20 Isolated B-7 4,015' 4,035' 3,341' 3,356' 20’ 6 09/05/20 Isolated B-8 4,054' 4,058' 3,370' 3,373' 4’ 6 09/05/20 Isolated C-1 4,178’ 4,226’ 3,463' 3,499' 48’ 6 03/27/2009 Plugged C-2 4,326’ 4,334’ 3,574' 3,580' 8’ 6 11/18/2008 Plugged C-2 4,348’ 4,364’ 3,591' 3,603' 16’ 6 11/18/2008 Plugged D-2 4,955’ 5,001’ 4,069' 4,109' 46’ 05/09/2007 Plugged STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 04/05/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL TBU M-03 (189-111) PERF 02/12/2021 Please include current contact information if different from above. PTD: 1891110 E-Set: 35213 06/11/2021 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 7,291 feet 3,035 feet true vertical 6,512 feet N/A feet Effective Depth measured 3,000 feet See schematic feet true vertical 2,888 feet See schematic feet Perforation depth Measured depth 2,139 - 2,812 feet True Vertical depth 2,131 - 2,730 feet 4-1/2" 12.6 / L-80 2,466 MD 2,434 TVD Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / L-80 3,085 MD 2,959 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: 480 937 1,451 TVD 480 measured true vertical Packer 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 200 Casing Pressure 34" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 189-111 50-733-20411-00-00 Plugs ADL001873 Trading Bay Unit M-03 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-049 23 Authorized Signature with date: Authorized Name: 0 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 135 N/A Oil-Bbl 757 Water-Bbl Junk 5. Permit to Drill Number: 880 McArthur River Field / Middle Kenai Gas PoolN/A measured 2,712 measured 7,268 Size 20 Production Casing Structural Length 480 Intermediate N/A MD Surface 4,760psi 20" 16" 13-3/8" 2,712 6,732 9-5/8" 907 777-8376 6,870psi 936 1,450 2,644 6,496 3,220psi Katherine.oconnor@hilcorp.com Tubing Pressure 1,020psi 1,540psi 2,630psi 3,090psi Burst Collapse Katherine O'Connor Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager 937 1,451 Conductor Production 536 10-3/4" 536 535 5,860psi Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:20 am, Mar 04, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.03.03 15:53:16 -09'00' Dan Marlowe (1267) ADL 018730 SFD 3/12/2021 SFD 3/12/2021 BJM 4/9/21 RBDMS HEW 3/5/2021 DSR-3/4/21 Revised by: JLL 02/25/21 SCHEMATIC Steelhead Platform Well: M-03 Last Completed: 9/08/2020 API: 50-733-20411-00 PTD: 189-111 PBTD =3,000’ TD = 7291’ MAX HOLE ANGLE =33q @ 5002’ RKB to TBG Head = 74.4’ KB to MSL = 160’, RKB to mudline = 345’ 20” 16” 13-3/8” SZ-22 SZ-23 SZ-24 & 24B A-2 SZ-18A SZ-20SZ-21 Casing patch 2661’-2681’ Tag sand ~3,900’ 05/26/16 Tag @ 4,093’ RKB ELM 10/21/10 B-2 A-6 B-3-B8 C-1 C-2 D-2 XO XO 1 3 5 67 8 9 10 11 12 13 14 15 16 17 18 19 X 2 4 TOC ±3,000’ X Est. TOC 1,950’ CBL 9/6/20 6a Fish 5,376’ 5’± Cut Tbg; “X” Nipple; 7’ 4-1/2” pup jt Casing Detail SIZE WT GRADE CONN ID TOP BTM. 34” Conductor 30” x 28.5” Surface 480’ 20”133 X-56 RL45 18.730” Surface 895’ 133 X-56 BTC 18.730” 895’ 937’ 16” 75 K-55 BTC 15.240” Surface 1,451’ 13-3/8”61 K-55 BTC 12.515” Surface 2,453’ 68 K-55 BTC 12.412” 2,453’ 2,712’ 10-3/4”55.5 N-80 BTC 9.760” Surface 153’ 51 L-80 BTC 9.850” 153’ 536’ 9-5/8” 47 N-80 BTC 8.681” 536’ 7,268’ Tubing Detail 4-1/2” 12.6 L-80 IBT 3.958” Surface 2,466’ 4-1/2” 12.6 L-80 AB mod BTC 3.958” 3,035’ 3,085’ JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 74.50’ 74.5’ Hanger, FMC TC-1A-EN 1 485’ 485’ 3.813 5.97 Halliburton TRSV NE-SLIM, PN 478ULXE381004E 2 1,503’ 1,503’ 3.935 5.985 GLM #1 - 4 1/2" slim hole 1" , running tool 1 5/16 JK, pulling 1 1/4" JDC 2,020’ 2,016’ 3.935 5.985 GLM #2 - 4 1/2" slim hole 1" , running tool 1 5/16 JK, pulling 1 1/4" JDC 3 2,073’ 2,067’ 3.990 8.25 DLH Packer, pinned 58k shear release 4 2,191’ 2,181’ 3.813 5.00 X Nipple 5 2,466’ 2,434’ 3.958 5.00 WLEG 6 3,035’ 2,017’ 9-5/8” CIBP w/ 36’ Cement (TOC ±3,000) 6a 3,035’ 2,017’ Tubing Cut 7 3,044’ 2,925’ 3.813” 5.250” OTIS X Nipple (with PX-plug installed 8/26/2020) 8 3,090’ 2,963’ 6.000” 8.440” Packer – Baker SC-1R w/ locator seal assembly 9 3,099’ 2,971’ 6.380” 8.130” Sliding Sleeve 10 3,124’ 2,992’ 4.950” 7.630” XO 11 3,185’ 3,043’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 12 3,290’ 3,131’ 3.725” 8.440”Packer - Baker SC-1L w/ S-22 snap latch, CAMCO XN Nipple, WLEG 13 3,299’ 3,138’ 6.380” 8.130” Sliding Sleeve 14 3,324’ 3,159’ 4.950” 7.630” XO 15 3,360’ 3,189’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 16 3,462’ 3,275’ 3.000” 8.125” Packer – Baker Model D w/ S-22 snap latch & seals 17 4,156’ 3,860’ TTS umbrella plug w/ cement on top 18 5,032’ 4,595’ 6.00” BWH Packer 19 6,600’ 5,905’ 6.00” BWH Packer Cement Plug: 5,002’–6,600’ - 8/6/93 Cement Plug: 7,169’–7,283’ - 8/2/90 Revised by: JLL 02/25/21 SCHEMATIC Steelhead Platform Well: M-03 Last Completed: 9/08/2020 API: 50-733-20411-00 PTD: 189-111 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet Spf Date Comments SZ-18A 2139’ 2156’ 2131’ 2147’ 17’ 6 02/12/21 Open SZ-20 2357’ 2363’ 2336’ 2341’ 6’ 6 02/12/21 Open SZ-21 2431’ 2450’ 2403’ 2419’ 19’ 6 02/12/21 Open SZ-22 2,490’ 2,518’ 2,455’ 2,479’ 28’ 10/11/20 Open SZ-23 2,537’ 2,545’ 2,496’ 2,502’ 8’ 10/11/20 Open SZ-24 2,555’ 2,560’ 2,511’ 2,515’ 5’ 10/11/20 Open SZ-24B 2,592’ 2,621’ 2,543’ 2,568’ 29’ 10/11/20 Open SZ-24B Stray 2,642’ 2,648’ 2,586’ 2,591’ 6’ 10/11/20 Open Sqz Perfs 2,661’ 2,681’ 2,602’ 2,619’ 20’ Sqz’d Sqz Perfs 2,671’ 2,673’ 2,610’ 2,612’ 2’ Sqz’d SZ-24B Stray 2,674’ 2,680’ 2,613’ 2,618’ 6’ 10/11/20 Open SZ-24B Stray 2,695’ 2,705’ 2,631’ 2,639’ 10’ 10/11/20 Open A-2 2,737’ 2,812’ 2,666’ 2,730’ 75’ 10/3/20-10/4/20 Open A-6 3,202’ 3,278’ 2,753' 2,808' 76’ 12 09/05/20 Isolated B-2 3,370’ 3,430’ 2,874' 2,917' 60’ 12 09/05/20 Isolated B-2 3,440’ 3,450’ 2,925' 2,932' 10’ 12 09/05/20 Isolated B-3 3,499’ 3,555’ 2,967' 3,007' 56’ 5 09/05/20 Isolated B-4 3,564’ 3,592’ 3,013' 3,033' 28’ 6 09/05/20 Isolated B-4 3,610’ 3,624’ 3,046' 3,056' 14’ 6 09/05/20 Isolated B-5 3,780’ 3,850’ 3,169' 3,220' 70’ 6 09/05/20 Isolated B-6 3,895' 3,898' 3,253' 3,255' 3’ 6 09/05/20 Isolated B-6B 3,956' 3,978' 3,298' 3,314' 22’ 6 09/05/20 Isolated B-7 4,015' 4,035' 3,341' 3,356' 20’ 6 09/05/20 Isolated B-8 4,054' 4,058' 3,370' 3,373' 4’ 6 09/05/20 Isolated C-1 4,178’ 4,226’ 3,463' 3,499' 48’ 6 03/27/2009 Plugged C-2 4,326’ 4,334’ 3,574' 3,580' 8’ 6 11/18/2008 Plugged C-2 4,348’ 4,364’ 3,591' 3,603' 16’ 6 11/18/2008 Plugged D-2 4,955’ 5,001’ 4,069' 4,109' 46’ 05/09/2007 Plugged ()()()() SZ-18A 2139’ 2156’ 2131’ 2147’ 17’ 6 02/12/21 Open SZ-20 2357’ 2363’ 2336’ 2341’ 6’ 6 02/12/21 Open SZ-21 2431’ 2450’ 2403’ 2419’ 19’ 6 02/12/21 Open ()()()() Rig Start Date End Date Eline 2/12/21 2/12/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-03 50-733-20411-00-00 189-111 02/12/21 - Friday Arrive on Steelhead, PTW, PJSM. Spot equipment. MIRU ELINE. Make up tool string. 3 1/8 gamma/ccl, 9' wt bar for depth determination. Stab on well, PT Lub/WLV low high 250/1500. Open well, swab 25, WHP 20. RIH, Tag at CCL depth 2451' + 5.6' to bottom of wt bar= 2456.6'. Log up to 2000'. Send log to town for corrections. Looks like we are on depth. POOH, Tagged up, swab shut, bleed down, pop off well. Make up Gun #1, 19'. 2.875" 15gram razor, 6spf, 60* phase gun. Stab on well, Open up, RIH, Tag at 2428' ccl depth. Log up to 2000', Send log to town for Correlation. Got approval to shoot SZ-21 2431-2450’ (Geologist). RIH to tag, pu getting on CCL depth 2421.9'. CCL t/top shot 9.1', CCL t/ bottom shot 28.1'. Shoot SZ-21 2431'- 2450'. ITP 20, FTP 20 increase in rate by 200,000 cfm. POOH, tagged up, swab shut, bleed down, pop off well. All shots fired. Dry gun. Make up Gun #2, 6', 2.875", 15gram razor, 6spf, 60* phase gun. Stab on well, Open well, WHP 20 psi. RIH, @ 2458', log up to 2000'. Send log to town for correlation. Got confirmation to shoot SZ-20 from 2357'-2363' (Geologist). RIH to 2400', PU getting on CCL depth 2348.7. CCL t/top shot 8.3'. CCL t/bottom shot 14.3'. Shoot SZ-20 2357'-2363'. ITP 20, FTP 22'. Increase in rate 225,000. Log up 200', POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired. Dry gun, Make up Gun #3, 17', 2.875", 15gram razor, 6spf, 60* phase gun. Stab on well, Open up, WHP 20 psi. RIH, @ 2400' pull log up to 2000'. Send log to town for correlation. Got confirmation to shoot SZ-18A 2139'-2156' (Geologist). RIH to 2400', PU getting on CCL depth 2127.7', CCL t/top shot 11.3', CCL t/bottom shot 28.3'. Shoot SZ-18A 2139’-2156’. ITP 23 psi, FTP 25 psi, 100,000 more in rate. log up 200', POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired, Dry gun. Rig down off of M- 03. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7,291'N/A Casing Collapse Structural Conductor Surface 1,020 psi Intermediate 1,540 psi Production 3,220 psi Production 4,760 psi Liner 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 6,512' 3,000' 2,888' 744 psi 6,496'9-5/8" 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. 2/14/2021 4-1/2" Daniel E. Marlowe See schematic Tubing Size: 7,268' Perforation Depth MD (ft): 536' 2,490 - 2,812 6,732' See schematic Tubing Grade:Tubing MD (ft): 2,455 - 2,730 Perforation Depth TVD (ft): 937' 20" 16" 13-3/8" 1,451' 10-3/4"536' 2,712'3,090 psi 1,450' 2,644' 535' 1,451' 2,712' 3,044' 937' 936' 12.6# / L-80 TVD Burst 2,466 & 3,085 6,870 psi MD 2,630 psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 189-111 50-733-20411-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-03 PRESENT WELL CONDITION SUMMARY Length Size 5,860 psi COMMISSION USE ONLY Authorized Name: Authorized Signature: Operations Manager Katherine O'Connor CO 228A Other: ~480' 34" ~480' ~480' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:50 am, Jan 26, 2021 321-049 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.01.26 08:35:33 -09'00' Dan Marlowe (1267) Perforate GAS 10-404 DSR-1/27/21SFD 1/27/2021gls 2/2/21 Comm. 2/2/21 dts 2/2/2021 JLC 2/2/2021 RBDMS HEW 2/3/2021 Well Work Prognosis Well Name:Trading Bay Unit M-03 API Number: 50-733-20411-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:02/14/2021 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:189-111 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Cell: 907-570-1801 Current Bottom Hole Pressure:775 psi @ 2593’ TVD Maximum Expected BHP:860 psi @ 1985’ TVD Maximum Potential Surface Pressure:744 psi Based on 0.1 psi/ft gas gradient Brief Well Summary: Well M-03 is a gas well completed in the SZ sands. The well had a recent RWO in summer 2020 to recomplete the well to access new sands uphole. Post RWO, 180’ of adperfs in the SZ sands were added. The objective of this program is to add more perforations uphole in the SZ-18A, SZ-20, and SZ-21. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. Perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Revised by:KDK 11/18/20 SCHEMATIC Steelhead Platform Well: M-03 Last Completed: 9/08/2020 API: 50-733-20411-00 PTD: 189-111 PBTD =3,000’ TD = 7291’ MAX HOLE ANGLE =33q @ 5002’ RKB to TBG Head = 74.4’ KB to MSL = 160’, RKB to mudline = 345’ 20” 16” 13-3/8” SZ-22 SZ-23 SZ-24 & 24B A-2Casing patch 2661’-2681’ Tag sand ~3,900’ 05/26/16 Tag @ 4,093’ RKB ELM 10/21/10 B-2 A-6 B-3-B8 C-1 C-2 D-2 XO XO 1 3 5 67 8 9 10 11 12 13 14 15 16 17 18 19 X 2 4 TOC ±3,000’ X Est. TOC 1,950’ CBL 9/6/20 6a Fish 5,376’ 5’± Cut Tbg; “X” Nipple; 7’ 4-1/2” pup jt Casing Detail SIZE WT GRADE CONN ID TOP BTM. 34” Conductor 30” x 28.5” Surface 480’ 20”133 X-56 RL45 18.730” Surface 895’ 133 X-56 BTC 18.730” 895’ 937’ 16” 75 K-55 BTC 15.240” Surface 1,451’ 13-3/8”61 K-55 BTC 12.515” Surface 2,453’ 68 K-55 BTC 12.412” 2,453’ 2,712’ 10-3/4”55.5 N-80 BTC 9.760” Surface 153’ 51 L-80 BTC 9.850” 153’ 536’ 9-5/8” 47 N-80 BTC 8.681” 536’ 7,268’ Tubing Detail 4-1/2” 12.6 L-80 IBT 3.958” Surface 2,466’ 4-1/2” 12.6 L-80 AB mod BTC 3.958” 3,050’ 3,085’ JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 74.50’ 74.5’ Hanger, FMC TC-1A-EN 1 485’ 485’ 3.813 5.97 Halliburton TRSV NE-SLIM, PN 478ULXE381004E 2 1,503’ 1,503’ 3.935 5.985 GLM #1 - 4 1/2" slim hole 1" , running tool 1 5/16 JK, pulling 1 1/4" JDC 2,020’ 2,016’ 3.935 5.985 GLM #2 - 4 1/2" slim hole 1" , running tool 1 5/16 JK, pulling 1 1/4" JDC 3 2,073’ 2,067’ 3.990 8.25 DLH Packer, pinned 58k shear release 4 2,191’ 2,181’ 3.813 5.00 X Nipple 5 2,466’ 2,434’ 3.958 5.00 WLEG 6 3,035’ 2,017’ 9-5/8” CIBP w/ 36’ Cement (TOC ±3,000) 6a 3,035’ 2,017’ Tubing Cut 7 3,044’ 2,925’ 3.813” 5.250” OTIS X Nipple (with PX-plug installed 8/26/2020) 8 3,090’ 2,963’ 6.000” 8.440” Packer – Baker SC-1R w/ locator seal assembly 9 3,099’ 2,971’ 6.380” 8.130” Sliding Sleeve 10 3,124’ 2,992’ 4.950” 7.630” XO 11 3,185’ 3,043’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 12 3,290’ 3,131’ 3.725” 8.440”Packer - Baker SC-1L w/ S-22 snap latch, CAMCO XN Nipple, WLEG 13 3,299’ 3,138’ 6.380” 8.130” Sliding Sleeve 14 3,324’ 3,159’ 4.950” 7.630” XO 15 3,360’ 3,189’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 16 3,462’ 3,275’ 3.000” 8.125” Packer – Baker Model D w/ S-22 snap latch & seals 17 4,156’ 3,860’ TTS umbrella plug w/ cement on top 18 5,032’ 4,595’ 6.00” BWH Packer 19 6,600’5,905’6.00”BWH Packer Cement Plug: 5,002’–6,600’ - 8/6/93 Cement Plug: 7,169’–7,283’ - 8/2/90 Revised by:KDK 11/18/20 SCHEMATIC Steelhead Platform Well: M-03 Last Completed: 9/08/2020 API: 50-733-20411-00 PTD: 189-111 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet Spf Date Comments SZ-22 2,490’ 2,518’ 2,455’ 2,479’ 28’ 10/11/20 Open SZ-23 2,537’ 2,545’ 2,496’ 2,502’ 8’ 10/11/20 Open SZ-24 2,555’ 2,560’ 2,511’ 2,515’ 5’ 10/11/20 Open SZ-24B 2,592’ 2,621’ 2,543’ 2,568’ 29’ 10/11/20 Open SZ-24B Stray 2,642’ 2,648’ 2,586’ 2,591’ 6’ 10/11/20 Open Sqz Perfs 2,661’ 2,681’ 2,602’ 2,619’ 20’ Sqz’d Sqz Perfs 2,671’ 2,673’ 2,610’ 2,612’ 2’ Sqz’d SZ-24B Stray 2,674’ 2,680’ 2,613’ 2,618’ 6’ 10/11/20 Open SZ-24B Stray 2,695’ 2,705’ 2,631’ 2,639’ 10’ 10/11/20 Open A-2 2,737’ 2,812’ 2,666’ 2,730’ 75’ 10/3/20-10/4/20 Open A-6 3,202’ 3,278’ 2,753' 2,808' 76’ 12 09/05/20 Isolated B-2 3,370’ 3,430’ 2,874' 2,917' 60’ 12 09/05/20 Isolated B-2 3,440’ 3,450’ 2,925' 2,932' 10’ 12 09/05/20 Isolated B-3 3,499’ 3,555’ 2,967' 3,007' 56’ 5 09/05/20 Isolated B-4 3,564’ 3,592’ 3,013' 3,033' 28’ 6 09/05/20 Isolated B-4 3,610’ 3,624’ 3,046' 3,056' 14’ 6 09/05/20 Isolated B-5 3,780’ 3,850’ 3,169' 3,220' 70’ 6 09/05/20 Isolated B-6 3,895' 3,898' 3,253' 3,255' 3’ 6 09/05/20 Isolated B-6B 3,956' 3,978' 3,298' 3,314' 22’ 6 09/05/20 Isolated B-7 4,015' 4,035' 3,341' 3,356' 20’ 6 09/05/20 Isolated B-8 4,054' 4,058' 3,370' 3,373' 4’ 6 09/05/20 Isolated C-1 4,178’ 4,226’ 3,463' 3,499' 48’ 6 03/27/2009 Plugged C-2 4,326’ 4,334’ 3,574' 3,580' 8’ 6 11/18/2008 Plugged C-2 4,348’ 4,364’ 3,591' 3,603' 16’ 6 11/18/2008 Plugged D-2 4,955’ 5,001’ 4,069' 4,109' 46’ 05/09/2007 Plugged Revised by: JLL 01/21/2021 PROPOSED Steelhead Platform Well: M-03 Last Completed: 9/08/2020 API: 50-733-20411-00 PTD: 189-111 PBTD =3,000’ TD = 7291’ MAX HOLE ANGLE =33q @ 5002’ RKB to TBG Head = 74.4’ KB to MSL = 160’, RKB to mudline = 345’ 20” 16” 13-3/8” SZ-22 SZ-23 SZ-24 & 24B A-2 SZ-18A SZ-20SZ-21 Casing patch 2661’-2681’ Tag sand ~3,900’ 05/26/16 Tag @ 4,093’ RKB ELM 10/21/10 B-2 A-6 B-3-B8 C-1 C-2 D-2 XO XO 1 3 5 67 8 9 10 11 12 13 14 15 16 17 18 19 X 2 4 TOC ±3,000’ X Est. TOC 1,950’ CBL 9/6/20 6a Fish 5,376’ 5’± Cut Tbg; “X” Nipple; 7’ 4-1/2” pup jt Casing Detail SIZE WT GRADE CONN ID TOP BTM. 34” Conductor 30” x 28.5” Surface 480’ 20”133 X-56 RL45 18.730” Surface 895’ 133 X-56 BTC 18.730” 895’ 937’ 16” 75 K-55 BTC 15.240” Surface 1,451’ 13-3/8”61 K-55 BTC 12.515” Surface 2,453’ 68 K-55 BTC 12.412” 2,453’ 2,712’ 10-3/4”55.5 N-80 BTC 9.760” Surface 153’ 51 L-80 BTC 9.850” 153’ 536’ 9-5/8” 47 N-80 BTC 8.681” 536’ 7,268’ Tubing Detail 4-1/2” 12.6 L-80 IBT 3.958” Surface 2,466’ 4-1/2” 12.6 L-80 AB mod BTC 3.958” 3,035’ 3,085’ JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 74.50’ 74.5’ Hanger, FMC TC-1A-EN 1 485’ 485’ 3.813 5.97 Halliburton TRSV NE-SLIM, PN 478ULXE381004E 2 1,503’ 1,503’ 3.935 5.985 GLM #1 - 4 1/2" slim hole 1" , running tool 1 5/16 JK, pulling 1 1/4" JDC 2,020’ 2,016’ 3.935 5.985 GLM #2 - 4 1/2" slim hole 1" , running tool 1 5/16 JK, pulling 1 1/4" JDC 3 2,073’ 2,067’ 3.990 8.25 DLH Packer, pinned 58k shear release 4 2,191’ 2,181’ 3.813 5.00 X Nipple 5 2,466’ 2,434’ 3.958 5.00 WLEG 6 3,035’ 2,017’ 9-5/8” CIBP w/ 36’ Cement (TOC ±3,000) 6a 3,035’ 2,017’ Tubing Cut 7 3,044’ 2,925’ 3.813” 5.250” OTIS X Nipple (with PX-plug installed 8/26/2020) 8 3,090’ 2,963’ 6.000” 8.440” Packer – Baker SC-1R w/ locator seal assembly 9 3,099’ 2,971’ 6.380” 8.130” Sliding Sleeve 10 3,124’ 2,992’ 4.950” 7.630” XO 11 3,185’ 3,043’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 12 3,290’ 3,131’ 3.725” 8.440”Packer - Baker SC-1L w/ S-22 snap latch, CAMCO XN Nipple, WLEG 13 3,299’ 3,138’ 6.380” 8.130” Sliding Sleeve 14 3,324’ 3,159’ 4.950” 7.630” XO 15 3,360’ 3,189’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 16 3,462’ 3,275’ 3.000” 8.125” Packer – Baker Model D w/ S-22 snap latch & seals 17 4,156’ 3,860’ TTS umbrella plug w/ cement on top 18 5,032’ 4,595’ 6.00” BWH Packer 19 6,600’5,905’6.00”BWH Packer Cement Plug: 5,002’–6,600’ - 8/6/93 Cement Plug: 7,169’–7,283’ - 8/2/90 Revised by: JLL 01/21/2021 PROPOSED Steelhead Platform Well: M-03 Last Completed: 9/08/2020 API: 50-733-20411-00 PTD: 189-111 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet Spf Date Comments SZ-18A ±2139’ ±2156’ ±2131’ ±2147’ ±17’ Future Proposed SZ-20 ±2357’ ±2363’ ±2336’ ±2341’ ±6’ Future Proposed SZ-21 ±2431’ ±2450’ ±2403’ ±2419’ ±19’ Futire Proposed SZ-22 2,490’ 2,518’ 2,455’ 2,479’ 28’ 10/11/20 Open SZ-23 2,537’ 2,545’ 2,496’ 2,502’ 8’ 10/11/20 Open SZ-24 2,555’ 2,560’ 2,511’ 2,515’ 5’ 10/11/20 Open SZ-24B 2,592’ 2,621’ 2,543’ 2,568’ 29’ 10/11/20 Open SZ-24B Stray 2,642’ 2,648’ 2,586’ 2,591’ 6’ 10/11/20 Open Sqz Perfs 2,661’ 2,681’ 2,602’ 2,619’ 20’ Sqz’d Sqz Perfs 2,671’ 2,673’ 2,610’ 2,612’ 2’ Sqz’d SZ-24B Stray 2,674’ 2,680’ 2,613’ 2,618’ 6’ 10/11/20 Open SZ-24B Stray 2,695’ 2,705’ 2,631’ 2,639’ 10’ 10/11/20 Open A-2 2,737’ 2,812’ 2,666’ 2,730’ 75’ 10/3/20-10/4/20 Open A-6 3,202’ 3,278’ 2,753' 2,808' 76’ 12 09/05/20 Isolated B-2 3,370’ 3,430’ 2,874' 2,917' 60’ 12 09/05/20 Isolated B-2 3,440’ 3,450’ 2,925' 2,932' 10’ 12 09/05/20 Isolated B-3 3,499’ 3,555’ 2,967' 3,007' 56’ 5 09/05/20 Isolated B-4 3,564’ 3,592’ 3,013' 3,033' 28’ 6 09/05/20 Isolated B-4 3,610’ 3,624’ 3,046' 3,056' 14’ 6 09/05/20 Isolated B-5 3,780’ 3,850’ 3,169' 3,220' 70’ 6 09/05/20 Isolated B-6 3,895' 3,898' 3,253' 3,255' 3’ 6 09/05/20 Isolated B-6B 3,956' 3,978' 3,298' 3,314' 22’ 6 09/05/20 Isolated B-7 4,015' 4,035' 3,341' 3,356' 20’ 6 09/05/20 Isolated B-8 4,054' 4,058' 3,370' 3,373' 4’ 6 09/05/20 Isolated C-1 4,178’ 4,226’ 3,463' 3,499' 48’ 6 03/27/2009 Plugged C-2 4,326’ 4,334’ 3,574' 3,580' 8’ 6 11/18/2008 Plugged C-2 4,348’ 4,364’ 3,591' 3,603' 16’ 6 11/18/2008 Plugged D-2 4,955’ 5,001’ 4,069' 4,109' 46’ 05/09/2007 Plugged Perfs will go through tubing tail. ... SZ-18A is above x nipple. SZ-21 ±2431’±2450’±2403’±2419’±19’Futire Proposed SZ-18A ±2139’±2156’±2131’±2147’±17’Future Proposed SZ-20 ±2357’±2363’±2336’±2341’±6’Future Proposed 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: G/L Completion / N2 Operations Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,291 feet 3,035 feet true vertical 6,512 feet N/A feet Effective Depth measured 3,000 feet See schematic feet true vertical 2,888 feet See schematic feet Perforation depth Measured depth 2,490 - 2,812 feet True Vertical depth 2,455 - 2,730 feet 4-1/2" 12.6 / L-80 2,466 MD 2,434 TVD Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / L-80 3,085 MD 2,959 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: Production 536 10-3/4" 536 535 5,860psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst Collapse Karson Kozub kkozub@hilcorp.com Tubing Pressure 1,020psi 1,540psi 2,630psi 3,090psi 907 777-8434 6,870psi 936 1,450 2,644 6,496 3,220psi 937 1,451 Conductor Surface 4,760psi 20" 16" 13-3/8" 2,712 6,732 Size 14 Production Casing Structural Length 480 Intermediate N/A Junk 5. Permit to Drill Number: 1,239 McArthur River Field / Middle Kenai Gas PoolN/A measured 2,712 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 3 N/A Oil-Bbl 0 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-320 58 Authorized Signature with date: Authorized Name: 0 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 189-111 50-733-20411-00-00 Plugs ADL001873 Trading Bay Unit M-03 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 820 Casing Pressure 34" 7,268 MD 480 937 1,451 TVD 480 measured true vertical Packer 9-5/8" Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:49 pm, Nov 09, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.11.09 15:42:58 -09'00' Dan Marlowe (1267) SFD 11/9/2020 RBDMS HEW 11/9/2020 SFD 11/9/2020 18730 DSR-11/10/2020gls 11/18/20 Revised by: JLL 11/02/20 SCHEMATIC Steelhead Platform Well: M-03 Last Completed: 9/08/2020 API: 50-733-20411-00 PTD: 189-111 PBTD =3,000’ TD = 7291’ MAX HOLE ANGLE =33q @ 5002’ RKB to TBG Head = 74.4’ KB to MSL = 160’, RKB to mudline = 345’ 20” 16” 13-3/8” SZ-22 SZ-23 SZ-24 & 24B A-2Casing patch 2661’-2681’ Tag sand ~3,900’ 05/26/16 Tag @ 4,093’ RKB ELM 10/21/10 B-2 A-6 B-3-B8 C-1 C-2 D-2 XO XO 1 3 5 67 8 9 10 11 12 13 14 15 16 17 18 19 X 2 4 TOC ±3,000’ X Est. TOC 1,950’ CBL 9/6/20 6a Fish 5,376’ 5’± Cut Tbg; “X” Nipple; 7’ 4-1/2” pup jt Casing Detail SIZE WT GRADE CONN ID TOP BTM. 34” Conductor 30” x 28.5” Surface 480’ 20”133 X-56 RL45 18.730” Surface 895’ 133 X-56 BTC 18.730” 895’ 937’ 16” 75 K-55 BTC 15.240” Surface 1,451’ 13-3/8”61 K-55 BTC 12.515” Surface 2,453’ 68 K-55 BTC 12.412” 2,453’ 2,712’ 10-3/4”55.5 N-80 BTC 9.760” Surface 153’ 51 L-80 BTC 9.850” 153’ 536’ 9-5/8” 47 N-80 BTC 8.681” 536’ 7,268’ Tubing Detail 4-1/2” 12.6 L-80 IBT 3.958” Surface 2,466’ 4-1/2” 12.6 L-80 AB mod BTC 3.958” 3,050’ 3,085’ JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 74.50’ 74.5’ Hanger, FMC TC-1A-EN 1 485’ 485’ 3.813 5.97 Halliburton TRSV NE-SlIM, PN 478ULXE381004E 2 1,503’ 1,503’ 3.935 5.985 GLM #1 - 4 1/2" slim hole 1" , running tool 1 5/16 JK, pulling 1 1/4" JDC 2,020’ 2,016’ 3.935 5.985 GLM #2 - 4 1/2" slim hole 1" , running tool 1 5/16 JK, pulling 1 1/4" JDC 3 2,073’ 2,067’ 3.990 8.25 DLH Packer, pinned 58k shear release 4 2,191’ 2,181’ 3.813 5.00 X Nipple 5 2,466’ 2,434’ 3.958 5.00 WLEG 6 3,035’ 2,017’ 9-5/8” CIBP w/ 36’ Cement (TOC ±3,000) 6a 3,050’ 2,032’ Tubing Cut 7 3,044’ 2,925’ 3.813” 5.250” OTIS X Nipple 8 3,090’ 2,963’ 6.000” 8.440” Packer – Baker SC-1R w/ locator seal assembly 9 3,099’ 2,971’ 6.380” 8.130” Sliding Sleeve 10 3,124’ 2,992’ 4.950” 7.630” XO 11 3,185’ 3,043’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 12 3,290’ 3,131’ 3.725” 8.440”Packer - Baker SC-1L w/ S-22 snap latch, CAMCO XN Nipple, WLEG 13 3,299’ 3,138’ 6.380” 8.130” Sliding Sleeve 14 3,324’ 3,159’ 4.950” 7.630” XO 15 3,360’ 3,189’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 16 3,462’ 3,275’ 3.000” 8.125” Packer – Baker Model D w/ S-22 snap latch & seals 17 4,156’ 3,860’ TTS umbrella plug w/ cement on top 18 5,032’ 4,595’ 6.00” BWH Packer 19 6,600’5,905’6.00”BWH Packer Cement Plug: 5,002’–6,600’ - 8/6/93 Cement Plug: 7,169’–7,283’ - 8/2/90 8-26-20PX plug set ’9-5/8” CIBP w/ 36’ Cement (TOC ±3,000) CIBP 3035ft 6 3,035’ 2,0117’ cut at 3035 ft PX plug Revised by: JLL 11/02/20 SCHEMATIC Steelhead Platform Well: M-03 Last Completed: 9/08/2020 API: 50-733-20411-00 PTD: 189-111 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet Spf Date Comments SZ-22 2,490’ 2,518’ 2,455’ 2,479’ 28’ 10/11/20 Open SZ-23 2,537’ 2,545’ 2,496’ 2,502’ 8’ 10/11/20 Open SZ-24 2,555’ 2,560’ 2,511’ 2,515’ 5’ 10/11/20 Open SZ-24B 2,592’ 2,621’ 2,543’ 2,568’ 29’ 10/11/20 Open SZ-24B Stray 2,642’ 2,648’ 2,586’ 2,591’ 6’ 10/11/20 Open Sqz Perfs 2,661’ 2,681’ 2,602’ 2,619’ 20’ Sqz’d Sqz Perfs 2,671’ 2,673’ 2,610’ 2,612’ 2’ Sqz’d SZ-24B Stray 2,674’ 2,680’ 2,613’ 2,618’ 6’ 10/11/20 Open SZ-24B Stray 2,695’ 2,705’ 2,631’ 2,639’ 10’ 10/11/20 Open A-2 2,737’ 2,812’ 2,666’ 2,730’ 75’ 10/3/20-10/4/20 Open A-6 3,202’ 3,278’ 2,753' 2,808' 76’ 12 09/05/20 Isolated B-2 3,370’ 3,430’ 2,874' 2,917' 60’ 12 09/05/20 Isolated B-2 3,440’ 3,450’ 2,925' 2,932' 10’ 12 09/05/20 Isolated B-3 3,499’ 3,555’ 2,967' 3,007' 56’ 5 09/05/20 Isolated B-4 3,564’ 3,592’ 3,013' 3,033' 28’ 6 09/05/20 Isolated B-4 3,610’ 3,624’ 3,046' 3,056' 14’ 6 09/05/20 Isolated B-5 3,780’ 3,850’ 3,169' 3,220' 70’ 6 09/05/20 Isolated B-6 3,895' 3,898' 3,253' 3,255' 3’ 6 09/05/20 Isolated B-6B 3,956' 3,978' 3,298' 3,314' 22’ 6 09/05/20 Isolated B-7 4,015' 4,035' 3,341' 3,356' 20’ 6 09/05/20 Isolated B-8 4,054' 4,058' 3,370' 3,373' 4’ 6 09/05/20 Isolated C-1 4,178’ 4,226’ 3,463' 3,499' 48’ 6 03/27/2009 Plugged C-2 4,326’ 4,334’ 3,574' 3,580' 8’ 6 11/18/2008 Plugged C-2 4,348’ 4,364’ 3,591' 3,603' 16’ 6 11/18/2008 Plugged D-2 4,955’ 5,001’ 4,069' 4,109' 46’ 05/09/2007 Plugged SZ-22 2,490’ 2,518’ 2,455’ 2,479’ 28’ 10/11/20 Open SZ-23 2,537’ 2,545’ 2,496’ 2,502’ 8’ 10/11/20 Open SZ-24 2,555’ 2,560’ 2,511’ 2,515’ 5’ 10/11/20 Open SZ-24B 2,592’ 2,621’ 2,543’ 2,568’ 29’ 10/11/20 Open SZ-24B Stray 2,642’ 2,648’ 2,586’ 2,591’ 6’ 10/11/20 Open SZ-24B Stray 2,674’ 2,680’ 2,613’ 2,618’ 6’ 10/11/20 Open SZ-24B Stray 2,695’ 2,705’ 2,631’ 2,639’ 10’ 10/11/20 Open A-2 2,737’ 2,812’ 2,666’ 2,730’ 75’ 10/3/20-10/4/20 Open Rig Start Date End Date HAK 404 / CTU SL / EL 8/26/20 10/11/20 09/02/20 - Wednesday Production fill annulus & pressure test t/750 psi good. Mobe crews to platform, & orientate. PJSM. Bleed tubing down & monitor good. Set BPV, lock open SSV, test void t/3k good, break flange bolts on tree valves, stand by while crane re-gens. Prep riser & clamp f/ nipple up. N/D tree valves, & adaptor ( had to work adaptor free ). Dress wellhead/tubing hanger. Clean and inspect lift threads (4 1/2" BTC). Install blanking sub. Set in first riser. Install wire line bridge. Set in second section of riser and install gray-lock clamps. Nipple up BOPE: mud cross, double gate and annular preventer. Torque bolts to specs. Organize drill deck equipment. 09/03/20 - Thursday Spot choke house, prep mast, raise, scope & secure same. Spot pits & pump, adjust to well, center. Cont. r/u floor, modify extensions for floor & install, run circulating lines from pump t/ pits, r/u & test gas alarms & pvt system. Modify dog house legs. Install guy lines. Attach super choke. Set landing on dog house. Set stairs to rig floor. Remove brake linkage for modification and re-install. Fabricate slip plate for top of an nular. Repair ruptured hydraulic hose on carrier motor. Reset rig floor. Gather subs for test joint. Assist welder with modifications. Fill pits with FIW. Finish brake linkage modification and install. Finish modifications on rig floor legs. Assist welder. Build test joint on drill deck. Mount weight indicator. Dress rig floor. 08/26/20 - Wednesday Mobe w/l crews out, orientate & PJSM. R/U w/l. M/U tools 3.80 GR. P/T lubricator 250/1500, good. RIH w/3.80 GR t/ 3086' WLM, POOH. RIH w/ 4 1/2" x-line & PX plug t/3064' WLM, set plug. POOH. RIH w/2 1/2" SB & prong t/3063' WLM, set prong, POOH, verify prong set. Fill tubing w/ FIW, bleed air as needed, PT t/250/500psi f/5 min good. R/D w/l & de-mobe crew from platform. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-03 50-733-20411-00-00 189-111 RIH w/ 4 1/2" x-line & PX plug t/3064' WLM, set plug. Production fill annulus & pressure test t/750 psi good. Rig Start Date End Date HAK 404 / CTU SL / EL 8/26/20 10/11/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-03 50-733-20411-00-00 189-111 M/U 4 1/2" Test jt, fill stack, continue working on DS stair install, unload boat. Shell test 250/2500psi, work through test eq. issues, & test, good. Test BOPE as per Hilcorp & AOGCC requirements. AOGCC witness waived by inspector Jim Regg 9-3-20 @ 11:12am. Tested with 4 1/2" TJ, 250/2500 psi good. (Note: Guy Schwartz w/AOGCC granted approval to drop single gate from stack configuration). Pull blanking sub, break down test eq. R/u handling eq. R/u circulating lines to production. P/U "T" bar pull BPV, install landing joint, break down test subs & m/u safety valve. Make up landing joint. Back out lock down screws. Pick up to 40K and unseat tubing hanger. Pick up another foot. Set slips. Rig Pollard wire line. RIH with 3.50 jet cutter. Make cut at 3035'. Tubing and annulus both went on vacuum. POOH with tools to SSSV. Valve had shut (possible ruptured control line on top of tubing hanger when pulling BPV). Attempt to pump SSSV open while working wire line. Rope socket failed. Pumped +/-230 bbls of FIW down tubing with no returns. Consult with town. Decision made to fish tools without picking string up more than a few feet. Picked up string +/-2 ' to insure tubing was cut. P/U weight 38K. Mobilize tools and wire line operator to platform. Pump 2 BPM into annulus while waiting on tools and operator. Tools and wire line operator arrived on platform. Discuss options and consult with engineer. Decision made to POOH and fish for jet cutter assembly due to well control issues. Rig down wire line. Cease filling hole (total of +/-430 bbls FIW pumped). Pull and lay down tubing hanger. 35K P/U weight. SSSV control line was severed. Pressured SSSV to 4K and locked in. POOH standing back 4 1/2" 12.6# BTC tubing to SSSV and lay down same. Pumping 20 bbls FIW into well bore every hour. 09/05/20 - Saturday Cont. POOH standing back total of 7 stands. L/d sssv, chem inj mandrel & 2 flow couplings. Started seeing pitting on pipe, decision made to l/d tubing. Install slide. Cont. POOH l/d 4 1/2" tubing t/ cut, recovered 92 joints, one cut joint, chem inj. mandrel, SSSV, 2-flow couplings, & 22 SS bands. R/U w/l. RIH w/2" JDC w/3.75" bell guide t/ 3030'KB, latch e-line tools & POOH recover tools. RIH w/8.23" GR/junk basket t/2660' tag. POOH. RIH w/7" junk basket t/ 3042' WLM, tag. POOH. R/D w/l. R/U e-line. Housekeeping & rig maint. while waiting on boat with 9 5/8" CIBP & running tools. TIH w/ 7 stands of 4 1/2" tubing. POOH l/d same. Rig up e-line. Pick up CIBP. RIH and set 9 5/8" CIBP at 3035'. POOH. Back load tubing and offload new 4 1/2" 12.6# tubing. Lay down running tool. Pick up cement dump baler. Fill hole pumping at 3 BPM (240 bbls). Monitor well static with fluid at mud cross. Make 4 cement baler runs putting 2.67 bbls or 36' on top of CIBP. TOC is +/-3000'. 09/06/20 - Sunday Finish POOH w/dump bailer run #4 dumped. R/u CBL tools. RIH & log CBL f/ 2980' -1300', ETC 1950. Prep to p/u c/o assy, get BHA to floor & m/u. Rig maint. & housekeeping while waiting on crane repair. M/U 9 5/8" scraper assy,- scraper, bit sub , xo = 8.33. RIH t/55', r/u & flush stack @ 3bpm. Cont. RIH p/u 4 1/2" L80 12.6# IBT tubing to 2398'. Rig up and circulate bottoms up at 3 BPM/50 psi. POOH standing back tubing. Lay down casing scraper. Rig up and test 9 5/8" casing at 1550 psi on chart for 30 minutes. Pick and run completion assembly with stands out of derrick. t/ 1505'. 09/04/20 - Friday Cutter left in hole... fish RIH w/2" JDC w/3.75" bell guide t/ 3030'KB, latch e-line tools & POOH recover tools. RIH w/8.23" GR/junk basket t/2660' tag. POOH. RIH w/7" junk basket t/ 3042' WLM, tag. POOH. POOH standing back 4 1/2" 12.6# BTC tubing to SSSV and lay down same. Pumping 20 bbls FIW into well bore every hour. TOC is +/-3000'. fish out tools Pick up CIBP. RIH and set 9 5/8" CIBP at 3035' Test BOPE as per Hilcorp & AOGCC requirements. AOGCC witness waived by inspector Jim Regg 9-3-20 @ 11:12am. Tested with 4 1/2" TJ, 250/2500 psi good. RIH with 3.50 jet cutter. Make cut at 3035'. Tubing and annulus both went on vacuum. Rig up and test 9 5/8" casing at 1550 psi on chart for 30 minutes. Pic Pick up to 40K and unseat tubing hanger. Rig Start Date End Date HAK 404 / CTU SL / EL 8/26/20 10/11/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-03 50-733-20411-00-00 189-111 Tested tree 250/5000 good. Pull TWC, turn well over to production. 09/30/20 - Wednesday PJSM & Permits. Spot flowback tank. Pull drill deck well hatch & set bridge. Run CTU hydraulic & electrical lines to/from power pack & generator to ops cab, CT reel, BOP stack & injector. MU riser & BOP to WH. Run pump and flowback lines. Test BOPE as per Hilcorp & AOGCC requirements, witnessed waived 9/29/2020 09:16 by AOGCC inspections Supervisor Jim Regg, 250 LOW /3000 HIGH. Email BOPE Test Report to AOGCC. Change packoffs, do chain inspection, stab pipe into injector. Stand by for wind to die down. Able to work crane, move N2 pump, N2 tanks. Rig in flow back tanks and filter pod. Run hardline from N2 pump to IA. Secure deck and well. SDFN 09/07/20 - Monday Cont. rih w/ 4 1/2" completion f/ 1505' t/1971'. P/U SSSV, make up, function test good, pump & lock open. Cont. rih w/ 4 1/2" completion f/1971' t/2458'. P/U hanger & make up same with landing joint. Drain stack & land hanger, up wt 25k, dn wt 25k. RILD pins, placing tubing tail @ 2461. R/u drop bar & set packer as per rep. Pressure up t/ 1100psi f/10 min, 2750 hold f/30 min (tubing test), 3500 f/10 min, all good, placing packer @2106'. R/U & test annulus t/ 1700 f/30 min good. R/D test eq. R/U w/l. (Note found mistake on tally, consulted with town decision made to pull completion & rectify mistake. Tail is at 2533', packer @ 2169'). RIH & retrieve prong, r/d wireline. BOLD pins, pull hanger free, cont. working string up staging up t/ 83k to pull packer free. Pull & l/d packer, l/D 2 joints & cont. POOH standing back stands changing seal rings. Lay down GLM's, SSSV and packer. Service rig while waiting on TriPoint packer and tool rep. Offload work boat. Add 4' pup joint to packer on drill deck. Make up packer. RIH with completion assembly as per running tally. Make up tubing hanger. Drain stack. Make up control line and test at 4000 psi. Land string. 25 K. Run in lock down screws. Tubing tail at 2466'. Pressure up on tubing to 1500psi f/10 min. 2750 hold f/30 min (tubing test), 3650 f/10 min, all good, placing packer @2070'. 09/08/20 - Tuesday Test annulus at 1700 psi on chart for 30 minutes. R/d testing eq. R/U w/l RIH w/2" JDC pull prong, POOH recovered, rih latch & recover PX plug. RIH w/ 2.25 bailer tag toc @ 2995' kb. POOH, R/D w/l. Pull landing joint, set BPV. Clear floor & start r/d aux eq. R/d circulating lines from pits & pump. Finish clearing floor, remove beaver slide. Break down stairs, rig floor. Prepare mast to scope down & lay over. Scope derrick down, prep to laydown. Unspool tuggers and drill line. Lay mast over. Nipple down annular, double gate and mud cross. Nipple down and pull risers. Dress tubing hanger. Nipple up tree and flow lines. Test void at 5000 psi for 10 minutes. Pull BPV/set two-way check. Testing tree at 250 L/5000 H. 09/09/20 - Wednesday Test annulus at 1700 psi on chart for 30 minutes. HAK 404 /HAK 404 Cont. rih w/ 4 1/2" completion f/ 1505' t/1971'. P/ pull and reset . R/u drop bar & set packer as per rep. Pressure up t/ 1100psi f/10 min, 2750 hold f Completion too deep placing packer @2070' Tubing tail at 2466' BOLD pins, pull hanger free, cont. working /U Rig Start Date End Date HAK 404 / CTU SL / EL 8/26/20 10/11/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-03 50-733-20411-00-00 189-111 10/02/20 - Friday Eline Crew arrive at Heliport for flight to Steelhead. Eline crew Arrive on Steelhead. PJSM & Permits. Move Eline Equipment into place. Put wire rack, Eline tool shack and grease box in place. Run Eline through grease head, Make up Eline to rope socket. Test Eline conectivity, good test. Make up firing head, Gamma/CCL. Test connection again. Good test. Put 30' lubricator on tree up to drill deck. Make up Gun #1, 25', 2.875" Razor, 6 spf, 60 deg phasing 15 gram gun. Stab on well, Pt Lub/WLV 250/1500. Good test. Open well, swab 25, WHP 40, IA 190, OA 140, OOA 140. RIH 239' lost communication with tools. Shut down computers. Reboot computers multiple times. Regained communication with tools. CRIH to tag depth 3035' RKB. Log up to 2553'. Sent log to Enginers. Got approval (Geologist) to shoot A2 sands, 2787'- 2812'. RBIH to tag, log up getting on CCL depth 2778'. CCL t/top shot 8.5', CCL t/bottom shot 34', perf 2787'-2812'. ITP 40psi, FTP 80.1psi Well shut in. Log up 200'. POOH. Tagged up, swab shut, pop off well. All shots fired. Dry gun. Secure well and Wireline unit. LDFN 10/03/20 - Saturday Back load boat with coil package. E-line standby. Boat loaded and gone. PU Lubricator, run E-line down, test connection, good test. Make up Gun #2, 25', 2.875" Razor, 6 spf, 60 deg phasing 15 gram gun. Stab on well, Pt Lub/WLV 250/1500. Good test. Open well, swab 25 turns, WHP 11, IA 180, OA 140, OOA 140. RIH to 3035'. Pull log up to 2500'. Download and send off for approval to shoot 2762-2787'. Got approval (Geologist) to shoot. RIH to tag depth, Pull up to CCL Depth 2753'. CCL T/top shot 8.5', CCL t/ bottom shot 34'. Shoot A2 sands 2762'-2787'. ITP 11, FTP 13. Rate increase of 200,000. log up 200'. POOH, Tagged up, swab shut, pop off well. All shots fired, dry gun, lay down spent gun. Make up Gun #3, 25', 2.875" Razor, 6 spf, 60 deg phasing 15 gram gun. Stab on well. Open well RIH. Tag 3035', Log up to 2500'. Send log to town for approval. Got approval ( Geologist) to shoot 2737'-2762'. RIH, log up to CCL depth 2728.5'. CCL t/top shot 8.5', CCL t/bottom shot 34'. Perf A2 sands 2737'-2762'. ITP 13 PSI, FTP 26 PSI. Log up 200'. POOH, Tagged up, swab shut, pop off well. All shots fired, dry gun. RDMO. 10/01/20 - Thursday PJSM & Permits. Pick up injector, 10' lubricator, make up cc, pull test 20k, make up two stingers and BDJSN. (CTC 1.5" X .34') ( STINGER 1.5" X 4.8') ( STINGER 1.5" X 4.8') ( XO 1.5" X .54') ( BDJSN 1.75" X .58') TOL=11.06'. Stab on well. PT low/high 250/3300. Open well, Swab 25, WHP 0, IA 0, OA 125, OOA 125. RIH, WT CK 2900'=6K. Park at 2930' CTMD. PT N2 line to gate valve on IA. 250/2500. Come online with N2 down IA @ 500 scfm, taking returns up the coil to the tanks. WHP 0, IA 825, OA 125, OOA 125. Returned 100 bbls to gas buster tank. Pumped N2 for extra 30 min. Getting all gas back to surface. PU to 2466' RKB letting whp bleed down before pooh. POOH, Tagged up, swab shut, bleed down, pop off well. Rig line to kill port on bops to bleed down rest of WHP and IA to return tank. Start Rigging down CTU package. CTU package rigged down and ready to be back loaded on the boat. displace to N2 with CT CTUCTU Eline perforating Park at 2930' CTMD. Rig Start Date End Date HAK 404 / CTU SL / EL 8/26/20 10/11/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name M-03 50-733-20411-00-00 189-111 PJSM & Permits. Pick up grease head, lubricator. Run wire down make up GR/CCL. Test wire. Good test. Make up Gun #4, 10', 2.875", 6 spf, 60* phasing, 15 gram razor gun. Stab on well, pt low/high 250/1500. O-ring leak on riser. Replace O-ring. Re pt, Good test. Open well, T/IA/OA= 26/12/160, @ 2900', pull correlation log up to 2500'. Send log to town engineers for approval to shoot SZ-24B stray sands 2695'-2705'. Got approval to shoot SZ-24B stray sands 2695'-2705' (Geologist). RIH t/2900', PU to CCL depth 2686.6', CCL t/top shot 8.5', CCL t/bottom shot 18.5'. Shoot SZ-24B stray sands 2695'-2705'. ITP 68, FTP 72. Well shut in. Log up 200'. POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired, Dry gun. Make up Gun #5, 6', 2.875", 6 spf, 60* phasing, 15 gram razor gun. Stab on well. Open up, RIH,@ 2900', log up to 2500', send log to town engineers for approval to shoot the SZ-24B Stray sands 2674'-2680'. Got approval to shoot SZ-24B Stray sands 2674'-2680' (Geologist) RIH to 2900', pu to CCL depth 2665.75', CCL t/top shot 8.25', CCL t/ bottom shot 14.25'. Shoot SZ-24B stray sands 2674'-2680'. ITP 79 psi, FTP 80 psi. Log up 200', POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired, Dry gun. Make up Gun #6, 6', 2.875", 6 spf, 60* phasing, 15 gram razor gun. Stab on well. Open up, RIH,@2900', log up to 2500'. Send log to town engineers for approval to shoot SZ-24B stray 2642'-2648'. Got approval to shoot SZ-24B stray sand 2642'- 2648' (Geologist). RIH to 2900', pu to CCL depth 2633.75', CCL t/top shot 8.25', CCL t/bottom shot 14.25'. Shoot SZ-24B stray stand 2642'-2648'. ITP 81 psi, FTP 82 psi. Well shut in. Log up 200'. POOH,Tagged up, swab shut, bleed down. Pop off well. All shots fired. Dry gun. Make up Gun #7, 29', 2.875", 6 spf, 60* phasing, 15 gram razor gun. Stab on well. Open up, RIH,@2900', log up to 2500', Send log to town engineers for approval to shoot SZ-24B 2592'-2621'. Got approval to shoot SZ-24B sand 2592'-2621' (Geologist) RIH to 2900', PU to CCL depth 2583.5', CCL t/top shot 8.5', CCL t/bottom shot 37.5'. Shoot SZ-24B sands 2592'-2621'. ITP 87.5 psi, FTP 90.5 psi. Well SI. Log up 200', POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired. Dry gun. Make up Gun #8, 5', 2.875", 6 spf, 60* phasing, 15 gram razor gun. Stab on well. Open up, RIH,@2900', log up to 2500', Send log to town engineers for approval to shoot SZ-24 2555'-2560'. Got approval to shoot SZ-24B sand 2592'-2621' (Geologist) RIH to 2900', PU to CCL depth 2546', CCL t/top shot 9', CCL t/bottom shot 14', Shoot SZ-24 sands 2555'- 2560'. ITP 96psi, FTP 98 psi. Well SI, Log up 200', POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired. Dry gun. Make up Gun #9, 8', 2.875", 6 spf, 60* phasing, 15 gram razor gun. Stab on well. Open up, RIH,@2900', log up to 2500', Send log to town engineers for approval to shoot SZ-23 2537'-2545'. Got approval to shoot SZ-23 sands 2537'-2545'. (Geologist) RIH to 2900', PU to CCL depth 2527', CCL t/top shot 10 ', CCL t/bottom shot 18' , Shoot SZ-23 sands 2537'-2545'. ITP 102psi, FTP 102 psi. Well SI, Log up 200', POOH Tagged up, swab shut, bleed down, pop off well. All shots fired. Dry gun. Make up Gun #10, 28', 2.875", 6 spf, 60* phasing, 15 gram razor gun. Stab on well. Open up, RIH,Tools stopped communicating while logging up. POOH change out tools. test tools at surface. test good. Stab back on the well, rih, @2700', log up to 2200', Send log to town engineers for approval to shoot SZ-22 2490'-2518'. Got approval to shoot SZ-22 sands 2490'-2518'. (Geologist) RIH to 2700', PU to CCL depth 2483', CCL t/top shot 7 ', CCL t/bottom shot 35' , Shoot SZ-22 sands 2490-2518'. ITP 102psi, FTP 115psi. Well SI, Log up 200', POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired. Dry gun. RD ELU. Turn well over to Production to BOL. Secure unit and drill deck for the night. 10/11/20 - Sunday / EL 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7,291'N/A Casing Collapse Structural Conductor Surface 1,020 psi Intermediate 1,540 psi Production 3,220 psi Production 4,760 psi Liner 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:kkozub@hilcorp.com Contact Phone: (907) 777-8384 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 6,512'3,900'3,644'917 psi 6,496'9-5/8" Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 8/14/2020 4-1/2" Daniel E. Marlowe See schematic Tubing Size: 7,268' Perforation Depth MD (ft): 536' 3,202 - 4,058 6,732' See schematic Tubing Grade:Tubing MD (ft): 2,753 - 3,373 Perforation Depth TVD (ft): 937'20" 16" 13-3/8" 1,451' 10-3/4"536' 2,712'3,090 psi 1,450' 2,644' 535' 1,451' 2,712' 4,156' 937'936' 12.6# / L-80 TVD Burst 3,085 6,870 psi MD 2,630 psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL001873 189-111 50-733-20411-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-03 PRESENT WELL CONDITION SUMMARY Length Size 5,860 psi COMMISSION USE ONLY Authorized Name: Authorized Signature: Operations Manager Karson Kozub CO 228A Other: G/L Completion N2 Operations ~480'34"~480'~480' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:07 am, Aug 03, 2020 320-320 Daniel Marlowe I am approving this document 2020.08.03 09:13:51 -08'00' Daniel Marlowe SFD 8/5/2020 DSR-8/3/2020 10-404 X 404/ CTU gls 8/21/20 *2500 psi BOPE test (rig 404) *3000 psi BOPE test (CTU) *CBL required before perforating well. dts 9/21/2020 8/21/2020Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.08.21 13:08:15 -08'00' RBDMS HEW 8/24/2020 Well Work Prognosis Well Name:M-03 API Number:50-733-20411-00-00 Current Status:SI Gas Producer Leg:Leg B2, NE Corner Estimated Start Date:8/14/2020 Rig:HAK 404 / Coil Tubing Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:189-111 First Call Engineer:Karson Kozub Office: 907-777-8384 Cell: 907-570-1801 Second Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Current Bottom Hole Pressure:358 psi @ 2,753’ TVD 0.130 psi/ft based on 82 psi SITP 7/31/2020 and 0.1psi/ft to 2,753’TVD Maximum Expected BHP:1,192 psi @ 2,753’ TVD 0.433 psi/ft water gradient to surface Maximum Potential Surface Pressure:917 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) Well History: M-03 produced ~1.5mmcfd of gas from the A-6 through B-6 sands until late 2015. After 2015 the well produced minimal amounts of gas until October 2017 and was then shut in due to water influx. This proposed work will isolate the sands from A-06 down and recomplete the well up hole to access the SZ-22 through A- 2 sands. Safety Concerns: x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting methane and Nitrogen during this job) x Ensure all crews are aware of stop job authority (Review Standard Well Procedure – Nitrogen Operations) Wellbore Notes: x Slickline will make drift runs Procedure: 1. RU Slickline pressure test lubricator to 250psi low/1,500psi high a. RIH and set a plug at ±3,040’ i. *this will isolate all open zones b. Fill tubing with FIW and pressure test plug to ±500psi for 5 min to ensure plug holds 2. RU E-line pressure test lubricator to 250psi low/1,500psi high a. RIH with tubing cutter. Cut tubing ±3,035’. RD E-line. 3. Circulate well with FIW from waterflood to the production header 4. MIRU HAK 404 5. Ensure well is full of fluid and static a. *Note: tubing plug at 3,040’ is isolating all open zones 6. Set BPV, ND Tree, NU BOPEs 7. Test BOPEs to 250psi low/2,500psi high /2,500psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 8. Monitor well to ensure its static, pull BPV 9. Unseat hanger and pull upper completion to ±2,500’. a. Laying down the SSSV, flow couplings, and GLM’s 10. RIH with tubing to ±3,035’ 11. RU cement set plug cut tubing 3035' MIRU HAK 404 BOPE test 2500 psi pull tubing (Test casing to 500 psi ?) Well Work Prognosis a. Test lines to 250psi low/4,500psi high b. Pump ±3bbl of cement TOC ±3035’ c. Slowly pick up above cement and circulate clean 12. POOH with 4.5” tubing. 13. RU E-line CBL Logging tool. RIH and Log ±3,030’ to TOC. POOH – Send log to AOGCC 14. Pressure test casing to 1,500psi, chart for 30min a. Wait on cement ~18hrs before testing 15. RIH with casing scraper to ±2,200’. Circulate clean. POOH. a. Note casing patch at ±2,661’ 16. RIH with 4-1/2” gas lift completion (live valves), SSSV, and packer assembly. See proposed schematic for details and set depths. 17. Set Packer / Pressure test completion: a. Pressure up and set packer b. Test tubing against plug in X nipple to ш2,500psig and chart for 30 minutes. c. Test IA to 1,500 psi and chart for 30 minutes (This will pressure up tubing also). d. Pull prong and plug in X-Nipple. 18. Set BPV. NU tree, test same. 19. RD HAK 404 20. MIRU Coil tubing 21. Test BOP’s to 250psi low/3,000psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). a. Blow the well dry with N2 b. Returns taken to the production header c. RD Coil tubing 22. RU E-line and perforate per program. 23. Turn over to production. 24. Schedule SVS testing with AOGCC as per regulations Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Wellhead Diagram 4. BOP Stack 5. Standard Well Procedure – Nitrogen Operations 6. Flow Diagrams 7. Coil Tubing BOP stack 8. RWO Sundry Revision Change Form MIT casing pre-completion Note: casing patch will see pressure. (send to: guy.schwartz@alaska.gov)CBL cement cap on plug Run completion MIT-IA (with X plug in tubing tail) MIRU Coil tubingMove in CTU Revised by: JLL 06/07/18 SCHEMATIC PBTD =5002’’ TD = 7291’ MAX HOLE ANGLE =33qq @ 500 2’ RKB to TBG Head = 74.4’ KB to MSL = 160’, RKB to mudline = 345’ 20” 16” 13-3/8” XCasing patch 2661’-2681’ Tag sand ~3,900’ 05/26/16 Tag @ 4,093’ RKB ELM 10/21/10 B-2 A-6 B-3-B8 C-1 C-2 D-2 XO XO 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Fish 5,376’ 5’± Cut Tbg; “X” Nipple; 7’ 4-1/2” pup jt Casing Detail SIZE WT GRADE CONN ID TOP BTM. 34” Conductor 30” x 28.5” Surface 480’ 20”133 X-56 RL45 18.730” Surface 895’ 133 X-56 BTC 18.730” 895’ 937’ 16” 75 K-55 BTC 15.240” Surface 1,451’ 13-3/8”61 K-55 BTC 12.515” Surface 2,453’ 68 K-55 BTC 12.412” 2,453’ 2,712’ 10-3/4”55.5 N-80 BTC 9.760” Surface 153’ 51 L-80 BTC 9.850” 153’ 536’ 9-5/8” 47 N-80 BTC 8.681” 536’ 7,268’ Tubing Detail 4-1/2” 12.6 L-80 AB mod BTC 3.958” Surface 3,085’ JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 74.50’ 74.5’ Hanger, FMC TC-1A-EN 1 436’ 436’ 3.958” 5.230” CAMCO Flow Coupling 2 441’ 441’ 3.958” 7.430” GLM – CAMCO MMG-LTS 3 450’ 450’ 3.958” 5.230” Flow Coupling 4 455’ 455’ 3.813” 7.150” SCSSV – CAMCO TRDP-4AO 5 3,044’ 2,925’ 3.813” 5.250” OTIS X Nipple 6 3,090’ 2,963’ 6.000” 8.440” Packer – Baker SC-1R w/ locator seal assembly 7 3,099’ 2,971’ 6.380” 8.130” Sliding Sleeve 8 3,124’ 2,992’ 4.950” 7.630” XO 9 3,185’ 3,043’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 10 3,290’ 3,131’ 3.725” 8.440”Packer - Baker SC-1L w/ S-22 snap latch, CAMCO XN Nipple, WLEG 11 3,299’ 3,138’ 6.380” 8.130” Sliding Sleeve 12 3,324’ 3,159’ 4.950” 7.630” XO 13 3,360’ 3,189’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 14 3,462’ 3,275’ 3.000” 8.125” Packer – Baker Model D w/ S-22 snap latch & seals 15 4,156’ 3,860’ TTS umbrella plug w/ cement on top 16 5,032’ 4,595’ 6.00” BWH Packer 17 6,600’ 5,905’ 6.00” BWH Packer Steelhead Platform Well: M-03 Last Completed: 09/19/1993 As Perforated: 07/20/2012 API: 50-733-20411-00 PTD: 189-111 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet Spf Date Comments A-6 3,202’ 3,278’ 2,753' 2,808' 76’ 12 09/17/1993 B-2 3,370’ 3,430’ 2,874' 2,917' 60’ 12 09/15/1993 B-2 3,440’ 3,450’ 2,925' 2,932' 10’ 12 09/15/1993 B-3 3,499’ 3,555’ 2,967' 3,007' 56’ 5 12/29/2011 B-4 3,564’ 3,592’ 3,013' 3,033' 28’ 6 10/22/2010 B-4 3,610’ 3,624’ 3,046' 3,056' 14’ 6 10/22/2010 B-5 3,780’ 3,850’ 3,169' 3,220' 70’ 6 10/21/2010 B-6 3,895' 3,898' 3,253' 3,255' 3’ 6 07/20/2012 B-6B 3,956' 3,978' 3,298' 3,314' 22’ 6 07/20/2012 Covered by sand B-7 4,015' 4,035' 3,341' 3,356' 20’ 6 07/20/2012 Covered by sand B-8 4,054' 4,058' 3,370' 3,373' 4’ 6 07/20/2012 Covered by sand C-1 4,178’ 4,226’ 3,463' 3,499' 48’ 6 03/27/2009 Plugged C-2 4,326’ 4,334’ 3,574' 3,580' 8’ 6 11/18/2008 Plugged C-2 4,348’ 4,364’ 3,591' 3,603' 16’ 6 11/18/2008 Plugged D-2 4,955’ 5,001’ 4,069' 4,109' 46’ 05/09/2007 Plugged Cement Plug: 5,002’–6,600’ - 8/6/93 Cement Plug: 7,169’–7,283’ - 8/2/90 tbg cut 3030 ft. set X plug Revised by: JLL 07/31/20 PROPOSED Steelhead Platform Well: M-03 Last Completed: Future API: 50-733-20411-00 PTD: 189-111 PBTD =5002’’ TD = 7291’ MAX HOLE ANGLE =33q @ 5002’ RKB to TBG Head = 74.4’ KB to MSL = 160’, RKB to mudline = 345’ 20” 16” 13-3/8” SZ-18 SZ-22 SZ-23 SZ-24 A-2XCasing patch 2661’-2681’ Tag sand ~3,900’ 05/26/16 Tag @ 4,093’ RKB ELM 10/21/10 B-2 A-6 B-3-B8 C-1 C-2 D-2 XO XO 1 3 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 X 2 4 Fish 5,376’ 5’± Cut Tbg; “X” Nipple; 7’ 4-1/2” pup jt Casing Detail SIZE WT GRADE CONN ID TOP BTM. 34” Conductor 30” x 28.5” Surface 480’ 20”133 X-56 RL45 18.730” Surface 895’ 133 X-56 BTC 18.730” 895’ 937’ 16” 75 K-55 BTC 15.240” Surface 1,451’ 13-3/8”61 K-55 BTC 12.515” Surface 2,453’ 68 K-55 BTC 12.412” 2,453’ 2,712’ 10-3/4”55.5 N-80 BTC 9.760” Surface 153’ 51 L-80 BTC 9.850” 153’ 536’ 9-5/8” 47 N-80 BTC 8.681” 536’ 7,268’ Tubing Detail 4-1/2” 12.6 L-80 AB mod BTC 3.958” Surface ±2,450’ JEWELRY DETAIL NO.Depth (MD) Depth (TVD)ID OD Item 74.50’ 74.5’ Hanger, FMC TC-1A-EN 1 ±455’ ±455’ TR-SCSSSV 2 ±1,093’ ±1,093’ GLM 2a ±2,070’ ±2,064’ GLM 3 ±2,100’ ±2,094’ Retrievable Packer 4 ±2,130’ ±2,122’ X-nipple 5 ±2,450’ ±2,419’ WLEG 6 ±3,030’ ±2,913’ Tubing Cut 7 3,044’ 2,925’ 3.813” 5.250” OTIS X Nipple w/ plug and ±5’ of cement 8 3,090’ 2,963’ 6.000” 8.440” Packer – Baker SC-1R w/ locator seal assembly 9 3,099’ 2,971’ 6.380” 8.130” Sliding Sleeve 10 3,124’ 2,992’ 4.950” 7.630” XO 11 3,185’ 3,043’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 12 3,290’ 3,131’ 3.725” 8.440”Packer - Baker SC-1L w/ S-22 snap latch, CAMCO XN Nipple, WLEG 13 3,299’ 3,138’ 6.380” 8.130” Sliding Sleeve 14 3,324’ 3,159’ 4.950” 7.630” XO 15 3,360’ 3,189’ 4.950” 6.190” 5-1/2” Screens, 0.12 Gauge 20/40 Bakerbond 16 3,462’ 3,275’ 3.000” 8.125” Packer – Baker Model D w/ S-22 snap latch & seals 17 4,156’ 3,860’ TTS umbrella plug w/ cement on top 18 5,032’ 4,595’ 6.00” BWH Packer 19 6,600’ 5,905’ 6.00” BWH Packer Cement Plug: 5,002’–6,600’ - 8/6/93 Cement Plug: 7,169’–7,283’ - 8/2/90 X plug with cmt cap (thru the tubing tail) CBL required Revised by: JLL 07/31/20 PROPOSED Steelhead Platform Well: M-03 Last Completed: Future API: 50-733-20411-00 PTD: 189-111 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet Spf Date Comments SZ-18 ±2,139’ ±2,156’ ±2,131’ ±2,147' ±17’ Future Proposed SZ-22 ±2,490’ ±2,518’ ±2455’ ±2479’ ±28’ Future Proposed SZ-23 ±2,537’ ±2,545’ ±2496’ ±2502’ ±8’ Future Proposed SZ-22 Stray ±2,555’ ±2,560’ ±2511’ ±2515’ ±5’ Future Proposed SZ-24 ±2,592’ ±2,621’ ±2543’ ±2568’ ±29’ Future Proposed SZ-24B Stray ±2,642’ ±2,648’ ±2586’ ±2591’ ±6’ Future Proposed Sqz Perfs ±2,661’ ±2,681’ ±2602’ ±2619’ ±20’ Future Proposed Sqz Perfs ±2,671’ ±2,673’ ±2610’ ±2612’ ±2’ Future Proposed SZ-24B Stray ±2,674’ ±2,680’ ±2613’ ±2618’ ±6’ Future Proposed A-2 ±2,742’ ±2,805’ ±2670’ ±2724’ ±63’ Future Proposed A-6 3,202’ 3,278’ 2,753' 2,808' 76’ 12 09/17/1993 Isolated B-2 3,370’ 3,430’ 2,874' 2,917' 60’ 12 09/15/1993 Isolated B-2 3,440’ 3,450’ 2,925' 2,932' 10’ 12 09/15/1993 Isolated B-3 3,499’ 3,555’ 2,967' 3,007' 56’ 5 12/29/2011 Isolated B-4 3,564’ 3,592’ 3,013' 3,033' 28’ 6 10/22/2010 Isolated B-4 3,610’ 3,624’ 3,046' 3,056' 14’ 6 10/22/2010 Isolated B-5 3,780’ 3,850’ 3,169' 3,220' 70’ 6 10/21/2010 Isolated B-6 3,895' 3,898' 3,253' 3,255' 3’ 6 07/20/2012 Isolated B-6B 3,956' 3,978' 3,298' 3,314' 22’ 6 07/20/2012 Covered by sand B-7 4,015' 4,035' 3,341' 3,356' 20’ 6 07/20/2012 Covered by sand B-8 4,054' 4,058' 3,370' 3,373' 4’ 6 07/20/2012 Covered by sand C-1 4,178’ 4,226’ 3,463' 3,499' 48’ 6 03/27/2009 Plugged C-2 4,326’ 4,334’ 3,574' 3,580' 8’ 6 11/18/2008 Plugged C-2 4,348’ 4,364’ 3,591' 3,603' 16’ 6 11/18/2008 Plugged D-2 4,955’ 5,001’ 4,069' 4,109' 46’ 05/09/2007 Plugged (these perfs are thru tbg tail)SZ-18 ±2,139’±2,156’±2,131’±2,147'±17’Future Proposed Isolated perfs. Steelhead Platform M-03 Current 11/13/2015 Starting head, FMC, 30'’ MSS FE X 28'’ butt weld Casing head, 20'’ BTC casing btm X 21 ¼ 2M FMC speedlock top, w/ 2-2'’ LPO Unihead, FMC Type 2, 16 ¾ 5M FE top X 21 ¼ 2M FMC speedlock bottom, w/ 4- 2 1/16 5M SSO Tubing head, FMC-TC-60, spec for unihead, 16 ¾ 5M FE top X 16 ¾ 5M stdd bottom, w/ 2- 2 1/16 5M SSO Valve, FMC-120, 2 1/16 5M FE, HWO, AA 28'’ 16'’ 13 3/8'’ 10 ¾’’ 4 1/2 Steelhead Platform M-03 28 X 20 X 16 X 13 3/8 X 10 3/4 X 4 1/2 Valve, Swab, FMC-120, 4 1/16 5M FE, HWO, DD Valve, Master, FMC-120, 4 1/16 5M FE, HWO, DD Valve, upper master, FMC-120, SSV, 4 1/16 5M FE, w/ 15'’ Baker operator, EE BHTA, FMC B-11-AO, 4 1/16 5M FE Valve, wing, FMC-120, 4 1/16 5M FE, HWO, DD Tbg hanger, FMC-TC-1A-EN- CCL, 16 ¾ 5M X 4 ½ IBT lift and susp, w/ 4'’ Type H BPV profile, 2- 3/8 continuous control line, Alloy material 20'’ &23<5,*+73$77(56215(17$/722/6$//3$7(175,*+765(6(59('UNLESS OTHERWISE NOTEDALL UNITS IN INCHES/POUNDS/SECONDS.125¥ SURFACE ROUGHNESS ON ALL MACHINED SURFACES.BREAK ALL SHARP EDGES 0.010" MINIMUM.ONE DECIMAL: .XTWO DECIMAL: .XXTHREE DECIMAL: .XXXANGLES:CONCENTRIC:FRACTIONAL:This Document contains Confidentialand proprietary information and maynot be Reproduced, Disclosed, orDistributed in any manner whatsoeverwithout the express written permissionof Patterson Rental Tools.DRAWING NUMBER: 17118R16&$/(5(9$%&'(%'$&('$7('(6&5,37,21%< $33'5HI2QO\ 0$7(5,$/0DWHULDOQRWVSHFLILHG!:WOE07/63(&6'5$:1%<(%RVZHOO&+(&.('%<REV: 1SHEET: 1 OF 216in 5m 2ram . ADFSRR . Hilcorp Alaska LLCDESCRIPTION:&855(175(9,6,21TOLERANCE STRUCTURAL MACHINED - REV. 1 16'-10" 10'-9" 11'-7" &23<5,*+73$77(56215(17$/722/6$//3$7(175,*+765(6(59('UNLESS OTHERWISE NOTEDALL UNITS IN INCHES/POUNDS/SECONDS.125¥ SURFACE ROUGHNESS ON ALL MACHINED SURFACES.BREAK ALL SHARP EDGES 0.010" MINIMUM.ONE DECIMAL: .XTWO DECIMAL: .XXTHREE DECIMAL: .XXXANGLES:CONCENTRIC:FRACTIONAL:This Document contains Confidentialand proprietary information and maynot be Reproduced, Disclosed, orDistributed in any manner whatsoeverwithout the express written permissionof Patterson Rental Tools.DRAWING NUMBER: 17118R16&$/(5(9$%&'(%'$&('$7('(6&5,37,21%< $33'5HI2QO\ 0$7(5,$/0DWHULDOQRWVSHFLILHG!:WOE07/63(&6'5$:1%<(%RVZHOO&+(&.('%<REV: 1SHEET: 2 OF 216in 5m 2ram . ADFSRR . Hilcorp Alaska LLCDESCRIPTION:&855(175(9,6,21TOLERANCE STRUCTURAL MACHINED - REV. 1ITEM NO. DESCRIPTIONQTY.116-3/4" 5M TYPE U DOUBLE BOP DRESSED WITH 4-1/2" SAFETY RAMS ON TOP AND BLIND RAMS ON BOTTOM1216-3/4" 5M DRILLING SPOOL WITH (2) 4-1/16" 5M OUTLETS13 4-1/16" 5M BLIND FLANGE6416-3/4" 10M -X- 16-3/4" 5M DSA1516-3/4" 5M TYPE U SINGLE BOP DRESSED WITH 3-1/2" SAFETY RAMS164-1/16" 5M -X- 2-1/16" 10M DSA272-1/16" 10M MANUAL GATE VALVE282-1/16" 10M HYDRAULIC GATE VALVE292-1/16" 10M -X- 2-1/16" 5M ADAPTER SPOOL21016-3/4" 5M HYDRIL ANNULAR113333267896789335410 Valve Position(O/C)Standpipe PumpManifold1(PM1) OManifold PumpManifold2(PM2) OPumpManifold3(PM3) CPumpManifold4(PM4) OPumpManifold5(PM5) CMud KillLine1OCross KillLine2OHCRvalve(ChokeLine1) CChokeLine2OChoke ChokeManifold1(CM1) OManifold ChokeManifold2(CM2) CChokeManifold3(CM3) OChokeManifold4(CM4) CChokeManifold5(CM5) OChokeManifold6(CM6) CChokeManifold7(CM7) OChokeManifold8(CM8) CChokeManifold9(CM9) CChokeManifold10(CM10) OSuperChoke CManualChoke CRigFloor SafetyValve O Valve Position(O/C)Standpipe PumpManifold1(PM1) OManifold PumpManifold2(PM2) CPumpManifold3(PM3) OPumpManifold4(PM4) CPumpManifold5(PM5) OMud KillLine1OCross KillLine2OHCRvalve(ChokeLine1) CChokeLine2OChoke ChokeManifold1(CM1) OManifold ChokeManifold2(CM2) CChokeManifold3(CM3) OChokeManifold4(CM4) CChokeManifold5(CM5) OChokeManifold6(CM6) CChokeManifold7(CM7) OChokeManifold8(CM8) CChokeManifold9(CM9) CChokeManifold10(CM10) OSuperChoke CManualChoke CRigFloor SafetyValve O Coiled Tubing BOP SWAB VALVE MASTER VALVE Hilcorp Monopod Rig 56 Flow Diagram Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Automatic Choke Manual Choke Pressure Gauge Knife Valve Choke Line P PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLD GAS BUSTER Panic Line C12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Rig 404 BOP Test Procedure Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program – Oil Producers, Gas Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. x Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test) joint to lift-threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) Rig 404 BOP Test Procedure Attachment #1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump-in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1 st valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open 1st valve of standpipe, close valves 3, 4 & 9 on choke manifold, open valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve / open outside valve on kill side of mud cross, close valves 5 & 6 / open valves 3 & 4 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to ~ 1200 psi and bleed off 200 – 300 #s recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. Rig 404 BOP Test Procedure Attachment #1 g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7 & 8 / open valve 10 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record “Accumulator Pressure”. It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2 nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read “10 bottles at 2,150 psi”). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to “Auto”, not “Manual” so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well M-03 (PTD 189-111)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /,~¢'-~/~/ File Number of Well History File PAGES TO DELETE RESCAN Ia Color items ~ Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] OVERSIZED [] Diskettes, No. Other, No/Type Logs of various kinds Other Complete COMMENTS: Scanned by: Bevedy B~Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent ~ Lowell NOTScanned,wpd • STATE OF ALASKA • RECEIVED AIL OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AUG 2 4 2012 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extensio Change Approved Program ❑ Operat. Shutdown ❑ Perforate G Re -enter Suspended Well ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 189 -111 " 3. Address: 3800 Centerpoint Drive, Suite 100 StratigraphiC❑ Service ❑ 6. API Number: Anchorage, AK 99503 50 -733- 20411 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 [Steelhead Platform] — Trading Bay Unit M -03 ' 9. Field /Pool(s): McArthur River Field/ Middle Kenai Gas Pool 10. Present Well Condition Summary: Total Depth measured 7,291 feet Plugs measured 4,156 feet true vertical 6,512 feet Junk measured N/A feet Effective Depth measured 4,156 feet Packer measured 3,090; 3,462; 5,032; 6,600 feet true vertical 3,859 feet true vertical 2,963; 3,274; 4,595' 5,904 feet Casing Length Size MD TVD Burst Collapse Structural 937' 20" 937' 936' Conductor 1,451' 16" 1,451' 1,450' 2,630 psi 1,020 psi Surface 2,712' 13 -3/8" 2,712' 2,644' 3,090 psi 1,540 psi Intermediate 536' 10 -3/4" 536' 535' 5,860 psi 3,220 psi Production 6,732 9 -5/8" 7,268' 6,496 6,870 psi 4,760 psi Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet :: 0 , Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6#/ L -80 3,085' 2,968' SC -1 L 3,090' (MD) 2,963' (TVD) Snap Latch /Model D 3,462; (MD) 3,274' (TVD) 5,032' (MD) 4,595' (TVD) 455' (MD) Packers and SSSV (type, measured and true vertical depth) (2) BWH Packers 6,600' (MD) 5,940' (TVD) SCSSV 454' (MD) 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2380 0 280 93 Subsequent to operation: 0 3300 0 875 55 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development O — Service ❑ Stratigraphic ❑ Daily Report of Well Operations Y 15. Well Status after work: Oil ❑ Gas El r WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP SPLUG❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Ted E. Kramer Printed Name Ted E. Kramer Title Sr. Operations Engineer Signature '. 4-2---,...._ �/� t b Z, Phone 907 777 -8420 Date 8/23/2012 form 10 404 Rcviscd 10/2010 RRDMS AUG 2 8lbiz #1(757 Cubmit Original Only 1 14 • • Steelhead Platform SCHEMATIC we11 #: M -03 Hilcorp Alaska, LLC Completed 8/28/1990 RKB to TBG Head =74.4' Casing Detail KB to MSL = 160' SIZE WT GRADE CONN ID TOP BTM. 20" 133 X -56 18.730" Surface 937' 16" 75 K -55 15.240" Surface 1,451' 1 13 -3/8" 61 K -55 12.515" Surface 2,453' _ 2 13 -3/8" 68 K -55 12.412" 2,453' 2,712' IIIIIIII 3 10-3/4" 55.5 N -80 9.760" Surface 153' 10 -3/4" 51 L -80 9.850" 153' 536' 20" L 4 9/5/2008 47 N -80 BTC 8.681" 536' 7,268' 16 "L Tubing Detail I 4 -1/2" 12.6 L -80 3.958" Surface 3,085' Jewelry Detail NO. Depth Length ID Item 13 -3/8" I 1 436' 5.20' 3.958" Flow Coupling 2 441' 8.64' 3.958" GLM 5 3 450' 5.19' 3.958" Flow Coupling elm 4 455' 6.09' 3.813" SCSSV Casing patch I - -. - Mt I 5 3,044' 1.61' 3.813" X Nipple 2661' -2681' = -- 6 6 3,090' 3.85' 6.00" SC -1L Packer (8.5" OD) gli 7 3,099' 2.14' 6.380" Sliding Sleeve • • • 7 8 3,124' 0.78" 4.98" XO II 9 3,185' 101.30' 4.95 5 -1/2" OD Screens 8 10 3,290' 4.57' 3.725" Snap Latch and SC -1L Packer (Pkr 6" ID; 8.5" OD) 111 _ 11 3,299' 2.13' 6.380" Sliding Sleeve 9 - - 12 3,324' .77' 4.950" XO 13 3,360 101.37' 4.950" 5-1/2 OD Screens 14 3,462' 4.14' 3.00" Snap Latch and Model D Packer (8.5" OD) 15 4,156' TTS umbrella plug w/ cement on top N_S_1�_ I 10 - N , 16 5,032' 12.4' 6.00" BWH Packer im 17 6,600 5' 6 BWH Packer • • • 1 1 Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm 2,91 (TVD) 7' 9/15/ Date 1993 Spf 12 Comments 1 A -6 B-2 3,202' 3,278' 2,753' 2,808' 9/17/1993 12 __ 3,370' 3,430' 2,874' 13 B -2 B -2 3,440' 3,450' 2,925' 2,932' 9/15/1993 12 B-3 3,499' 3,555' 2,967' 3,007' 12/29/2011 5 B-4 3,564' 3,592' 3,013' 3,033' 10/22/2010 6 I ' G"" '' ' B 4 3,610' 3,624' 3,046' 3,056' 10/22/2010 6 14 IMI - B -3 B -5 3,780' _ _ 3,850' -- 3 169' 3,220' 10/21/2010 6 - B 6 3,895' 3,898' 3,253' 3,255' 7/20/2012 6 B -6B 3,956' 3,978' 3,298' 3,314' 7/20/2012 6 \* (--...---7 B -7 4,015' 4,035' 3,341' 3,356' 7/20/2012 6 - - r- , /_ '13-8- B-8 4`0-54' - 3 1 3'73' -mac /2012 6 Tag @ 4,093' *M C -1 4,178 4,226 3,463 3,499 3 27 `/0 - 't Wugg>Sd RKB ELM =c C -2 4,326' 4,334' 3,574' 3,580' 11/18/2008 6 Plugged 10/21/10 =C - C -2 4,348' 4,364' 3,591' 3,603' 11/18/2008 6 Plugged =D4 D -2 4,955' 5,001' 4,069' 4,109' 5/9/2007 6 Plugged - 1 Cement Plug: 5,002' - 6,600' - 8/6/93 i - ; 1 6 Cement Plug: 7,169' - 7,283' 8/2/90 E - °- 17 Fish �,+ 5,376' I 5'± Cut Tbg; "X" Nipple; 7' 4 - 1/2" pup it I PBTD = 5002" TD = 7291' MAX HOLE ANGLE =33° @ 5002' Revised by: TDF 8/23/2012 • • Hilcorp Alaska, LLC Hileorp Alaska. LLC Well Operations Summary Well Name API Number (Well Permit Number Start Date End Date M -03 50- 733 - 20411 -00 189 -111 6/6/2012 7/20/2012 Daily Operations: 06/06//12- Wednesday Rig up lubricator. Pressure test to 250 psi low and 2,500 psi high. RIH with 2.75 "" gauge ring to 4,088' RKB and tag fill. POOH. 07/20/12 - Friday Pull hatches and rig up wireline bridge. Pressure test to 250 low and 2,500 psi high. RIH with CC /GR, GPT tool, 2- 1/2 "x4' HC, 4 spf, 60 deg phase and tie into RST log dated 1/5/2007. Tagged fill at 4,072'. Spotted shot from 4,054' to 4,058' (B8 sand). Fired guns and POOH. RIH with CC /GR, 2 -1/2 "x20' HC, 6 spf, 60 deg phase. Tagged up at 4,056'. Spotted shot from 4,015' to 4,035' (B7 stray sand). Fired guns and POOH. RIH with CC /GR, 2 -1/2 "x22' HC, 6 spf, 60 deg phase. Tagged up at 4,056'. Spotted shot from 3,956' to 3,978'. (B6B sand). Fired gun and POOH. RIH with CC /GR, GPT tool, 2- 1/2 "x3' HC, 6 spf, 60 deg phase. Tagged fill at 4,056'. Spotted shot from 3,895' to 3,898'. Fired gun and POOH. All shots fired from all guns. Rig down lubricator and turn well over to production. STATE OF ALASKA ALASK L AND GAS CONSERVATION COMMISSIlk REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well Ll Plug Perforations I_ _1 Stimulate Li Other Li Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 189 -111 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic Service ❑ 6. API Number: 50- 733 - 20411 -00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 [Steelhead Platform] Trading Bay Unit M -03 9. Field /Pool(s): McArthur River Field/ Middle Kenai Gas Pool 10. Present Well Condition Summary: _ Total Depth measured 7,291 feet - "' Plugs measured 4,156 feet true vertical 6,517 feet Junk measured N/A feet Effective Depth measured 4,156 feet Packer measured 3,090; 3,462; 5,032; 6,600 feet true vertical 3,859 feet 7,1 true vertical 2,963; 3,274; 4,595' 5,904 feet Casing Length Size MD TVD Burst Collapse Structural 937' 20" 937' 936' Conductor 1,451' 16" 1,451' 1,450' 2,630 psi 1,020 psi Surface 2,712' 13 -3/8" 2,712' 2,644' 3,090 psi 1,540 psi Intermediate 536' 10 -3/4" 536' 535' 5,860 psi 3,220 psi Production 6,732 9 -5/8" 7,268' 6,496 6,870 psi 4,760 psi Liner Perforation depth Measured depth 3,202- 3,278, 3.370- 3,430, 3,440- 3,450. 3,499- 3,555: 3.564- 3,592, 3.610- 3,624, 3,780 -3,850 feet True Vertical depth 3,057 - 3121. 3,197- 3,247. 3.256- 3,264. 3.316- 3,358': 3,360- 3.383, 3398- 3,410, 3.542 -3,601 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6 # / L -80 3,085' 2,968' 3,090(MD),2,963(TVC) ;3,462(MD),3,274(TV SC -1 L, );5,032(MD),4,595(T 455(MD) Snap Latch /Model V6,600(MD),5,9041 I�� E I\/E D 454(TVD' Packers and SSSV (type, measured and true vertical depth) D, (2) ) BWH Packers VD) r ) 11. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A JAN 2 7 2012 Treatment descriptions including volumes used and final pressure: N/A Alaska Oil & Gas Cons. Commission Anchorage 12. Representative Daily Average Pre .. - - •• • ID - . Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2184 6 136 psi 90 psi Subsequent to operation: 0 3292 5 122 psi 110 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations Y 15. Well Status after work: Oil ❑ • Gas 0 WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -287 Contact Hilcorp Drilling Dept. at 777 -8301 Printed Name Timothy C. Brandenburg Title Drilling Manager i Signature ,& — (, - _'� Phone 276 -7600 Date 1/25/2012 r. 10-404 Rcvia - ..Lur- .7 - �T7til - iTaSY1 =I' • i 111 y ♦ 1 .,.. �' /.," • e7 r z-/ - ,) • • Steelhead M -03 Actual Schematic as of 12/29/2011 RKB to TBG Head = 74.4' KB to MSL = 160' ' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 2160:: " 133 X -56 18.730" Surface 937' 1 75 K -55 15.240" Surface 1451' 2 13 -3/8" 61 K -55 12.515" Surface 2453' 3 13 -3/8" 68 K -55 12.412" 2453' 2712' 10 -3/4" 55.5 N -80 9.760" Surface 153' 20" 4 10 -3/4" 51 L -80 9.850" 153' 536' 9 -5/8 47 N -80 BTC 8.681" 536' 7268' 16" Tubing: 4 -1/2" 12.6 L -80 3.958" Surface 3085' 13 - 3/8" 1 JEWELRY DETAIL NO. Depth Length ID Item 5 1. 436' 5.20' 3.958" Flow Coupling 2. 441' 8.64' 3.958" GLM Casing patch • 'tot • • 3. 450' 5.19' 3.958" Flow Coupling 2661' -2681' 6 4. 455' 6.09' 3.813" SCSSV 5. 3,044' 1.61' 3.813" X Nipple 6. 3,090' 3.85' 6.00" SC-1L Packer (8.5" OD) 7. 3,099' 2.14' 6.380" Sliding Sleeve 8. 3,124' 0.78" 4.98" XO 9. 3,185' 101.30' 4.950 5 -1/2" OD Screens A - 10. 3,290' 4.57' 3.725" Snap Latch and SC -1L Packer (Pkr 6" ID; 8.5" OD) �_ 11. 3,299' 2.13' 6.380" Sliding Sleeve 12. 3,324' .77' 4.950" XO • • • 13. 3,360' 101.37' 4.950" 5 -1/2 OD Screens 10 14. 3,462' 4.14' 3.00" Snap Latch and Model D Packer (8.5" OD) Al - 15. 4,156' TTS umbrella plug w/ cement on top • • • 16. 5032' 12.4' 6.00" BWH Packer - 17. 6600' 5' 6.00 BWH Packer B-2 CURRENT PERFORATION DATA (MD) Zone To 1 Btm Date S if Comments A -6 3,202' 3,278' 9/17/93 12 . 14 B -2 3,370' 3,430' 9/15/93 12 B -2 3,440' 3,450' 9/15/93 12 / B -3 B -3 3,499' 3,555' 12/29/11 5 ✓ B -4 B -4 3,564' 3,592' 10/22/10 6 B -5 B -4 3,610' 3,624' 10/22/10 6 E - ;. 15 B -5 3,780' 3,850' 10/21/10 6 ",a `' ' . r *4 C -1 4,178' 4,226' 3/27/09 6 Plugged Tag @ 4,093' RKB ELM c-i C -2 4,326' 4,334' 11/18/08 6 Plugged 10/21/10 - C -2 C -2 4,348' 4,364' 11/18/08 6 Plugged D -2 D -2 4,955' 5,001' 5/9/07 6 Plugged v "• zi , :4T 16 Cement Plug: 5002' - 6600' - 8/6/93 '`! Cement Plug: 7169' - 7283' - 8/2/90 E - . _. -a m.. = 17 PBTD = 5002" TD =7291' MAX HOLE ANGLE =33° @ 5002' M -03 Actual Schematic Revised 1/13/2012 TDF • Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M-03 TRADING BAY UNIT M -03 ADL0018730 5073320411 KW6081 160.00 . p. , . , X ' ES� � .. � �_X Y V'� { 7 ' ,. -. °Yb Primary Job Type Job Category Objective Actual Start Date Actual End Date Perforation - Post Production Well 12/27/2011 Services Primary Wellbore Affected Wellbore UWI Well Permit Number M -03 507332041100 1891110 12/27/201100:00.12128 /2011 00:00 Operations Summary Mobe to location. R/U slick line equipment and lubricator. 12/28/2011 00:00 - 12/29/2011 00:00 Operations Summary Pressure test lubricator to 250 psi low/ 3,000 psi high. RIH w/ 2.80 guage ring to 4,092' RKB WLM. RIH w/ pressure/ temp too RKB WLM, R/D slickline. R/U E -line and pressure test lubricator to 250 psi low/ 3,000 psi high. M/U and arm spiralpower enerjet, 5 spf, 45 deg. phase gun. Tie into RST log dated 1/5/2007. Perf from 3,555' to 3,538'. 12/29/2011 00:00.12/30!2011 00:00 Operations Summary R/U E -line and pressure test lubricator to 250 psi low/ 3,000 psi high. M/U and arm gun with 8 -1/2" of spiralpower enerjet, 5 spf, 45 deg. phase gun. Tie into RSTdated from 1/5/2007. Perf from 3,538' to 3,499'. R/D E -line and secure location. Turn well over to production. LW • . f SEAN PARNELL, GOVERNOR s irr s ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager ` g f Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, Trading bay Unit M -03 Sundry Number: 311 -287 Dear Mr. Brandenburg: ANNED SFP 3 20,E Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ►1 Daniel T. Seamount, Jr. Chair DATED this Z., of September, 2011. Encl. • 9 ° • STAT OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED' APPLICATION FOR SUNDRY APPROVALS �� ddLL.• 20 AAC 25.280 SEP 2 1 2011 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing ❑ Naska Oil & GastTevniflee ti tna s Qn Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Attrilt>,t>p 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development Ei • Exploratory ❑ 189 -111 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20411 -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 -03 . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0018730 [Steelhead Platform] McArthur River Field/ Middle Kenai Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,291 6,517 • 4,156 3,859 4,156 N/A Casing Length Size MD / TVD Burst Collapse Structural 937' 20" 937' 936' Conductor 1,451' 16" 1,451' 1,450' 2,630psi 1,020psi Surface 2,712' 13 -3/8" 2,712' 2,644' 3,090psi 1,540psi Production 536' 10 -3/4" 536' 535' 5,860psi 3,220psi Production 6,732' 9 -5/8" 7,268' 6,496' 6,870psi 4,760psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3,202- 3,278, 3,370- 3,430, 3,057- 3,121, 3,197- 3,247, 3,440- 3,450, 3,564- 3,592, 3,256- 3,264, 3,360- 3,383, 4 -1/2" 12.6 # / L -80 3,085' 3,610- 3,624, 3,780 -3,850 3,398- 3,410, 3,542 -3,601 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 1 SC -1 L, Snap Latch and Model D, BWH, BWH Packet and SCSSV 3,090(MD),2, 963 (TVtL�;3,462(MD),3,274(TVD);5, 032( MD),4,595(TVD);6,600(MD),5,904( TVD) and 455(MD),454(TVD) 1 ZCfo 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: I Oil ❑ Gas 0 WDSPL ❑ Suspended ❑ 1/15/ 011 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Billy Applewhite Phone: 263 -7671 Printed Name i i/ Timothy C. Brandenburg Title Drilling Manager Signature (( -�� ' Phone 276 -7600 Date 9/21/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 61 l ` AI Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: to -^ 404. / APPROVED BY Approved by: , / pp Q OMMISSIONER THE COMMISSION Date: , Z2, 1 1 Form 1`': R- ised 1/21107 MS SEP 2 2 2O �,ORIGINAC. Su[fm in Duplica e )‘tf11 . • • Steelhead M -03 PROPOSED Schematic RKB to TBG Head = 74.4' KB to MSL = 160' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 133 X -56 18.730" Surface 937' 1 16" 75 K -55 15.240" Surface 1451' ` 2 13 -3/8" 61 K -55 12.515" Surface 2453' 1 3 13 -3/8" 68 K -55 12.412" 2453' 2712' 10 -3/4" 55.5 N -80 9.760" Surface 153' 20" 1 4 10 -3/4" 51 L -80 9.850" 153' 536' 9 -5/8 47 N -80 BTC 8.681" 536' 7268' 16" S Tubing: 4 -1/2" 12.6 L -80 3.958" Surface 3085' 13 - 3/8" I 5 I NO. Depth] Length ID Item JEWELRY DETAIL _ 1. 436' 5.20' 3.958" Flow Coupling �� 2. 441' 8.64' 3.958" GLM Casing patch 3. 450' 5.19' 3.958" Flow Coupling 2661' -2681' 6 4. 455' 6.09' 3.813" SCSSV • • • 7 5. 3,044' 1.61' 3.813" X Nipple 6. 3,090' 3.85' 6.00" SC -1L Packer (8.5" OD) 7. 3,099' 2.14' 6.380" Sliding Sleeve 8 8. 3,124' 0.78" 4.98" XO - 11 1 9. 3,185' 101.30' 4.950 5-1/2" OD Screens 9 - - 10. 3,290' 4.57' 3.725" Snap Latch and SC -1L Packer (Pkr 6" ID; 8.5" OD) 11. 3,299' 2.13' 6.380" Sliding Sleeve - - 12. 3,324' .77' 4.950" XO 13. 3,360' 101.37' 4.950" 5 -1/2 OD Screens 10 14. 3,462' 4.14' 3.00" Snap Latch and Model D Packer (8.5" OD) 15. 4,156' TTS umbrella plug w/ cement on top • • • 11 16. 5032' 12.4' 6.00" BWH Packer 17. 6600' 5' 6.00 BWH Packer 12 13 B -2 C CURRENT PERFORATION DATA (MD) Zone To I Btm Date S if Comments A -6 3,202' 3,278' 9/17/93 12 14 B -2 3,370' 3,430' 9/15/93 12 B -2 3,440' 3,450' 9/15/93 12 = B-3 .1 41 B -3 +/- 3,499' +/- 3,555' Proposed =B- B -4 3,564' 3,592' 10/22/10 6 =B-5 B -4 3,610' 3,624' 10/22/10 6 B -5 3,780' 780' 3,850' 850' 10/21/10 6 " 15 C -1 4,178' 4,226' 3/27/09 6 Plugged Tag @ 4,093' RKB ELM =c -1 C -2 4,326' 4,334' 11/18/08 6 Plugged 10/21/10 =8=G2 C -2 4,348' 4,364' 11/18/08 6 Plugged =D-2 D -2 4,955' 5,001' 5/9/07 6 Plugged tom1 Bai 7 I 16 Cement Plug: 5002' — 6600' - 8/6/93 Cement Plug: 7169' — 7283' - 8/2/90 17 PBTD =5002" TD = 7291' MAX HOLE ANGLE =33° @ 5002' M -03 Proposed Schematic Revised 8/1/2011 BCA • • Steelhead M -03 Actual Schematic RKB to TBG Head = 74.4' KB to MSL = 160' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 133 X -56 18.730" Surface 937' 1 16" 75 K -55 15.240" Surface 1451' 2 13 -3/8" 61 K -55 12.515" Surface 2453' 3 13 -3/8" 68 K -55 N -80 12.412" 2453' 2712' 10 -3/4" 55.5 9.760" Surface 153' 20" 14 10 -3/4" 51 L -80 9.850" 153' 536' 9 -5/8 47 N -80 BTC 8.681" 536' 7268' . 16" Tubing: 4 -1/2" 12.6 L -80 3.958" Surface 3085' JEWELRY DETAIL 13.3/8" I NO. Depth] Length ID Item s 1. 436' 5.20' 3.958" Flow Coupling 2. 441' 8.64' 3.958" GLM Casing patch I = --!-N g p - 6 3. 450' 5.19' 3.958" Flow Coupling 2661' -2681' 4. 455' 6.09' 3.813" SCSSV • • • 7 5. 3,044' 1.61' 3.813" X Nipple 6. 3,090' 3.85' 6.00" SC -1L Packer (8.5" OD) 7. 3,099' 2.14' 6.380" Sliding Sleeve 8 8. 3,124' 0.78" 4.98" XO 7 01_ 9. 3,185' 101.30' 4.950 5 -1/2" OD Screens 9 = A -6 10. 3,290' 4.57' 3.725" Snap Latch and SC-1L Packer (P 6" ID; 8.5" OD) 11. 3,299' 2.13' 6.380" Sliding Sleeve 12. 3,324' .77' 4.950" XO t_�_ 13. 3,360' 101.37' 4.950" 5 -1/2 OD Screens 10 14. 3,462' 4.14' 3.00" Snap Latch and Model Packer (8.5" OD) 15. 4,156' TTS umbrella plug w/ eement on top • • • 11 16. 5032' 12.4' 6.00" BWH Packer • 17. 6600' 5' 6.00 BWH Packer 12 VA° 13 B - F CURRENT PERFORATION DATA (MD) — Zone To 1 Btm Date S . f Comments 1 =It _..I� • A -6 3,202' 3,278' 9/17/93 12 14 B -2 3,370' 3,430' 9/15/93 12 B -2 3,440' 3,450' 9/15/93 12 B -4 3,564' 3,592' 10/22/10 6 — 13 - 4 2 ,P 4 B -4 3,610' 3,624' 10/22/10 6 =B-5 B -5 3,780' 3,850' 10/21/10 6 is C -1 4,178' 4,226' 3/27/09 6 Plugged k, ' ' ° ..$40.4 C -2 4,326' 4,334' 11/18/08 6 Plugged Tag @ 4,093' =c -1 �C -2 C -2 4,348' 4,364' 11/18/08 6 Plugged IZ ELM D -2 4,955' 5,001' 5/9/07 6 Plugged 10/21/10 21/10 =D-2 16 Cement Plug: 5002' — 6600' - 8/6/93 - = Cement Plug: 7169' — 7283' - 8/2/90 PBTD = 5002" TD = 7291' MAX HOLE ANGLE =33° @ 5002' M -03 Actual Schematic Revised 11/16/2010 CVK Chevron • • Trading Bay Unit * %10 Well # M -03 9/7/11 OBJECTIVES: • Add the B3 zone Current BHP: 206 psi @ 3,306' TVD Max Downhole Pressure: 1,487 psi @ 3,306' TVD (B �n virgin pressure gradient of 0.45psi /ft of TVD) MASP: 1,371 psi (Based on a pressure gradient of � si/ foot of TVD) PROCEDURE SUMMARY: 1. RU Slickline. Pressure test lubricator 250psi low /2,500psi high. 2. RIH with gauge ring and tag fill at ( +1 -) 4,093'. 3. RIH with dummy gun to ( + / -) 4,093'. 4. RIH with pressure /temperature tool to ( +1 -) 4,093' 5. Rig down slickline. 6. RU Eline. Pressure test lubricator 250psi low /2,500psi high. 7. Perforate the B3 sand from +/- 3,499' to +/- 3,555'. 8. Rig down E -line. 9. Turn well over to production. Chevron FraSco Castro Chevron North AmelI Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 . Anchorage, AK 99503 %1111. Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcastro @chevron.com DATE December 8, 2010 To: AOGCC Shartzer, Christine R 333 W. 7 Ave. Ste #100 ) , s Anchorage, AK 99501 DATA TRANSMITTAL x "�". ' L . ,a- I " - tx z r..�`;i x - arm * ti .; 1 le ' ' "" 5 , f °k' a t t r t q -- 1 � `` v s'-' r t 7 k f` r -. a a ^t s „, ' : . i , .. t r' 3 . t';v r r 4 , : �1...� .. .. a..a, ..ux ^»ti. _:�.a"�p s -1 .:�. "". .r ....., �Ya. s o,a� e, ...., . .�i +� . �� >'"L�"��:�"�±8c.� +`. ��.a',r�?' � ti . TBU M -06 PERFORATION RECORD F6 ZONE 10/27/2010 11382 -11390 X X TBU M -06 PERFORATION RECORD F7 ZONE 10/23/2010 11430 -11442 X X TBU M -06 PERFORATION RECORD G01 ZONE 10/23/2010 11430 -11442 X X -° TBU M -03 PERORATION RECORD B5 ZONE 10/21/2010 3780 -3850 X X TBU M -03 PERFORATION RECORD B4 ZONE . 10/22!2010 3624 -3564 X X L FEB (i 1 2OV X 09 -ooq 066 l tl --ir t ads 4 ( Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: .....5.____ _A,!� ('& STATE OF ALASKA �'�" e t I �3 ALAS IL AND GAS CONSERVATION COMMISON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well Li Plug Perforations Stimulate LJ Other Li Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 189 -111 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 733 - 20411 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 [Steelhead Platform] Trading Bay Unit M -03 9. Field /Pool(s): _ McArthur River Field / Middle Kenai Gas Pool 10. Present Well Condition Summary: Total Depth measured 7,291 feet Plugs measured 4,093 feet true vertical 6,517 feet Junk measured N/A feet 3,090', 3,290', Effective Depth measured 4,093 feet Packer measured & 3,462' feet 2,963', 3,131', true vertical 3,806 feet true vertical & 3,274' feet Casing Length Size MD / TVD Burst Collapse Structural 937' 20" 937' 936' Conductor 1,451' 16" 1,450' 1,450' 2,630 psi 1,020 psi Surface 2,712' 13 -3/8" 2,712' 2,712' 3,090 psi 1,540 psi Intermediate 536' 10 -3/4" 536' 536' 5,860 psi 3,220 psi Production 6,732' 9 -5/8" 7,268' 6,496' 6,870 psi 4,750 psi Liner Z Perforation depth Measured depth 3,200- 3,278', 3,370'- 3,430', 3,440'- 3,450', 3,564'- 3,592', 3,610'- 3,624', 3,780'- 3,850' feet True Vertical depth 3,057'- 3,121', 3,197'- 3,247', 3,256'- 3,264', 3,360'- 3,383', 3,398'- 3,410', 3,542'- 3,601' feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 3,085' MD 2,959' TVD (2) SC -1 L & Model 3,090', 3,290', 3,462'MD / Packers and SSSV (type, measured and true vertical depth) D Packer (2, 963', 3, 131', 3,274 _ ; 5'MD (4547VD) 11. Stimulation or cement squeeze summary: t� t Intervals treated (measured): N �d V t NOV I q Z010 N/A � w Treatment descriptions including volumes used and final pressure: ''�I4� N/A A 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 65 psi 225 psi Subsequent to operation: 0 2500 0 135 psi 117 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development ❑ o Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil Gas � i WDSPL GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1 310-225 Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276 -7600 Date 11/17/2010 DIMS NOV Y 9 � �� Form 10 -404 Revised 10/2010 Submit Original Only Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -03 TRADING BAY UNIT M -03 JADLOO18730 15073320411 KW6081 160.00 Primary Job Type F e Category Objective Actual Start Date Actual End Date Perforation - Post Production ll 10/6/2010 rvices Primary Wellbore Affected Wellbore UWI Well Permit Number M -03 507332041100 1891110 010 0 0 - 1 w %� 'fan '.. a.. Operations Summary . RU wireline, pressure test lubricator 250psi low /2500psi high. RIH, tie in to schematic, set 9 5/8" Umbrella Plug at 4156' to 4165'. 10!712010 00:00 - 1018!2010 00:00 - r „ Operations Summary RIH w/ 2 -1/8 "x31' dump bailer, dump bailed 4' of ceramic beads on top of umbrella plug. 10�$l2 1 2U 00:00 .° Operations Summary Made multiple dump bailer runs with 16.6ppg cement to 4,167'WLM (2' below top of umbrella plug vent). WOC. Operations Summary RU wireline. Pressure test lubricator 250psi low /2500psi high. RIH w/ 2.83" LIB and close vent tube on 9 -5/8" umbrella plug at 4,165' WLM. Operations Summary Continue dump bailing 16.6ppg cement (4 runs) until TOC at 4,138' RKB WLM. WOC. 10116 2 m0a 40 t Operations Summary RU wireline. Pressure test lubricator 250psi low /2500psi high. RIH & tag TOC at 4,134'RKB WLM. Continue dump bailing 16.4ppg cement from 4,134' to 4,126' RKB WLM. 1Q61712010 00:110 �" 10!18!2010 00;00 _ n .° _, Operations Summary RD wireline. WOC. 461111 :06• 10121/t016 00:00';' Operations Summary RU Eline. Pressure test lubricator 250psi low /2500psi high. RIH and tag TOC at 4,093'RKB ELM. Perforate w/ 45deg 5spf Power Spiral Enerjet guns from 3,830'- 3,850', 3,810'- 3,830', 3,790'- 3,810', & 3,780'- 3,790'RKB ELM. RD Eline and turn well over to production. 4012212 f Operations Summary �. ., K . . RU Eline. Pressure test lubricator 250psi low /2500psi high. RIH and tag TOC at 4,093'RKB ELM. Perforate w/ 45deg 5spf Power Spiral Enerjet guns from 3,614'.5- 3,624', 3,610'- 3,614.5', 3,582.5'- 3,592'RKB ELM. :00 - 10!2412010 00:00 0— "� Operations Summary Continue to perforate w/ 45deg 5spf Power Spiral Enerjet guns from 3,573'- 3,582.5', 3,573'- 3,564'RKB ELM. RD Eline and turn well over to production. Steelhead M -03 Schematic RKB to TBG Head =74.4' KB to MSL = 160' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 133 X -56 18.730" Surface 937' 1 16" 75 K -55 15.240" Surface 1451' 2 13 -3/8" 61 K -55 12.515" Surface 2453' 3 13 -3/8" 68 K -55 12.412" 2453' 2712' 4 10 -3/4" 55.5 N -80 9.760" Surface 153' 20 " 10 -3/4" 51 L -80 9.850" 153' 536' 9 -5/8 47 N -80 BTC 8.681" 536' 7268' 16" Tubing: 4 -1/2" 12.6 L -80 3.958" Surface 3085' 13 -3/8" JEWELRY DETAIL NO. De th Len th ID Item 5 1. 436' 5.20' 3.958" Flow Couplin 2. 441' 8.64' 3.958" GLM Casing patch 2661' -2681' 6 3. 450' 5.19' 3.958" Flow Couplin 4. 455' 6.09' 3.813" SCSSV 7 5. 3,044' 1.61' 3.813" X Nipple 6. 3,090' 3.85' 6.00" SC -IL Packer 8.5" OD 7. 3,099' 2.14' 6.380" Sliding Sleeve 8 8. 3,124' 0.78" 4.98" XO 9. 3,185' 101.30' 4.950 5 -1/2" OD Screens 9 A -6 10. 3,290' 4.57' 3.725" Snap Latch and SC -1L Packer Pkr 6" ID; 8.5" OD 11. 3,299' 2.13' 6.380" Sliding Sleeve 12. 3,324' .77' 4.950" XO 13. 3,360' 101.37' 4.950" 5 -1/2 OD Screens l0 14. 3,462' 4.14' 3.00" Snap Latch and Model D Packer 8.5" OD 15. 4,156' TTS umbrella lu w/ cement on to 11 16. 5032' 12.4' 6.00" BWH Packer 17. 1 6600' 5 6.00 BWH Packer 12 13 B -2 CURRENT PERFORATION DATA MD Zone Top Btm Date &f Comments A -6 3,202' 3,278' 9/17/93 12 14 B -2 3,370' 3,430' 9/15/93 12 B -2 3,440' 3,450' 9/15/93 12 B -4 3,564' 3,592' 10/22/10 6 B-4 B -4 3,610' 3,624' 10/22/10 6 B-5 B -5 3,780' 3,850' 10/21/10 6 15 C -1 4,178' 4,226' 3/27/09 1 6 Plugged Tag @ 4,093' C -2 4,326' 4,334' 11/18/08 6 Plugged RKB ELM C -1 C -2 4,348' 4,364' 11/18/08 6 Plugged 10/21/10 C D -2 4,955' 5,001' 5/9/07 6 Plugged D-2 16 Cement Plu g: 5002' — 6600' - 8/6/93 Cement Plug: 7169' — 7283' - 8/2/90 17 Zt 7 4 PBTD= 5002" TD =7291' MAX HOLE ANGLE =33° @ 5002' M -03 Actual Schematic Revised 11/16/2010 CVK • • ~~al~~ 0[~ a~a~~{Q /,Ew..w.E.~w....~ Timothy C. Brandenburg Drilling Manager (' Union Oil Company of California ~ U ~ ~ t r.0. Eox 196247 Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, TBU M-03 Sundry Number: 310-225 Dear Mr. Brandenbur ~ ' ~~-` ~~ ~ ~.~~°~~ ~ '~' ~~~'~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair ' ~s~~ f Jul 2010. DATED this ~ day o y, Encl. STATE OF ALASKA ~ ,~V ALASKA OIL AND GAS CONSERVATION COMMISSION ~' APPLICATION FOR SUNDRY APPROVALS ~n AAC ~s 2ao 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ~ Perforate ~ ~ .Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^ ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^Q , Exploratory ^ 189-111 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20411-00 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 ~ Trading Bay Uriit M-03 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018730 [Steelhead Platform] McArthur River Field /Middle Kenai Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7,291 6,517 4,166' 3,867 5,002' & 7,169' (cement) 4,166' (fill) Casing Length Size MD ND Burst Collapse Structural g37' 20" 937' 936' Conductor 1,451' 16" 1,450' 1,450' 2,630 psi 1,020 psi Surtace 2,712' 13-3/8" 2,712' 2,712' 3,090 psi 1,540 psi Intermediate 536' 10-3/4" 536' 536' 5,860 psi 3,220 psi Production 6,732' 9-5/8" 7,268' 6,496' 6,870 psi 4,750 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3,202'-3,278', 3,370'-3,430', 3,057'-3,121', 3,197'-3,247', 3,440'-3,450', 4,178'-4,226', 3,256'-3,264', 3,878'-3,918', 4-1/2" 12.6# L-80 3,085 4,326'-4,334', 4,348'-4,364', 4,002'-4,009', 4,021'-4,034', 4,955'-5,001' 4,530'-4,569' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): j (2) SC-1 L Packers & Model D Packer / SCSSV 3,090', 3,290', & 3,462'MD (2,963', 3,131', & 3,274'ND) / 455'MD (454'ND) 12. Attachments: Description Summary of Proposal ^~ 13: Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 14. Estimated Date for 8/5/2010 15. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^~ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: N/A WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263-7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature C Phone 276-7600 Date 7/22/2010 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~' O ~ ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ~~~0` ,~® V 1 Other: f ~i 1~.. ~ 7 2010 Alaska ~~ ~ ~~ Cam. Ct~rpssio Subsequent Form Required: (p _ t't!' Q ~• ~r1G~1~~~3t~' C APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~0 // v ~- - ~ 7• Y1%' ('~ of ~ . Form 10-403 Revised 12/2009 O R 1 ~ I n ~ A ~D~S ~Ul ~Gi ~ Submit in Dup~icate (v H W4A' o~ 281 zoto Chevron • . Trading Bay Unit Well # M-03 7/22/10 OBJECTIVE: • Set plug in 9-5/8" casing and perforate the B-3, B-4, 8~ B-5 zones. PROCEDURE SUMMARY: 1 RU Eline. Pressure test lubricator 250psi low/2500psi high. 2 RIH and set 9-5/8" plug on to top of fill at +/- 4,165' RKB. 3 Dump bail at least 25' of cement on top of 9-5/8" plug. 4 RD Eline. 5 WOC. 6 RU Eline. Pressure test lubricator 250psi I~w/2500psi high. 7 Tag top of cement at +/- 4,140' RKB. I 8 Perforate B-5 zone from +/- 3,780' to +/- 3,850'. 9 Perforate 6-4 zone from +/- 3,564' to +/- 3,626'. 10 Perforate B-3 zone from +/- 3,500' to +/- 3,556'. 11 RD Eline. 12 Turn well over to production. M-03 REVISED BY: CVK 7-22-IO • Steelhead M-03 Schematic as of 4/1/09 RKB to TBG Head = 74.4' KB to MSL = 160' CASING AND TUBING DETAIL 20" 1f 13 Casing pat 2661'-268 SIZE WT GRADE CONN [D TOP R"I'M. 20" 133 X-56 18.730" Surface 937' 16" 75 K-55 15.240" Surface 1451' 13-3/8" 61 K-55 12.515" Surface 2453' 13-3/8" 68 K-55 12.412" 2453' 2712' 10-3/4" 55.5 N-80 9.760" Surface 153' 10-3/4" 51 L-80 9.850" 153' 536' 9-5/8 47 N-80 BTC 8.681" 536' 7268' Tubin 4-1/2" 12.6 L-80 3.958" Surface 3085' JEWELRY DETAIL NO. De th Len th ID Item 1. 436' 5.20' 3.958" Flow Cou lin 2. 441' 8.64' 3.958" GLM 3. 450' 5.19' 3.958" Flow Cou lin 4. 455' 6.09' 3.813" SCSSV 5. 3,044' 1.61' 3.813" X Ni le 6. 3,090' 3.85' 6.00" SC-lL Packer(8.5" OD 7. 3,099' 2.14' 6.380" Slidin Sleeve 8. 3,124' 0.78" 4.98" XO 9. 3,185' 101.30' 4.950 5-1/2" OD Screens 10. 3,290' 4.57' 3.725" Sna Latch and SC-IL Packer Pkr 6" ID; 8.5" OD 11. 3,299' 2.13' 6.380" Slidin Sleeve 12. 3,324' .77' 4.950" XO 13. 3,360' 101.37' 4.950" 5-1/2 OD Screens 14. 3,462' 4.14' 3.00" Sna Latch and Model D Packer 8.5" OD 15. 5032' 12.4' 6.00" BWH Packer 16. 6600' S' 6.00 BWH Packer CURRENT PERFORATION DATA (MD) Zone To Btm Date S f Comments A-6 3,202' 3,278' 9/17/93 12 B-2 3,370' 3,430' 9/15/93 12 B-2 3,440' 3,450' 9/15/93 12 C-1 4,178' 4,226' 3/27/09 6 C-2 4,326' 4,334' 11/18/08 6 C-2 4,348' 4,364' 11/18/08 6 D-2 4,955' 5,001' 5/9/07 6 Re erfed 11/18/08 i001'(DIL) MAX HOLE ANGLE =33° @ 5002' Cement Plug: 5002' - 6600' - 8/6/93 Cement Plug: 7169' - 7283' - 8/2/90 M-03 Actual Schematic Revised 4/1/2009 CVK PBTD =5002" TD = 7291' Steelhead M-03 Proposed Schematic RKB to TBG Head =74.4' KB to MSL = 160' CASING AND TUBING DETAIL 20" 1f 13 Casing pat 2661'-268 SIZE WT GRADE CONN ID TOP B"TM. 20" 133 X-56 18.730" Surface 937' 16" 75 K-55 15.240" Surface 1451' 13-3/8" 61 K-55 12.515" Surface 2453' 13-3/8" 68 K-55 12.412" 2453' 2712' 10-3/4" 55.5 N-80 9.760" Surface 153' 10-3/4" 51 L-80 9.850" 153' 536' 9-5/8 47 N-80 BTC 8.681" 536' 7268' Tubin 4-1/2" 12.6 L-80 3.958" Surface 3085' JEWELRY DETAIL NO. De th Len th ID Item 1. 436' 5.20' 3.958" Flow Cou lin 2. 441' 8.64' 3.958" GLM 3. 450' 5.19' 3.958" Flow Cou lin 4. 455' 6.09' 3.813" SCSSV 5. 3,044' 1.61' 3.813" X Ni le 6. 3,090' 3.85' 6.00" SC-IL Packer 8.5" OD 7. 3,099' 2.14' 6.380" Slidin Sleeve 8. 3,124' 0.78" 4.98" XO 9. 3,185' 101.30' 4.950 5-1/2" OD Screens 10. 3,290' 4.57' 3.725" Sna Latch and SC-1L Packer (Pkr 6" ID; 8.5" OD) 11. 3,299' 2.13' 6.380" Slidin Sleeve 12. 3,324' 77' 4.950" XO 13. 3,360' 101.37' 4.950" 5-l/2 OD Screens 14. 3,462' 4.14' 3.00" Sna Latch and Model D Packer 8.5" OD 15. +/-x,165' 7°1S umbrella lu w/+/-25' cement on to 16. 5032' 12.4' 6.00" BWH Packer 17. 6600' S' 6.00 BWH Packer CURRENT PERFORATION DATA (MD) Fill 4, 5/. Zone To Btm Date S f Comments A-6 3,202' 3,278' 9/17/93 12 B-2 3,370' 3,430' 9/15/93 12 B-2 3,440' 3,450' 9/15/93 12 B-3 +/-3,500' +/-3,556' Pro osed 6 B-4 +/-3,564' +/-3,626' Pro osed 6 B-5 +/-3,780' +/-3,850' Pro osed 6 C-1 4,178' 4,226' 3/27/09 6 Pro osed Plu ed C-2 4,326' 4,334' 11/18/08 6 Pro osed Plu ed C-2 4,348' 4,364' 11/18/08 6 Pro osed Plu ed D-2 4,955' 5,001' 5/9/07 6 Pro osed Plu ed Cement Plug: 5002' - 6600' - 8/6/93 Cement Plug: 7169' - 7283' - 8/2/90 MAX HOLE ANGLE =33° @ 5002' M-03 Actual Schematic Revised 4/1/2009 CVK PBTD=5002" TD=7291' • .~~ ®(~ ~r~l'~clSC® Castro chevron north America Exploration and Production _ Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com ®ATE April 9, 2009 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 ~~~ WELL ~ i LOG TYPE -- - - - - INTErTVAL .SCALE ! LOG-DATE LOGGED ~ - - - - - RUN # - B-LINE ~ i -- CD I -- --- .NOTES -LAS, PDS, DLIS -- TBU M-03 PERFORATION RECORD 5" 27-Mar-09 4178'-4226' 1 1 1 PDS ~l<l 1 ~~~ Please acknowledge receipt by signing and returning one copy of this transmittal or FAX`to 907 263 7828. Received By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~~~~~ ~Pf~ ~ ~ 2009 1. Operations Abandon Repair Well Plug Perforations Stimulate ' B r , ~ S ~ ~ K Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver ^ Time x ension ~3~ LIlilt~'1fS Change Approved Program ^ Operat. Shutdown^ Perforate ^~ ` Re-enter Suspended Well ^ QtiC~IU~aQB 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development^ - Exploratory^ 189-111. 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^ 6. API Number: 50-733-20411-00 - 7. KB Elevation (ft): 9. Well Name and Number: 160' Trading Bay Unit M-03 . 8. Property Designation: 10. Field/Pool(s): ADL0018730 [Steelhead Platform] McArthur River Field /Middle Kenai Gas - 11. Present Well Condition Summary: Total Depth ~ measured 7,291 feet Plugs (measured) 5,002' & 7,169' (cement) true vertical 6,517, feet Junk (measured) 5,001' (fill) Effective Depth measured 5,001 feet true vertical 4,569 feet Casing Length Size MD TVD Burst Collapse Structural 937' 20" 937' 936' Conductor 1,451' 16" 1,450' 1,450' 2,630 psi 1,020 psi Surface 2,712' 13-3/8" 2,712' 2,712' 3,090 psi 1,540 psi Intermediate 536' 10-3/4" 536' 536' 5,860 psi 3,220 psi Production 6,732' 9-5/8" 7,268' 6,496' 6,870 psi 4,750 psi Liner h y~e !~ ry/ Perforation depth: Measured depth: See Attached Schematic True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 4-1/2" L-80 12.6# 3,085' Packers and SSSV (type and measured depth) (2) SC-1L Packers & 3,090', 3,290', 3,462' / 455' Model DPacker / SCSSV 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 670 0 65 psi 60 psi Subsequent to operation: 0 1070 0 65 psi 67 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^~ ~ 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: N/A Contact Steve Tyter 263-7649 Printed Name Timothy C. Brandenbur Title Drilling Manager y^-~ Signature ~ ` Phone 276-7600 Date 4/1/2009 Qtt .ice" Form 10-404 Revised 04/2006 _ ~ n ~ubmit Original Only r 4 ~__-.. Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M-03 _ -_ TRADING BAY UNIT M-03 ADL0018730 5073320411 KW6081 160.00 _ _ _ _ --- Joks - ---- PrimaryJob Type Job Category Objective - Actual Start Date Actual End Date Perforating -Post Production Well Services 3/25/2009 3/28/2009 Primary Wellbore Affected Wellbore UWI Well Permit Number M-03 5073320411-00 1891110 Dall d oat[ons _ _ __ _ 3/2512009 00:00•- 3/26/2.009 00:0.0_ Operations Summary ~ - - -- - - _ -- -- Rigged up Wireline, PT 250 psi low, 2500 psi high, and ran 2.81" GR to TD at 5004' RKB SLM, Picked up 22' of 2.5" Spent pert gun and ran in we~,_, II to TD '° at 5004' RKB SLM. RD slickline. ---- - __ - 3/27/2009 00:00 - 3/28/2009.00:00.. __ _ _ Operations Summary ~~- Complete rigging up Schlumberger Eline on rig. PT 250 psi low/2500 psi high. Perforate C-1 sands from 4,178'-4,226' RKB ELM. RD Eline unit. • • Steelhead M-03 Schematic as of 4/1/09 RKB to TBG Head = 74.4' KB to MSL = 160' CASING AND TUBING DETAIL 20" 1E 13 Casing pat 2661'-268 SIZE WT GRADE CONN ID TOP BT~t. 20" 133 X-56 18.730" Surface 937' 16" 75 K-55 15.240" Surface 1451' 13-3/8" 61 K-55 12.515" Surface 2453' 13-3/8" 68 K-55 12.412" 2453' 2712' 10-3/4" 55.5 N-80 9.760" Surface 153' 10-3/4" 51 L-80 9.850" 153' 536' 9-5/8 47 N-80 BTC 8.681" 536' 7268' Tubin 4-1/2" 12.6 L-80 3.958" Surface 3085' JEWELRY DETAIL NO. De th Len th ID Item 1. 436' 5.20' 3.958" Flow Cou lin 2. 441' 8.64' 3.958" GLM 3. 450' 5.19' 3.958" Flow Cou lin 4. 455' 6.09' 3.813" SCSSV 5. 3,044' l.bl' 3.813" X Ni le 6. 3,090' 3.85' 6.00" SC-lL Packer 8.5" OD 7. 3,099' 2.14' 6.380" Slidin Sleeve 8. 3,124' 0.78" 4.98" XO 9. 3,185' 101.30' 4.950 5-1/2" OD Screens 10. 3,290' 4.57' 3.725" Sna Latch and SC-1L Packer Pkr 6" ID; 8.5" OD 11. 3,299' 2.13' 6.380" Slidin Sleeve 12. 3,324' .77' 4.950" XO 13. 3,360' 101.37' 4.950" 5-1/2 OD Screens 14. 3,462' 4.14' 3.00" Sna Latch and Model D Packer (8.5" OD 15. 5032' 12.4' 6.00" BWH Packer lb. 6600' S' 6.00 BWH Packer CURRENT PERFORATION DATA MD Zone To Btm Date S f Comments A-6 3,202' 3,278' 9/17/93 12 B-2 3,370' 3,430' 9/15/93 12 B-2 3,440' 3,450' 9/15/93 12 C-1 4,178' 4,226' 3/27/09 6 C-2 4,326' 4,334' 11/18/08 6 C-2 4,348' 4,364' 11/18/08 6 D-2 4,955' 5,001' 5/9/07 6 Re erfed 11/18/08 001' (DIL) Cement Plug: 5002' - 6600' - 8/6/93 Cement Plug: 7169' - 7283' - 8/2/90 MAX HOLE ANGLE =33° @ 5002' M-03 Actual Schematic Revised 4/1/2009 CVK PBTD =5002" TD = 7291' ,~~,~ ~ STATE OF ALASKA r 'v " ALA OIL AND GAS CONSERVATION COM~ION /~ REPORT OF SUNDRY WELL OPERATIONS /.~?~~ ~~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate Q ~ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ~ Exploratory^ 189-111 ~ 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-733-20411-00 7. KB Elevation (ft): 9. Well Name and Number: 160' Trading Bay Unit M-03 8. Property Designation: 10. Field/Pool(s); ADL0018730 [Steelhead Platform] . McArthur River Field /Middle Kenai Gas 11. Present Well Condition Summary: Total Depth measured 7,291 ~ feet Plugs (measured) 5,002 & 7,169 (cement) true vertical 6,517 feet Junk (measured) 5,001 (fill) Effective Depth measured 5,001 feet true vertical 4,569 feet Casing Length Size MD TVD Burst Collapse Structural 937' 20" 937' 936' Conductor 1,451' 16" 1,450' 1,450' 2,630 psi 1,020 psi Surface 2,712' 13-3/8" 2,712' 2,644' .3,090 psi 1,540 psi Intermediate 536' 10-3/4" 536' 536' 5,860 psi 3,220 psi Production 6,732' 9-5/8" 7,268' 6,496' 6,870 psi 4,750 psi Liner ~~ +~ u~,r~+ ~` ~{ yr~;~ ~ ' ~ ' J t !! e € U h . SJ tJ c.l Perforation depth: Measured depth: See Attached Schematic True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 4-1/2" L-80 12.6# 3,085' Packers and SSSV (type and measured depth) (2) SC-~ L Packers & 3,090', 3,290', 3,462' / 455' Model DPacker / SCSSV 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 860 0 55 psi 110 psi Subsequent to operation: 0 1160 0 55 psi 110 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^~ - Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas ~ _ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-397 Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager - - > - ~ s -, . Signature " ,` _,,,~„ ~ - - A Phone 263-7600 Date 12/2/2008 Form 10-404 Revised 0412006 ~ ~ { s ~r,, ~ _„ C"•-'~~ Submit Original Only ~. • • Steelhead M-03 Schematic as of 11/19/08 RKB to TBG Head = 74.4' KB to MSL =160' CASING AND TUBING DETAIL 20 SIZE WT GRADE CONN ID TOP BTM. 20" 133 X-56 18.730" Surface 937' l6" 75 K-55 15.240" Surface 1451' 13-3/8" 61 K-55 12.515" Surface 2453' 13-3/8" 68 K-55 12.412" 2453' 2712' 10-3/4" 55.5 N-80 9.760" Surface 153' 10-3/4" 51 L-80 9.850" 153' 536' 9-5/8 47 N-80 BTC 8.681" 536' 7268' Tubin 4-1/2" 12.6 L-80 3.958" Surface 3085' JEWELRY DETAIL Casing I 2661'-2t NO. De th Len th ID Item 1. 436' 5.20' 3.958" Flow Cou lin 2. 441' 8.64' 3.958" GLM 3. 450' 5.19' 3.598" Flow Cou lin 4. 455' 6.09' 3.813" SCSSV 5. 3,044' 1.61' 3.813" X Ni le 6. 3,090' 3.85' 6.00" SC-lL Packer 8.5" OD 7. 3,099' 2.14' 6.380" Slidin Sleeve 8. 3,124' 0.78" 4.98" XO 9. 3,185' 101.30' 4.950 5-l/2" OD Screens 10. 3,290' 4.57' 3.75" Sna Latch and SC-1L Packer Pkr 6" ID; 8.5" OD 11. 3,299' 2.13' 6.380" Slidin Sleeve 12. 3,324' .77' 4.950" XO 13. 3,360' 101.37' 4.950" 5-1/2 OD Screens 14. 3,462' 4.14' 3.00" Sna Latch and Model D Packer 8.5" OD 16. 6600 S b.li0 BWH Packer CURRENT PERFORATION DATA MD Zone To Btm Date S f Comments A-6 3,202' 3,278' 9/17/93 12 B-2 3,370' 3,430' 9/15/93 12 B-2 3,440' 3,450' 9/15/93 12 C-2 4,326' 4,334' 11/18/08 6 C-2 4,348' 4,364' 11/18/08 6 D-2 4,955' 5,001' 5/9/07 6 Re erfed 11/18/08 i001' (DIL) Cement Plug: 5002' - 6600' - 8/6/93 Cement Plug: 7169' - 7283' - 8/2/90 M-03 Schematic Revised 12/1/2008 CVK PBTD =5002" TD = 7291' MAX HOLE ANGLE =33° @ 5002' Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChavNo Original RKB (ft) Water Depth (ft) M-03 TRADING BA_Y UNIT M-03 ADL0018730 5073320411 KW6081 160.00 Primary Job Type Job Category Objective Actual Start Dale Actual End Date Perforating -Post Production Well 11/17/2008 Services Primary Wellbore Affected Wellbore UWI Well Permit Number M-03 5073320411-00 1891110 ,, ra:_ ail`:: rations ' ~ , . _, _. ,, ---,- _ -- -_- ___ 10/12/2008 00:00 - 10!1312008 00:00 _ _ ___ _ Operations Summary RU Slickline. Pressure test lubricator 250 psi low / 2,500 psi high. RIH with 2.80" gauge ring and tag bottom at 5,001' RKB SLM. POOH. RIH with 2.5"x20' dummy gun and tag bottom at 5,001' RKB SLM. 10/13/2008 00:00 -10/14/2008 00:00 T ___ _ __ _ Operations Summary R_D Slickline. Turn well back over to production. 11/48/2008 00:00 - 11/19/2008 00:00 Operations Summary RU Eline. Test lubricator 500 psi low/2500 psi high. Perforated 4,326'-4,334', 4,348'-4,364', 4,955'-4,981', & 4,981'-5,001' with 2-1/2" Powerjet hollow carrier guns, 6 spf, 60 degree phasing. RD Eline. • ~ ~. ~ ~~. I~ ~ t~ ~~~ ~ ~ ~ ~ ALASSA OIL AI~TD GAS C01~5ERVATIOI~T COM1~II55IO1~T Timothy Brandenburg Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 Re: McArthur River Field, Middle Kenai Gas, Sundry Number: 308-397 Dear Mr. Brandenburg: '~ ~ u SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 ~~1 ~~ Trading Bay Unit. M-03 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 far 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?' day of November, 2008 Encl. ~ o~ ~~~~ ~ ~ ~ ~~ ; . STATE OF ALASKA °~ ~~ -, il' ~ti AL OIL AND GAS CONSERVATION COM SION ~~t ~,~ ~ APPLICATION FOR SUNDRY APPROV~-,~~,~ ~ , , ,~< 20 AAC 25.280 ~' ~° `r'~ i 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ^~ Waivi?'r^ Other^ Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ 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 ^ Exploratory ^ 189-111 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20411-00 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 ~ Tradin Ba Unit M-03 9. Property Designation:. 10. KB Elevation (ft): 11. Field/Pool(s): ADL0018730 Steelhead Platform 160' McArthur River Field /Middle Kenai Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,291' • 6,517' 5,001' 4,569' 5,002' & 7,169' (cement) 5,001' (fill) Casing Length Size MD TVD Burst Collapse Structural 93T 20" 93T 936' Conductor 1,451' 16" 1,451' 1,450' 2,630 psi 1,020 psi Surface 2,712' 13-3/8" 2,712' 2,644' 3,090 psi 1,540 psi Intermediate Production 536' 10-3/4" 536' 535' 5,860 psi 3,220 psi 6,732' 9-5/8" 7,268' 6,496' 6,870 psi 4,750 psi Liner Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4-1 /2" 12.6# L-80 3,085' Packers and SSSV Type: Packers and SSSV MD (ft): (2) SC-1 L Packers & Model D Packer / SCSSV 3,090', 3,290', 3,462' / 455' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development^ Service ^ 15. Estimated Date for 11/18/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas Q Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. t hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature one 276-7600 Date 11/3/2008 ~. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: a Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. ,~ , ~T, Subsequent Form Required: Lt`~ ~ ~t'~`~~~R ~' (~ ~~Q~ APPROVED BY ~ ~ ~~ ~~ ~ Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised / 0 ~ ~ ~ubmit in `D-uplira ~ ~~~ /o. ~•D° ~ ~ Steelhead M-03 Schematic as of 5/9/07 RKB to TBG Head = 74.4' KB to MSL =160' CASING AND TUBING DETAIL ~,~ 1E 13 Casing pat 2661'-268 SIZE WT GRADE CONN ID TOP BTM. 20" 133 X-56 18.730" Surface 937' 16" 75 K-55 15.240" Surface 1451' 13-3/8" 61 K-55 12.515" Surface 2453' 13-3/8" 68 K-55 12.412" 2453' 2712' 10-3/4" 55.5 N-80 9.760" Surface 153' ]0-3/4" 51 L-80 9.850" 153' 536' 9-5/8 47 N-80 BTC 8.681" 536' 7268' Tubin 4-1/2" 12.6 L-80 3.958" Surface 3085' JEWELRY DETAIL NO. De th Len th ID Item 1. 436' 5.20' 3.958" Flow Cou lin 2. 441' 8.64' 3.958" GLM 3. 450' 5.19' 3.598" Flow Cou lin 4. 455' 6.09' 3.813" SCSSV 5. 3,044' 1.61' 3.813" X Ni le 6. 3,090' 3.85' 6.00" SC-1L Packer 8.5" OD 7. 3,099' 2.14' 6.380" Slidin Sleeve 8. 3,124' 0.78" 4.98" XO 9. 3,185' 101.30' 4.950 5-l/2" OD Screens 10. 3,290' 4.57' 3.75" Sna Latch and SC-1L Packer (Pkr 6" ID; 8.5" OD 11. 3,299' 2.13' 6.380" Slidin Sleeve 12. 3,324' 77' 4.950" XO 13. 3,360' 101.37' 4.950" 5-I/2 OD Screens 14. 3,462' 4.14' 3.00" Sna Latch and Model D Packer (8.9' OD i, CURRENT PERFORATION DATA (MD) 1 Zone To Btm Date S f Comments A-6 3,202' 3,278' 9/17/93 12 B-2 3,370' 3,430' 9/15/93 12 B-2 _ 3,440' 3,450' 9/15/93 12 [)-~ - ~.~)~;~ ~ x.001' I ~ ~?0~ ~ _ _ i - -- 001'(DIL) Cement Plug: 5002' - 6600' - 8/6/93 Cement Plug: 7169' - 7283' - 8/2/90 MAX HOLE ANGLE =33° @ 5002' M-03 Schematic Revised 10/13/2008 BCA PBTD =5002" TD = 7291' Steelhead M-03 Proposed Schematic as of 5/9/07 RKB to TBG Head = 74.4' KB to MSL = 160' CASING AND TUBING DETAIL 20" 1f 73 Casing pat 2661'-268 SILE WT GRADE. CONN ID TOP BT11. 20" 133 X-56 18.730" Surface 937' 16" 75 K-55 15.240" Surface 1451' 13-3/8" 6l K-55 12.515" Surface 2453' 13-3/8" 68 K-55 12.412" 2453' 2712' 10-3/4" 55.5 N-80 9.760" Surface 153' 10-3/4" 51 L-80 9.850" 153' 536' 9-5/8 47 N-80 BTC 8.681" 536' 7268' Tubin 4-1/2" 12.6 L-80 3.958" Surface 3085' JEWELRY DETAIL NO. De th Len th ID tem 1. 436' 5.20' 3.958" Flow Cou lin 2. 441' 8.64' 3.958" GLM 3. 450' 5.19' 3.598" Flow Cou lin 4. 455' 6.09' 3.813" SCSSV 5. 3,044' 1.61' 3.813" X Ni le 6. 3,090' 3.85' 6.00" SC-1L Packer 8.5" OD 7. 3,099' 2.14' 6.380" Slidin Sleeve 8. 3,124' 0.78" 4.98" XO 9. 3,185' 101.30' 4.950 5-1/2" OD Screens 10. 3,290' 4.57' 3.75" Sna Latch and SC-IL Packer Pkr 6" ID; 8.5" OD 11. 3,299' 2.13' 6.380" Slidin Sleeve 12. 3,324' .77' 4.950" XO 13. 3,360' 101.37' 4.950" 5-1/2 OD Screens 14. 3,462' 4.14' 3.00" Sna Latch and Model D Packer 8.5" OD ~, CURRENT PERFORATION DATA (MD) Zone To Btm Date S f Comments A-6 3,202' 3,278' 9/17/93 12 B-2 3,370' 3,430' 9/15/93 12 B-2 3,440' 3,450' 9/15/93 12 C-2 +/- 4,326' +/- 4,334' Pro sed ' C-2 +/- 4,354' +/- 4,366' Pro sed D-2 4,955' 5,001' 5/9/07 6 Pro osed Re erf 001'(DIL) Cement Plug: 5002' - 6600' - 8/6/93 Cement Plug: 7169' - 7283' - 8/2/90 MAX HOLE ANGLE =33° @ 5002' M-03 Schematic Revised 10/13/2008 BCA PBTD =5002" TD = 7291' Chevron OBJECTIVE: • Reperforate D-2 GGS Zone & perforate new C-2 GGS Zone. PROCEDURE SUMMARY: Steelhead Platform Well # M-03 10/21/08 1 MIRU Slickline. RIH gauge tbg. Tag fill. POOH. RIH w/ Dummy Gun to tagged fill depth. POOH RD Slickline. 2 MIRU Eline. PT BOPE to AOGCC Standards. 3 RIH repeforate D-2 GGS Zone (4,955' to 5,001') 4 RIH Peforate C-2 GGS Zone (+/- 4,326' to +/- 4,334' & +/- 4,354' to +/- 4,366') 5 RD Eline Unit. Package for Demobe M-03 REVISED BY: CVK IO-20-08 • Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: fcbn@chevron.com December 3, 2007 To: AOGCC Howard Okland 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 ~ ~ ~ ~ ~ ~ PERMIT ~ ~~ F ~ h.1BE I S'~ EC~ I ~ LOG TYPE SCALE i L ~~ C; T~ I~ Ih: rt,',';L P.`.1N 8 ~ILP:1 ^~ LC ~S~D ~ 7 li Lif;E ~ ~~ '~ ~ ~:JTES - L--~~~~ ~ PAS, COMPLETION RECORD 2.5" POWERJET HSD GUNS GAMMA RAY /CCL 24-Aug- 3060 - 189-133-0 507332041300 TBU M-05 CORRELATION 5" 06 3809 1 1 1 PDS COMPLETION RECORD TTS SUMP PACKER 3550 - 189-133-0 507332041300 TBU M-05 SETTING 5" ~ 5-Sep-06 3810 1 1 1 PDS COMPLETION RECORD 2 1!4" POWERJET HSD 6 3200 - 189-133-0 507332041300 TBU M-05 SPF 5" 1-Jan-07 3684 1 1 1 PDS PERFORATION RECORD 2.5" POWERJET HSD, S SPF, 60 DEG GAMMA RAY / 9-May- 3955 - 189-111-0 507332041100 TBU M-03 CCL 5" 07 5001 1 1 1 PDS ~ O ~ '1 ~ ~ ~ r's~~ ~~~ DE.C ~ ~ Z00~ Please acknowledge receipt by signing and returning one copy of this=transmittal"or FAX to 9D7 263 7828. Received By: Date: ~_° ~;~~ _ _ -- . STATE OF ALASKA . 6~¡1 I»~C'^ ALA OIL AND GAS CONSERVATION COM ION k. 4~ J{¡, ~/~ REPORT OF SUNDRY WELL OPERATIONS b) ~.r.fq4i~ íV <~;; " ~b '~. . '/', 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other U 4, "or l'1' ./ Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool D Waiver D Time Extension D ~ðol: ''-: C. D q~ c',' Change Approved Program D Ope rat. Shutdown D Perforate 0 Re-enter Suspended Well 'e '/.7J.;j-:.. 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: ~~... 'v' "" - Name: Development 0 Exploratory D 89-111 /J'9-///t:J ~ 3. Address: P.O, Box 196247, Anchorage, AK 99519 Stratig raph ic 0 Service D 6. API Number: or 50-733-20411-00 - 7. KB Elevation (ft): 9. Well Name and Number: 160' M-03 - 8. Property Designation: 10. Field/Pool(s): Steel head Platform ADL 18730 Trading Bay Unit (Middle Kenai Gas Pool) ~ 11. Present Well Condition Summary: Total Depth measured 7291 , feet Plugs (measured) 5002' true vertical 6512 ' I feet Junk (measured) none I Effective Depth measured 5001 feet true vertical 4569 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 937' 20" 937' 937' 3060 psi 1450 psi 1452' 16" 1452' 1452' 2630 psi 1020 psi Surface 2453' 13-3/8" 2453' 2422' 3090 psi 1540 psi 260 ' 13-3/8" 2713 2645' 3450 psi 1950 psi Production 153' 10-3/4" 153' 153' 6450 psi 4020 psi 383' 1 0-3/4" 536' 536' 5860 psi 3220 psi 6732' 9-5/8" 7268' 6497' 6870 psi 4760 psi Peforation. Depth Measured Depth: See Attached Schematic True Vertical Depth: See Attached Schematic Tubing: (size, grade, and measured depth) 4-1/2", 12.6# L-80, AB Mod Butt 5032' Packers and SSSV (type and measured depth) See Attached Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNEDJUN 2 5 2007 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Ca~i~¡;¡ Pressure Tubing Pressure Prior to well operation: 0 200 0 . . 50 psi 221 psi Subsequent to operation: 0 1960 0 50 psi 122 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory D Development 0 Service D Daily Report of Well Operations X 16. Well Status after work: oilD Gas 0 WAG D GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 307-109 Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature y- ßL¡/ ~ Phone 907-276-7600 Date 5 -;(t.¡~0'7 (---- // ?/ Form 10-404 Revised 04/2006 0 RIG I N A L RBDMS BFL JUN 2 2 2007 Submit Original Only \I!!'. ¡¡¡, ;¡¡@ R '~. "~,, .~, Æ!II.* .. _..' ,~, N@.·¡¡¡¡¡"\\r "",'111 "..'W;'1~ .ill . 0\\"ill ,,'~ ;&\ 8m""" :« .~ "K" ,,"';~h,0G ,," ,,'!& ", XX ,,«*A1 "1't,,,'4'~~ 1M" ~..W\'kill/;01¡""/~k;:".~" 00S~.' ~j§ ;till\' ss.,\},,,,,*.N..fu10~).tP'" ¿¡¡ ~.'.~~ ø,:,< »." x xC(" %" " 2 '~\\y,,,,, »"" X" "'A1R x :;; ""NY" ,,+" R'fuy "=t%W" ""illillillill~'h'B" "0 B2s" N"" 1m ~ "lli@ ~~ N" @. oYili\«« '.@'8à&~ ~1S'tZ<U "II ".~0 ,.'m~." x & ""ffiß<UY"."S¡ IIz* ,,4%**",,~\;èfu"Sdmœ~\ m<,,; ß ~ ~ ~,;j0 clt~ A\m@%ill ~ Daily Operations 5/9/200700:00 - 5/10/2007 00:00 Operations Summary 1. Ran 2.84" Gauge Ring and tag fill at 5046' (5001' dil) Slickline Measurement. 2. Ran 2-1/2"x25' dummy gun and tag fill at 5046' Slickline measuremet. 3. Perforate w/2-1/2" Powerjet, HC, 6 spf, 60 deg phase from 4955' to 5001' dil. · .. Steelhead M-03 Schematic as of 5/9/07 RKB to TBG Head = 74.4' KB to MSL:: 160' 20" 2 3 4 r,t< èH¡,¡r AND Tnn' Mr nvm n SIZE WT roD" rn" CONN m TOP BTM. 20" 133 X-56 18.730" Surface 937' 16" 75 K-55 15.240" Surface 1451' 13-3/8" 61 K-55 12.515" Surface 2453' 13-3/8" 68 K-55 12.412" 2453' 2712' 10-314" 55.5 N-80 9.760" Surface 153' 10-3/4" 51 L·80 9.850" 153' 536' 9-5/8 47 N-80 BTC 8.681" 536' 7268' Tubing: 4-112" 12.6 L-80 3.958" Surface 3085' 16" 13-3/S" i. 5.20' 3.958" 2, 8.64' 3.958" / 3, 5.19' 3.598" 4. 6.09' 3.813" Casing patch 5. 1.61' 3.813" 2661 '-2681' 6, 3.85' 6.00" 7, 2.14' 6.380" 8. 078' 4.98" 9. 10130' 4.950 lO. 4.57' 3.75" 7 H. 2.13' 6.380" 12. 77' 4.950" 13. 10 13 7' 4.950" 14, 4.14' 3.00" 8 15. 12.4' 6.00" 16. 5' 600 10 H 12 14 16 Cement Plug: 5002' - 6600' 8/6/93 Cement Plug: 7J69' -7283' - 8/2/90 PBTD =5002" TD ::: 1291' MAX HOLE ANGLE =330 @ 5002' M-03 Schematic Revised 5/9/07: BCA . ~~!Æ~Œ mJ~ !Æ~!Æ~æ!Æ . A1tASIiA OIL AlO) GAS CONSBRVATlON COMMISSION SARAH PAUN, GOVERNOR 333 W. 7IhAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 ...... ---- Re: McArthur River Field, Middle Kenai Gas Pool, M-03 \r'2Q./ \ \ \ Sundry Number: 307 -109 lJ - \ SCANNEDI APR 092007 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may fIle with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this i day of April, 2007 Enc!. Sincerely, (fl ~/4))1 A STATE OF ALASKA . ALWA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 ~9A ki.\/~ ~ 1. Type of Request: Abandon D Suspend D Operational shutdown D Perforate 0,r Waiver D Other D Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of Califomia Development 0 Exploratory D 89-111 / 3. Address: Stratigraphic D Service D 6. API Number: P.O. Box 196247, Anchorage, Alaska 99519 50-733-20411-00 ,r 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: RECEIVED property line where ownership or landownership changes: Spacing Exception Required? Yes D No 0 M-03 ^......... ^ n ^ 9. Property Designation: AÞ" 16730 f:. .,.07 10. KB Elevation (ft): 11. Field/Pool(s): ~' fì \1 *I LUUI\AfJ Steel head Platform 160' Trading Bay Unit:.\I\1.( ~~~~'"~. 12. PRESENT WELL CONDITION SUMMARY . ""...".. '" '.... ...... "VII;). . Total Depth MD (ft): ~~~otal Depth TVD Sft): Effective Depth MD (ft): Effective Depth TVD (ft): 1~IUgS (measured): r .n' easured): µegr '1t.1( Þ.¡.,. 6;86' (,f'I''}..)f.j..5,001' 4,569' 5,002' Casing Length Size MD TVD Burst Collapse Structural Conductor 937' 20" 937' 937' 3060 psi 1450 psi 1,452' 16" 1.452' 1,452' 2630 psi 1020 psi Surface 2,453' 13-3/8" 2,453' 2,422' 3090 psi 1540 psi 260' 13-3/8" 2,713' 2,645' 3450 psi 1950 psi Intermediate Production 153' 10-3/4" 153' 153' 6450 psi 4020 psi 383' 1 0-3/4" 536' 536' 5860 psi 3220 psi 6,732' 9-5/8" 7,268' 6,497' 6870 psi 4760 psi Li ner Perforation Depth MD (ft): l~erfOration Depth TVD (ft): 11~Ubing Size: ITubing Grade: I~Ubing MD (ft): 3440'-50'; 3370'-3430'; 3202'-78' 3256'-3264'; 3197'-3247'; 3057'-3121 4-1/2", 12.6# L-80, AB Mod Butt 5032' Packers and SSSV Type: Cameo SSSV; SC-1R Pkr; SC-1L Pkr; 0 Pkr; Packers and SSSV MD (ft): Cameo SCSSV-459'; SC- 1R- 3,090': SC-1L- 2- BWH Pkrs 3,290', 0 pkr - 3,463'; BWH - 5,032'; BWH - 6,600' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 Service D 15. Estimated Date for 4/7/2007 16. Well Status after proposed work: Commencing Operations: Oil D Gas 0 Plugged D Abandoned D 17. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 18. I hereby certify that the foregoing is true and eorrect to the best of my knowledge. Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature "'7 '~/5 ß~:ne 907-276-7600 Date ~ - 2'6' -o:¡- ( ^ -=-y---- COMMISSION USE ONLY L---"" Notify commis~hat a representative may witness ISUndry Number: Conditions of approval: :?JJ7 ., 1001 Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D .- Other: \-. ~ (,L \\ <0"'\ \""C) \ ~ '-> ... Ç> ~CL~ " ~ ~ L<J~ ~ "'-.) I ~~~C~S I.)ß, S"""",OlFomR"";"'4(Øá 1 R8DMS 8Fl APR 0 5 2007 / AJI ,¿ ,~V APPROVED BY Date: '1-'1-0 ¡- Approved by: --f't'(Ø ~." OMM R THE COMMISSION Form 10-403 Revised 06/2006 \.7 , '1 IC:;I I I / ' , ... I( 7D/ g- ~ ~~ub~Plicate " I ~ t/·a·Þ 1)./\ 7 7 'Chevron . . . Trading Bay Unit Well # M-03 2/21/07 OBJECTIVE: · Perforate D-2 Grayling Gas Sands. PROCEDURE SUMMARY: · Run 2.84" Gauge Ring and tag fill approx 5001' DlL. · Run 2-1/2"x25' Dummy Gun and tag fill. · Run 2-1/2" PI HC, 6 spf, 60 degree phase and perforate D-2 Grayling Gas Sands from 4955' to 5001' (+/-). M-03 REVISED BY: BCA 2/21/07 Steelhead M-03 As Completed 9/19/93 RIŒ to TBG Head::: 74.4' KB to MSl:::: 160' 16" If"' --.- ANn TUBlNG DETAIL SIZE WT GRADE I CONN In TOP BTM. r 20" 133 X-56 18.730" Surface 937 r 16" 75 K-55 15.240" Surface 1451' 13-3/8" 61 K-55 12.515" Surface 2453' 13-3/8" 68 K-55 12.412" 2453' 2712' 10-3/4" 55.5 N-80 9.760" >:lIrf""<' 153' 10-3/4" 51 L-80 9.850"· 1,1' 536' 9-5/8 47 N-80 BTC 8.681" 536' 7268' Tubinl!: 4-112" 12.6 L-80 3.958" Surface 3085' 20" 13-3/8" 7 JEWELRY DETAIL In Item 8 1. 2. 3, 4. 5. 6. 7. 8. 9. 10. U. 12. 13. 14. 15. 16. Casing patch 2661 '-2681' 12 A-6 B-2 B-2 3202' 3370' 3440' 3278' 3430' 3450' Fill at 5001' Cement Plug: 5002' - 6600' 8/6/93 Cement Plug: 7169' -7283' - 8/2/90 PBTD =5002" TD = 1268' MAX HOLE ANGLE =330 @ 5002' M-03 Schematic Revised 3/13/07: BCA f"A<i n..rr. ANn nID'T, U SIZE WT GRADE CONN m TOF BTM, 20" 133 X-56 18.730" Surface 937' 16" 75 K-55 15.240" Surface 1451 ' 13-3/8" 61 K-55 12.515" Surface 2453' 13-3/8" 68 K-55 12.412" 2453' 2712' 10-3/4" 55.5 N-80 9.760" Surface 153' 10-314" 51 L-80 9,850" 153' 536' 9-5/8 47 N-80 BTC 8.681" 536' 7268' Tubinp'; 4-1/2" 12.6 L-80 3.958" Surface 3085' .. t IÍ> RKB to TBG Head == 74.4' KB to MSl == 160' 20" 2 3 4 16" Steelhead M-03 Proposed Schematic 3/26/07 13-3/8" JEWELRY DETAIL Casing patch 2661 '-2681' 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 436' 441' 450' 455' 3,044' 3,090' 3,099' 3,124' 3,185' 3,290' 3,299' 3,324' 3,360' 3,462' 5032' 6600' 5.20' 3,958" 8.64' 3.958" 5.19' 3.598" 609' 3.813" 1.61' 3.813" 3,85' 6.00" 2.14' 6.380" 0.78' 4.98" 101.30' 4.950 4.57' 3.75" 2.13' 6.380" .77' 4.950" 101.37' 4.950" 4.14' 3.00" 12.4' 6.00" 5' 6.00 13. 14. 15. 16. Flow Cou ¡in GLM Flow Cou Jin SCSSV XNi Ie SC-1 L Packer 8.5" aD SJidin Sleeve XO 5- 1/1" aD Screens Sna Latch and SC·l L Packer Pia 6" ID; 8.5" aD Slidin Sleeve XO 5- 1/2 aD Screens Sna Latch and Mode! D Packer 8.5" aD BWH Packer BWH Packer PBTD ==5002" TD = 7268' MAX HOLE ANGLE =33" @ 5002' M-03 Schematic Cement Plug; 5002' - 6600' - 8/6/93 Cement Plug: 7169' -7283' - 8/2/90 Revised 3/13/07: BCA Chevron === . Debra Oudean Technologist Chevron North Am.a Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: oudeand(Cùchevron.com January 15, 2007 To: AOGCC Howard Okland 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 1189-111 5073320411 L.h ôCANNED JAN 1 9 2007 '"'\\\\1 ~:\~ '- ~ Lv'-' .~~' ..~&.~ .,~ ~\J/ ,...~C/!\('"' G&- \'(fìA~( ___ 1 L(336 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. I Received By: I Date: STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OiL: GAS: x SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number ~1~ I Union Oil Company of California (Unocal) 89-111 ~,~r~ -,. ~ 3. Address 8. APl Number P.O. Box 196247 Anchorage, AK 99519 50- 733-20411-00 4. Location of well at surface 9. Unit or Lease Name Leg B2, Cond. slot 10 Steelhead Platform, 1039' F~E,:602; FWL,'~ec. 33, T9N, R13W~,9'~J?,.'.:~i Trading Bay Unit At Top Producing Interval ! ,,~ ~,/ i : ":'~!!t~*~,~'~,'Z' i 10. Well Number At Total Depth i: ,-'/'..;.'. \ 11. Field and Pool 250' FSL 2 227' FEL Sec 28 T9N R13W SM~ . -:-JT~-.~7'i.: .' '.~.i;~'-~ McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Grayling Gas Sands Pool 152' KB above MSLI ADL 18730 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 7/04/90 7/28/90 9/19/93I 187' feet MSLI 1 17' T°tal Depth (MD+TVD) 18' Plug Back Depth (MD+TVD) I 19' Directi°nal SurveY 20' Depthwhere SSSVset J 21' Thickness°f Permafr°st7291' & 6512' 5002' & 4562' Yes: x No: 459 feet MD N/A 22. Type Electric or Other Logs Run DIL/AMS/TCC/SGC; LDT/CNL; DIL/SDT/GR; LCT/CNL/GR; SHDT/GR; CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# X-56 0 937' 26" 550 sx Class G cmt N/A 16" 75# K-55 0 1452' 17.5" 516 sx Class G cmt 65,000# 13-3/8" 61/68# K-55 0 2713' 17.5" 600 sx Class G cmt 60,000~ 10-3/4" 55.5# N-80 0 535' 12.25" 660 sx Class G cmt N/A 9-5/8" 47# N-80 535' 7268' 12.25" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) A.5 3300' i3090', 3290'8, 3463' A6 3202-3278 MD 3049-3112' TVD B1 3370-3430 MD 3189-3240 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. B2 3440-3450 MD 3248-3256 TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED All perforation were 12 SPF 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 8/28/90I Flowing Gas Well Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ! GAS-OIL RATIO I 10/93 31 day average TEST PERIOD => 18443 0 NA INA Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE '-> 18443 0 NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,~? .... ~,:, r~i'~ ~, f'~:;.:; fi:," :".~., ~,;,.,,¥ ?.'r?,:;~'~' Form 10-407 Rev. 7-1~80 CONTINUED ON REVERSE SIDE Submit in duplicate 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ORIGII' AL 31. LIST OF ATTACHMENTS of my 32, I hereby, certify, that the fore~oinfl is tr~ue and correct to the best knowledge Signe . Titl ~,&(..L.~/~(..\ ~/~r~. Date Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 472.0 - 478.0' SQUEEZE 495.0 = 495.0' SQUEEZE PERFS 6/27/90, Sqz'd 79,9 - 145i.5 i6.90!! OD 75.001/fi K-55 SURF C<SG 78.6 - 2458 1.J.47~ OD 61.00t/fl BaS SUEF g,,J 2453.5- 23112 6; 13.375' OD 68.OOl/f( K45 suRF c96 2671.0- 2675,0' SQUEE~ PUB 70.0- 155~? !0 5/4? OD .55 501/l. N40 PROL/CSG 155,5 - 555171 10 3/4!! OD fil,OOl/it L40 PROD CSG 55.5.7 72o7.9 9.6L OD 47.00~/~[ N-80 BOB egg 5052.0 - 6600.0' GAF. NT PLUG 5170.0 ~ 5210,0' SQUEEZE BBB B-3B, Sqz'd 3525.1 = 54~s,9 5;)0 OD-~...Sfl ,U bSO~/~t K-55 ~B6 5290.4 - 529/}.9' REFRV. PACKER ~}nb 19040 9C-IL PkL W/(:~ !xt. 3202.0 - 3278? PERFS A4; 9/17/95, I2HPF, 78', 6" }CP Guns 3570.0 - 5430.0' PERFS B.1, 9/15/95; 12HPF, 60', 6" lOP Guns 5440.0 - 5450,0 PBo B-2, 9/!5/95, 12HPF, 10, 6" TCP Guns 5002,0 - 5102.8' CEMENI PLUG 5U02.0 ~ 5102,0 -.500 OD 12,601/fl b8OlB Ab'd !bg. SBU 501~2.(} 5,~a,4' PACKER PL W/Sd i~o.n Ext 7169.0 7283.0' CE,~ENT PLUG 6600,0 ~ 6618,U'C[MfNiBLUG E ORANDUM STATE Ol 3 LA SKA ALASKA OIL AND G~4S CONSER V,4 TION COMMISSION TO: David Johnst..~ Chairma~ DA TE: September 9, 1993 FILE NO: A26HIIAC.DOC THRU: Blair Wondzell P.I. Supervisor FROM: Doug Amo~ Petroleum Inspector PHONE NO.: 279-1433 ,, SUBJECT: BOPE Test Steelhead Pltf. Marathon TBU M-3 McArthur Rv. Field PTD No. 8~ Wednesday September 8, 1993: ! traveled this date to Kenai and on to Marathon's Steelhead Platform to witness the BOPE Test on TBU Well M-3. I found the Rig and Platform in good repair and all personnel knowledgeable about their equipment and test procedures. As the attached AOGCC BOPE Test Report indicates there were two failures, both the 2 1/16" Choke Manifold Valve and the Lower Kelly Cock were replaced and retested before I departed the Platform. IN SUMMARY, witnessed the BOPE test on Marathon's Steelhead Platform on Well TBU M-3, test time 8.0 hr's, 20 valves, 2 failures. Attachment A26HIIAC.XLS ",,~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Pool Arctic Drilling Rig No. Operator: Marathon Oil Co. Well Name: TBU M-3 Casing Size: 9 5/8" Set @ 7,291 Test: Initial X Weekly Other DATE: 9/8/93 Stlhd PTD # 89-11 Rig Ph.# 564-6578 Rep.: Lance Landry Rig Rep.: Richard Kennedy Location: Sec. 33 T. 9 N. R. 13 VV. Meridian Seward Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign YES Drl. Rig OK BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves 1 Kill Line Valves 1 Check Valve I Test Pressure P/F 250/2,500 P 250/2,500 250/2,500 250/2,500 250/2,500 250/2,500 250/2,500 FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F I 250/2,500 P 1 250/2,500 F/P 1 250/2,500 P I 250/2,500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 13 250/2,500 P 29 250/2,500 P I Functioned P I Functioned P ACCUMULATOR SYSTEM: 250/2,500 P System Pressure 3,000 I P Pressure After Closure 1,300 I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 45 Trip Tank OK OK System Pressure Attained 4 minutes 8 Pit Level Indicators OK OK Blind Switch Covers: Master: YES Remote: Flow Indicator OK OK Nitgn. Btl's: 2 ~ 2,200, 4 @ 2,300 Gas Detectors OK OK Psig. sec. sec. YES Number of Failures: 2 ,Test Time: 8.0 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The 2 1/16" Choke Manifold Gauge Block Valve and the Lower Kelly Cock failed. Both non compliance items were repaired and retested before I departed the Platform. Distribution: orig-Well File c - OperJRig c- Database c - Trip Rpt File c -Inspector FI-021L (Rev. 7/93) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: A26HIIAC.XLS Doug A~os STATE OF ALASKA ALAS,,,, OIL AND GAS CONSERVATION COMM,,~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operations Shutdown Stimulate Plugging X Perforate Pull Tubing m Al-~'er Casing __ 'R-"~epair Well__ -- Other m 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB)~"~ .~ UNOCAL (Marathon Oil Company - Sub Operator) De_vel.oprn. ent X 160' KB ~" feet ~ ~ ....... ~-xp~ora~ory 7. Unit or Property name ,~. Aaaress S tratig rap h ic m P.O. Box 196247 Anchorage, AK 99519 Service- Trading Bay Unit 4. Location of well at surface Leg B-2 Cond. 10 Steelhead Platform 1,039' FNL, 602' FWL, Sec. 33-9N-13W-SM At top of productive interval 274' FNL, 2,092' FWL, Sec. 33-9N-13W-SM At effective depth At total depth 250' FSL, 2,227' FEL, Sec. 29-9N-13W-SM 8. Well number M-3 9. Permit number/approval number 89-111 / 93-143 10. APl number 50- 733-2041 1 11. Field/Pool Grayling Gas Sands Pool 12. Present well condition summary Total Depth: measured 7,291' feet Plugs (measured) 5,002' - 6,618' Cmt Plug true vertical 6,51 2' feet Effective depth: measured 7,1 76' feet Junk (measured) None true vertical 6,409' feet Casing Length Size Cemented Measured depth True vertical depth Structural 937' 20" 2,550 sx 937' 937' Conductor 1,452' 16" 1,516 sx 1,452' 1,452' surface 2,713' 13-3/8" 1,600 sx 2,713' 2,645' Intermediate 7,268' 10-3/4" X Production 9-5/8" 1,660 SX 7,268' 6,497' Liner Perforation depth: measured All Perforations Plugged '~J true vertical S E P - 995 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, AB Mod Butt to 5,043' A~aska 0il & Gas tuns. (,0mmissior~ Packers and SSSV (type and measured depth) Arlchorage Otis FMX SCSSV (~ 458' MD; Otis BWH Parma-Drill Pkr w/SBE @ 5,032' & 6,600' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcr Water-Bbl. Casing Pressure Tubing Pressure Prior to well operation SI SI 300 1050 Subsequent to operation SI S I 310 0 5. Attachments 116. Status of well classification as: I Copies of Log and Surveys run ~ Daily Report of Well Operations X Oil Gas X Suspended -- 7. I hereby, e~rtify that the foregoing i~ true and correct to the best of my knowledge Signed . Title l~'tL~ [/~ ~ A~ Form 10-404 Rev 06/15~88 Service Date SUBMIT IN DUPLIC~f.~ DAILY WELL OPERATIONS STEELHEAD WELL M-3 PLUGB~'~' July 31, 1993 PERFORATIONS: Open: D-3B 5170' - 5210' DIL (4711' - 4744' TVD) Below wireline plug set in isolation packer tail pipe: D-16A 6723' - 6735' DIL (6011' - 6023' TV~, Alas~ 0d & 6as Co,is. C0mmissi0~ Anchorage 1. Safety meeting with co±led tubing and pumping personnel. $ITP = 1050 psi. 2. AU lines to kill well. Pressure test lines to 3000 psi. 3. Open well and bullhead 85 bbls drill water (fresh H20) at 1.5 BPM, 1000 psi. SITP = 850 psi. Bleed tubing to 300 psi, 4. Repeat pump and bleed operation until SZ~ = 10 psi. Total of 110 bbls of drill water pumped° Monitor tubing pressure. August 1, 1993 · · RU coiled tubinc equipment on well. Pressure test coil, lines, and lubricator to 3500 psi. Close BOP rams and test to 3500 psi. RIH with coil while circulating drill water to production. Tag isolation packer top at 6610' DIL. (NOTE: Production packer tubing tail at 5090' DIL.) 7. Mix cement: Class "G" with 0.2% Halad-344, 0.2% CFR-3, 0.3% HR-5. · By the displacement method, set a continuous cement plug from isolation packer top at 6610' DIL to 5040' DIL, keeping nozzle about 30' below cement top in the 9-5/8" casing. Max circulating pressure = 3600 psi @ 1 BPM. Total of 546 sxs pumped. 9. PU to 5000' DIL. CBU (65 bbls). Continue POOH while circulating 10. RD coiled tubing equipment. Fluid level at surface. SITP = 0 psi. AUGUST 6, 1993 11. RU braided line equipment on well. Pressure test lubricator to 2000 psi. RIH and tag cement at 5002 '. POOH. RD. NOTE: A RIG RECOMPLETION IS SCHEDULED FOR MID-SEPTEMBER. 1. Type of Request: STATE OF ALASKA ...~ ALA~r,A OIL AND GAS CONSERVATION COMI~h,~SION APPLICATION FOR SUNDRY APPROVALS Abandon __ Suspend__ Operation shutdown __ Re-enter suspended well__ Alter casing Repair well Plugging __ Time extension Stimulate Change approv--ed program -- Pull Tubing Variance P~rforate Othe-'~" X Re~etion 6. Datum elevation (DF or KB) 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: 106' KB above MSL feet 4. Location of well at surface Leg B-2 Cond. 10 Steelhead Platform 1,039' FNL, 602' FWL, Sec. 33-9N-13W-SM At top of productive interval 274' FNL, 2,092' FWL, Sec. 33-9N-13W-SM At effective depth At total depth 250' FSL, 2,227' FEL, Sec. 29-9N-13W-SM 7. Unit or Property name Trading Bay Unit 8. Well number M-3 9. Permit number/approval number 89-111 0. APl number 50- 733-2041 1 11. Field/Pool Grayling Gas Sands Pool Development X Exploratory ~ Stratigraph ic ~ Service m 12. Present well condition summary Total Depth: measured 7, 291 ' feet true vertical 6, 51 2' feet Effective depth: measured 7,176' feet true vertical 6,409' feet casing Length Size Structural 937' 20" Conductor 1,452' 16" Surface 2,713' 13-3/8" Intermediate 7,268' 10-3/4" X Production 9-5/8" Liner Perforation depth: measured true vertical Plugs (measured) 5,002' - 6,618' Cmt Plug Junk (measured) None Cemented Measured depth True vertical depth 2,550 SX 937' 937' 1,516 SX 1,452' 1,452' 1,600 SX 2,71 3' 2,645' 1,660 SX 7,268' 6,497' All Peforations Plugged Tubing (size, grade, and measured depth) ~4-1/2", 12.6#, L-80, AB Mod Butt to 5,043' Packei's and SSSV (type and measured depth) Otis FMX SCSSV @ 458' MD; Otis BWH Perma-Drill Pkr w/SBE @ 5,032' & 6,600' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X Estimated date of commencing operation Sept. 6, 1993 If proposal was verbally approved Name of approver Date approved 15. Staffs of well classification as: Oil Gas X Suspended Service 17. I hereby c~ tha~<l~ f°reg°~ tru~n~~t of mY kn°wledge. Signed /~..-~,..~~~~Title FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test Location clearance Mechanical Integrity Test __ -~ubsequent form required 10'"~ Approved by order of the Commision Form 10-403 Rev 06/15/88 IApproval No~... ~ ~ / Approved Copy Returned SUBMIT IN TRIPLICATE STEELHEAD WELL M-3 RECOMPLETION PROCEDURE AFE #8301093 OBJECTIVE: CURRENT STATUS: Recomplete as a gravel packed commingled A-6, B-i, and B-2 producer. Existing completion (D-3B, D-16A, and D-16BC perforations) was plugged-back 8/1/93. Cement top is at 5002' braided line measurement (ref. rotary table). See Figure 1. TP = 0 psi. CP = 0 psi. Drill water in tubing. PULL EXISTING COMPLETION; MILL-UP CASING PATCH 1. Skid rig over M-3. · · RU equipment to cut tubing (wellhead connection is 4-1/2" 8RD). PT lubricator to 1500 psi. RIH and cut 4-1/2" tubing above Production packer. RD cutting equipment. Circulate drill water to ensure tubing and casing is free of gas. Monitor well. 4. Close SCSSV by bleeding control line pressure. Set BPV. · ND tree. Wing valve, choke, and 3-1/2" long spacer will be reused. Send remaining wellhead equipment to FMC for inspection/repair. (To be used for M-19.) NU BOPE and riser. Test to 250/2500 psi. Pull BPV. 6. MU landing joints and crossover into tubing hanger (4-1/2" CS Hydril). 7. POOH and LD 4-1/2" tubing. · · 10. MU casing patch mill as recommended by Homco for milling-up patch at 2661' - 2681' DIL. RIH to 2600'. Close annular preventer and pressure casing to 1000 psi. Monitor bleed-off. Mill-up casing patch. Push debris to bottom. Repeat pressure test of casing to 1000 psi. POOH with mill. RIH with bit and casing scraper. Thoroughly scrape casing from 9-5/8" top to 3600'. PU and RIH with clean 3-1/2" 13.3# IF S-135 workstring. Lightly dope pin ends only. Displace drill water with filtered completion fluid: Drill water' + 13.6% KCl (9.0 ppg). This will provide 150 psi overbalance to the proposed A-6, B-i, and B-2 gas sands. 11. Continue circulating and filtering until returns are less than 25 NTU's with no visible particles after one hour of settling. POOH. RUN SUMP PACKER 12. 13. MU and RIH to 3500' DPM with Baker Model "D" permanent packer, setting tool, one stand of 3-1/2" drillpipe, and RA sub. RU E-line and RIH with GR/CC1 to correlate packer setting depth. Note DPM vs. DIL. POOH and RD E-line. Locate packer at 3460' DIL (10' below bottom shot). Drop ball, then pressure-up and work drillpipe as directed by Baker rep on location to set packer. Shift ball seat, release tool, and POOH. PERFORATE B-1 AND B-2: 3370' - 3430' DIL (60'); 3440' - 3450' DIL (10') 14. 15. 16. 17. 18. 19. Prior to PU of guns and prior to POOH with the guns, conduct safety and MU procedure meeting with rig, MOC, and Baker perforating personnel. Repeat meeting at each crew change. · MU and RIH with perforating guns (6", 12 SPF, 32 gram GP PerfForm charges, with weld-on blade centralizers) and associated annulus pressure firing and underbalance features as described in Figure 2. Fill workstring with completion fluid while RIH to obtain an 800 psi underbalance. While RIH, mix a 10 bbl pill of 100# per 1000 gal HEC, sheared and filtered (Baker to provide HEC). Do not add breaker until it is determined that fluid loss control is required. Tag sump packer at 3460' DIL, space-out with pups for a safe working height above rig floor, and PU until bottom shot is at 3450' DIL. Set packer by rotating to the right and slacking off. Install TIW on workstring. Run chicksan from TIW valve to Baker's test manifold and to the rig's choke manifold. PT to 2000 psi. Close choke on rig manifold. Close annular preventer and pressure annulus to 500 psi. Check for bleed-off. Increase pressure to 1,000 psi to fire guns. Bleed annulus back to 200 psi. Monitor flow into workstring with bubble bucket. Upon verification that the guns fired, slowly PU workstring until annulus pressure bleeds off indicating packer bypass is open. Reverse circulate through rig manifold and gas buster to kill well. Continue reversing until returns are clean. Monitor fluid loss throughout reversing process. 20. 21. 22. SD pumps. Monitor fluid loss. If fluid loss is excessive (as determined by drilling foreman), slackoff on workstring to close packer bypass, add enzyme breaker to 10 bbl pill for a 12-hour breaking time. Spot pill and monitor fluid loss. POOH and LD TCP equipment. RIH with workstring to sump packer. Circulate well clean. POOH. GRAVEL PACK THE B-1 AND B-2 SANDS 23. 24. 25. 26. 27. 28. MU and RIH with the following GP assembly: a. Snap latch seal assembly, 1/2 MS. b. Slim Pack screen, 5-1/2" 15.5# 8rd base, .012 gage, 20-40 Baker Bond, 100'. c. Centralized blank pipe, 5-1/2" 15.5# K-55 8rd, 35'. d. Crossover, 7" 8rd box x 5-1/2" 8rd pin. e. Model'S' gravel pack ext. with sliding sleeve and seal bore. f. SC-iL packer, 96A4-60. g. Hydraulic setting tool, crossover assembly, and 4" flush joint washpipe (for a 0.81 WP to BP ratio). Space out pipe to achieve a safe working height on the rig floor. Locate sump packer at 3460' DIL. Snap in and out to verify position. Snap in and hang pipe in neutral, circulate 5 bbls of completion fluid to clean ball seat at no more than 3 BPM. Drop 1-7/16" ball and let gravitate to bottom. Set SC-iL packer at 3290' as directed by Baker rep on location. Verify slip anchoring of the packer by alternately setting down and picking up 30,000 - 40,000 lbs. Pressure annulus to 500 psi to test packer. Increase to 1500 psi to release service tools from the packer. Hold for 5 minutes, then bleed off. The service tools may now be snapped out of the packer. Pressure-up workstring to shift ball seat. RU gravel infuser pumping equipment and chicksan with safety cables. PT lines to 2000 psi. Position and test the crossover tool in the squeeze, circulating, and reverse positions. Record rates and pressures for squeeze rates of 1, 2, 3, and 4 BPM and circulating rates of 1/2, 2, 3, and 4 BPM. For the 4 BPM circulating test, send returns to the trip tank and record return rate. Accuracy is important. If return rate is greater than 60% of the injection rate, choke returns until a 60% return rate is achieved. 29. 30. 31. With the crossover tool in the circulating position, pump slurry at a constant rate of 4 BPM while infusing 20-40 sand at 1 ppg. Sand-out should be reached after about 100 bbls of slurry is pumped (4200 lbs of sand). When a 1000 psi pumping pressure is observed, reduce the injection rate while keeping pump pressure constant. When the rate has been reduced to 1/2 BPM at 1000 psi (corresponding to about 30' of sand above the screen top), SD pumps and immediately reverse-out excess gravel by pressuring annulus to 500 psi and moving the crossover tool to the reverse position. Do not SD the reversing operation until returns are free of gravel. Return crossover tool to the circulating position. circulation at 1/2 BPM. Record pressure. Establish Close and pressure test the sliding sleeve. POOH with service tools. PERFORATE THE A-6: 3200' - 3278' DIL (78') 32. 33. 34. 35. 36. 37. 38. MU and RIH with Baker S-1 latching type packer plug. Locate and set 10,000 lbs on SC-iL packer at 3290' to latch into packer. Release running tools. Apply pressure from above to test plug. Spot 4' of sand on top of plug. Prior to PU of guns and prior to POOH with the guns, conduct safety and MU procedure meeting with rig, MOC, and Baker perforating personnel. Repeat meefing at each crew change. MU and RIH with perforating guns (6", 12 SPF, 32 gram GP PerfForm charges, with weld-on blade centralizers) and associated annulus pressure firing and underbalance features as described in Figure 3. Fill workstring with completion fluid while RIH to obtain an 800 psi -underbalance. While RIH, mix a 10 bbl pill of 100# per 1000 gal HEC, sheared and filtered (Baker to provide HEC). Do not add breaker until it is determined that fluid loss control is required. Tag sand top and PU to neutral. RU E-line. RIH with GR/CCl and log across RA sub for gun correlation. POOH and RD. Space out with singles and pups for a safe height above the rig floor. Set packer by rotating to the right and slacking off. Install TIW on workstring. Run chicksan from TIW valve to Baker's test manifold and to the rig's choke manifold. PT to 2000 psi. Close choke on rig manifold. Close annular preventer and pressure annulus to 500 psi. Check for bleed-off. Increase pressure to 1,000 psi to fire guns. Bleed annulus back to 200 psi. 39. 40. 41. 42. Monitor flow into workstring with bubble bucket. Upon verification that the guns fired, slowly PU workstring until annulus pressure bleeds off indicating packer bypass is open. Reverse circulate through rig manifold and gas buster to kill well. Continue reversing until returns are clean. Monitor fluid loss throughout reversing process. SD pumps. Monitor fluid loss. If fluid loss is excessive (as determined by drilling foreman), slackoff on workstring to close packer bypass, add enzyme breaker to 10 bbl pill for a 12-hour breaking time. Spot pill and monitor fluid loss. POOH and LD TCP equipment. MU and RIH with Baker'S' plug retrieving tool. Tag fill. PU and circulate to wash out fill. Continue pumping down workstring while slacking off to latch plug. Monitor fluid loss. POOH with plug. GRAVEL PACK THE A-6 SAND 43. 44. 45. 46. 47. MU and RIH with the following GP assembly: · a. Snap latch seal assembly, with 4' spacer tube, crossover, 4-1/2" pup, CAMXN no-go landing nipple, wireline entry guide. b. Seal bore receptacle. c. Slim Pack screen, 5-1/2" 15.5# 8rd base, .012 gage, 20-40 Baker Bond, 100'. d. Centralized blank pipe, 5-1/2" 15.5# K-55 8rd, 60'. e. Crossover, 7" 8rd box x 5-1/2" 8rd pin. f. Model'S' gravel pack ext. with sliding sleeve and seal bore. g. SC-iR packer, 96A4-60. h. Hydraulic setting tool, crossover assembly, and 4" flush joint washpipe (for a 0.81 WP to BP ratio) with a ported bull plug on bottom. Space out pipe to achieve a safe working height on the rig floor. Locate packer at 3290'. Snap in and out to verify position. Snap in and hang pipe in neutral. Circulate 5 bbls of completion fluid to clean ball seat at no more than 3 BPM. Drop 1-7/16" ball and let gravitate to bottom. Set SC-IR packer at 3093' as directed by Baker rep on location. Verify slip anchoring of the packer by alternately setting down and picking up 30,000 - 40,000 lbs. Pressure annulus to 500 psi to test packer. Increase to 1500 psi to release service tools from the packer. Hold for 5 minutes, then bleed off. The service tools may now be snapped out of the packer. Pressure-up workstring to shift ball seat. RU gravel infuser pumping equipment and chicksan with safety cables. PT lines to 2000 psi. 48. 49. Position and test the crossover tool in the squeeze, circulating, and reverse positions. Record rates and pressures for squeeze rates of 1, 2, 3, and 4 BPM and circulating rates of 1/2, 2, 3, and 4 BPM. For the 4 BPM circulating test, send returns to the trip tank and record return rate. Accuracy is important. If return rate is greater than 60% of the injection rate, choke returns until a 60% return rate is achieved. With the crossover tool in the circulating position, pump slurry at a constant rate of 4 BPM while infusing 20-40 sand at 1 ppg. Sand-out should be reached after about 105 bbls of slurry is pumped (4400 lbs of sand). When a 1000 psi pumping pressure is observed, reduce the injection rate while keeping pump pressure constant. When the rate has been reduced to 1/2 BPM at 1000 psi (corresponding to about 30' of sand above the screen top), SD pumps and immediately reverse-out excess gravel by pressuring annulus to 500 psi and moving the crossover tool to the reverse position. Do not SD the reversing operation until returns are free of gravel. 50. Return crossover tool to the circulating position. Establish circulation at 1/2 BPM. Record pressure. Close and pressure test the sliding sleeve. POOH with service tools. RUN NEW CASING PATCH TO COVER SQUEEZE PERFS AT 2661' - 2681' DIL 52. 53. 54. 55. 56. NOTE: THIS WORK IS TENTATIVE. DEPENDS ON THE RESULTS OF THE PRESSURE TEST OF THE CASING, FOLLOWING MILL-UP OF THE EXISTING CASING PATCH. HOMCO TO HAVE 20' PATCH AVAILABLE IF NEEDED. PU 20' casing patch, running tools, one joint of drillpipe, and RA sub. RIH and locate patch top at 2700' DPM. RU E-line. PT lubricator to 2000 psi. RIH with GR/CCl to correlate patch setting depth. POOH and RD E-line. Locate patch 2661' - 2681' DIL. Set patch per Homco rep on location. POOH with setting tools. MU 8.25" gauge ring in drill pipe and run through patch to 2800'. POOH. RUN PRODUCTION TUBING 57. 58. 59. 60. 61. RU to run production tubing: 4-1/2" 12.6# L-80 AB Mod Butt. Change rams. Refer to Figure 4 for Proposed Completion Schematic. Drift all 4-1/2" tubing and pups with 3.83" rabbit. Externally pressure test field connections to 5000 psi. All other connections will have been internally tested to 5000 psi prior to load-out. RIH with tubing. Dual encapsulated control line to be run above the SCSSV and sliding sleeve landing nipple and tested to 5000 psi. Locate seals in the SC-iR packer at 3093' and PU to neutral. Apply 500 psi to the annulus to test seals. Bleed off. PU and space out with pups. Before MU of tubing hanger, reverse circulate 155 bbls of completion fluid with 10 gal per 100 bbl CRONOX corrosion inhibitor. MU hanger and RIH until landed. Test annulus to 1000 psi for 30 minutes. Bleed control line to close SCSSV. RU slickline. RIH and set plug in sliding sleeve landing nipple. POOH and RD slickline. Set BPV. ND BOPE. NU and test tree to 5000 psi. Pull BPV. RU slickline. PT lubricator to 2000 psi. RIH, latch plug, POOH. RIH and shift sliding sleeve open. POOH and RD slickline. · Release rig. Install and test flowline. Bring well on line by running a jumper from M-5, and displace M-3's wellbore fluid into the formation until tubing pressure = 1200 psi. Well rate and pressure to be specified by Reservoir Engineering. J Sqz per'Fs 267I'-73' Comp(e~ed 8/90 TRADING SAY · S TEELHFA13 PI_ A T F E]R[',. EL ,M COMPLETION STRING 0'-5043' 4.5% iB.6~ L-SO, AB Mod Butt Cpt9, n-- I 4 43'-467' FLow CoupLing (3.863" ID:, Otis XXO Inj Nipple (3.8]3' X Prot:iie~ ! FLow Coup[ina (3.863~ I Otls Series ]0 SCSSM I Flow Coupllng (3,863" L 937' 20% 133~, Butt, Cs9. 145B' t6" 75~4, Butt . Cs9. B661'-8681' 9-5/8' Os9 Patch 8718' 13-3/8' 61/68~, K-55 Cs9. 0'-535' 10-3/4~ ~ _,5,J~. N-80 BTC 535'-7869' 9-5/$% 47~. N-80 mc 5002' Top of Cement 5038' 5053' 5093' 510~' PRDDUCTION PACKER AL:'ZENBLY [3tis 9-5/8" >, 5" Per-manenT packer w/SBE Otis 'X' nipple (2.813' Otis 'X' nippie ~3.813' Proof' WL Re-ent~^y guide' Sqz per-Cs 5308'-10' D-SO PERFORATIONC Inte~vo[ Zone ~m SPF , , 5170'-5810' D-3B 40 ~_ 67~3'-6735' D-16~ !.2 6810'-6870' D-16BC 60 Phase C,(/° Phasing NOTE: Ali Perforations Plugged per' ~C~undry 95-14:~, ; 2/1 8,/~7/90 LOWER PACKER ASSEMBLY 6600' Otis 9-5/8" x 5' Permanent Pocken w/SBE 6609' Otis 'X' nipple (3.8t3' Pr-oFite) 6618' Otis 'XN' nipote (3.813' P~o~rite; 3.725' NoGo) ~// Otis 'XXN' PLug set 18/'16/92 66~8' WL Re-ent~y guide D-t6A D-t6BC PBTD e 7176' xtxxxxxxxtx T~, ~_ 7291' kev,s,on Dote: 8/50/9.5 P, ev,se¢ By: JCM/evo P, eoson: iTT Plugbock Prev,ous Revision: 12/21/92 MARATHON OIL STEEL HEAD WELL #M-3 "B" - Sands 7 8 Item 7 8 9 10 Depth Length i.D. O.D. 1.00 2.74 6.35 2.28 6.00' 2.22 10.00' 80.00' 4.313 4.50 6.218 4.250 3.687 6.00 6.00 · 2.441 1.625 2.441/ 1.625 1.625 Description Crossover, 3 1/2" RIF box x 2-7/8" EUE 8rd pin Model "PR" crossover tool upper disconnect Baker Perforating Packer, size 47 Model "P-I" Underbalancing valve, (set to open 1,000 psi) 6' 2 7/8" pup joint Model "B" Firing Head Safety Blank 6" Tubing conveyed perforating guns, 12spf, 32 gm "Perfform" GP charge Perf, interval 3,450' - 3,440' 3,430' - 3,370' Marathon~SteelhdWI-3TC P B MARATHON OIL STEEL HEAD WELL #M-3 "A" - Sand ) 1 7 8 o o o °o o 10 item 4 5 6 5 7 8 9 10 Depth Length I.D. O.D. 1.00 4.313 2.750 30.00' 4.313 2.750 1.00 4.313 2.441 2.74 4.50 1.625 6.35 6.218 2.441/ 1.625 2.28 4.250 1.625 6.00' 2.22 10.00' 78.00' 3.687 6.00 6.00 Description R.A. Tag Sub 1 Joint of 3 1/2" workstring Crossover, 3 1/2" RIF box x 2-7/8" EUE 8rd pin Model "PR" crossover tool disconnect Baker Perforating Packer, size 47 Model "P-I" Underbalancing valve, (set to open ~ 1,000 psi) 6'2 7/8" pup joint Model "B" Firing Head Safety Blank 6" Tubing conveyecl perforating guns, 12spf, 32 gm "Perfform" GP charge Perf. interval 3,278' - 3,200' Mamthon~SteelhdWI-3TC P_A WEt, L~OFILE OPERATOR ~')/}~;~-r#0,.) i S,ZE , W~,GHT , GRAgE ! THREAa COMPANY REP. .... WELL~ /~)-~ -- ~ LINER : ~ATE ~ [ , ~ _ ~ rU~NS ~ LOnG ~N~ SHO~ ~,N~ ====================================== ::: ~:: .................. ......................... ,l i I~of~o~b_ , p~, STEELHEAD PLATFORM CHOKE MANIFOLD TO GAS BUSTER TO DERRICK VENT :=' I CtlOKE LINE A...-_I TO SHALE StlAKERS j SWACO J ALL VALVES IH FLOW PATH ARE 3-1/16' 5000 PSI CAMERON GATE TYPE SECTION AA i Flow Line Pipe Rams Blind Rams Pipe Rams Hyelrll 18-314' 5000 Type GK Annular Gate Valve HCR Valve ~ 1 ~ 16-314' 10,000 Singlegate 16-3/4' 5000 psi Riser Ball Valve Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) .... LUBRICATOR MANUALLY OPERATED BOP / 10 ~ X-4018-K-REV. 2 MARATHON OIL COMPANY STATE OF ALASKA ALASI'~-~ OIL AND GAS CONSERVATION COMM,o,SION REPORT OF SUNDRY WELL OPERATIONS Operations Shutdown Stimulate Plugging Perforate Pull Tubing Al'~'er Casing ~epair Well -- -- Other __ __ 5. Type of WDeel?elop men, X.~. 6' D;t;; elKeV¢~o(vD; °r~ KsBJ 1. Operations Performed: 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Achorage, AK 4. Location of well at surface Leg B-2 Cond. 10 Steelhead Platform 1,039' FNL, 602' FWL, Sec. 33-9N-13W-SM At top of productive interval 274' FNL, 2,092' FWL, Sec. 33-9N-13W-SM At effective depth At total depth 250' FSL, 2,227' FEL, Sec. 29-9N-13W-SM Exploratory Stratigraphic Service 7. Unit or Property name Trading Bay Unit 8. Well number M-3 9. Permit number/approval number 89-111 / 93-144 10. APl number 50- 733-2041 1 11. Field/Pool Grayling Gas Sands Pool 12. Present well condition summary Total Depth: measured true vertical 7,291' feet 6,5 1 2' feet Plugs (measured) 6,618' Otis'XXN' Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: J measured true vertical 7,176' 6,409' Length 937' 1,452' 2,713' 7,268' feet Junk (measured) None feet Size Cemented Measured depth 20" 2,550 sx 937' 16" 1,516 sx 1,452' 13-3/8" 1,600 sx 2,713' 10-3/4" x 9-5/8" 1,660 sx 7,268' D-3B 5,170' 5,210' 4,711' D-16A 6,723' 6,735' 6,011' D-16BC 6,810' 6,870' 6,088' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, AB Mod Butt to 5,043' Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 458' MD; Otis BWH Perma-Drill Pkr w/SBE @ 5,032' & 6,600' True vertical depth 937' 1,452' 2,645' 6,497' 4,745' 6,023-;~ RE6EIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure J U L - 6 1B93 Alaska 0il & Gas 00Ds. C0mm;,ssio~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcr Water-Bbl. Casing Pressure SI 0 0 SI 0 0 Tubing Pressure 99O 82O 15. Attachments 116. Status of well classification as: Copies of Log and Surveys run __ Daily Report of Well Operations X Oil Gas X -- 17. I hereby ~fy t~~best of my knowledg~t, Signed Title ~. ~ (.,,(., k/k~ C~, Form 10-404 Rev 06/15/88 Suspended Service Date ~,. ?~o.\ ~ .~ ~ SUBMIT IN DUPLICATE _~ DAILY WELL OPERATIONS M-3 5/24/93 Safety meeting. RU on well to perform a data frac on the D-3B gas sands (5170' - 5210' DIL) with E-line pressure gages downhole. SITP = 990 psi. Pressure test pumping lines and lubricator to 3000 psi. RIH with temperature and pressure sensors and ~og from isolation packer top at 6610' DIL to tubing tail at 5088' DIL. Fluid level at 5825' DIL. POOH. 5/25/93 Safety meeting. RIH with temperature and pressure sensors and position at 5150' DIL. Perform "pump-in/flowback" data frac as follows: 1. Pump 140 bbls YF140 (delayed Borate crosslinked guar) at 10 BPM. Max pressure = 3000 psi. 2. SD pumps and flowback at 1/2 BPM to induce rapid closure of the created fracture. 3. Pump 50 bbls YF140 at 10 BPM. 4. SD pumps. Record pressure falloff (no flowback). 5. Pump 40 bbls fresh water at 8 BPM. 6. SD pumps and flowback at 1/4 BPM. 7. Pump 35 bbls fresh water at 8 BPM. 8. SD pumps and flowback at 3/8 BPM. Using 250 bbls of fresh water, perform step rate test as follows: INJECTION STABILIZED SURFACE RATE PRESSURE (BPM) (psi) 8 1150 6 1060 4 910 2 775 SD pumps and record pressure falloff. Log with temperature and pressure sensors from 5050' DIL to 5300' DIL. POOH. 5/26/93 RD pumping and E-line equipment. Leave well SI. RECEIVED JUL - 6 Alaska Oil & Gas CoDs. Co STATE OF ALASKA .... ALA=SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation shutdown Re-enter suspended well Alter casin"~' Repair w~' Plugging -- Time extension Stimula-~' ' ~7~ .~' Change approv'~ program _ -- Pull Tubing ~ Variance__ P'"'~rforate__ Othe"~"X.~. ' · Type of Request: 2. Name of Operator UNOCAL (Marathon Oil Company-Sub-Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface Leg B-2 Cond. 10 Steelhead Platform 1,039' FNL, 602' FWL, Sec. 33-9N-13W-SM At top of productive interval 274' FNL, 2,092' FWL, Sec. 33-9N-13W-SM At effective depth At total depth 250' FSL, 2,227' FEL, Sec. 29-9N-13W-SM 6. Datum elevation (DF or KB) 160' KB feet 7. Unit or Property name Trading Bay Unit 8. Well number M-3 9. Permit number/approval number 89-111 O· APl number 50- 733-20411 1. Field/Pool Grayling Gas Sands Pool 12. Present well condition summary Total Depth: measured true vertical 7,291' feet Plugs (measured) 6,512' feet 6,618' Otis 'XXN' 13. Effective depth: measured 7,1 76' feet Junk (measured) true vertical 6,409' feet Casing Length Size Cemented Structural 937' 20" 2,550 sx Conductor 1,452' 16" 1,516 sx surface 2,713' 13-3/8" 1,600 sx Intermediate 7,268' 10-3/4" x Production 9-5/8" 1,660 SX Liner Perforation depth: measured D-3B 5,170' - 5,210' MD 4,711' D-16A 6,723' - 6,735' MD 6,011' true vertical D-16BC 6,810' - 6,870' MD 6,088' - None Measured depth 937' 1,452' 2,713' 7,268' 4,745' 6,023' 6,141' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, AB Mod Butt to 5,043' Packers and SSSV (type and measured depth) Otis FMX SCSSV (~ 458' MD; Otis BWH Perma-Drill Pkr w/SBE ~ 5,032' & 6,600' Attachments Description summary of proposal X.~ Detailed operations program __ True vertical depth 937' 1,452' 2,645' 6,497' TVD TVD TVD -\ BOp ~~ - Estimated date of commencing operation May 24, 1993 If proposal wes verbally approved Mike Minder Name of approver May 21, 1993 Date approved, 15. Static of well classification as: Oil Gas X Service Suspendedm 17. I hereby certify, that the,foregoing is true~rrect to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance Mechanical Integrity Test __ Subsequent form required 1 O-/-./G ~ ORIGINAL SIGNED BY RUSSELL A. DOUGLASS Approved by order of the Commision Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE~ Steelhead Well M-3 ,.P. ump- In Test · · · · e · e e · Conduct pre-job meeting with pumping and E-line personnel. Place grated hatch cover over NE leg. Spot E-line unit and secure. Spot and RU fracture pumping equipment capable of pumping 10 BPM at 2000 psi. Install handpump on SCSSV and pressure to 4500 psi. Install fusible cap on master manumatic. RU E-line lubricator on well with pump-in sub about 3' above grated hatch cover. RU all surface lines. Secure lines with chains. MU E-line tool string: sinker bars, COl, ATC, PTS. Install in lubricator. Advise all personnel to evacuate vicinity of lines to be tested. Isolate area with caution tape. Post signs at all access points to deck level and well rooms. With lubricator pump-in valve closed, circulate FIW to clear air and visually check for leaks. SI flowback valve and pressure test lines to 4000 psi. Walk lines and inspect for leaks. Open pump-in valve and pressure test lubricator to 4000 psi against swab valve. Bleed off pressure at pumps upstream of check valves to test check valves. Bleed off pressure on all lines and lubricator. SI pump-in valve, open swab slowly, and RIH with E-line tools. Tag fill and log up to top of isolation packer. Pull up to 5250' DIL and log from this depth into bottom of tubing tail at 5102'. Position logging tools at 5150' for the data frac. MONITOR CABLE TENSION THROUGHOUT PUMPING OPERATIONS. Repeat safety meeting and review of all job assignments for data frac. Visually monitor treating lines at all points throughout pumping. Also, monitor casing pressure throughout pumping. Check gel quality and cross-link, as well as viscosity and pH. The data frac fluid will be a delayed Borate crosslinked guar with a polymer loading of 40 lbs/Mgal (YF140). No pre-pad or pad fluid will be pumped. H: \wp\WLPRO\M3 RECEIVEg Alaska Oil & Gas Cmos. At~chorag~ -2- 10. 11. The data frac will be a "pump-in/flowback" test, with a surface flowback valve and line running to an empty tank. Near the end of each pumping stage, a surface return rate of about 0.5 BPM will be established while pumping at 10 BPM. When the injection pumps are halted, the flowback will be maintained at a constant rate to induce relatively rapid closure of the created fracture. This sequence will be repeated three times to ensure reproducibility. It is possible that the closure stress will be too low to maintain flow to the surface at fracture closure. If so, bottomhole shut-in pressure can be analyzed to determine closure. Treatment details are as follows: PUMP RATE VOLUME STAGE FLU I D (BPM) (BBLS) 1' YF140 10 140'* SD & Flowback at 0.5 bpm 2 YF140 10 50*** SD & Flowback at 0.5 bpm 3 YF140 10 50*** SD & Flowback at 0.5 bpm 4 FIW 10 50 SD & Flowback at 0.5 bpm 12. 13. 14. Bleed gas off top of lubricator before frac fluid hits perfs. Well volume + 50 BBLS into perfs. Start counting 50 BBLS from the time surface pressure is picked-up. *** Include breaker in these stages. Evaluate pressure data. If data is good, overdisplace well with 150 bbls of FIW. SD and monitor pressure. While recording temperature and pressure, log up from 5300' DIL to tubing tail at 5102'. POOH. RD E-line and pumping equipment. H: \wp\WLPRO\M3 TRADING BAY UNIT STEELHEAD PLATFORM WELL M-~ CoMp(eted 8/90 COMPLETION STRING 0'-5043' 4.5', 12.6# L-BO, AB Mod Butt Cplg. I!43'-467' Flow Couplin9 (3.863' ID) tis XXO Inj NippLe (3.813' X ProFile) iow Coupling (3.863' ID) tis Series 10 SCSSV (3.813 X Pro¢iie) iow Couplin9 (3.863' ID) 937' 20', 133#, Butt. Csg. 1452' 16', 75#, Butt . Csg. Sqz perFs 2671'-73' 2661'-2681' 9-5/8' Cs9 Patch 2712' 13-3/8', 61/68#, K-55 Cs9. 0'-535' 10-3/4', 55.5#, N-80 BTC 535'-7869' 9-5/8', 47#, N-80 CS Sqz peres 5308'-10' 5038' 5053' 5093' 5102' PRODUCTION PACKER ASSEMBLY Otis 9-5/8' x 5' PerManent packer w/SBE Otis 'X' nipple (3.813' Pro¢iLe) Otis 'X' nipp[e (3.813' Pro¢i/e) WL Re-entry guide D-3B Interval 5170'-5210' 6723'-6735' 6810'-6870' PERFDRATIDNS Zone FT SPF Phase D-3B 40 6 60' Phasin§ D-16A 12 ' D-16BC 60 ' ' ~ate 12/17/92 8/87/90 8/27/90 6600' 6609' 6618' 6628' D-16A D-16BC LOWER PACKER ASSEMBLY Otis 9-5/8' x 5" Permanent Packer w/SBE Otis 'X' nipple (3.813' ProfiLe) Otis 'XN' nipple (3.813' ProFile; 3.725' NoGo) W/ Otis 'XXN' Piug set 12/16/92 WL Re-entry guide PBTD lB 7176' TD 8 7891' Revision Date: 12/21/92 Revised By: SSL/evo Reason: Perf D-SB Previous Revision: 10/90 Wireline Lubricator w/Associated BOPE , GREASE HEAD (Hydraulically Activated) - LUBRICATOR MANUALLY OPERATED BOP Alaska Oil & Gas Cons, .C, om ' II t2 X-4018-K-REV. 2 MARATHON OIL COMPANY 1. Type of Request: STATE OF ALASKA ALASr.,A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS , Abandon Suspend Operation shutdown Re-enter suspended well Alter casin"~- Repair wet~i' Plugging X ~ Time extension Stimulat--~' Change approved program~ Pull Tubing ~ Variance ~ Pe 1"orate ~ Other 2. Name of Operator UNOCAL (Marathon Oil Company-Sub-Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 5. Type of Well: Development Exploratory Stratig raphic Service Datum elevation (DF or KB) 160' KB Unit or Property name Trading Bay Unit 4. Location of well at surface Leg B-2 Cond. 10 Steelhead Platform 1,039' FNL, 602' FWL, Sec. 33-9N-13W-SM At top of productive interval 274' FNL, 2,092' FWL, Sec. 33-9N-13W-SM At effective depth At total depth 250' FSL, 2,227' FEL, Sec. 29-9N-13W-SM 8. Well number M-3 9. Permit number/approval number 89-111 10. APl number 50- 733-2041 1 11. Field/Pool Grayling Gas Sands Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 7,291' feet Plugs (measured) 6,51 2' feet 7,1 76' feet Junk (measured) 6,409' feet Casing Length Size Cemented Structural 937' 20" 2,550 sx Conductor 1,452' 16" 1,516 SX Surface 2,713' 13-3/8" 1,600 SX Intermediate 7,268' 10-3/4" x Production 9-5/8" 1,660 SX Liner Perforation depth: measured D-3B 5,170' - 5,210' MD 4,711' - D-16A 6,723' - 6,735' MD 6,011' - true vertical D-16BC 6,810'- 6,870' MD 6,088'- 6,618' None Measured depth 937' 1,452' 2,713' 7,268' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, AB Mod Butt to 5,043' Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 458' MD; Otis BWH Perma-Drill Pkr w/SBE @ 5,032' & 6,600' Otis 'XXN' True vertical depth 937' 1,452' 2,645' 6,497' 4,745' TVD 6,023' TVD 6,141~, ~V~.~ ~.. \~ 13. Attachments Description summary of proposal X Detailed operations program (etch X Estimated date of commencing operation June 2, 1993 If proposal was verbally approved Name of approver Date approved 15. Statis of well classification as: Oil Gas Z Service Suspended 17. Signed correct to the best of my knowledge. Title FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity.~ BOP Test__ Location clearance B Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commision Original Signed By David W. Johnston ,,pproved Copy Returned Commissioner IApproval No. ~,.~ -~ ~ Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Steelhead Well H-3 Coiled Tubing Plugback · e e e e e 0 e Conduct pre-job meeting with coiled tubing and pumping personnel. Spot equipment. NOTE: Injector head will have to be supported by the crane at all times, as grated hatch cover cannot withstand the weight. Install handpump on SCSSV and pressure to 4500 psi. Install fusible cap on master manumatic. RU lubricator on well. RU surface lines. Circulation will be down the coil with returns going through M-3's flowline and to the "C" separator. RU lines to overboard green cement i f necessary. RU check valve and end-of-tubing locater on coil. Feed into injector head and lubricator. Close master valve, open swab valve, and circulate FIW to clear air from lines and check lines for leaks. Close swab valve and PT coil, surface lines, and lubricator to 3000 psi. Open tree valves, establish circulation at 1.25 BPM, and RIH with coil to "XXN" plug @ 6,618'. Tag plug and mark coil. PU to tubing tail and mark coil again. RIH to 5100'. While continuing to circulate at 1.25 BPM, determine fluid loss to the D-3B sand. If any fluid loss is observed, circulate a 10 bbl LCM without breaker to the end of the coil and squeeze into the perforations. Reestablish circulation, monitor fluid loss, and pump additional LCM as required to maintain full returns. POOH. Install cement nozzle. RIH to 10' above plug. Mix and pump cement, setting a continuous plug from fill to 5070'. (Keep nozzle about 30' below the top of the cement while POOH with coil.) Cement recipe will be as follows: Cement: Additives: Class G 0.2~o Halad-344 (fluid loss of 150 cc/30 min) 0.3~o CFR-3 (friction reducer) 0.1~o HR-5 (retarder) Displace cement with FIW. Continue circulating while POOH. SI well. RD coiled tubing. Cement plug will be pressure tested and cement top will be tagged with slicklinewhen rig mobilizes to recomplete M-3 in the following proposed intervals (anticipated in 9/93): Sand MD TVD A-6 B-1 B-2 3,200' - 3,280' 3,380' - 3,430' 3,460' - 3,475' 3,055' - 3,122' 3,205 ' - 3 , 247 '~,~[L~\~N 3,272' - 3,285' TRADING BAY UNIT TEELHEAD PLATFFIRM WELL M-3 Completed 8/90 CDMpI ETION STRING 0'-5043' 4.5", 1B.6~ L-80, AB Mod Bu±~ Cpi9. I143'-467' Flow Coupling (3,863' ID) tis XXD Inj Nipp~e (3,813" X Iow Coupbn9 (3,863" ID) 'tis Series I0 SCSSV (3.813" X Pro¢~te) Iow Coup[lng (3,863" iD) 937' BO", 133~, Butt, Cs9, 145F" 16", 751*, Butt, Cs9, Sqz pemFs B671'-73' 2661'-B681' 9-5/8' Csg Patch 2712' 13-3/8', 61/68~, K-55 Cs9, 0'-535' 10-3/4', 55,5~, N-80 OTC 535'-7~69' 9-5/8~, 47~, N-80 CS 5032' 5053' 5093' 5t02' PRODUCTION PACKER ASSEHBLY D'tls 9-5/8" x 5" Permanent packer w/SBE D±is 'X' nlppte (3,813" ProCRe) Otis 'X' nippte (3,813" Pro,Fi[e) WL Re-entry 9ulde Sqz perFs 5308'-10' D-3B Interva[ 5170'-5~10' 6723'-6735' 6810'-6870' PERFDRATIBNS Zone F_~_T SPF Phase D-3B 40 6 60° Phasing D-16A 13 ~ ~ D-16BC 60 ~ ~ 12/17/92 8/87/90 8/27/90 6600' 6609' 6618' 6628' D-16A D-16BC LOWER PACKER ASSEMBLY Otis 9-5/8" x 5" Permanent Packer- w/SBE Otis 'X' nipple (3,813" Pro¢i[e) Otis 'XN' nipp(e <3,813" ProFite; 3,725" NoGo) V// Otis 'XXN' Ptu9 set I2/16/9P V/L Re-entr-y 9ulde PBTD @ 7176' TD @ 7291' Revision Date: 12/21/92 Revised By: SSL/evo Reason', Perf D-3B Previous Revision'. 10/90 STE, 'LHEAD PL ATFuRM Coiled Tubing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 psi WP -- HYDRAULIC RAMS 4'1116". 5000 psi CHISTMAS TREE POSITIVE CHOKE Oil & ~as Goss. 2' 5000 psi t ~ , 2' 3000 psi. · 13 3/8' CASING Unocal North Amer; ~ Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 ~D Alaska Region UNOCAL RECEIVED APR 2-. 0 199~ Alaska Oil & Gas Cons. Commission DOCUMENT TRANSMITTAL April 16, 1993 TO: Larry Grant FROM: Kirk Kiloh LOCATION: 3001 PORCUPINE DRIVE LOCATION: P.O.BOX 196247 ANCHORAGE, AK 99501 ANCHORAGE AK 99519 ALASKA OIL & GAS CONSERVATION COMM. UNOCAL :- ~ :: .... ' ..... -- ~ ......-"- -'--'-' ___ __L _ , ,., ,, ...... , ...... , ...., .... TRANSMITTING AS FOLLOWS ' TRADING BAY UNIT 1 blueline and 1 sepia Logs from specified wells listed below 7 7--~Z- -- D-7RD ~;"-%5 --D-1TRD Perforating Record Perforating Record Perforating Record 'Perforating Record · Perforating Record .Perforating Record Completion Record Completion Record 10-18-92 10-19-92 11-30-92 11-22-92 11-29-92 12-04-92 6-29-92 6-16-92 ~-3l~ D-43RD ql-II D-47 G-mD Completion Record Perforating Record Perforating Record Perforating Record Perforating Record Perforating Record Continuous Gyro Tool Cement Bond Tool Perforating Depth Control 6-20-92 11-21-92 11-25-92 10-17-92 12-03-92 12-18-92 7-24-92 7-24-92 8-12-92 M-29 TUbing Patch Record 11-13-92 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF TItlS DOCU1V~NT TR~SM/TTAL. THANK YOU DATED: 1. Operations performed: STATE OF ALASKA ~ ALASKA OIL AN D GAS CONSERVATION COM M lS510 N . ~ REPORT OF SUNDRY WELL OPERATION ii ti J Operation shutdown __ Stimulate __ Plugging __ Pedorate ~ Pull tubing __ Alter casing __ Repair well __ Other __ 2. Name of Operator / 5. Type ~eWve~lot: ment X UNOCAL (Marathon 0il Co - Sub 0Derat4r) Expl~atory-- 3. Address ' I Stratigraphic ~ P. 0. Box 190247 Anchorage, AK 995~9 Service__ 4. Location of well at sudace Leg B-2 Cond. 10 Steelhead Platform 1039' FNL, 602' FWL, Sec. 33 9N - 13W - SM At top of productive interval 274' FNL, 2092' FWL, Sec. 33 9N- 13W- SM At effective depth At total depth 250' FSL, 2227' FEL, Sec. 29 - 9N - 13W - SM 6. Datum elevation (DF or KB) ;]60' KB 7. Unit or Property name Trading Bay Unit 8. Well number M_'~ feet · ~). '~ermit number/approval number ~C)-lll 10. APl number 50- 733-20411 11. Field/Pool McArthur River Graylin9 Gas Sand Pool 12. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical 7,291' feet Plugs (measured) 6,512' feet 7,176 ' feet Junk (measured) 6,409' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 937' 20" 2,550 sx 937' 1,452' 16" 1,516 sx 1,452' 2,713' 13-3/8" 1,600 sx 2,713' 7,268' 10-3/4 x 9-5/8" 1,660 sx 7,268' measured D-3B 5,170' - 5,210' MD 4,711' D-16A 6,723' - 6,735' MD 6,011' D-16 BC 6,810' - 6,870' MD 6,088' true vertical - 4,745' - 6,023' - 6,141' TVD TVD TVD True vertical depth 937' 1,452' 2,645' 6,497' Tubing (size, grade, and measured depth) 4.5", 12.6#, L-80, AB Mod butt tbg to 5,043' Packers and SSSV (type and measured depth) 0t i S FMX SCSSV 0 458 ' Otis BWH Perma-Drill Pkr W/ SBE @ 5,032' and 6,600' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MD JAN 1 I t99) Alaska Oil & Gas Cons. Commissi~ll Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 0 0 310 SI 16,307 /'~"~ 2.1 450 924 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil __ Gas ~ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Re Date t~,z~!~L., q~ SUBMIT IN DUPLICATE~~. DAILY WELL OPERATIONS M-3 12/16/92 Safety meeting. Isolate manumatic meter & SCSSV. SITP 860 psig. R/U on well. M/U 3.7" GR on tool string. Pressure test lub to 2000 psi. Test good. RIH. Tag fill @ 6810' WLM. POOH. C/O GR w/ 1-7/8" bailer. RIH & obtained sample. POOH. MU XXN plug w/ equalizing feature dressed for No-Go. RIH. Unable to work into lower packer assembly. POOH. OOH w/ setting tool. No plug. MU pulling tool. RIH latched plug ~ lower X-nipple ~ 5,096. POOH. OOH w/ plug.. Redressed. Added KJ between spangs & running tool. RIH. Worked to 6,618. POOH. Some formation sand on plug. Cleaned up & redressed w/ new packing. Added KJ between spangs & oil jars. RIH w/ plug. Located XN nipple 0 6,618' Set plug & POOH. OOH w/ running tool. Plug set O.K. Started bleeding tubin~ to test plug. 12/17/92 Bled tubing pressure to flare. Stop 0 54 psig. SITP @ 54 psig. Plug test good. RD. Started charging tbg pressure to 1000 psi. R/U E-line. Pressure test lub to 2000 psi. Test good. Established CBO. MU & armed 20', 3-3/8" HC, 6SPF, 60 phased. RIH. SITP 964 spig. Perforated D-3B sand 5,170' - 5,190' DIL. Tbg press increased to 1054 psi. POOH w/ gun. Re-establish CBO @ 1000' ELM. OOH w/ gun. All shots fired. ..1...2/18/92 RIH w/ 3-3/8" HC, 6SPF, 60 phase. Well flowing. 6.7 MMSCFD @ 1011 psig surface. Perforated D-3B sand 5,190' - 5,210' DIL. Well flowing 6.01 MMSCFD 0 1021 psig surface. SI well to POOH. OOH w/ guns. All shots fired. RD. RT to production. H: \wp\WE L LOPS\M3 TRADING E;a'¥' 5 STEELHEAD PLATFn~ w~M WELL Sqz pemFs 267i'-73'j S~z per~s ~ S308'-10' Completed 8/90 k 5032' 5053' 5093' 5102' COMPLETION STRING 0'-5043' 4,5', 1B,6~ L-80, AB Mod Butt CRt9, 443'-467' Flow Couptin9 q3.863" Oils XXO I,-,i NippLe (3,813" X , FLow Coup~in~ (3.863" iotas Secies ~0 SCSSV <3.813" X I F~ow Couptln9 (3.863" 937' 20" 133~, Butt. Cs9, 1452' !6", 758, Butt , Cs9. 2661'-268I' 9-5/8" Cs9 Porch 2712' !3-3/8% 6~/68~, K-55 Cs9, 0'-535' 10-3/4~, 55,5~, N-80 OTC 535'-7269' 9-5/8~, 47~, N-80 CS PRODUCTION PACKER ASSEMBLY Otis 9-5/8" x 5" Pemmonent packem w/SBE Otis 'X' nipple (3,813" Peck'ire) Otis 'X' nippte (3.813" Pr'oF'ire) WL Re-entry 9uide D-3B PERFORATIONS Intervo[ Zone FT }PF Phase 5170'-5210' D-3B 40 6 60° Ptno sin9 6723'-6735' D-16A ~2 " 6810'-6870' D-16BC 60 ~ D-16A LOWER PACKER ASSEMBLY 6600' Otis 9-5/8" x 5" Permanent Packe~ w/SBE 6609' Otis 'X' hippie (3.813" ProFite) 6618' Otis 'XN' nippte (3.813" ProFile; 3.725" No6o) W/ Otis 'XXN' Plug S o 9.~ # ~r, 6698' WL Re-entry 9uide ~~[~ ~ D-16BC J PBTD e 7176' //$/XXXV~l/X.A A/'q '~ T D e 7291' Alaska Oil & Gas Cons, 'Anchorage 1'2/17/92 8/27/90 8/~7/90 Revision Date: i2/21/92 Revised By: SSL/evo Reoson: Perf D-3B Pr'evious Revision: 10/90 ! Typeof Request: 2. Name of Operator IINr~r'AI 3. Addr~]~v .... ' ........... P. 0, Rnx 190247 4. Location of well a~ surface :L039.' FNL. 602' At top of productive ~nterval 274' FNL, 2092' At effective depth STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION .~, ,.. APPLICATION FOR.,S,, UNDRY APPROVALS Abandon __ Suspend M Operation s u down ~ Re-enter suspended well M ~' .. Alter casing __ Repair we~i __ Ptuggmg __ Time exlenslon __ ~, ~[imutate __ Change approved program __ Pull tubing w Vanance ~ PerforateA~A Otl~er I5. Type of Well: n~ ~ r~ ~,,h n,n.~.thr) Deveiopment_~X .... - _ Exploratory ~ Stratigraomc ~ Anchoraae, AK 995 9 Serv~ce~ Leg B-2 C0nd. !0 Steeihead Platform FWL, Sec. 33 - 9N- Z3W- SH total depth 250' FSL~ 2227' FWL, Sec. 33 9N - 13W- SM FEL, Sec. 29 - 9N- 13W- SM 6. Datum elevation (DF or KB) 160' KB 7. Umt or Property name Trading Ba,y Unit 8. Well number feet __ 9. Permit number 89-111 10. APl number 50-733-20411 11. Field/Pool McArthur River Grayl i ng Gas Sand Pool 12. Present well condition summary Total depth: measured true vertical 7,291' feet Plugs (measured) 6,512' feet Effective depth measured 7, ! 76 ' · feet Junk (measured) true vertical 6,409 ' feet None Casing Length Size Cemented Measured depth True vertical depth Structural 937' 20" 2,550 sx 937' 937' Conductor 1,452' !6" Z ,5].6 sx !, 452' 1,452' Sudace 2,713' 13-3/8" 1,600 sx 2,713' 2,645' Intermediate 7,268' 10-3/4 x Production 9-5/8" 1,660 sx 7,268' 6,497' Liner Perforation depth:measured D-16A 6,723' - 6,735' MB 6,011' - 6,023' TVD D-16 BC 6,810' - 6,870' MD 6,088' - 6,141' TVD true vert,ca, RECEIVED Tu bincl_(.size, g r_ad..e., ana. me..c~ureg,ge p,~h), 4.5 , IZ.b¢, L-SU, A~ moa butt tbg to 5,043' DEC--' '1~ ~ 99~ Packers and SSSV (type and measured de~!h,) Otis FMX SCSSV 0 458' MD Alaska 0il & Gas Cons. Cpmm~'ssi°~ Otis BWH Perma-Dri 11 Pkr w/ SBE @ 5,032' and 6,600' Anchorag.e 13. Attachments Description summary of proposal X__ Detailed operations program __ BOP sketch A J Plug integrity ~ Mechanical Integnty Test ~ J Approved order of the Commission Form 10-403 Rev 06/15/88 14. Estimated date for commencing operation 115. ~2/10/92 'I' 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certi_fy that the foregoing is true and correct to the best of my, knowledge. Signed ~)~ ,c~.,~ ~, ~:::~~ Title "~ _¢_ ,_~_\. '. _,~...~J~ ~ ,¢'\ ~ FOR COMMISSION usr'-~INLY Conditions of apprtYvai: Notify CommiSS~on so Cepresentative may witness BOP Test w Location clearance ~ Subsequent form required 10- ORIGINAL SIGNED BY ~IJSSELL A. DOUGLASS Status of well classification as: Oil ~ Gas X__ Suspended Date J Appr°val N(~,~,..,.¢,,¢t¢~ .,./ ommissioner Date/~_..~ ~-, SUBMIT IN TRIPLICATE WELL M-3 COMPLETE D-3B SAND 1) 2) 3) 4) 5) RU wireline unit. Pressure test lubricator to 2500 psi. Take SCSSV off platform system and put on hand pump (4000 psi). Install fusible cap on master manumatic valve. RIH with wireline and set plug in XN at 6,618'. R/D wireline unit. Bleed tubing pressure to zero through test separator to insure plug testing. RU E-line unit and pressure test lubricator to 2500 psi. Perforate D-3B sand from 5,170' to 5,210' using 3-3/8" hollow carrier 6SPF, 60 degree phase perforating gun. Prior to arming guns and until guns are 1000' in hole, establish communications blackout. Re-establish CBO when POOH above 1000'. R/D E- line unit. Flow well to cleanup and test rates. H:\wp\WLPRO\M3 OEO -'~. !992 Alaska OiJ & Gas Cons. Cornmissiol'~ Anchorage ' ~'-,,.,, STEELHEAD PLATFORM Wireline Lubricator w/Associated BOPE - GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP / 10 RECEiVE ., DEC - 't' Ig92 Alaslm OJJ & Gas Cons. Cornmissiorl OIL 'COHPANY T:~ADING P~AY ~i .... 'T STEELHEAD PLATFRRP1 ELL Completed 8/90 J Sqz perFs 2671'-73'~ t J , 5038' 5053' 5093' 5!02' COHPLETION STRING 0'-5043' 4.5', '2.6~t L-80, AB Hod Butt Cp(9 443'-467' Ficw Coup~inq (3.863" Otis XXO [nj Nipple (3.8i3' X Pr'3FJe) Ftow CoupLinQ ,:3.863' ID) I Otis Secies i( SC$SV (3,813' ~iow CoupLin9 ~3.863' 937' BO', 133.~, Butt. Cs9. !458' 16', 75~. Butt . Csg. 8661'-8681' 9-5/8" Cs9 Patcin 8718' 13-3/8', 61/68~, K-55 Cs9, 0'-535' 10-3/4~. 55,5~, N-80 BTC 535'-7869' 9-5/8', 47~, N-80 CZ PRODUCTION PACKER ASSEMBLY qtis 9-5/8" x 5" Penm~nent packer- w/aBE Otis 'X' nippte (3.813" ProFile) .~tis 'X' hippie (3.813~ Pr'oFiLe) '#L Re-entmv 9ulde Sqz per~s $ 5308'-10' T D-3B (Ppoposed per-Poco t, ions) Interval $170'-$~i0' 6810'-6870' PERFQRATION% Zone FT SPF Phose -- D-3B 40 6 60° Phasing D-16A i8 D-16BC 60 Proposes 8/~7/90 8/~7/90 6,600' 6609' 6618' 66~8' D-16A D-i6BC LBWER F'P, CKER AS!:EHBLY Otis 9-5/8" x 5' Pe~?~one. nt F'oc¼er w/SBE Otis 'X' nipple (3,813" Pr'of'lie) Otis 'XN' nipple q3.813" ProFite', 3.725" No6o) WL Re-entpy guide !::.' r, - 7 ! L1 ...... ~ k ,~;~ ~; lg Anchorage PBTD e 7176' TD e 7891' F:evision Date: 10/90 Revised By: KWB/neF Reason: New WeLl Compiezion Ppevious Revision: None Marathon Oil Company Alaska I ~n Domestic r-roduction P.O. Box 190168 Anchorage, AK 99519-0168 Telephone 907/561-5311 November 18, 1992 Mr. Blair Wondzell Senior Engineer Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell: In the near future, Marathon will be proposing recompletion plans for Steelhead Platform gas Well M-3. The economic justification for this work will be dependent on the plugging procedures. For planning purposes, Marathon requests that AOGCC review the proposed procedures and indicate agreement that these procedures fulfill State requirements for plugging. It is understood that this is only an agreement to the method proposed, and is not an approval to proceed with the work. This will be handled at a later date by means of an "Application for Sundry Approvals." M-3 RECOMPLETION PROCEDURE (see attached wellbore diagram) A. Recomplete from a D-16A,BC gas producer to a D-3B gas producer. 1) Set a wireline plug in the XN-nipple at 6,618'. NOTE: Permanent plugging of the D-16A,BC will occur in Part B below. 2) Pressure test wireline plug. 3) Perforate the D-3B gas sand: 5,170' - 5,210'. Produce from the D-3B sand until the rig recomp!etion. Be Recomplete to a commingled A-6 and B-1 gas producer, anticipated in 1993. 1) Plug the D-16A,BC perforations in accordance with 20 AAC 25.105 (h)(1)(C), using coiled tubing to lay a cement plug on the production packer at 6,600'. 2) Plug the D-3B perforations in accordance with 20 AAC 25.105 (h)(1)(A) by using coiled tubing to space a continuous cement plug across the perforated interval. Continue operations to complete as a commingled A-6 (3,320' - 3,345') and B-1 (3,385' - 3,430') gas producer. EC[IV D 3) H: \wp\920E 11 \90. LCI N 0V 2' 0 Alaska OJJ & Gas Cons. ~nchorage.' A subsidiary of USX Corporation Mr. Blair Wondzell November 18, 1992 Page 2 I'm confident that you will find these plugging procedures will meet State requirements. Your prompt response to this informational request is appreciated. Detailed procedures will be submitted with Sund~ Applications for your formal approval at a later date. ~~Sinc~relY,ibele~ Operations Engineering Supervisor LCI/crc H: \wp\920E 11 \90. LCI NOV 2 0 !992 Alaska OiJ & Gas Cons, Oomraission Anchorage ..... TRADING BAY-UI STEELHEAD PLATFORM WELL M-3 Completed 8/90 Sqz er Fs I 2671'-73'~[ %. 5032' 5053' 5093' 5102' · , COMPLETION STRING 0'-5043' 4.5", 12.6,4 L-80, AB Mod Butt Cp~9, I143'-467' F~ow Coupt. in9 (3.863' ID) tls XXO Inj NippLe (3.813' X ProfiLe) /ow CoupLing (3.863' ID) tis Series 10 SCSSy (3.813' X Profile) ~ow CoupLing (3.863 937' 20', 133~, tlutt, Cs9, 1452' 165 75~, Bu-tt , Csg, 2661'-2681' 9-5/8' Csg Patch 2712' 13-3/8% 61/68~, K-55 Csg. 0'-535' ~ o-~- ~u--~/=, ~,~, N-80 BTC 535'-7269' 9-5/8', 47N, N-80 CS PRODtJCTIBN PACKER ASSEMBLY O-tls 9-5/8' x 5' Permanent packer w/SBE Otis 'X' nipple (3.813' Profll,e) Fl-tis 'X' nlppte (3,813' Prof'll.e) WL Re-en~ry guide perF$ ~ .8'-10' D-3B (Proposed per¢oro¢lons) PERFORATIONS Interval Zone FT SPF Phase 5170'-5210' D-3B 40 6 60' Phosin9 6723'-6735' D-16A 12 ' ' 6810'-6870' D-16BC 60 ' ' LO~/ER PACKER ASSEMBLY 6600' O-tl~ 9-5/8' x 5' Permanent Packer w/SBE . 6618' 'N6688' ~-16A '-- ! 25' KXXXXX>, D-16BC O'~ls 'X' ntppte (3.813' Prof'll.e) D-tls 'XN' nipple (3,813' ProFIte~ 3.725' NoGo> WL Re-eh-try guide PBTD @ 7176' TD ~ 7291' Dote Proposect 8/~7/90 S/87/90 Revision D6-te, 10/90 Revised By: KWB/nef Re6son, New WeLt Compl,etlon Previous Revision: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAES 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ ' ~' ~'/ Alter Casing __ Repair well __ Plugging __ Time extension __ ~Stimulate __ Change approved program __ Puli tubing __ Variance __ Perforate ~ Other __ 2. Name of Operator ! 5. Type of Well: 1 Development ~ UNOCAL (Marathon Oil Co - Sub Operat r) Exploratory__ 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 190247 Anchorage, AK 995]t9 Service__ Trading Bay Unit 4. Location of well at surface Leg B-Z Cond. 1U Steelhead Plattorm 1039' FNL, 602' FWL, Sec. 33 - 9N- 13W- SM At top of productive interval 274' FNL, 2092' FWL, Sec. 33 9N- 13W- SM At effective depth At total depth 250' FSL, 2227' FEL, Sec. 29 - 9N - 13W - SH 6. Datum elevation (DF or KB) 160' KB feet True vertical depth 937' 1,452' 2,645' 6,497' SUBMIT IN'TRIPLICATE ~ ,, 8. Well number M-3 9. Permit number 89-111 10. APl number 507-33-20411 11. Field/Pool NcArthur River Grayling Gas Sand Pool 12. Present well condition summary Total depth: meas'ured true vertical 7,291' 6,512' feet feet Plugs (measured) Effective depth: measured 7, ! 76 ' true vertical 6,409 ' feet Junk (measured) feet None Casing Length Size Cemented Measured depth Structural 937' 20" 2,550 sx 937' Conductor 1,452' 16" 1,516 sx 1,452' Sudace 2,713' 13-3/8" 1,600 sx 2,713' Intermediate 7,268' 10-3/4 x , Production 9-5/8" 1,660 sx 7,268' Liner Perforation depth: measured D-16A 6,723' - 6,735' MD 6,011' - 6,023' TVB KI:L IV U true vertical Tui ,lsiz ra an¢ rrl,~sur~d~pth) , , , L-UU, AU MOO butt tbg to 5 043 Packers and SSSV (type and measured dept.h) Otis FMX SCSSV @ 458' MD 0tis BWH Perma-Drill Pkr W/SBE 0 5,032' and 6,600' 13. Attachments I & 2 Description summary of proposal X__ Detailed operations program __ BOP sketch X__ 14. Estimated date for commencing operation November 7, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas _~X Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed GO,-,-~-& ~-"~-~,..,.~__~,. Title,e.g. ,~¢\,. Conditions of a oval: tify Commission so representative may witness Plug integrity__ BOP Test__ Location clearance __ /, , Mechanical IntegrityTest __ Subsequent form required 10-~ed Copy ORIGINAL SIGNED BY ~'~"'-~Ret~rned C. SMm't ~ LONNIE Approved by order of the Commission Commissioner Date ~t-~.-~o IApprova' No.¢~--~ ~' Date Form 10-403 Rev 06/15/88 Attachment #1 Well M-3 PROCEDURE 1. Obtain 24-hour test. Leave well in test during procedure. Shut well in at wing valve. Hold pre-job operational meeting. 2. RU E-line unit. Pressure test lubricator to 2500 psi with methanol. Take SCSSV off platform system and put on hand pump (4000 p. si). Monitor hand pump pressure throughout job. Locate hand pump near inside well room entry door. Install fusible cap on master manumatic valve. 3. PU and RIH with CCL depth control, pressure and temperature tools. Correlate on depth with the CET-CBT log (07-AUG-90). Note that top of isolation packer assembly is 6589' CET-CBT depth. Determine a) depth of fill, b) gas/water contact in wellbore, and c) static pressure at 6780'. 4. With gauge at 6780', open well to test and slowly reduce BHP by 104 of shut-in BHP. Allow BHFP, FTP, gas rate, and water rate to stabilize. Obtain flowing pressure/temperature gradient from PBTD to 5150'. 5. Reposition gauge at 6780' and pinch well back to 7.54 drawdown and obtain stabilized BHFP, FTP, gas rate, and water rate. Repeat for drawdowns of and 2.54. 6. SWI and POH with pressure/temperature tools. 7. PU and RIH below tubing tail with 30 foot length of 3-3/8", 6 spf, 60 degree phasing OMNIKONE hollow carrier perforation gun. NOTE: Prior to arming guns and until guns are 1000' in hole, notify logistic support and establish the communications blackout. Reestablish when POOH above 1000'. Open well to flow and slowly lower FTP to same as obtained in Step 4 at the 104 drawdown. Perforate the D-3B from 5,179' - 5,209' CET-CBT depth. CET-CBT is 1' shallow to DIL across the D-3B interval. Without making any choke adjustments, allow rate and FTP to stabilize. SWI and POH. 8. Repeat Step 6 perforating 5,169' - 5,199' CET-CBT depth. 9. RD. 10. Leave well in test for 24 hours at a rate to be determined. NOTE: Maximum anticipated SBHP is 2050 psi. RECEIVED NOV 1 3 1990 , & Gas Co,s. Attachment #2 DOLLY VARDEN F .ATFORM Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) , LUBRICATOR MANUALLY OPERATED BOP -4':1J~-1~6-'..'5000 psi CHISTMAS TREE POSITIVE CHOKE ---- 2' 5000 psi .--- 2' 3000 psi 13 3/8' CASING "- "~"" STATE OF ALASKA tl3L.R lb ! N/~ L ~ · ALASKA'~L AND GAS CONSERVATION CC .nMISSION W Lt COMI LI=TION OR R COMI LI:TION RI: ORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS)~] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator LOCA~ 7. Permit Number UNOCAL (Marathon Oil Co Sub-operator) v~u=m~ 89-111 3. Address ~,,,,~ 8. APl Number P. 0. Box 190247 Anchorage, AK 99519 B.~'~ 5o- 733-20411 4. kocat~on of we~ at surface Leg B2, Cond. slot 10 Stee]head Plat-fbrm ....... 9. unitor LeaseName 1,039' FNL, 602' FWL, Sec. 33 9N-13W-SM Trading Bay Unit At Top Producing Interval ~ (;U~-'.?.P~~ 10. Well Number 274' FNL, 2,092' FWL, Sec. 33 9N-13W-SM ~g'/J-~]~.~rI" __.. M-3 At Total Depth ~ ......... : ........ ~ 11. Field and Pool 250' FSL, 2,227' FEL, Sec. 28 9N-13W-SH ~'~ ..... ~ McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Seri~,[]-~,~'~;;~i]~Z'j Grayl i ng Gas Sands Pool 152' KB above MSLI ADL 18730 12. Date Spudded 13. DateT.D, Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 7/04/90 7/28/90 ~I 187' feet MSLt 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth whereSSSV set I 21. Thickness of Permafrost 7,291' & 6,512' 7,176' & 6,409' YES[~ NOD 458'feet~Dt N/A 22. Type Electric or Other L_o§s Run DIL/AMS/TCC/SGC; LDT/CNL; DIL/SDT/GR; LDT/CNL/GR; SHDT/GR; CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# X-56 0' 937' 26" 2~50 sx Class G cmt N/A 16" 75# K-55 0' 1,452' 17.5" 1)16 sx Class G cmt 65.00~)# 13-3/8" 61/68# K-55 O' 2,713' 17.5" 1500 sx Class G cmt 60:000# 10-3/4" 55.5# N-80 0' 535' 12.25" 1~60 sx Class G cmt N/A 9-5/8" 47# N-80 535' 7,268' 12.25" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5 5.043' .':;032' - .5044' D-16A 6723'-6735' MD 6011'-6023' TVD Is~lation oacker 6600' - 660.5' D-16BC 6810'-6870' MD 6088'-6141' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. A11 perforations were 6 SPF 60u phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 8/28/90 Flowing Gas Well Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 9/06/90 24 TESTPERIOD ~ NA 1621q 2 NA[ NA . Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1560 0 24-HOUR RATE ~ NA 16219 2 NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED None OCT 2.5 1990 · as/a & Cons. sslla. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME AC-! A-1 B-I C-1 P-1 D-3 D-16 GEOLOGIC MARKERS MEAS. DEPTH 1491 2738 3368 4154 4612 5166 6723 TRUE VERT. DEPTH 1491' 2667' 3196' 3853' 4243' 4703' 6011' 30. FORMATION TESTS Include interval tested, pressure data, ail fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS Attach #1, Summary of Operations; Attach ~.2, Current ~'Jellbore Diagram; Attach #3, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge __ , , , Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 Attachment #1 Steelhead Platform Well M-3 Summary of Daily Well Operations 07/03/90 ACCEPTED RIG from Well M-4 @ 2200 hrs. on 07/02/90. Skid rig. NU diverter. 07/04/90 Fin NU diverter. PU BHA. Function tested diverter. Displaced hole w/ spud mud. Ran gyro surveys. Drld and surveyed from 382'-525'. 07/05/90 Drld and surveyed from 525'-980'. CBU. POOH. BHA. RIH w/ 26" hole opener. Washed and reamed from 382'-486'. Opened hole from 486'-540'. 07/06/90 Opened hole from 540'-980'. Circ high visc sweep. ST to shoe, no fill. Circ high visc sweep. Spot LCM pill on bottom. POOH. RU and started running 20" csg. 07/07/90 Fin running 20" csg. RIH w/ stab in equip. Cemented csg w/ 2550 sxs cmt. WOC. 07/08/90 WOC. Tested csg to 500 psi. LD landing its. RIH. Tested 20" by 30" annulus to 500 psi. Drill cmt and float equip. POOH. RIH. Drld and surveyed from 980'-1313'. 07/09/90 Drld and surveyed from 1313'-1480'. CBU. POOH. PU UR. UR from 943'-1480'to 22". Circ high visc sweep. ST to shoe. 07/10/90 Run 16" K-55, 75#/ft Buttress csg to 1451'. Run 5" stab in assembly. Circ and cond mud while reciprocating csg. Cmt w/ 1066 sxs TLW w/ additives and 450 sxs Class G w/ additives. CIP @ 0500 hrs on 01/10/90. POOH w/ 5" d.p. WOC. 07/11/90 WOC. LD 16" landing jt. ND diverter. Install 16" packoff and unihead spool. Test to 2000 psi. NU ~0~. RECEIVED OCT 2 1990 · aska Q~ & Gas Cons. 6om~issjl~l Steelhead Well M-3 Summary of Daily Well Operations Page 2 07/12/90 NU BOPE. Test BOPE 250/3000 psi. RIH w/ 14-3/4" bit. Test csg to 1850 psi. Drill floats and 10' formation. Test shoe to 14.0 ppg EMW. POOH. PU mud motor BHA. 07/13/90 RIH w/ mud motor and MWD. Drill 12 1/4" hole and survey 1490'-2200'. 07/14/90 Directionally drill and survey 2200'-2740'. RU run E logs. Run #1 DIL/AMS/TCC/SGC 2740'-1451'. Run #2 LDT/CNL 2740'-1451'. 07/ 5/ 0 Fin logging run #2 LDT/CNL. PU 17.5" UR. RIH and UR 1458'-2197'. 07/16/90 UR to 17.5" 2397'-2740'. POOH. RU RIH w/ 13-3/8" csg. 07/17/90 Fin running 13-3/8" csg and cmt same w/ 1600 sxs of cmt. Set packoff. Started testing BOP's. 07/18/90 Tested BOP's. Found flange on stack leaking. POOH w/ test plug. Left test plug bushing in hole. Changed ring gasket on stack flange. Attempted to retrieve test plug bushing w/ spear w/o success. Set pkr @ 460'. PU stack and heated bushing. Latched same w/ spear and POOH w/ same. NU stack. Retrieved pkr. 07/19/90 Set test plug. Found flange leaking. Changed ring gasket and tested blind rams. RIH to 2600'. Tested csg to 2200 psi. Drld out to 2750'. Tested shoe to 14.0 ppg EMW. Drld from 2750' to 3165'. 07/20/90 Drld from 3165' to 3776'. CBU. Made 12 stand ST. Drld from 3776' to 4060'. 07/21/90 Drld from 4060' to 4534'. CBU. Made 10 stand ST. Drld from 4534' to 4841'. Steelhead Well M-3 Summary of Daily Well Operations Page 3 07/22/90 Drld from 4841' to 5008'. CBUo Tripped for bit and BHA. Drld from 5008' to 5325'. 07/23/90 Drld from 5325' to 5833'. CBU. POOH. Changed stab sleeve. RIH to shoe. 07/24/90 Cut drlg line. TIH. Drld 5833'-6568'. 07/25/90 Drlg 6568'-6587'. POOH. Test BOPE 250/3000 psi. RIH. Drl9 6587'-6871'. 07/26/90 Drl9 6871'-7141'. Loggin9 run #1DIL/SDT/GR. 07/27/90 Fin lo9 run #1: DIL/SDT/GR 7093'-2710'. Log run #2: LDT/CNL/GR 7091'-2710'. RIH w/ d.p. to 7141'. Circ and cond mud. POOH. Log run #3: RFT's. 07/28/90 Fin log run #3: RFT pressures from 2757'-6953'. Log run #4: SHDT/GR from 7100'-5310' (dipmeter). RIH. Drill 150' from 7141'-7291' for rathole. Circ and cond mud and hole. 07/29/90 ST. CBU. POOH. Running 9-5/8" x 10-3/4" csg. 07/30/90 Fin running 9-5/8" csg string. Circ and recip. Mix and pump preflush followed by 800 sx of TLW cmt w/ additives. Followed by 860 sx Class "G" w/ additives. Bump plug w/ 1900 psi. WOC. 07/31/90 Tested BOP's. Pulled test plug bushing from wellhead. LD BHA. RIH w/ bit and scraper. Drld cmt from 7123' to top of float @ 7176'. Circ. Tested csg to 3000 psi. POOH. Steelhead Well M-3 Summary of Daily Well Operations Page 4 08/01/90 Ran bond log from 7168' to 2600'. Reran bond log w/ 500, 1000 and 1500 psi. Running rate gyro. 08/02/90 Ran rate gyro from 7130' to surface. Made bit and scraper trip. Shot squeeze perfs from 5308' to 5310'. RIH w/ retrievable pkr to squeeze. 08/03/90 Squeezed perfs w/ 100 sx cmt. WOC. POOH. RIH w/ bit and scraper. Drld cmt. RIH to 7176'. Circ. Preliminary Loq Results Zone Top D3B Sand 5169' MD D6 Sand 5526' MD D16A Sand 6723' MD D16BC Sand 6813' MD 08/04/90 Base Gross Interval Net Pay Porosity 5236' MD 67' MD 57' ~ = 254 5590' MD 64' MD 0 ~ = 04 6741' MD 18' MD 11' ~ = 214 6877' MD 64' MD 43' ~ = 184 08/05/90 RIH to 5150'. Circ and WOC. Drld cmt. CBU. Tested squeeze perf to 2000 psi, bled to 1600 psi in 30 min. POOH. Round tripped bit and scraper. RIH and set retainer. Establish inj rates. 08/06/90 Squeezed perfs w/ 175 sx. RO and POOH. Test BOPE 250/3000 psi. RIH w/ bit and boot basket. WOC. 08/07/90 WOC. RIH drlg cmt and retainer from 5225'-5244'. RIH to 7176'. CBU. Test squeeze perfs to 2000 psi, ok. POOH. RIH w/ bit and scraper to 7176'. Circ hole clean. POOH. Circ. Tested perfs to 2000 psi. Pressure bled to 1270 psi in 20 min. POOH. RIH open ended and set 100 sx balanced plug. POOH 5 stands, RO. Pressured up to 1500 psi and WOC. POOH. RIH w/ bit. Steelhead Well M-3 Summary of Daily Well Operations Page 5 o8/o8/go POOH. RU E-line. Run CET/CBT 7176'-5000' 0 0 psi and 1500 psi. RIH w/ bit and scraper and displace mud w/ inlet salt water. Make bit and scraper trip. Circ inlet water. o8/o9/9o Displaced hole w/ filtered 34 KC1. POOH. Change rams and test. PU DST equipment and pressure test same. MU TCP guns. o8/ o/9o PU and RIH w/ TCP guns and DST assembly on 3-1/2" hydril tbg. Hydro testing tbg to 5000 psi. 08/11/90 Fin running and hydro testing 3-1/2" tbg. Run depth correlation log. Space out guns from 5170'-5210'. Set pkr La 5116'. RU and test all surface equip to 500/3500 psi. Observe gas bubbling on tbg/csg annulus. Call for wellhead service rep to test packoff. 08/12/90 RU and test 10-3/4" csg packoff void area. Found seals bad. Inject 38 sticks of plastic. Annulus will bleed to 0 psi and builds to 160 psi in 1.5 hrs while shut in. Gas begins to bubble inside 10-3/4" csg as annulus pressure builds. 08/13/90 Pump additional plastic into packoff void area. Attempt to test packoff seals from 13-3/8" x 10-3/4" side. Packoff failed La 400 psi. POOH w/ tbg and DST assembly. Set storm pkr. Attempting to retrieve packoff. 08/14/90 Retrieved 10-3/4" packoff. Inspected wellhead. Attempted to set new 10-3/4" packoff w/o success. Washed wellhead w/ rotary shoe. Set packoff and tested same. Held 5000 psi for 5 min then lost all pressure. POOH w/ packoff. Retrieved storm pkr. RIM. Displaced brine w/ mud. o8/ .5/9o Circ and cond mud. POOH. RIH. Set retainer La 2830'. POH. RIH w/ RTTS and set La 2450'. RU WL and perf 2671' to 2673'. POOH and LD RTTS. RIH w/ retainer and set La 2600" Est inj rate i BPM La 2950 psi. Started mixing cmt. Steelhead Well M-3 Summary of Daily Well Operations Page 6 08/16/90 Squeezed perfs w/ 200 sx cmt. WOC. POOH. Observed well. Well bubbling. 08/17/90 Monitored well. Ran CBT from 2600 to 100'. Monitored well. LD 3-1/2" tbg from derrick. o8/ .8/9o Fin LD tbg and 4-3/4" d.c. from derrick. Monitored well. Packed dry ice around unihead. Closed blind rams and pressured up to 350 psi. Monitored pressure and temperature while freezing unihead. 08/19/90 Monitored wellhead temperature and pressure while maintaining ice pack around wellhead. Tested ice plug to 500 psi for 30 min. Open rams and monitored well for 30 min, no bubbling. RU to change out tbg spool. 08/20/90 Nippled down BOP's and changed out tbg spool. Tested same to 1500 psi for 15 min. RIH to 74' and circ on open choke to thaw ice plug. 08/21/90 Circ above csg hgr to thaw ice plug. Attempt to set packoff several times w/o success. Send packoff to machine shop for modification. Installed packoff. Test pull to 30,000# and test void to 5000 psi. RU to test annulus below packoff. 08/22/90 Test void to 5000 psi. Test 10-3/4" x 13-3/8" annulus to 1000 psi. Tested BOPE 250/3000 psi. RIH. Drld EZSV and cmt 2600'-2780'. 08/23/90 Drld to 2805'. Test csg and squeeze perfs to 2000 psi. Drld EZSV @ 2830'. TIM to 7176'. POOH. RIH w/ bit and scraper. Displace mud w/ inlet seawater. Round tripping bit and scraper. 08/24/90 With bit & scraper @ 7176', displaced hole w/filtered 34 KCL. Trip for packer #1 and set 0 6600'. P/U packer #2. Steelhead Well M-3 Summary of Daily Well Operations Page 7 08/25/90 RIH set 2nd BWH permanent packer 0 5025'. Run and set 9-5/8" casing patch 2661 '-2681'. Run 8.250" gauge through casing packoff. Rig up to run 4-1/2" AB modified buttress tubing. 08/26/90 Test PKR seal assy to 5000 psi. Run 4-1/2" AB mod buttress tubing testing each connection to 5000 psi. Installed SCSSV & XXO sliding sleeve. Tested assy to 5000 psi. 08/27/90 Finish running and testing 4-1/2" completion. N/D bope. N/U tree. R/U coiled tubing and nitrogen units. RIH w/coiled tubing. 08/28/90 Circulated completion fluid out of tubing. POOH w/coil tubing. R/U W/L and lubricator. RIH and perforated 6810'-6840' DIL. Flowed well, recovered 51 BBLS fluid. RIH w/gun #2 and perf 6840'-6870' DIL. Flowed well, recovered 19 BBLS add'n fluid. Max Rate 7.8 MMCFD w/1360 psi FTP RIH w/gun #3. 08/29/90 Perforated 6723'-6735' DIL. R/D wireline and lubricator. Flowed well for 2 1/2 hours. Stabilized rate at 14.4 MMCFD w/1500 psi FTP. Broke down top drive and inspected all breaks and load carrying points. Reassembled top drive system. 08/30/90 Finished reassembling top drive. Changed bolts on outside of west side of rig, substructure to main and diagonal girders. R/D and prep to skid rig. Rig released from M-3 to M-19 at 1400 hrs. 8-29-90. \docs\shp\m3 .doc RECEIVED OCT 2 1990 ~aska Oil & Gas Cons. Boml~l~]~ Anchora~ AI[ACHMI-N I ~Z Compl`eted 8/90 ~RADING BAY UNIT STEELHEA]] PLATFF1RM WELL H-3 CFINPLET]BN STRING 0'-5043' 4.5; 18.65 L-80, AB Mod :Butt Cpi9, I143'-467' Fl,ow Coupl,ln9 (3.863' ID) %Is XXD InJ Nipple (3,813' X Pro¢lte) l,ow Coupl,in§ (3.863' ID) %Is Series 10 SCSSV (3.813' X Pro¢iLe) tow Coupl`in9 (3.863' ID) 937' 20', 133~I, 3u%t, Csg, 1452' 16% 75~, Butt , Csg, Sqz peres 2671'-73' 2661'-868t' 9-5/8' Cs9 Pc~ch 27:]2' :]3-3/8', 61/685, K-55 Cs9, 0'-535' 10-3/4', 55,55, N-BO BTC 535'-7869' 9-5/8', 47~, N-80 CS 5032' 5053' 5093' 5~02' PRODUCTION PACKER ASSEMBLY Btls 9-5/8' x 5' Permanent packer w/SBE Otis 'X' nipple (3.813' Pro¢iLe) Otis 'X' nlppte (3,813' ProFi(e) %/L Re-er"[ny 9ui0te Sqz peres 5308'-10' ]]-33 (Proposed per¢o~-c~lon~) Intepvot 5170'-5210' 6723'-6735' 6810'-6870' PERFDRATIBNS Zone FT SPF Phc~se ]]-3B 40 6 60' Phcsin9 D-16A 1~ ' ' D-16BC 60 ' ' Dote Ppopos6'c:l 8127/90 8/~7/90 6600' 6609' 6618' 66~8' D-16A LB~WER PACKER ASSEMBLY Btls 9-5/8' x 5' Permanent Packer w/gBE Otis 'X' nipple (3,813' Pro¢ll, e> Otis 'XN' nlpp(e (3,813' ProFil`ej 3,725' NoGo) ~/L Re-en~y 9ulcte D-16BC PBTD @ 7t76' TD @ 729t' Revision De-be: 10/90 Revised By, KA/B/ne¢ Reasom New A/ell Comptetlor, Prevlous Revision. None SUB - S URFA CE DIRECTIONAL SURVEY ~'l UIDANCE J'~ ONTINUOUS l-~ OOL RECEIVED OCT 2. 2 1990 Alaska Oit & ~as Cons. commission · Aachora~ie Company MARATHON OIL COMPANY Well Name TBU M-3 ( 1039' FNL, 602' FWL SEC Field/Location TRADING BaY, KENAI, ALASKA 33, T9N,R13W) Job Reference No. 74016 Logged By: MACKAY Date MICROFILMED Date ),O/,~w/r~ ... - ~:o..zNc GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR MARATHON OIL COMPANY TRADING BAT KENAI, ALASKA SURVEY DATE: OZ-AUG-90 ENGINEER: MACKAY METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZo DISTo PROJECTED ONTO A TARGET AZIMUTH OF NORTH 62 DEG 4Z gin EAST CDHPUTATION DATE: 14-AUG-90 ,, PAGE 1.' HARATHO# OIL COHPANY TBU #-3 TRADING BAY KENAI, ALASKA DATE OF SURVEY: 01-AUG-90 KELLY BUSHING ELEVATION: 160000 F~ INTERPOLATED VALUES FOR EVEN 100 FEET OF HEASURED DEPTH TRUE SUB-SEA COURSE NEASURED VERTICAL VERTICAL'DEVIATION AZINUTH DEPTH DEPTH DEPTH OEG NIN DEG 0.00 0.00 -160000' 0 0 N 0 0 E 100.00 99.99 -60.01: 0 14 S 11 14 E ZOO.O0 199.99 39099 0 10 S 6 11E 300000 299.99 139099 0 21 S 18 23 ti 400.00 399.98 239.98 I 12 S 26 42 Id 500.00 499095 339.95 I 25 S 19 44 # 600.00 599.92 439092 I 25 S 9 2 bi 700.00 699.89 539089 I 25 S 9 6 ti 800.00 799.86 639.86 I 24 S 10 48 M 900.00~ 899.83 739.83 I 8 S 21 19 ti 1000.00 999.82 839.82 1100.00 1099082 939.82 1200.00 1199.81 1039081 1100.00 1299.81 1139.81 1400.00 1399.81 1239.81 1500.00 1499081 1339081 1600.00 1599.79 1439079 1700.00 1699051 1539.51 1800.00 1798.85 1638.85 1900000 1897.77 1737.77 047 S 11 0 31 S 19 41 0 19 S 33 49 ti 0 15 S 61 48 bi 0 18 S 75 22 ti 0 19 S 71 36 ti 2 33 N 18 3 E 5 37 N 28 11 E 7 29 N 40 28 E 912 N 53 9 E 2000000 1996.18 1836018 11 25 2100.00 2093.54 1933.54 14 47 2200.00 2189.53 2029.53 17 54 2300.00 2283.58 21Z3.58 21 46 2400.00 2375.13 2215013 25 41 2500.00 2463.66 2303.66 29 29 2600.00 2549.67 2389.67 31 41 2700.00 2634.47 2474.47 31 57 2800.00 2719.24 2559.24 32 14 2900.00 2803.85 2643.85 32 22 ENGINEER: NACKAY 3000.00 2887.93 2727.93 33 6 3100.00 2971.51 2811.51 33 27 3200.00 3055.01 2895.01 33 14 3300.00 3138.94 2978094 33 1 3400.00 3222.51 3062.51 33 15 3500.00 3306.58 3146.58 32 56 3600.00 3390.49 3230.49 32 37 3700.00 3474.99 3314.99 32 35 3800000 3559.07 3399007 32 25 3900000 3643.55 3483.55 32 39 VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/blEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG NIH 0.00 0.00 -0.28 1.14 -0.28 0.00 -0,.55 0.39 -1.56 0.56 -3043 0.37 -5.11 0.00 -6.54 0.00 -8.05 0.21 -9.61 0.49 -10.76 0.18 -11.45 0.30 -12.01 0.17 -12.45 0.15 -12.93 0.00 -13.46 0o41 -12.69 3.96 -6.92 2.Z4 3.12 2.70 17.18 2.42 N 63 56 E 34.82 3.20 N 66 26 E 57.54 2.95 N 64 15 E 85-53 3.98 N 62 32 E 119.43 3.71 N 61 26 E 159.61 4.23 N 62 37 E 206.07 2080 N 62 42 E 257.07 N 62 27 E 310.06 1.03 N 62 53 E 363.11 0.33 N 63 32 E 416.41 0.69 N 63 43 E 470.54 0.50 N 63 57 E 525.43 0.76 N 63 50 E 580.44 1.65 N 63 27 E 634.81 0.74 N 63 27 E 689.71 1.56 N 63 16 E 743.86 0.68 N 63 18 E 798.27 0.96 N 63 15 E 851.73 1.06 N 62 45 E 905.86 2.03 N 62 37 E 959.38 1.25 0.00 N 0000 E 0.45 N 0.55 Id 0.19 N 0.41 Id 0.23 S 0.50 Id 1.43 S 1.OZ ~ 3.61 S 2.00 Id 6.10 S 2.60 Id 8.51 S 2.97 Id 10.94, S 3.41 bi 13.16 S 4.02 Id 0.00 .N 0 0 E 0.71 N 50 58 Id 0.45 N 65 15 Id 0.55 S 65 4 ti 1.76 S 35 34 bi 4.12 $ 28 57 Id 6.63 S 23 3 bi 9.02 S 19 14 bi 11.46 S 17 18 ti 13.76 S 16 59 Id 14.67 S 4.54 Id 15.78 S 4.74 16.42 S 5.05 Id 16.73 S 5.38 Id 16.90 S , 5.83 17.04 S 6.35 15.46 S 6.31 ti 8.91 S 3.19 ti 0.54 N 3.23 E 10.46 N 13.93 E 15.36 S 17 11 bi 16.47 S 16 17.17 S 17 6 ti 17-57 S 17 49 bi 17.88 18.19 S 20 25 16.69 S 9.47 3.28 N 80 35 E 17.42 N 53 6 E 19.45 N 29.15 E 35.04 N 56 17 E 28.77 # 49'90 E 57.60 N 60 Z E 40.49 N 75.35 E 85.54 N 61 45 E 55.68 N 105.66 E 119.43 N 62 13 E 74.67 N : 141*08 E 159.62 N 62 7 E 96.49 N 182.10 E 206.08 N 62 5 E 119.85 N 227.44 E 257.08 N 62 13 E 144.34 N 274.43 E 310.07 N 62 15 E 168.65 N 321.58 E 363.12 N 62 19 E 192.66 N 369.17 E 416.42 N 62 26 E 216.75 N 417.65 E 470.54 N 62 34 E 240.92 N 466.94 E 525.43 N 62 43 E 265.12 g 516.36 E 580.44 N 62 49 E 289.44 N 564.99 E 634.81 N 62 52 E 313.90 N 614.15 E 689.72 N 62 56 E 338.28 N 662.50 E 743.87 N 62 57'E 362.72 N 711.11 E 798.28 N 62 58 E 386.87 N 758.81 E 851.74 N 62 59 E 411.30 N 807.12 E 905.88 N 63 0 E 435.95 N 854.62 E 959.39 N 62 58 E COHPUTATION DATE: 14-AUG-90 PAGE 2' NARATHON 0IL COHPANY TBU H-3 TRADING BAY KENA~i ALASKA DATE OF SURVEY: 01-AUG-90 * KELLY BUSHING ELEVATION: 160.00 F~ ENGINEER: ~ACKAY INTERPOLATED VALUES FOR EVEN 100 FEET OF HEASURED DEPTH TRUE SUB-SEA COURSE #EASURED VERT]:CAL VERTICAL DEYZATZON AZIPIUTH DEPTH DEPTH DEPTH DEG PlIN DEG llilIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/VEST DIST. AZIHUTH FEET DEG/IO0 FEET FEET FEET DEG 4000000 3727083 3567o83:!~ 32 5 N 62 37 E 1013020 4100000' 3812.47 3652047 32 23 ' N 63 1 E 1066.45 4200000 3896.47 3736.47 33,17 4300000 3980.45 3820.45 32 15 4400.00 4064.87 3904097 '32 42 4500000 4149.10 3989.10 32 35 460.0.00 4232.96 4072.96 33 17 4700.00 4316.75 4156075: 33 7 4800000 4400.17 4240.17 33 45 4900.00 4484.06 4324006 32 30 N 63 18 E 1120.70 N 62 58 E 1174098 N 63 16 E 1228059 N 63 10 E 1282.49 N 63 41 E 1336.95 N 62 53 E 1391.53 N 62 56 E 1446.67 N 61 33 E 1501.09 0.20 1.09 0.74 0.04 0.55 0.69 0.31 0.56 0.64 1.13 460.67 N 902.43 E 1013.21 N 62 57 E 485.03 N 949.78 E 1066.46 N 62 57 E 509.55 N 998.17 E 1120.71 N 62 57 E 533.93 N 1046.68 E 1175.00 N 62 58 E 558.28 N 1094.44 E 1228.6! N 62 58 E ~1 582.57 N 1142.56 E 1282.51 N 62 59 E 606.90 N 1191.29 E 1336.97 N 63 0 E 631.40 N 1240.06 E 1391.56 N 63 I E 656043 N 1289.19 E 1446.69 N 63 I E 681.75 N 1337.37 E 1501'11 N 62 59 E 5000o00 4568.32 4408032 32 37 5100.00 4652.50 4492.50 32 45 5200.00 4736027 4576.27 33 28 5300.00 4819.49 4659.49 33 53 5400.00 4902037 4742037 34 8 5500.00 4985023 4825023 34 14 5600.00 5067.83 4907.83 34 15 5700. O0 5150019 4990019 34 38 5800000 5232.30 507Z.30 34 59 5900.00 5314.33 5154.33 34 42 N 60 55 E 1554.93 N 61 4 E 1608.89 N 61 12 E 1663.47 # 61 18 E 1718.91 N 61 28 E 1774.85 N 61 36 E 1830.81 N 61 46 E 1887.18 N 61 54 E 1943.89 N 62 23 E 2000.96 N 62 49 E 2058016 0.66 O.ZO 0.53 0.73 0.27 0.97 1.00 0.66 0.90 0.29 707.70 N 1384056 E 1554.94 N 62 56 E 733091 N 1431.76 E 1608.90 N 62 52 E 760.30 N 1479056 E 1663.48 N 62 48 E 787.00 N 1528.16 E 1718.91 N 62 45 E 813.82 N 1577.27 E 1774.85 N 62 42 E 840048 # 1626'49 E 1830.81 N 62 40 E 867.21 N 1676012 E 1887018 N 62 39 E 893.97 N 1726*13 E 1943.89 N 62 37 E 920.60 N 1776.61 E 2000.96 N 62 36 E 946.,93 N 1927.40 E 2058.17 N 62 36 E 6000.00 5396.93 5236093 34 2 6100.00 5480.14 5320.14 331 ,00.00 6500000 5819.10 5659.10 31 27 6600000 5904.82 5744.82 30 38 6700000 5991.32 5831.32 29 28 6800000 6078.80 5918.80 28 32 6900000 6166099 6006.99 27 36 N 63 4 E 2114o52 N 63 2 E 2169.98 N 63 7 E 2224.33 N 63 12 E 2277.84 N 63 9 E 2330018 N 63 7 E 2382031 N 63 8 E 2433080 N 63 12 E 2483097 N 62 59 E 2532.43 N 63 4 E 2579056 0.81 1.27 0.47 1 0.61 1.16 0.61 0.93 0007 0052 972.52 N 1877061 E 2114.52 N 62 37 E 997.65 N 1927,05 E Z169o98 N 62 38 E 1022.31 N 1975.48 E 2224.33 N 62 38 E 1046.46 N 2023.23 E 2277.84 N 62 39 E 1069.98 N 2069.99 E 2330.18 N 62 40 E 1093.56 N Z116.49 E 2382.31 N 62 41 E ,! 1116.86 N 2162.41 E 2433080 N 62 41 E 1139.55 N 2207.16 E 2483097 N 62 42 E 1161.51 N 2250.35 E 2532.43 N 62 42 E 1182095 N 2292.33 E 2579.56 N 62 42 E 7000000 6255.92 6095092 26 41 TlOO.O0 6345.47 6185047 26 9 7200.00 6435.42 6275042 25 53 7250.00 6480040 6320.40 25 53 N 63 9 E 2625.29 N 63 10 E 2669.80 N 63 0 E 2713.48 N 63 0 E 2735030 0.88 1.59 0.00 0.00 1203067 N 2333.09 E 2625.29 N 62 43 E 1223.72 N 2372.83 E 2669080 N 62 43 E 1243.51 N 2411077 E 2713.48 N 62 43 E 1253042 N 2431.22 E 2735.30 N 62 44 E CO#PUTATION DATE: 14-AUG'90 PAGE #ARATHON OIL COHPANY TBU H-3 TRADING BAY: KENAIt ALASKA DATE OF SURVEY: 01-AUG-90 KELLY BUSHING ELEVATION: 160.00 FT- ENGINEER: HACKAY INTERPOLATED VALUES FOR EVEN 1000 FEET OF HEASURED DEPTH TRUE SUB-SEA COURSE HEASURED VERTICAL VERTICAL DEVIATION AZINUTH DEPTH DEPTH DEPTH DEG'MZN DEG HIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIHUTH FEET DEG/IO0 FEET FEET FEET DEG 0000 0.00 -160.00 0 0 1000000 999.82 839.82 0 47 2000.00 1996.18 1836.18 11 2~ 3000.00 2887.93 727.93 33 4000.00 3727.83 3567.83 32 5 5000.00 4568.32 4408.32 32 37 6000.00 5396.93 5236.93 34 2 7000.00 6255.92 6095.92 26 41 7250.00 6,80.40 6320.40 25 53 N 0 0 E 0.00 S 11 I g -10.76 N 63 56 E 34.82 N 63 43 E 470.54 N 62 37 E 1013.20 N 60 55 E 1554.93 N 63 4, E 2114.52 N 63 9 E 2625029 N 63 0 E 2735030 0.00 0o18 3.20 0.50 0.20 0.66 0.81 0.88 0.00 0.00 N 0.00 E 0.00 N 0 0 E 14.67 S 4.54 M 15.36 S 17 11 W 19.45 N 29.15 E 35.04 N 56 17 E 216.75 N 417-65 E 470.54 N 62 34 E 460.67 N 902.43 E 1013.21 N 62 57 E 707.70 g 1384.56 E 1554.94 N 62 56 E 972.52 N 1877.61 E 2114.52 N 62 37 E 1203.67 N 2333.09 E 2625,29 N 62 43 E 1253.42 Ni:2431022 E 2735.30 N 62 44 E CO#PUTATIO# DATE: 14-AUG-90 PAGE PIARATHON 'OIL CONPANY TBU PI-3 TRADZNG 'BAY K, ENA~Z ~, ALASKA DATE OF 'SURVEY: 01-AUG-90 KELLY BUSHING ELEVATION: 160.00 FTo ENGINEER: MACKAY INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG NIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST OISTo AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG 0.00 160.01 160.00 260001 260.00 360.01 360.00 460.03 460.00 560.07 560.00 660'10 660-00 760.13 760.00 860.16 860.00 960.17 960.00 0.00 -160.00 0 0 : N 0 0 E 0.00 0 12 S 30 36 E 100.00 200000 0 50 S 23 46 bi 300.00 400.00 500000 I 23 S 8 19 ti 600000 I 25 S 10 13 ti 700.00 I 19 S 16 23 800000 0 51 S 18 26 bi 0.00 0.00 0.00 N 0.00 E -0.26 0.08 0.30 N 0.45 bi -0.40 0.00 0.02 -0099 1.23 0077 S 0o71 Id -2068 0027 2.69 S 1.63 -4049 0.51 5.12 S 2.41 -5.97 0000 7.55 S 2.82 bi -7.45 0.00 9.98 S 3.23 bi -8.99 0.34 12.35 S 3074 Id -10.38 0.45 14.12 S 4.40 bi 0.00 'N 0 0 E 0.54, 0.44 S 87 3 14 1.05 S 42 33 Id 3.I4 S 31 12 Id 5-66 S 25 12 bi 8.06 S 20 31 bi 10.49 S 17'57 bi 12.90 S 16 SI'bi 14.79 S 17 18 bi 1060.18 1060000 900000 1160.19 1160.00 1000000 1260019 1260.00 1100.00 1360.19 1360-00 1200000 1460.19 1460.00 1300.00 1560.19 1560.00 1400.00 1660.33 1660.00 1500.00 1760085 1760.00 1600000 1861077 1860.00 1700.00 0 37 S 8 50 ti 0 23 S 28 46 M 0 16 S 51 36 bi 0 18 S 69'53 ii 0 18 S 74 58 ti I 5 N 3 0 E 4 30 N 26 Z E 646 N 35 2 E 8 40 N 48 34 E N 61 6 E 1963.15 1960.00 1800.00 10 26 -11.18 0.06 15.38 S 4.65 bi -11.80 0.29 16.21 S 4.92 I~ -12.28 0.00 16063 S 5.23 bi -12073 0000 16.84 S 5.64 Id -13.25 0.00 i 16.98 S 6.15 bi -13.50 3.37 16.67 S 6.58 bi -9077 2.93 12004 S 4.78 bi -1.28 2.37 3.29 S 0.26 E 11.36 2.58 6o71 N 9032 E 27.84 2.84 16.25 N 22.94 E 16.07 S 16 48 bi 16.94 $ 16 52 bi 17.44 S 17 28 bi 17.76 S 18 31 Id 18.06 S 19 54 ti 17.92 S 21 33 Id 12.95 S 21 4O bi 3.30 S 4 31 E 11.48 N 54 15 E Z8.1Z N 54 41 E 2065039 2060.00 1900.00 13 45 2169007 2160 O0 2000000 16 48 2274.69 2260:00 2100.00 20 46 2383026 2360.00 2200000 25 1 2495081- 2460.00 2300.00 29 21 2612016 2560.00 2400.00 31 53 2730007 2660.00 2500.00 31 53 2848015 2760.00 2600000 32 9 2966.69 2860.00 2700.00 32 57 3086.20 2960.00 2800.00 33 29 N 66 21 E 49.02 3.68 N 64 50 E 76.32 3.04 N 63 I E 110025 4.06 N 61 29 E 152.45 3.82 N 62 34 E Z04.02 3.00 N 62 39 E 263.47 1.13 N 62 40 E 325.95 0.44 N 63 14 E 388.75 0.30 N 63 36 E 452.39 0.61 N 63 57 E 517082 0.22 25.36 N 42.07 E 49.12 N 58 55 E 36.53 N 67.03 E 76.34 N 61 25 E 51.48 N 97.50 E 110.25 N 62 10 E 71.24 N 134079 E 152.45 N 62 8 E 95.55 N 180.28 E 204.03 N 62 5 E 122.79 N 233.12 E 263.48 N 62 13 E } 151.67 N 288052 E 325.95 N 62 16 E 180.27 N 344.44 E 388076 N 62 22 'E 208.69 N 401.38 E 452039 N 62 32 E 237057 N 460.10 E 517.82 N 62 41 E 3205096 3060.00 2900.00 33 9 3325014 3160.00 3000.00 33 11 3444.62 3260.00 3100.00 32 37 3563072 3360.00 3200000 33 1 3682022 3460000 3300.00 32 23 3801010 3560.00 3400000 32 24 3919056 3660000 3500.00 32 46 4037.99 3760.00 3600000 32 10 4156.46 3860.00 3700.00 32 54 4275.79 3960.00 3800000 32 30 N 63 47 E 583.71 N 63 33 E 648.54 N 63 10 E 713.90 N 63 21 E 778.60 N 63 10 E 842.18 N 62 44 E 906.46 N 62 41 E 969.95 N 62 40 E 1033.41 N 63 11E 1096.92 N 63 13 E 1162.03 1.63 0.73 0.33 0.70 1.36 1.97 0.28 0.46 0.73 2.38 266.56 N 519.29 E 583.71 N 62 50 E 295.56 N 577.28 E 648.54 N 62 53 E 324.76 N 635.76 E 713.91 N 62 56 E 353.89 N 693.53 E 778.60 N 61 58 E 382.56 N 750.29 E 842.19 N 62 59 E 411.57 N 807.65 E 906.47 N 63 0 E 440.80 N '864.01 E 969.96 N 62 58 E 469.96 N 920.37 E 1033.42 N 62 57 E 498083 N 976.95 E 1096.93 N 62 57 E 528.07 N 1035.13 E 1162.05 N 62 58 E CONPUTAT[ON DATE: 14-AUG-90 PAGE NARATHON OIL CONPANY DATE OF SURVEY: 01-AUG-90 TBU N-3 KELLY BUSHING ELEVATION: 160.00 FT TRADZNG BAY KENA2,'~ALASKA ENGINEER: HACKAY INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE NEASURED VERTICAL VERTICAL DEVIATZON AZZNUTH SECTION SEVERITY NORTH/SOUTH EAST/MEST O~ST. AZIHUTH DEPTH DEPTH OEPTH '~DEG NIN DEG #IN FEET DEG/IO0 FEET FEET FEET DEG 4394.22 4060.00 3900000 32 41 N 63 13 E 1225.47 4512.94 4160.00 4000.00~ 32 39 N 63 15 E 1289.47 4632.33 4260.00 '4100.00 33 8 4751074 4360.00 4200.00' 33 27 4871.44 4460.00 4300.00' 32 40 4990.12 4560.00 4400.00'~ 32 40 5108093 4660.00 4500.00 32 48 5228045 4760.00 4600.00 33 33 5348.82 4860.00 4700.00 34 4 5469.52 4960.00 4800.00 33 59 N 63 31E 1354.67 N 63 5 E 1419.92 N 61 57 E 1485.71 N 60 55 E 1549.60 N 61 4 E 1613.72 N 61 12 E 1679.17 N 61 22 E 1746.14 N 61 37 E 1813073 5590053 5060000 4900000 34 12 5711093 5160.00 5000.00 34 41 5833.82 5260.00 5100.00 35 0 5955.39 5360000 5200.00 34 10 6075088 5460.00 5300.00 33 31 6195.15 5560.00 5400.00 32 39 6313.46 5660.00 5500.00 31 41 6430.71 5760.00 5600.00 31 20 6547083 5860.00 5700.00 30 59 6663.93 5960.00 5800.00 29 59 N 61 44 E 1881.85 N 61 59 E 1950.67 N 62 33 E 2020.36 N 63 I E 2089.49 N 63 3 E 2156.?0 N 63 5 E 2221.71 N 63 13 E 2284.92 N 63 8 E 2346014 N 63 3 E 2407.10 N 63 3 E 2466009 6778060 6060.00 5900000 28 37 6892011 6160.00 6000.00 27 38 7004.56 6260.00 6100.00 26 38 7116.17 6360.00 6200000 25 55 7227032 6460000 6300000 25 53 7250.00 6480.40 6320040 25 53 N 62 57 E 2522019 N 63 3 E 2575.91 N 63 10 E 2627.33 N 63 11 E 2676.89 N 63 0 E 2725.41 N 63 0 E 2735.30 0.80 0.58 1 1.26 0.78 0.33 0.65 0.81 0.94 0.72 0.85 0053 0.41 0.14 0.92 0078 0096 0.66 1.31 1.30 0.58 0087 1.14 1.09 O.O0 0.00 556.87 N 1091.65 E 1225.48 N 62 58 E 585.72 N 1148.78 E 1289.48 N 62 59 E 614.77 N 1207.16 E 1354.69 N 63 I E 644.28 M 1265.36 E 1419.95 N 63 1 E 674.47 N 1323.82 E 1485.73 N 63 0 E j 705.11 N 1379.89 E 1549.61 N 62 56 E 736.25 N 1435099 E 1613.73 N 62. 51 E 767086 N 1493.32 E 1679.17 N 62 47 E 800.08 N 1552.05 E 1746.14 N 62 44 E 832035 N 1611.46 E 1813.73 N 62 41 E 864.69 N 1671.43 E 1881.85 N 62 39 E 897.16 N 1732.11 E 1950.67 N 62 37 E 929.57 N 1793.81 E 2020.36 N 62 36 E 961.16 N 1855.30 E 2089.49 N 62 37 E 991063 N 1915.21 E 2156070 N 62 38 E 1021013 N 1973015 E 2221071 N 62 38 E 1049066 N 2029.55 E 2284.92 N 62 39 E 1077.20 N 2084023 E 2346.14 N 62 40 E 1104078 N 2138.60 E 2407.10 N 62 41 E 1131045 N 2191.22 E 2466009 N 62 41 E 1156086 N 2241.23 E 2522.19 N 62 42 E 1181.29 N 2289.07 E 2575.91 N 62 42 E 1204.59 N 2334.92 E 2627.33 N 62 43 E 1226.92 N 2379.16 E 2676.89 N 62 43 E 1248093 N 2422.40 E 2725.41 N 62 44 E 1253.42 N 2431.22 E 2735.30 N 62 44 E COHPUTATION DATE: 14-AUG-90 PAGE MARATHOM OIL COMPANY TBU M-3 TRADING BAY' KENAI, ALASKA MARKER BOTTOM 13 3/8# CASING GCT LAST READING PBTD BOTTOM 9 5/8" CASING DRILLEReS DEPTH DATE OF SURVEY: 01-AUG-90 KELLY BUSHING ELEVATION: 160o00 FT ENGINEER: MACKAY INTERPOLATEO VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1039e FNL & 602e FMLp SEC33 TON R13M MEASURED DEPTH' BELOM KB TVD FROM KB, SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH 'EAST/WEST 2712o00 264~o66 2484.66 14ToZ7 N Z80o05 E 7133°50 6375.S9 6215.59 1230o3a N 2385.91 E T176.00 6413.8Z 6253.82 1238o76 N Z40Zo44 E 7250°00 6480°40 6320°40 1253o42 N ,Z431oZ2 E 7250°00 6480.40 63Z0.40 1253o42 N 2431o22 E CO#PUTATION DATE: 14-AUG-90 PAGE MARATHON OIL CO#PANY TBU TRADING BAY KENAIt ALASKA DATE OF SURVEY: 01-AUG-90 KELLY BUSHING ELEVATION: 160.00 ENGINEER: HACKAY SURFACE LOCATION = 1039' FNL & 602" F~Lt SEC33 TgN R13~J RARKER MEASURED DEPTH BELOI~ KB TVD FROH KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/MEST PBTD DRILLEReS'DEPTH 7176.00 6413.82 6253.82 7250.00 6480.40 6320.40 1238.76 N 1253.42 N 2402.44 E 2431.22,E FTHAL IIELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7250.00 6480.40 6320.40 2735.30 N 62 44 E SCHLUHBEROER D I RE C T I ONPlL SURVE Y COMPANY MARATHON OIL COMPANY WELL TBU M-3 F I ELD TRAD I NO BAY COUNTRY USA RUN TWO DATE LOOOED O1 - AUO - 90 REFERENCE 740]6 · oWEL'L: TBU M-3 ' HORIZONTAL PROJECTION (~'i039" FNL, 602' FWL, bEC 33, T9N, R13W) NORTH 25OO 2000 1~00 1000 ,~:)0 -SOO -1000 SOU~H -lSO0 REF 74016 SCALE = 1/SO0 IN/FT --4:.-4---*--4 ..... -."---1.-4--4---..-+.+.4-4--.{-.4--4--4..4 ....... ,---*.-4---i---t---:;--4.-+.-.: ...... +--4--4---,.+¢4.-4---.:-----4..+-4--4.--..-4---.5.?'"---¢---4.-.,..4...,-.4.-4..+-.+-.; ....... ;---;.4..-~ .,.-.4..-~..;...: ...... 4...;..;~[ 4..-;..~..4 ...~4 ......... ;--~--4--4 ....... }.-4--4-.4--+.+-+-.¢-~ ....... ~.--~.---~--+--t-~.--4---¢-4 ...... {...~...~..-+-.4..+.-~...4--.~ ...... ~-.-~--4.--+...-.4.--~-.-¢---4 ....... ¢.-+.. +...~-.+..-~.. ~..4-..~ .:.--+ ~+ 4 .{. ¢..~ ~..~. ~.-~ .~ ~.~ ¢~ ~..~. ~ ~ ~ . ~ , , * : ~ ~ ..... ~ - ' , . ~ ~ · ; i .... i ....... , . . . . ....... ~ ~ ......... "i"T"?-h?*'??'?""TT'?ti"~"~'"r~ ........ t'-f'v"t'f'?t'?-'T ...... :"T'-;"T'*~'"t"?"T ...... ?T*'i'"T ....... i'"?T ...... ~"?'?T'?T*"?~ ...... ?'?T'"T'"T'"?'t"~: ...... ~"t-t't+!-~,-T LL.4..4.._L. ui...;.4..4 ...... ~..4..44...'..&L.i-.J ....... i...i...i...i..4.,.;...;..~...; ....... ;...LL; ....... ;...;...;...;.--~...;,..;..4...;,..;...;...;...;...; .... L..LL.;..I..; ;..;..; ;.;.;...;...L.;..; ~ ....... ~ .L.',: Y.J. -444.4- 4--+.4..4--.,..T++.+--,-+-+--~-~ ....... {.-.+--+--+-.4..-F-F++-.--~.+-F-~ ....... +.--F+-.+-~.--{---i--4...{ ....... F+--FS..* .-4---F.¢F.{--~,.-F-~..4 ...... ~..-~..FS..-t...F+.~...{ ....... +--.F.~ -4--~-~*~- *--4.~-4.-4---*~*.Q-+-~--- --+-4..~ ....... 4.--4.-~---4--~---4.-~-4--.4-*- -.4...,...i...~ ....... *-.-i-.+-i'--~ .--!---4--4-.4..-,.-i-.-*.-.*-.-*---..4..4..4...4..~..4..4...4..4 ...... 4...~..4...{...{...4..4...4...1 ....... 4...4...4...,... h..i...; ..;...~... _~4..~.~- ..$..L$.&....&4-4..;-...-4..4..$.~ ....... l-..i.-4.-.L4...L4.-4..$.-..~..$..i...~ ....... L.;.4..4 ...... ~...i..4..4...;--$..LJ...~ ...... ~...i...L.;..4...L.L.LJ ...... i...i...L.i.4..J..--L.L.i ....... 1...2..~..i ...... ~-;&;-J..$.&&&...*.&$.¢.*--4..$..L4 ....... ;.&~.$.+..L&$.$.--.$.$..4..4 ....... ;.-4.-4...;...~..4.-+.+.4...t-4..4..+..i ...... ~.-.;-.;---$.--.-~.-1...¢4 ..... 4..4..4...1-4..4-.4.4...i ....... +..-1..-¢-4 ...... '~77 ,"i" L..i_~..i..J..iWTW; ~ ~ ' "J"J"i ~ W i , WW T ii"3"'+" :'* i"* i"i ....... T7 ~ 71'"i ._[...; ..,, .iTTTT~ .L .~ ..... ~ i TT L"i"' L**; ....... 7 : W ; , : : ~ , ~ , :L"i'* L..i...; ..4...1..~...4...$...;...;...;...; .... ...... ;...l... L.;7 ...... ........ ;...;-.;..4 ...... {.-.4...4...¢..4..St .......... ....... ;"'; ...... ¢...4...¢,..¢.. ..~.~-t-~-~..;-..~.~.-+...+-~-+-+--,.-+.4.-+-~ ....... i'-'{'-~'"; ....... ~-.+.4.--+ ...... +---+---i..-+ ....... {--+-'4---i"-~ "'!"+'+'+" ~.-+.-+--{-.4---..4.-i-**+...; ....... {...+..4..~ ...... i"'r"+'"+ ....... +"+"~'*+ ....... -;..$..4.-&t.4--4.-+-+-..-+-4.-+-+--..-4-4--4--4 ....... F+-4.--i ....... i-4--4-4 ...... ~--+-.1.-4 ....... ¢-4--4--+--~--4.4.-4..+.-~..4.--~-4-4-----4--+-.!.4---4...¢4..~ ...... ¢-+..~..4-...-.4..--~.-.+...; ....... 4...+.4.+. -4-4---F&4--$-4.-4--&-..-4.-4.-4.-4--..-4.-4.-.¢4 ...... F+-4-4 ....... 4.:..&..l ...... i-.1-.-¢4 ....... 4-4-+-¢-~..+-+.4-.+--;.4-4.-4-.+-..--+.4-+.;-.-r.+-.~.-+-4 ...... ;..+.+-.~ ....... +"-;"+"i ....... t'-~"-+'+"h¢'+"4'"+ .-;.~..i.g..,..J-;.4.-4.....;.4.4..~...-4-4...~.4..-;.4..4...i ....... i--&4-4 ...... !.-4-4--4 ....... 4--;--+.-¢.'---4--4--4--+-,.4--i--+-;.-..-.4.-.¢-.¢+--'.-;.4.-.{.-( ...... ¢4..+.-{ ....... ~.-4..4.--+ ....... +.-4.-.i...¢..~-..~.-.~..+.-1... -~4-i"+'~"+4-+'+" .-+.+-+-+-.--+4--+-~ ....... i'-~'-~"i-*'+'~"+'+'-"+"¢+'+'" '-+"f'+-i ...... i'"f'?'?"'~'+'i"i'"' '-+'+-'¢'¢~"'f'+"t'~" ~"T'T'?f" "'T'~'"f"f'" "~"+"!'"f" hi'"!"+"i ..+.+-~.+.. -.+.+-(.4.....+.+-?-+.-.--~--4--+-+--*~---?.+-+.+.+-.!.-+--i--- "+'+'i'-'f'"'-~'"f"f'i ...... f'i'-T"f" :"~'"f'T"f'- "TT"f'T'~'"f'+'+'+"~"T'T"?¢ ....... ~"T"!'"i ....... f'??"i ...... f"f'T'T" ~$..~-~ -4.4..&~....4..4-4..~.....4.-4...;..;.- ....i-..1..4...1--4-;.*-¢--4..-~ ..... ~...i...~..4 ..... ~..+%..1 ...... !'-+-+~"- -.+.-!*.-i-.*..-. -.+.+*.i...i-.~ ..+..~---t-.~ ....... !'"i'"i"~ ....... ?'+"+-i ....... i'-~-?'*~ ....... ?+'ff-'i .... .~..$.$.$.j..$.$.$.&. ~..$.$.$.$.....i.~...L2 ....... i.-&-&--L$..L$-i..-i ...... L.i..-L$4..$..i..¢.-i ...... i...i..4..4 ....... ;..i..$.$.-..~...i...;-$..~..4..$..~..4 ....... l...i...i...i ....... ~.&..~..i ....... 1..+.4...I ....... ;-.i...i-.l · .4-¢4-& -i--¢-$.4-.-L$-4-4-.4-..--4--4.-4.-4 ....... ¢-i-4.4.-4---I---¢-~-4 ...... i.4-4.4.-.{..-i--~4-4 ..... i.-4--¢-¢-.t--4---¢.!..4---.-.4--.i-4-.¢+--¢.i..4..4 ...... F.¢.i-4 ....... i..4.4-.-i ....... 1-.4---i..-; ....... ¢4.-4.-.i ~..;.~..¢.- -i.~.4..4.-. -&4..~.-;....--~--.~..~ ....... i..*;-.;.4..~..4..~.-~--; ...... ;--+.+.+-+-+-+-4-.-i..- ..4.-4-4--4N*.4-4-i-.~-...-4.-i--;.--~--~.---~.-.i-4..+-.--.¢-!-.+--¢--..4..4..-¢.¢..~...~ ....... · ;i.i..;- ..$.$.&L LLLi~..'.-i.&LL-A...L$..LS-.Li..$..i--..!...L.i..$.$..L.~.i.$_ F.i..LL.i......~...LLi-....$..Li.4..4...LL-i..4 ....... Li...i...L ~ · ++-+d .... ¢+-+-+-.'-+.+-++--"-+-+--¢~ ....... ¢-i'-+-'+'-~--+--¢-ki ...... f-+-+-+"~"+-+*-t-+-'~'-+'+--~-~ ...... ¢i-'-?+-----+-+-+'-¢+-"}'-+'-!"~ ...... i'"i-'i~'"t'+-i'"t-',"'!"~*"f"i ....... f'-f-'f*-i .... .-p.i.-.i..4....-~.-~.-4..~ ....... ~..~.-+.+..-4..+..{.-~ ...... i---%+--{--~'"{"'+'+"i ...... %4"+"i ...... i'-{---i--'i.-- ~---i'.-!--~ ....... +'-i--*{---{ ...... i--+-+--{--+'-+'*i-'+"~ ..... ~'~'"~ ...... +.-i --~'"! ...... i..?-!'"~ ....... ?i"-i-"i · 4.-4.~-+-'-i--$-¢-$- ..-~-$.~.~......$.~.4..4 ...... i.--¢.-~..*;-.+.4..-;.-4-..i ...... ;...L.i..4 .... i.4..7.-4 ....... i..4..4..4.-.-4..4..4-.4.., ..4--4--.i.-.;..-i.--;-.-i..+-4..: ~-.4-4 ....... i..4.--{.-.i ...... !'-4'"~'-'~ ....... i-'i--i-..i .... .~...i...~A._L4...i..$.;.....$4..x..$..4..i..i..~ ...... Li..i..i..$..i...i..&.i ...... i...L!...i...4.4...;..$_L:...;...~..L2 ....... i...i...i...i...:..$..i...~4.-4.~..~.'.~A...i ........ L.L!...i ...... L.L.L.i ...... i...i...Li .... · -?+'i'¢"~'f'4"+'+ ...... ~'-+'+'+--,"'+'+"!"~"-"+"f'?f'4"'?'f+'i ...... f"f"f'T"~'"?f'?"f":'"f'+'~'"f"-'~--T-f'~"~--~'--?~yj? ....... f'-f'-}-'i--""T-2'-T'i ...... t"¢"'r"?T"f'T'? M-~ {-4--~--444--4- ~-4-4.-4.-4.-4.-4..4--4 ..... 4---4.*-~.--4.-4-.-4---4--~.-4 ..... 4.-4.--4---4 ...... &.-4---4.--1 ....... &~-~--4 ..... 4---i.-.4.-.4.-.~ ..4.~.M--1..4-4 ....... 4-.4...*--4 ....... T ..... i--4 ...... ~-.-4---4...~-..r-.4 ..... ....~ .... ...,-~.+~ ...... ,.-*-*.*-*...*.*.-.*+-4--~.+-~..~ ...... +.+++4-++.+-i ...... i--~ ....... + ...... +-+*+' -'+--,--*-,'--'--+-+++.-~~~'"~", ...... ,"T"~ ........... t'*'?"" ...... ,""'"" ''~''F''-''''''''' .... ' ~'~ .... · ," .*'~-'-~' .'~ .' ~ . '~*~ .... ~' ~ ? ~'] ~ ~ ~ * ~ ~ T ~ T T T T T T'?''' "~/-~ ....... T''?''' T ~ :"'T ~".' T - I ~ T , : ~ , . · z . T : ~;4 -;-. · $.4--;-4-- .-~4..4..~ ~-4 -44 - i -4 -4 -;- 4...1-.-~.-4...1 .... *--.~.--~--I--4 ...i.--~--4.-.~ ...... ~.--i.4--4.~ ~--~i...i-.*~ ..-t-.~-~...l.-...~...~...1.-~ ....... 1...I.4..4 .......... 4...I...i ...... ~-.4.--~.-.~..-t--.~-.4.-4-.-t !--/ I · : ~ : * : : : ~ : ' : : : : : : ~ : : ; : : : : : : : : : : ; : ~ : : i * : : : : i t : : ~ I i : : ; ; : } : ; ; -w ¢--~- -+~ ............................... 4 ........ ~ ........................ ~ ....... ,---.~.-4 ......... , ...... ~ ...... ~ ....... , .................... ~ .......... , ........ , ............ ,.-*-.=?.-.i ...... ?. -4-4.4.4 ...... M-4--4--- ..-4--4-4.-4.--. 4-4-4.-4.-- ~ ~ ~ ~ t i i ~ i ~ i ! i i i ~,~ ~!~ i~! !~i~ ..4..+..f..l .... .... ...LJ...;..~ ...... ;-4...~...~..-F~-4--!...! .... · .--~--~--- ...... ~'--~-~'*-~ ....... ~"~"~"-- ...... ~'" , "~ ....... ?'~'~'~'*" *'~'"*'*'~'"~"* "~'"~"'?'~ ....... ~*"T'"~"~"- .~.4-..k+- -~.~-.-+.++.4.......4.-~-¢¢~ .4..&$..i.-~-$.$-4.-.{ ..... L&$..i-~i[.--~-.$-;4.-....$.~..&.i-.&4...;...;.- -~..+-+-~ ....... !--+.+.+.- ?'TTT'" · "~"T'?'r" "--?~--r-'~ .... ~'T'T~-"7~-T'T--TTT'7-""T'T'T'T~ '' ~ ~ .... *' ...... ..+..?.+..+... .~.~.,.~.. ..... ~...,...?+.+.~...+...+..~...+ ...... +._,..~ ....... ,..?,.+...~.++.., ....... ?.+.,.~ ...... ,.+ .............. ?..,..., ....... --4-~--~---~-.- ,-,.~.-~.-~ ....... ~.-.~-.-~ ....... ~---~---*--.~ ...... F-.*--.*..-~ ....... ~..4.-~..~ ....... ~"'r"~"~"' "~"-~'"~'"~'- FT'T"~ .... · "T'-~?"T ..... t'T'T"T ....... r'T'T"t ....... ~"'~"'r"t ...... t'"t"'7"~ ..... ~"'t"'t"~ ...... r"t'"T'T'~ "T"T'"T'"~"' '+t+-~, , , ....... ~..+.+.+.....Xe+.+.. ...?.*,-~ ...~...,..~ ..... ,...,..,..~ ...... ,..,._~..~ ....... ;...,...,...~.....,..~..~...~....++..~..~ ...... +..++.,...~.++.+..,... 'TTVT'"'i'i"i"~ ..... ~i-ii"""*'*'*'=,,.. ...... ~ ~ ~ ~ ~ ~ ~,~ ,,,, ~,~, ',~,'"" ....... T":-T"~ .... -4-4.4..~ ....... t?i"T ...... ~--*-+-+'-'--?='-++,"+'+'+'+""+"i"+-+ ...... ~-4-4-4 ....... ~.-+4-4 ...... ~--4..+.4-.-~-4...~..-v.~ ........ ~-'+-'~'--~-" "+"-~'-+'~ ...... ?f"t'i ...... 4""~"'~'"~'" ' ' ' · -4..4.-J...;.-. ..~-+~.-....~.~-.-~..~ ..... ~.-~.,.~ ...... ~.,.~., .... +++..+-....++.4.-+ ....... +-++i-"--$4"$-'~"'?~'-+"~ ....... ~...+..~.., ...... ?.,..+...+ ...... ,.-.~.--~-..~...'.:::~::~::~:::~::::--.~.++..~ .-.,.4++-...+4..+..;.-.-+4.. ...... ~..+4.4 ........-+-+.-+.+--+-~...~..* .... $-.+--~---$ ...... ¢+'+-i-" · -~.~..**.~**....~..$-..--~-.. ---****~-.~--..-. -.4..**-~-~--- ~,' ~ , ~ ~ ~ ~ ~ i ~... ' ~ ~ ~ .&~..$.4 ....... $..-$-~.-4---.--$-4-~-$....4..+-+-.~.-4 ; ~4 ; $ ~4 , , . . · ........ :::::::::::::::::::::::::::: 4-~-4.~ ....... 1.4.¢.4......4_~..$.~..~~,~ ~ ~ ...L~.~...~... ,~,~ ~ ,~ ~ ~ ~ ~ .... LL..L: .... .......{..4..-~... -+.+-++~..+.+.+--~ ...... ~--+-+.+ ....... ~.-+-+--+ ...... f-+.++..-+-+++.---+-+-+..i ....... ~..+-+..-~ ....... ?+..f.-~ ...... .4-*~-*....-.~.-4-.4-4-.--+'{"¢4-' --4--4--4.-4.-~ ..4-4..&-4 ..... ~-* ...... L&4.--~ ...... *.4-4-..* ....... ~..4-4.-4.- .4..4-*--4-----&-.i..-~...i-.- ..4..4-4..4 ....... ~4--.;...*..-[..+~.~-+ ....... *..4...~..-1 ....... ~..-~--;.-$.- '~-*~-i~'44-"~&&':+~?4[['4~$4-4'4"'i"4"4"'t 4-444' ~4--+-' ' ..4-4..$.4..4.4..$.4-; ...... .4-4¢4~4..~4._ .... ~' ..... ~ ~'~ ..... ~4.&.~...-~4..&4...,, .4.4.4...i...-.4-z.$4,,., , , ~, ...... ~..;...;..x,,: ~ ...... .4-.~.4...;-.-,, ~ ..4..+.+-+.....-4..4--4.4, ,~, .... .... ....... ....... ....... t'T":¥"'::: ,,~' L~..,4 ..._,.$4.4..&_.4 .4_~... : ........ ~ ~ ~ ~$-4..~- .4 ¢¢-L...$-i.~.~..'~.$~ ....... i...L.~...L-...L~...~..$.:...LL~-i... ,,, } . ,.~ ..... ¢ ....... ~'T'"'4"4-4"¢'""4'4"¢'4"'"4-4"+'4"~"+'4-+'4 ...... ~--+-4-;-.- .-+4-4---{ ....... i.~4-i ....... }...~..&4.....4..$.$.4 ...... ~...;...~-.i ........ [...;...~...~..~...;...~.&..~..-;...~..4...~...;... -i.-*++-'--*'--+-+-~ ..... ,---+"-,'--,----*?--t'? ....... *'","'='~ ...... *"?"*",'" ;'4"4'"4"4 ....... ;.. '...;.4 ...... *-.-4-¢..4.-- ++~+--++-+-+--++-4-4-~-~.+4.--+--~.-+-4-+--~____, - --- ..... {--f~..?.- ' ....... ~:~ ~ '~ --;-4--4--4.-- --~.~--*~'~--~ --~-~-~--'~ ..... ~"~-?"~ ...... ?'?"T'"T ...... ?-T*?"T "'T'"T-~''~ ...... ~'"T"'T"'~ ........ r"*T"'~'''~ ....... ~'*'~'"~'"? ...... T'"~'"~"~ ....... ~'"?"? ....... -~-+.~...~.-...4..4...,-.~--~ .-., ...... ,.-.~ ...... "*"'"T"'~ .... ~...~...1...~ ........... F~-.-, ....... ~..4 ...... ~"' '*+--t"~"'~ ....... ~*"??-'~ ........... ~"'~'"~ ...... ?'"'~"'~ ....... ~ ........... ~ ...... ~'"i"'I ....... ' ~' '' ~ ' ~ .... ~ ........ ~ ........... ' .... ~ ....... "'+'4'"I"'~ ....... ?,'-'?'4--' -+'~-~'-+--' "+~-'r~-' '~"~'+'~ ..... ~.-~-+.+-- -+--+'-~'-~-' '--'~"+~'-t"" '-~"+'+~ ..... +--+-+-+'- "-+-?"?'--t ....... r"v-?'--* ...... ~.-?...,---~ ....... r"~"f"~ ....... ~ ,..,_..- · · I ! ~ .............. ~ : : ' ~ , . ...... ~..4.-+4 ...... ;...+-4.-+.- ' , ...... ~ ~ :. i i~i i i i il -&X-~..~-~..4..4....+4+~ ..... ,..¢.~+-~.4..4-+4--44-4-4..--4.4.44...[.4...¢4-.-¢...4...~..H..--++4..~ ...... ~--+-.,.-.~.-...-4.-4+-~ ....... ~-.*-$..~ ...... ~...,..a..$.. 2Tm'""q-rT'T".4..4_4.&...4+~ .... &~.....~..*..4..t ...... *..4 ...... ~-...4..4..4--4 ....... ;..4..4..4...~..4...,...*..4 ....... *..4..4-..* ....... * ....... I..~ ...... {..+..+ .......... +.+-+..+ ..... ~..¢~-4 ....... ~--.~.-.~.4 ' ,'T'T'~ ..... ~"T'+'+'""t-¢T+'" 444 ~ ~ $-4-. ~-~-~ .... L.L.L.... ~_ ~ ~ ~..~ ~ L ~ ..... L i...i..$ ...... L-;..-;..~.....4...;..4...L--.4...i...~...~ ...... i..4...~....; ....... ;...~...;--.i ....... k"~'"T"'~"'~'"~'"~-'~'"{ I · : i I : , , i I : t , : : : . I , I i : : i : , . -~-+~.-.-M-+-+---~-*4 ..... ~.--.-+~-+4 ..... ~=:~ ,~-.~..~-.-+.+.,..~ ..... ??-,.., ..... +.~.?.~-.~ ..,-=..?~ ....... ,--.,-.-?~ ...... ~..4.-.~-~ ....... ~..,-.,..4 ....... r'T-Ut"~"i'"f'?f" -+.4~.*-~.~..4..4-.i ~ ' i ~ ~ ~ i 444 ..... 4 ~' ' ; .................. * * .-+.+..~...~ ...... ¢.+.--¢-+ · '?*~" ~'w"*'~' ' ," ,",'": ..... r'-rT"w "'~"'f"~"'~" '":'-~ '~'"~ ....... ,-"f--?t--"'?'5"?'f'" "?t"t'-5-'"T"v'T"~ ...... r'T"T"T'" '"T'"r'?', .... ~-&~.x-.44..+.~ +~. -4~..~... -~..+.~ 'f'+'+'t"-+'+++'""+'+++"~"'~'~"++'"'~-+"+"~ ....... +"++'+ ...... :'~'"~"~ ...... tT"'"T""T+'~'"t ....... *"~'"f"~ ...... +'"+-+'+" ~-4--, {:= +~.- _&~_&&.-&.~ ...... i..4~,4..4-,-~..4.--T .... ~.4..4...~ ...... $.-~--+-+...-*.+.+..~ ....... ~..+.+..~ ........ ~-$...$..4 ........ ?-+-+.--[ ...... ?+...$.--~ ....... t.4.-.+.--~ ...... +'-~ ....... ~ ...... ~..4-4.-$ .... ~'&& .....i4-4"4"4'" .&,.&&....&4-$.4 ..... i..4..+-i..&4..4..-F.+ ..... $.4.4-4 ....... +.4-.4..+.-~--4--+4--+-..-4--+--F.{ ....... ~.-+..;.--¢ ....... [..+.-~...4 ...... ~.-+..~...~ ..... f.-~...~...+ ....... *...~...~..-~, ...... ~...*.-.~---~ .... -I000 -SO0 0 500 1000 ISO0 ZOO0 2500 3000 . ., WEf',L: TBU M-3 (~'1039~ FNL, 602' FWL, oEC 33, T9N, R13W) VERTICAL PROJECTION -SOO 0 0 SOO !000 IS00 2000 2500 a000 asoo .4....;.44.,.!4...;...~..4..~,...i..4..4..-.::.4.~...!...i.~4...~44~.~..H..h:.`.~.i...! ....... i--4-.-i---i4-.-i.--!.-i---i ...... ~--~..i---i.4..!..-!---i--i ....... !.-..r!4---!...!...i...i.-.i ..... !..i.--i...i.-.!.!-..i.-.;-.-i ....... !..i-..i..;--~"~"~'"i-'-i'" -4.~.4...~"J~.~...~....;..~.k..~........4...4....4`.~.4....4...4...4....4.".4....~..~....4..~4....~.,.4...4`..~k..~...~ ....... ~---4---.;....-4-..-t--~-.-~---~'---~- ...... ~'"~'"'~"-?'"~'-?"'?"'i'"'? ..... t' ~'-?'"?'"'~'-~' '1." ~ "!' ..... !'' ?' 1'' ?' I~ ? ..... ? '1 ...... 1'' 1'' ?'"'t ...... ---;.".4---~.--;:--½.--;:.--~---;:.--~ ...... i.--i.-i-4---~,.--~----i.-;:-...;---h-i-.-~-4-.-~.-.~---i---!.--~---~ ...... ~--4--.;:.--;."---~--.-~...H-.-.,' ...... h+'-h--ht"?:""~-"i'i ..... i"';' i4--? ~' 4.i i- i i'i' it '+ 'i 'i.-i !. i-i.. ...;.-~.--;L.-4.-.4...4....4....~.....i. ...... ;..~;~..&...½..4..4...4...o:..._ !-4...;..4...;...t...~...4..4-...~ ....... 4---4-.-¥-,~----~----~--~..-~.---~--~ '"~'-"+"'~""~'"t"~'-'?'"~'"? ....... 1'-...?. ~;..-+...tl...~...?.-.~. ~ ..-~ ..-~.-.i-.-~.T- +..-~--i .i ..... +..4 .-i...,.. ~r .~....;....,..~... · '4'-+--'~-~',--+--~--+---+"~ '".'"~"'+'"i'"~ '--?~-'-+--4--' "+'4---+'--+--T-'~"+"~'"~ ....... ?'~'"f'"+-T"i'"~'"+'"+ ...... ~"+'+-'+'"V"+"'~'"~'"t ....... t ....... ~...? ,..?-~...?~ ............... , ....... ,"4"' '.. ~...4 ....... ;...4-..+..~..4-.~..4...*..4-.. -.4..4...~.4 ...... {.-.1---;---{ ...... 1...+...i--4...;...;--4-.4..4.....4...;..-k.4---?.;.-4-..;..-4 ....... ~..4...4..4...f..~..4...~.~.¥~..+.4...4...;..1...;...¥.;...;.`.~...;...L..~...~..4...;...L..;...; ...... ;...;...;.4...f.,..+..,...¥.,...e...,..,...,4...+ ....... +..+.-. i 4 4 1 ..... ;...L..;...~ ....... ~...~.--L.-L.4.....4...i...L.i...4...i.-4...L.i ...... L4.4...i..+..;...L-.L..~ ...... ;...4...L.i..+..i...;..-;..-L..;...~...;...;...4...t...;...~..4.4 ...... 4...~...4...;...,....V...+..;..~ ....... +...;..;...;...f...+...4...;...+... l..4.-+.+--.-4.-.i-4---+ ...... ~k!'i--',"!'"+'-+--~m-l'-f---~---+"+-'t'"f"ff-'?"t ....... t"~'"r"T"T","~"'T'"T ......%'T'"%'T"T"T'"%'T'"T" r"%'T'":"T-,'"T"%'T'-; ...... T'-?T'"T"'~"'%'¥'T"'T ...... T'"T 'T"T ....... .... ¥-¥.¥-¥-!---~---¥.¥.~ ....... ~%~--4-4--~--4..~--4---~--4---~.--i---!---h-i.--i ...... i--,--?-i---t-.-!--.!...i-.-! ....... !'"?-!--'-h'i"-i'-i--'i'-'i---~--'i--?i"--?-'t' 7"~"~'"7 ..... 7"¥'7'T'I"¥?-; -;" ;":-:'?"i ...... .... . .... ~ ~ ~ + ~ ~ ~~..~ ..~...~ .~ ...~...~ ........ ~.-~...~--.~ ....... ~..-~.-.~-.? ....... ~---~.--t--.~ ...... ~--~,--~.--,- ~ ~ ~ : , ~~ . . ~ , ~ T .... T'~'"T"? ~ : ~ : ' : : : : ' ' ' ~~4-'-¥-'~ ~ ~ ~ ~ ~ ~ : i ~ ~ : ~ ~ ~ ~ ~ ~ ~ : , , ~ ; : : i ~ ..... '...L..L..~....~...~...'..' ..... ~..4..4 .......... J...~...~...;... -4 ~ ' ~ . -~ ~--4-.-~---.-.~---~--~---~--. --~--~---;..4--~ .-4---;-.4-.-~ ...... - -,'"~'"~ ........ '"~"-+'"~ .......... ?"T'"~ ...... t'"t ...... ~ .... t'"t'"+"~ ...... t'"~'"~"~ ..... ?"~ ...... .' t t ~ ~ . ~-~.-~'-"-'-~'-'"'~'-'"'+'"t ....... +"'?"'?'"?'~"*'",'"~'? ...... ,...?.~...?...,_.~,...~ '"'-T"T"~ ...... ' ~'~'"" ~ ................ , : : : i , , L4 4.~ ~- ~...~..4.-; ....... ;. ' ' ' ..4...~..-;--~.-..4-..¥4..-~ ...... +--4--~--¥-- '.-?.-, ....... +-.+.-~---~ ...... ~.-4.--f.-4---~--+-+--?-~..---?+..+.-f ...... ~..-f..-f.-.f ...... ~'"?'i'"f'"'"?'+'ff"'f ...... t"?~'"~ ....... ~ ~ ~ : : : : : ; : ~ : ' ' $ g .... -~ ¢ $ ~& 4 ~--~ ....... '.-.~---$ ..... ~--.~.--$.-4 ...... $..~--.~.--~.--~'.-~.'+--?--~ ...... ~-'-~--~"-~ ...... ~'"*"-~'"~"-"!'''~'''~'''~ ...... ~'"~"~ ......... ~'"~"~"'~'" 2~:ZZ:%:1~2;:;.:.+111.4..~-..~.4 ...... ~---~-4..4.-~..4-4.-4-4---,-4.-4-4---~ ...... ~--4-4-4.-..~ d:-~-~h~-.-~-..¥-~.--f-.,.--~-..?4-..t.-,..-?.-~...~ ...... ~..-?.~..-~......i...?-i-.+-. ?.f-]..,-- .q.-4...~4 ....... ~...~.-.¥+.-..4.4...¥4...t.4---~-+--q--4--4--4--4---~-d--+-+--~ ....... ~-.+--H ....... f--t--f--.f---.-~/~.f.-f-4--.f ...... f"ff'"?'!"'t'"?'?"f'"f ....... ,"'t'"f'-t"".'T't"T'! ....... ?'¥!"! ...... r'm'"t'" .... +.4...~..~.4...;...~...~...; ...... ;.-4...;..-;-..f¥---¥4---~-----4--¥.q-.+--f--+-~-+--+ ....... ~--+-+--~ ....... +.-?--+.-+ ..... ~~?-+"f-'-~-'.f"-f'+-~'-'r"f--~-'-~'"t ...... r"r"t'"t"""T'?'"r"t ....... ?'r'T"r'-'"r'~'"r"~'" ~'T'T'q ....... ?'F"~'""T"T"T'T']"T'TTT' "T'T'T"T;I ~ -{; ~ ]..?. ~..].J...[..i...~...~.;...L ,...L L..L.L.g...L..L.. %..¢~...;.-.; ....... L.L.L.L.4..4...L.L..~ ....... '~-T'~""F""?'?'~ ........ '"?'~"T'"F,"T"%'T'-f"*"~'"%%"T'~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i ~ i ~ : : ' ~ ~ : i ~ i ~ ' ~ i ~ I , ~ ~ ,.4--++-, ....... ,..+..~.-....~...~..+.+++-+..,.-~..--+.+.+--~ ....... ~--+-+--, ....... ~.-+-+.+-4.-+--,.--,--.,--.--??--, ...... ,.-,--?..-? ~-~q'", ......,'","-,"+'""~ ...... ,"',"'"'+"?'?"* ...... ?","','"~'" '4 ' : 4 ' ~ : ~ : : ~ ' ~ ~ ' ' : : · -- ~ ' ~ : ~ :_ ........ L..~...~...~ ...... ~..-~..4..4 ....... ~..-' '..4 ...... ~..¥..~...~ ..... 4...~...~...' ....... ~...~..4...~ ...... ~...~...~..4... '-~'-?'-~ ..... ,---t--~....-.-~n~ ..... ??'--?'T'T"?' M~ ~A~, S~!~ ~~ t ~ :. ,. i, Il ~ ~ ~ { ~ ~ { { i ~ ~ i i i ~ ~ i i ~ i ~ i ] ~.J.i { i } ~i ~ ~. ~ ! ~..~ ....... i._L..L.~ ....... }...~...L..L...%L..~...~..~ ...... L..Li..i ....... ~...L.L.$... ....... T--~-~ ....... ?.-??--! ..... ?!.-?--r--t--~---??-~.-~--?--?-'?--t ....... T---F?'"? ....... T"U'"T"'/"r"."'T"T'"T ...... T"F'T-T .....T'?'"T T { T ? ~ T T T T ~ ~' ', ~ ~ } z .4.4.-4..4 ....... ~-~--.¥.~....4-4...;...~..~..4.-;-~--~.~.-4.4-.4..4.T+.-~--+--~ ....... +-+-+-+-+4---+-+--~.-, .-+.+--+~-- '-+'+-+"~"' r'"r"+"t"~ ....... r"r"f"T .....T"rT~ "T~" ;'"?'?"~'"~ ...... -4.4.-4-&.--~..4-..~.~....-+-4-4--4-4--4.-~..-¥-k-.-4.4.-4--.¥+.+.4--.¥-~ ...... ~-+-~.-.+.-.+.-+.+..+...f ...... +"+"+"+"t"+'+-+-'?"f"?-'i"-?'~ ...... ??'d-"i ....... i'"i'"?"i"""1"1"i"'~'"r"!'"i"!'"i ....... ..4..4..4..~--$..4...;~--¥4.-.¥+..+..4--4..+.4..-.-4--4--+.-; ...... ¥4--4---~ ....... +--+-+-+-.+--+-+--+.--i ...... +--+-+-+--~---i.'+--i.-'i ...... i-"i--ff'-ff ....... ?'+"!'-i ...... T"'t"t'T'"'T'?'t'T"'"T"t"r"~ ....... Tm'FT" -,-~.~¢ ,~ ~ .-,...~.~.~..~..+-.,..-~..4..,..~...~--~--,..-~..*~.~..~ ....... ~ ....... ,...L.~...+-.,..~ ..... '---~'-~--"4"'*"*'"+"' ...... ~"+'"+ ....... k+.++-+ ...... ,"-?'?"-"* ...... ,-'?""?'*"+"* ...... -'t ~ ...... ~- ~ ~- ~' 4..+.-+~ ........... · ........................ . ................ * ................ '-4--'~ ............................. 'T : : · .............. ~ ~ ~ ~ ...... ~ ~ : , .t · . :I:i ;:Z; :i;! ~: ...k~ .4..;..;..4.._ 4 ;4; -~...~..4.-.~--.; ...... ~-4.4.4...~-.~-.~4.4 ...... ~.4.4.-4-..~...~...k~.4 ...... ~.4...~..~..;..I-4..4...~ ....... ~.-.~-..~.+-..-4...~-.44 ...... ~.-++-.~ ..~...~...~.~..,...L.L~m.,,..i4...~4-....!..LLZ-..4.4.Z..~..i-.~..4..-~.4 ....... ~..i..;...~..L;4...~...~._...~.4...~...~44.4...t.; ...... L.~4..4 ....... ;...~...~..~ ....... ~...~...;...; ..4...L.L.;... k~...~-.4.4..-..4..-L'~.4... <~..++..,4.4...O:-~4-4..~.--4.-4.4-4~4-4-4-4-4-4--~4 ...... ~-4-44-+-~.4.-.~ ...... ~-Y.--~--4-.-~--.H-.-H ...... 4-.+--~..4 ....... ~..++4 ...... ~'"Y!"i'"'"~'!"'H"'"'4'"~¢?'d'd'"f"f" : I : . : ' ' ~ ....... - '. ............. ~ , .~..-+ --~...i ....... +--*..-+.-*--- -~---*---*-~.-~-*...*...~ ...... ?.--*-? ...... ~4-4-.+-'.-4-4-4~ ~--+-+-+.-¥-.--4--4..-L4.---4--4'-+-4 ...... ¥+-+-?--.--??.?..r+--r-'r-'r--~ ...... r-x'-r--~- ~: :-: ~ x ~ .............. , x .... t--'H-~-"-'¥-4--4--4 ...... k-?--,.-4-.--'4"+-'~"4'+4'-4"4'"~ ...... ~'+'H'"h~"'t'"?"~ ...... ~, ~,, ~:~ ~, ;, ~ ~ F~ ~, 4 ~ ~ 4 ~ 4 ...... ~-.,~.-4.. ~-- -~...~., ~..4 4 4 4 ~-.-4-~...~-..~..-..-4...~..,~...~ ...... ~-..?.,4.-.+.---.4,.4..-~..-~,.- ..4--+4.-4..._ ~ ~; &. ~ ~.~_; 4; ~ 4 4; ~; t 4-~ ~; .-;.4-L.L.t..~..L.~.-.; ...... L-L.L4...:...;..4...L.; ...... ;-..;..4..4 ....... ;...;...~...; ...... ;...;...;...~ ...... 4...;...~...; ...... +.--..4..., ....... ¥4..4..4..- ............'-?T?' ...... '"'" .............. : . . T"TT';. .............. .... 7'T-T'"T ....... T"T'T"T ,'-T'"T"T-T"'"TT'T"T",'"T'"T'"T"'T ....... T"'T'-T"'~ .... T T ~T .. T. , , , , , : , , ,' , ,',, -4 4 ~.~ -4 ~ ~-~ ~.-4--.~-.;.----.4.--~---~.-.~--...4...;.-4...; ....... ~..4..4..-~ ...... ~.-4.4.--+ ....... ~"'~'"*"+"I'"f"4'"~-'~ ...... +-'i'--?'~ ....... ~'"+"~-'* ...... +'"?'?'~ ....... ~"'f'"~"'i'"i'"'?'r'+"~ ....... t'"t"i"'+ ...... ~"'~'"?" , ! ~ ~ ~ ; , · ~ : ! i ! ~ ~ i i i ~ i i!; : ; ~ : ! ~ ~ : q ~ ; : : : : ' ; ; : ~ ~ : ' ' : ...... '...¢..~,.¢.,.4-4-,4.-.~.-' ...... ~,-4--4,~..--.-~ .... ' ,- ,~ ........ ~ +..+..~...+....~..+.~...~.+.....+..~...~..+....+..+...~ ~ -~ ~ ~ + ~ ~ ~ $ -- ~. ~-¥,-~.~.-4--~ ..... ~-.-~---$.--~ ....... ~'"$"'~"-~'" "'~"'*"~'"~ ...... +'"+"~'"+'"~"+"~'"+"~ ....... +"+'~,, ........ T +'?~ ~-~"+" ' I ' I · : ~ : : ~ , I : ~ : :: ;~: I ; : ~ I ~ . : ~ ...... ~. ' · .'..~ ...... ~...~....~...~ ...... ~...,...,...~ ....... ~...~...e..-~ ....... ~.-.+..-+..-, .......... ~"4"~"~"'m'tT't""'~T'T'T"'~'T't"T" 'q ..... T"T"'q?T"T'-'"'T'T'T"T ...... T ...... T"'T"~'TT"T'"T"; 'T'T'"T'"~ ...... T'"T"T~ ~ : ~ : --.~--4-H-.~-,-.+-+.+~.-,-~.-+.-~.+.-'-+--+---%e-- "+--%+--~ ....... t--+--~--+---f'l"'t--~ ....... ?-f'--t'--r-~"T':"'r"t"~'"t'"r":'"t ....... t-',"-t", ...... t--ft"-: ....... t"~'"t"~ ...... .?"',"'~ ....... f"," F" ;'": '" F'T'¥"[" 4-4 ~ ~.---.~.-4-4 4 .--G ~4. ~ - 4 4 ~-~ ~ ~ 4 ~ .... ~..4..4--4----4.-4.-~.4.... 4..+..4...~.4 ...~..4..-~..4..-~...~...~...~.--~ ...... ~.--~...~-.~ ....... ~"~""P"~ ....... ~'"~"'~'"t ....... ~'"t"'t"'~ .......... ?'l'"t''~ '"%'t'" ,"'. ' , , i , i ~ i : :~i i ' ~ . ~ i ~ ~ ~ ~ ~ i : ' ~ i ~ ~ ' i4 i ~ i ~ ~ ~ ~ ~ ~ , ; ~ : i :-....~.-.~-~.-.:......4..-~...'..-' ...... ~..:..4...~ ...... ~...~.4-4- ~*-4---.'+'"'~ ....... 4--' -~-*---~-4-' "* .........., ............. . ..... *"*"?"-~"* ..... ~"4"?'4""T.'''~'-~''~'''??~ ......... ??"t'? ...... ."~'"'"'~' ,:.: '. ~ ~ ~ ~'. ~ ~- -4-.-L-L-~ ...... ~,~.~ 4 ~ 4 "-.4-44---~ ...... ~..4...L4 ....... ~.~4-4 ......~-4-4--4 ....~4'-4--4--'t-~-'4--4"'~ ....... ~'--¥+'~-"'4'-'¥'~"'~ ...... +'-+-4--ff-'"--4'"f'--f'--f ....... f'"?'~'"?'4'"f'+'ff'" 4_4.~.~_.4 ~ ~_~. ,_ ,_i ,.._, :., 4~..4.. ~..~.4_ ~; ~.~4 ._4..~.4 .... ~-4.-.k~-~--4-4--L-;---~--;---;---:-..~ ...... ;._¥+.4......~...;.-+...+ ....... ~-4.-4-.f-..,~-4--4--+ ...... +.-~-.4-.+- ~ ~ ~ ~ ~-~--,---~-~ -~ .... e- ~ · ~ ~ ..-e--~.-.e ........... e ...... e .......... e-.-e-.~ ....... ~--~..'~...~ .......... 4 ......... ~ ....... ~. -- ~.-.~"- '~ .................... 'l--~--Y-,--~-i-'i'T~-'F~"!'-~"i""'i-r'i"i"~-i'"t ,' r"h~4",, , ,,, ;,,; .~.,., ~..~...,...,...,...,...L..,...,...,....~ ...... ~...~...~...! ...... k;.-.;...~-.-...4.4...~..-~...;.-.k¥.k~ ...... ;.4..-~.-.~.. "~4-['+-?~-+-H'"'~'H'"~"'+'~"H--"+"H4'-F+-H"-~ ...... H'-'H ..... f"f"f"h"~4'"?f"f-??" 7!"'?~ ...... ~"t"~'"~ ...... ?'? "?71'" ~"~'"~"~'"~ ...... }'"~'-~'-~": ·, [ i ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~..L.. ~..I...;..-; ....... I...~...~...~ ...... I...~...~-4..--4...I...*...1 ....... *...~..-1..,* ....... I.,4.--~...:... · .4..~..4.~-,.~-.-~.--*-~... ~..4..4.--~..4..-..-4...~..4-~-..~-~..4.4 ...... '" '4'--~ ....... ~'~-'~'-~ ......... t-.-t--~--~ '.'~-'m--,'-'?~"'," ~' '. t '? ' ..... i i ; , . i ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~4 ~ ~ i , ..... . ..................... ~...~.......Z...~...L..L..~...~ ..... ~...~...~....~ ....... ~...~..4...~ ...... ~..-~..-~ .......... ~ ....... +4 ' ~ ..~ ....~..-~...'-..~..- '-~"4"T"T" ~'"?~'-~'"r'"~'"~"'?r"? "%'r'T'T"'"TT F'! ..... ~'"~'"YT'";'"r'T'T"! I I ~ ~ ~ ~ ! i ~ ~ ~ ~ ~.L.....' ..:...L.: : ~ · , I , ~ ~ ~ ~ t ~ ~ ...... ...... ....... ....... ..... ...... ...... .... PROdECTION ON VERTICAL PLANE 63, - 2~43. (SCALED IN VERTICAL DEPTHS HORIZ SCALE = I/SO0 IN/FT C:!ear~nce RePor-t (SPher. icml Method) ElliPse din',ensions NOT included in calcul,stions C:~sin~ di~ensions NOT included in ,::a. lculm, tior~s P r'. o ::< i n', i t"," r'. ~,J i d s .i. s 300. .F e e t All depths ~r.e in .Feet ¢.:~nd ar-e r. efer. enced to the REFE?REt'.fCE WELL. RKB Re-Fer. ence File Name :- DDI: [300..,O03]POOS:.38.2MA SteP~ise vet`-ti,:~l depth sta. t:i. ons r. un fr.,::,m 0,, to 6:300, ~t inter'va, ts oi: 100, ~:eet Re~:er-ence Slot N."-',me :- B2 ..... '!.0 Refer-ence Well N~n'~e :- M-:3 Requested b'.,' :- BRIAN ROY Accepted b.¥. : ..... Object Slot Na~.~es B2-'F; B2-I Al-! A1 .... '[ 1 BI -1 B1-'2 Bi-3 B1-4 BI-6 B1-7 B1-8 B1-9 B1-10 B~-I! B1-12 B2-3 B2-8 B2-11 G-3-1 G-3-2 G-3-3 G-3-4 G-3-5 G-3-6 G-3-7 G-3-8 G-3-?~ G-3 ....10 G-3-11 G -' 3- i '":' G'-' 4-1:3 G-~ ....14 G-~ ....15 0-4-I6 G"-~ ..... I7 G'-'4-19 G-4-20 G-4--21 G-4-24 G-2'-:}7 G-2-38 G-2-3'P G-2-'40 0-2-41 G-'2.-42 0-2-43 G-2-44 G-2-""45 M-...6 M-13 M-'l. 4 M-26 M- 28 M-:27 ~M.-27 ~M.-30 ~,'-M-.31 M'-25 ~.M-32 M-2 M-1 ST ~1 G-21 G-26 G-25 G-24 G-20 G-27 G-:--.:6 DPN G-34RD L',-i,~.oRD G-:'::3 G- :1. :.~ G-1:3 G ..... ~.5 G-:3 Ri: ,~ G-2RD G .... :t.i G- '7 O- 12RD2 G-4RD O .... 1 G-- 18RD :3--I 4 G-3C) G-SRD O:.-... A F-.: T'l Not zr'~ Proximlt-r r-radius. Not zn Pr. oxim.~.t'.,' N o t blot zn Pr.o::...:zmitY r-;&dius. Not' zn r;.r. oxi,mit'.,' r.¢sdius. blot in Pr. oxzmzt'-,' r"sdius,, N o t i r': ~, r. o ::.:: i m i t'.,' r.e. d i u s. blot in ~r-o::.::imit'.,' r-,~dzus,, Not .'Ln Pr'o>::~.m:LtY r.,.:~dius. blot zr', r-'r-ox~.m:~.t'-,' radiu,_.'..'., Not zn ~=-r. oxim'~t'-,-' r'.adzus. N o t .'L n ~=. r, o :.'.:: i m :~. t Y p a d z u s ,, Not ir'~ Pr-o::.::imitY r. adius,. Not in mr-ox'i, mitY r-,~dius'.. No t i biot in mr"O.':.::itT~it'v' No t i r', N,:,t .~.n Pr.o::..':~m].t'.,' r'.adzus. Not in ~,r-o::.::imitY r.a.d:i.u,_=.. Not in Pr'.oximit'-,' r'.¢zdius. Not in F:.r. oximit'-,- r. adius,, blot in Pr.o×irr~it'.,- radius. Not ir~ Pr'o::.::imit'.,-' r. adius. blot zn Pr-oxzmzt'v' r.,md_~.us. N o t i ri Not in F.r.o:.'-::imit'.,- r. adius. Not zn Pr.o>::zmzt'.,.' pa.d~.us. Not in PPO::.::lmlt'¥' G-2.-.48 D-A1 .... 1 D-AI-2 D-A1 .... 3 D-A1-4 D-A1 D-Al -6 B-A1-7 B-A1-8 D-A 1 .... D-Al-10 D-Al-1 1 D-Al-12 D-A2 .... 1 D-A2-2 D-A2-3 D-A2-4 D-A:.--'-5 D-A2-6 D-A2-7 D-A2-8 D-A2-9 D-A2-10 D-A2-1 I D-A2-12 D-.B1 ....! D-BI-2 D-"B 1 -"3 I')-B 1-4. D---B 1 5 D-BI-6 D.'"'B 1 ..... 7 D-B 1-8 D-B 1 ..... D-B 1-- !0 D-BI-11 I].-B i-- 12 K S-- 4- 2. 8 KS-2 ....10 KS- I ..... 8 KS .... i .... t ... :--. ~ 126 · 127 G -.;_:: 2 G-'J6 D- .2'7 D'--28 D--2?RD D---32 D-')ORD D-4i D-'26 D-25RD D-43 B34/24 D-31RD D-24A D--1 D-17RD D--11 D-7 RD D-'9 RD D'- 1 '.--.~RD D-.42 / 23 D-44 / 21 D-5 RD D-15RD2 D-3RD2 D-45 '(B-13) D-8 RD D-6 RD D.-14RD D-20 D--t6RD D-22 D-2A RD D-4 RD D--10 D- 1 '~' ~' n D-18 D-.-3ORD K-25 K-9 K-20 K-.21 RD K-24 RI,,..F-..1. OB ~.~2 N o t i r, :::, r. o ::-:: i m i 't'-,' r. ,~ d i u s. Not in Pr-o::<imitY r. mdius. N,:,'~ in ~r.o:.'-::imi'.~';- r-~dius. Not ih PpO:,-:'.imit'-,- r.~dius, Not in PI~'Oi:<IITtit"K p~dius. Not in Pr.o:..<lmitY r-~dius. Plot in Pcoximit'.,- c~diu:s. N,;,t Not in Ppoxlmlt'.,.' p..zdlus. Not in ~co'.>.-:imit'-,- r-~.dius. Plot in ~r-oximit'-,- r-,~dius. Not in ~r-oxlm!tY r-adlus. Not ~n ~r-o:..-..:imlt'.,-' c~dlus. Not in ~r-oximlt'.,- r-~dlus. Plot in Ppo>:;lmlt'.,. r.~dlus. Not in ~r-oximitY r.~dius. Not in ~r-oximitY r-~dius. Not in Pr-oximit'.,' r-~dius, Not in ~r. oximit'.,-' p~idius. Not in ~r. oximitY r-a. dius, N o t i n P.r. o :.-< ~ m 1 t'-,' r. ~ d ~ u s. Not in ~r.o;.....:lm~t'.,' r.~_,dlus. Plot in ~po;.-<lmltY r. ad~us. Not in ~r.o;....-:im:i.t'.,- r-~dlus. Plot ~n ~r-,.-,ximitY p~dlu~. Not in Pr.o:...:imltY c,~dlus. Not in ~r. oxlm~t'.,' blot in ~r-oxlmit'-,- r.a. dius. Not in ~,co'.....:lmit-.,- r.,.idlu.s. Not in ~,r'o>.':Imzt'.,.' r.,sdius, Not ~n ~cc,::..';imlt'.,' r. ad~us. Not in ~r.o>.:imltY r.,-~dius. N o t 1 n ~- r. ,;.',:...:: .lm 1 t'-,' r-,.s d ~ u s. Not in ~P,-,;...::imit'.,' r.~dius, Not in Pr. oxim_'i.t'.,, r.~dius, Not iii F~r-nl:.::lmitY p.~.dlus. Not in Pco×Imlt'.,- c~dius. N o t .', n ~ r. ,::, :.,.'; i m i t'.," r-a d i u s. Not in Pr.o>:;imltY r.a.d~us. Not in Pr-oximit'.,' r-;~dius, Not in ~---.r. oximit'-,.' r-,.idius. Not in ~.ro:.....:imit'-,.' ca. dius~ Not Not in r.~.r, oximitY r-,sdius, ERSTMRN CHRISTENSEN Position on ,.~ell H--3 MD TVD NS 0.00 0.00 100.00 100.00 200.00 200.00 300.00 300.00 400.00 400.00 500. O0 500-00 600. O0 600. O0 7C~00 700.00 800. O0 800. O0 '.-.vO0. O0 900. O0 000.00 1000.00 ,100.00 1100.00 200.00 1200.00 300.00 1300.00 400.00 1400.00 500.00 1500.00 CAI...CL1LAT!ON OF LEAST DISTANCE BETWEEN WELL.z, Ct,:,sest Position or, ~.,ell M-4 0.00 N 0,00 N 0.00 N 0.00 N EW MD TVD NS EW E E E E 0.00 0.00 1.00.00 100.00 200.00 200~00 300.00 :300.00 0.00 N 0.00 N 0,.00 N 0.00 N 0.00 O. O0 O. O0 O, O0 E E E E 400. O0 400. O0 49'? :, .=,c~,,-',, 62 =:.- ,:',, c~ ~,- ._ .... ~ ._i .'..-...'] 6'79 . 16 699 . 01 0.00 N 0.00 N 0.00 N ,:). O0 N O. O0 O~ O0 0.00 O. O0 E E E E 798.37 797.96 897.22 896.34 794.,.89 993.20 1071,,07 1088.08 0.00 N 0.00 tq 0.00 N 0.00 N 0.00 0.00 0.00 0.00 E E E E 1185,; 64 1180.6]. ~ ,' ,:,. 17 12'70.34 1 "-" ~¢. ,:, .:;,.-,,'z,. ..... ,-, 3 3 l'"r"-' ,_-, 146.'2:., 0:31446.52 1.27 N !5.10 N 11.53 N 0,.00 O. O0 0.00 O. O0 E E E 1 ~ 4'-? ,, 64 1 ._ .~-..,~ .... 1634 70 16.).:,. = 17:18 80 lZ"-' ..:,o 'P. 18 20.72 Re.F : F'OOSll. OMA Distance Directio Bet:~een Bet~,een Wel 1 s We! 1 s . o,.:, N..:,'-'. 'Pi E 8 . .-,..,'--'~ N27 F,.~._ .._ E 7 3:E: N :3 "?I E 8 ':'.~ · -,._ N27 7.38 N 3, 91 E 8~35 N27 55E 7. :38 N 3.91 E 8.:::5 N27 55E 7.38 N 7.67 N 9.52 N 13.79 N 20.46 N 27.45 N 41.18 N 55.77 N 3,91E 8.:85 N27 55E 4.02 E 8.68 N27 37E 4,.68 E 10.62 N26 12E 6.23 E 15.16 N24 18E 8.,64 E 2:2.31 N22 54E 11,,89 E 31~97 N22 OFf 16.1:3 E: 44.. 74. N21 24E 21.49' E 6i. 13 N21 OE 6.:,,3:3 E 200:1 NI'-? 4,3E 7/-, 79 E '-.' _. ~.:34.54 NtB 21E :..-::,:r.~ 00 E :, ,'. c:, ~ c) .~ ................ N t 6 '-'SE 74.12 N 95.30 N 119.14 N :I. 47. '76 N ERSTMRN CHRISTENSEN P o s i t i o r, o n ~e 11 Pt-3 MD TVD NS }-' 1-'! t' '"-r' _.Al ...... um, ION OF L. EAF::T FftSTANCE BETWEEN WEL.LS EW 0.00 0.00 0.00 N 0.00 E 100.00 100.00 0.00 N 0,00 E 200.00 200.00 0.00 bi 0.00 E 300.00 300.00 0.00 N 0.00 E 400. O0 4~ ~: O0 500.00 500. O0 600. O0 6,00. O0 7 ~,, 00 700.00 ~:¢)0. C)O 800.00 900.00 900. O0 i000.00 1000.00 i100.00 i100.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 lq 0.00 N 0~00 N 0.00 N 0.00 N 0,,00 N 0.00 N i.2'7 N 5. i 0 N 11.53 N 20.59 N 1200.00 1200.00 1300.00 1300.00 1400.00 1400.00 1500.00 1500.00 1600.05 1600.00 1700.:37 1700.00 1801,,25 1800.00 1902.98 1900,,00 Closest Position on weli M-6 ._ MD TVD '"-' i\t .'", EW Re~: : P0044:::.:3MA 0.00 E 400.00 400.00 3.38 N O. O0 E .4':?'P. 92 497.92 3.64 N 0.00 E 599.7] 599.67 5.22 N 0.00 E 69':?. 30 6':.'.~'.-?. 16 8. :38 N Distance Dire,-tio Bet-.,een Bet:,een Wel 1 s We! 1 s 0.00 E 798.58 798.17 14.61 N O. O0 E 897.48 8':76.6,0 22.33 Iq 0.00 E '.-?'F~5.23 9'.-?3.54 32.40 N 0.,00 E 1091.53 !088.51 45.12 N 5 57 E 6 ~":' NS:E: 456 -- ~.._ · ,, ._, ?, /- 52 N~'R 456 5 ._7 E -_ · ..-...~ i_ =, 57 E 6 .=;'-;-' '.'=:'-' 4=._,E · ..- u -- ~ -- .-- i.. 5. F,' =;'-' · _7 E 6 5o .... - N._ ,:, 456 0.00 E 0.00 E 0.00 E 0.00 E ~ :~7 E 6,. 5'2 -~'-' ...... N-_c, 4.5E ._.'=;. 76 E 6 . ,:, .."-'"' N._7~'; 4'.2E 6, ,, .'F..':;:'. E :--:. 6,7 ~'-' N....-, OE '?.6,1 E 1:3. ! l N4.7 14E 2,.29 E 9.18 E 20.72 E :::7 C'-' - .... ) .,. I550,61 1528.17 149.27 N 16:36,,46 1607.00 176.66 N 1721.42 1683.72 2C, 6.04 N 1805.82 1758.60 237.39 N I :B.,_,o 1 E -.?':]. 1 ':¢.. N 4:3 2:3 E 17.47 E 29.:32 N4I 56 2,S. 86, E 42.5:5: N39:396 36.18 E 58.76 N38 446 4'7.62 E 79.43 N38 76 60. '? 7 E 10:3. :::37 hi:37 41E '75.99 E 132.13 N37 246 'F~4.00 E 164.27 N:37 116 ERSTMRN CHRISTENSEN Position on ~ell M-3 CALCULATION CIF LEAST Di:--':TAF,!(.':E BETWEEN WELLS PtD TVD N~E; Closest Position on ~etl M-13 EW MD TVD NS 0.00 0.00 0,,00 N 0.00 E 100.00 lO0. O0 0.00 N 0.00 E 200.00 200.00 0.00 N 0.00 E 300.00 300.00 0,00 N 0.00 E 400.00 400.00 0.00 N 0.00 E 500.00 500.00 0.00 N 0.00 E 600.00 600.00 0.00 N 0.00 E 700.00 0.00 N 0.00 E 900. C)0 L 000.00 0.00 0.00 8.90 S 99.93 99.93 8. '..-? 1 S 200 ,. 00 200 = 00 8: 97 S 300.21 300.21 ?. 13 S ,:,(J 0.00 C). C) 0 N C). 00 E ?00.00 C).OC) N 0. C) 0 E 1000. C) 0 0. C) 0 N ('). 00 E 790.86 790.61 13.88 S :'--:86.79 886.21 17.32 S .'Y 7 .'Y 00 777 '-'=' '--" ~.1 62 ,z: :i071.85 1069.6I 27.03 $ L100.00 110o.00 20¢).00 t200.00 30(2). C, 0 1300. O0 400.00 14£)0.00 500.00 1500.00 0.00 N 0.0C) N 0.00 N 0.00 N 0.00 N 0.00 E 0.00 E 0.00 E 0.00 E 0,,00 E 161.79 1157.73 33:. 19 5; 250.59 t244.46 40.71 S 338.44 132'P.33 4.9.90 S 427.76 1414.90 60.88 S Dist,~nc.e Dir-ectir, .... Between Betmeer, EW Wei 1 s Wel ! s 149.37 W !49.63 S86 35W i49.41W 147.68 S86 35W 149.41W 147.68 S86 33W 147.27 W 147.55 < S86 30W 149.20 W 149.50 < S86 22W 149.42 W 147.75 S86 10W 150.62 W 151.02 S85 55W 153.78 W 154.32 S85 38W 158.76 W 159.84 S85 C)W 166~13 W 167.60 S84 3W i75.25 W i77.96 S82 58W 188.3I W 172.65 S81 50W 203.97 W 210.89 S:"::O 45W ."~ --: .-I .,:. -" -,--:.. 31 W .--:'-'.z,""""'..'. 7:3 F;.. 7 ':~.. .~.,/''~'" W 242,.'P5 W 257,'.:;'0 S78 24W · 7'./',.. 1',_. 07 W ~..,_,? '::' ._.~. 9. 1 S 7 '7 7 W ERSTMRN CHRISTENSEN Pos i t i on on L~ell M--:3 I'IF~ TVD NS 0.00 O. O0 100. O0 100. O0 200. O0 200. O0 300.00 300.00 400. O0 400. O0 500.00 500. O0 600. O0 600. O0 7c ~ -00 00 . 700. 800.00 800. O0 900.00 900. O0 000.00 1000.00 100.00 1100.00 1200.00 1200.00 1:300. ,.'}0 ! :300.00 1400.00 1400.00 1500.(}0 1500.00 1600.05 1600.00 1700. :37 1700.00 1801.25 1800.00 1902.78 1900.00 90 2000.00 :34 '-' .:: 1()0. ()0 2216.70 2200.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0,00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 hi 0,,00 N 0.00 N 1 ,, 2'7 N 5.10 N 11.53 N 20.59 N :32 ~ :38 N 47.01 N 64.61 N C A [. C U L. A T t 0 N 0 F L E A'.:::; T Fi I S T A N C E BETNEEN WELL'.-]; EW c:i,:,$est Positi,:,n on k~e!t M D T V D N S M-14 EW 0.00 E 0~00 0.00 0.00 E I00.02 i00.02 0.00 E !99.97 199.97 0.00 E 300. (}:3 300.03 9:34. c- 9,,'..7,'4 S 10. '-'::.'5 F; 10./', i '=' Re~: : '.S()8i46.81dA 0.00 E 399.95 399.95 0.00 E 497.93 499.93 0.00 E 599.84 599.83 0. O0 E 697.61 69'.:.). 60 · 0.00 E 799.40 799.38 0., O0 E 8'P8.74 :_--:9:3.71 0.00 E 'P 9'.-}. 1 (} 999.06 O. O0 E 1099.11 1099.05 11. 11. 12. 13. 14. 15. 17. 18. 07 S 69 S 47 S 32 S 30 S 58 S :30 S 84 S Distance Dir. ectio Bet~eer: Berne.eh We! i s Wel ! s 0.00 E 1199.24 1197.17 0.00 E 1299.5:3 !299.46 0.00 E 1400.05 139".:). 97 0.00 E 1500.30 i500.22 2(}. 21. 22.. 22. 1:2:9.60 W 1:3'F¢. 95 $85 58W 139.57 W 1:39.92 '.:] ',385 56W 139.59 W 139.96 S85 48W 1 :"":'P. 59 W 139.99 S85 3'PW 2, .... '-'::"::' E 16 0 (). 15 16 0 (':,, 0." 7 9.18 E 1700.01 i6'P9.9:3 20.7:2 E 1799 .9'7 17 ? 9 . '"",=, '-':.. :37.,02 E 1700.15 1700.07 22. 22. 22,, 77 S 85 S 89 S 82 S 139.57 W t40.01 S85 28W 139.55 W 140.03 '.385 13W 139.58 W 140.13 S84 54W 1:39.72 W 140.3/:, S84 33W 140.0t W 140.74 S84 10W 140.61 W 141.47 S8:3 41W 14.1 c, . .......... :, (}W . . 4 W _1. 42 20 ':' '"-''''-'' 141.74 W 142.99 S82 2/.':,W :3::: S 01 S 22 ':' 14. 2 1 M W 14-:2: ':;"--' ':":' ! 5 4. W u -.. n -- ~..I ...i 1_, 142.44 IAI 144.04 F;81 29W 14,2.46 W 144. I7 S81 'PW I42.24 W 144,.0:':: <Z S80 58W 14,2.14 W 146.42 S80 3:3W 142,, 13 W 15:3. :37 S77:3'2W 142,,24 W !66.55 S78 4N 142.22 W !84.4I S76 2:3W 14-2 41 W 208 (..),:, S74 '".:',7 ti ~. '"" 6::: K.;72 ._,.--W J., .t..~ .... W 2:37.7 ::: '="'" 14 2 ,, 8 8 W :2 7:3.5 2 S 7 i ! ;:,W HRISTENSEN Position on well H-3 MD TVD NS 0.00 0.00 i00.00 100.00 200.00 200.00 300.00 300.00 400.00 400. 500.00 500. 600.00 600. O0 700. : O0 800. 900.00 900. O0 O0 O0 O0 O0 O0 00 0O i000.00 1000. · 100.00 I100. :200.00 1200.00 ,300.00 1300.00 L400.O0 1400.00 :500.00 15(}0.00 :600.(}5 1600.00 :700.37 I'700.00 :801.25 1800.00 :902.98 1900.00 C:ALCULATiON OF L.EAST DISTANCE BETWEEN WFt..LS :.'0~90: ...... 2o00 .00 : 1 :b~,~ .:,4 ":' ~ 100.00 ::216.70 2200.00 ~325.46 2300.00 Closest Position on well M-Q6 0~00 N 0.00 N 0.00 N 0,00 N EW MD TVD NS EW 0.00 0.00 0.00 0.00 0.00 E 0.00 0.00 0.00 E 100.00 I00.00 0.00 E 200,00 200.00 0.00 E 300.00 300.00 400.00 400.00 500.00 500.00 600.00 600~00 700.00 700.00 O. O0 O. O0 O. 00 0.00 0.. 0,0 E 0.00 E 0.00 E 0.00 E 799.56 799.56 901.02 901.01 999.03 999.01 1097.24 1097.19 O. O0 O. 00 0.00 O. 00 0,00 E 0.00 E 0.00 E 0.00 E 1193.79 1193.5'7 1292.3:3 1291.66 1386.05 1384..35 1481.78 1478.2'6 I,,27 5.10 11,,53 20.59 0.00 E 0.00 E 0.00 E 0,,00 E 1580.0~ 15'74.3::: 1674,27 i666,,30 17'73,46 1762,.43 I87:3.59 1859.47 47.01 64,, 61 '""' :38 t:2.i ...t. 2, 29 E 9.1:3 E 20.72 E 37.02 E 1967,,11 1949.98 2068,,87 2047.48 217~.84 2146,,14 2271.77 2241.52 58.21E 84,,50 E 1].6. I5 E 153.48 E 74.72 N 74.72 N 74~72 N 74.72 N 77.80 W 77.80 W 77.80 W 77.80 W 74.72 N 74.72 N 74.72 N 74.72 N 77.80 W 77.80 W 77.80 W 77.80 W 74.76 N 74.55 N 73.60 N 75.70 N Ref : 8]. 1:3 N 90.40 tq 103,, 87 N 121.98 N S07078.1MA 14,1.71 N I. 8, i. 89 N 185.48 N 209.2:E: N Distance Dir. ectio Between Between Wells Wells 231.98 N 260.17 N 288.69 N :317.56 N 107.8'7 N46 9W 107.87 N46 9W 107~87 N46 'gw 107.87 N46 9W 107.87 N46 9W 107.87 N46 9W 107.87 N46 9W 107.87 N46 9W '77.90 W 107.97 N46 11W 78.74 W 108.44 N46 34W 78.74. W 107.79 .C N46 56W 79.10 W 109.52 N46 15W 79.4i W 78.54 W 76,,14 W 72.45 W 11:3 71 N44 ~._,W 120.04 N4.1 OW 129.74 N:36 I5W 14:3.53 N30 4.2W 159.15 N26 37W ].75.96 N24 47W 194,16 N24 3W 211.92 N24 53W 68.08 W 63.23 W 56.9I W 50.5:3 W 44.48 W 229,,97 N27 13W 37.19 W :251.01 N29 43W 29.81W 2'72.79 N33 5W 22~52 W 297.!6 N37 10W ERSTMRN CHRISTENSEN Position on well M-3 MD TVD O. O0 O. 100. O0 100. 200. O0 200. 300.00 300. O0 O,. C~O N OO O. OO t',i O0 O, O0 N O0 O. O0 N 400.00 400. 500.00 500. 600.00 600. 7C,::,00 700. 800.00 800. ~00.00 'PO0. 000.00 1000. 100.00 1t00. O0 0.00 N O0 0.00 N O0 0.00 N O0 0.00 N O0 0,00 N O0 0,00 N O0 0,~00 N O0 0,00 N 200.00 1200.00 0.00 N EW CALC:UL.ATION OF LEAST DISTANCE BETWEEN WELLS MD Closest ~osition on ~ell TVD NS EW 0.00 E 0.23 0,23 73.43 N 0.00 E ??.71 97.71 73~35 N 0.00 E 200.26 200.26 73.17 N 0.00 E :300~i 300,41 72.71N Re-F : S07885.8MA 0.00 E 399.36 399.36 72.93 N 0~00 E 502.'28 502.26 74.11N 0.00 E 604~13 604.02: 73.16 N 0.00 E 702.21 701.75 73.66 N Dist:nce Dir-ectio Between Between Wells Wells 0.00 E 801.01 800.64 75.62 N 0.00 E ~01.,~0 901.48 76.05 N 0.00 E 927.25 ?26.82 76.21. N 0.00 E '~27.25 926.82 76.21N 7:2:.43 W i03.84 N45 OW 73.54 W 103.87 N45 5W 73.58 W 103.77 < N45 10W 73.53 W t03~41C N45 I?W 0.00 E 927.25 ~26.82 '76.21N 73.07 W 103,24 < N45 3W 72.59 W 103.76 N44 25W 68.42 W 100.25 < N43 5W 63. I2 W 97,03 < N40 36W 59.14 W 96.00 <~ N38 2W 56.07 W 74.~' '-' ._0 -C N.~6 24W 55.18 W 119.20 N35 54W 55.18 W 177.09 N35 54W 55. 18 W 288.93 N35 54, W ERSTMRN CHRISTENSEN Position on ~.ell M-s3 MD TVD Isis O. O0 1 O0.00 200. O0 300. O0 400. O0 500. O0 600. O0 7t 00 800.00 900.00 1000.00 I. l O0. O0 0~ lO0. 200. :300. 4-00 500 6,00 700 800. 900. 1000. 1100. CALCULAT!ON r]F LEAST DIF;"FANCE BETNEEN WELLS Closest Position on mel! M-28 EW MD TVD NS EW O0 0.00 N 0.00 E 00 0.,00 N 0.00 E O0 0,.00 N 0,00 E O0 0,00 N 0.00 E O0 0.00 N 0.00 E O0 0.00 N 0.00 E O0 0.00 N 0.00 E O0 0.00 N 0.00 E O0 0.00 N 0.00 E O0 0.00 N 0.00 E O0 0.00 N 0.00 E 00 0.00 N 0.00 E 200.00 1200.00 300.00 1:300.00 400.00 1400.00 500.00 1500.00 0.00 N 0.00 N 0.00 N 0.00 N 1,.27 N 5.10 N 11.53 N 20,59 N 32.38 N 47.01 I',,l 64.61 N 600.05 1600.00 700. :37 1700.00 801.25 1800.00 'P0:2.98 1 'PO 0.00 0,29 0.29 99.72 99.71 200.22 200.22 :300.34 :300.:34 401.02 401.02 501.92 501.90 602.66 602.62 702.66 702.55 ~'~2 02 ,=, 91 901.71 901.48 1001.6t 1001.32 1100.56 1100.16 0.00 E 0.00 E 0.00 E 0.00 E 1!97.95 1197.4!. 1293.57 1292.67 · -,,'.., -.~, 56 1 '.-? 0 1 '2 "2 '.- 3 8 7. 14::::6.4.5 14:.:::3.4A 2,,29 E 9.18 E 20.72 E 37.02 E 1580.69 1575.62 1671,71 1663.30 1764.04 1750.86 1857,,20 i837.97 =;c, 2,,~ E 84.. 50 E 116. i5 E Re.F : S08172.8MA Distmnce Dir. ectio Between Be't~eer, Wells Wells 69.49 N 70.71 W 99.14 N45 30W 69.36 N 70.63 W 78.?? 'C N45 31W 69.18 N 70.83 W 99.01 N45 40W 68.84 N 70.85 W 98.7? C N45 49W 68.74 68.04 66.88 66.35 N N N N 70u06 W 98. i6 C N45 33W 68.78 W 96.77 <~ N45 i?W 66.77 W 94..54 'C N44 57W 6:3.26 W 91.71C N43:38W 66.42 66.50 67.2] 69.11 N N N I',1 73. I] 80.74 92.44 108.07 59.58 W 89.24 < N4! 54W 56.44. W 87.23 53.00 W 85.61 < N38 16W 49.17 W 84.81 < N35 26W N 4.6.0i W 86.42 N32 11W N 44.00 W 92. ',:i:4 N28 35W 4.'-.' :3/-, W 1 ,:'.~ 2 4 ('~ N 24 :'-: 7 W N 39.23 W 11/,. I7 hll'iP 57W 127.11 N :34.54. W 133.36 N16 I?W 150.62 N 28.15 W 154.65 NJ. 4 23W 178.40 N 19.06 W 178.45 N!3 24t4 209,,43 N 7.82 W 203.76 ht13 21W 194. 9.41 "-:¢""'-'., 79 --, z --,..z,..:, '":' ''":' C) 9 :L N :L 4 14 W 1 :: z..,.'. ~.-~..:, '-"-' N 4 ,, 71 E ~ ..... 2.'044,, 2:-3 2008. '.-70 :2:".':0,, 5';8 Isl 18.72 E 259.20 N 15 4z!.W 2136.02 2090.22 3:;-!'.0.10 N 34.08 E 28':.?. 93 N i 7 4.8W ERSTMRN CHRISTENSEN Position on well M.....3 PID TVD NS 0.00 0.00 0.00 N 100.00 100.00 0.00 N 200.00 200.00 0.00 N 300.00 300.00 0.00 N 4.00.00 400.00 0.00 N .500.00 500.00 0.00 hi 600. O0 600. O0 O. O0 N 7 (~'~: ,,~ 00 700.00. 0 .00 N 800.00 800.00 0.00 N 900.00 900.00 0.00 N L000.00 1000.00 0.00 N £100.00 i100.00 0.00 N CALCULATION OF LEAST DISTANCE BETWEEN WFLLS L200.00 1200.00 0.00 N Closest Position on u,e'll M--.'27 EW MD TVD his EW 0.00 E 0.00 0.00 0.00 E 100.54 100.53 0.00 E 200.44 200.44 0.00 E 300.45 300.44 64.72 N 64.11N 63.74 N 63.24 N Ref : S07837.8MA 0.00 E 400.62 400.61 0.00 E 501.53 501.51 0.00 E 602.87 602.81 0.00 E 702.63 702.51 0.00 E 801.94 801.76 0~00 E 902.12 901.87 0.00 E 982,,95 ~82.63 0.00 E 982.95 982.63 63.03 N 62.14 N 60.35 N 59.37 N 59.58 N 60.09 PI 60.54 N 60.54. N Distmnce Dir. ectio Between Between Wells Wells 0,,00 E 982.95 982.63 60.54 N 7i. I7 W ~6.20 N47 43W 71.15 W ~5.78 4 N48 OW 70.95 W 95.38 < N48 4W 70.81W ?4.94 < N48 14W 70.20 W ~4. ~,..°~ <] N48 5W 69.27 W 93.07 C N48 6W 67.17 W 90.34 < N48 4W 63.90 W 87.26 <] N47 6W 60.52 W 84.94 < N45 27W 56.89 W 82.77 <] N43 26W 53.53 W 82.65 < N41 29W 53.53 W 14.2.50 N41 29W 53.53 W 231.~0 N41 29W ERSTMRN CHRISTENSEN Position c,n ~elt M-.., TVB NS CALCI.~LATION r]F LEA'ST DIF.;TANCE BETWEEN WEL.LS 0. O0 0. O0 100.00 100.00 200. O0 200. O0 300.00 300.00 Clc, sest Position on t~el! 400. O0 400. O0 500. O0 500. O0 600.00 600.00 7C:00 700.00 800.00 800.00 900.00 'F.'O0. O0 L000.00 1000.00 EW MD TVD his EW 0.00 N 0.00 N 0.£)0 N 0.00 N 0.00 E 0.00 E 0.00 E 0~00 E 0,.14 0.14 100.04 !00.04 200.14 200. i4 :30 ~].. 1 ._. '~ :30o_. 13 60.98 N 60.62 N 60.31N 59.85 N 0.00 N 0.00 N 0.00 N 0.00 N 0,00 N 0.00 N 0~00 N 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 0.00 E 400.23 400.23 ' 4?9.25 4?9.24 598.75 598.73 698.68 698.65 784.25 784,.21 784.'25 7°4 '~ 784,,25 784.21 59.5i N 58.95 N 5~.01N 59.00 N 59.34 N 59.34 N 59.34 N Ref : SO7815.8MA Distmnce Between Wells Dir-ectio Between Wells 7'F..'. 36 W 1 O0.08 N52 79.4.5 W 99.94 .:.'] N52 79.63 W '--.,'.. '-}.. 89 ,.:]N...--F.'-' 79.77 W 99.73 .-':] N5:3 79.88 W 99.6 80.35 W 99.66 8I. 97 W 101. 83.53 W 102. '7"8 84.81 W 104.70 84.81 W 155. :31 :34. 'F:: 1 W 2:3 ?.'~. :3:3 28N :39W 52N 7W N53 N5:3 N54 N54 19W 44W 15W 46W N,=.;~ I",155 N55 OW OW OW ERSTMRN CHRISTENSEN Position on welt M-3 MD TVD NS O. O0 100. O0 200.00 300.00 O. O0 0. O0 N 100.00 0,00 N 200.00 0.00 N 300.00 0.00 N 400. O0 400. 500.00 500. 600.00 600. 7 '~.00 700. 800. O0 800. 900.00 900. 000.00 1000. 100.00 1100. O0 0,00 N 00 O~ O0 N 00 O. O0 N 00 0. O0 N O0 0, O0 N 00 0.00 N O0 O. O0 N O0 O. O0 N 200.00 1200.00 0,,00 N EW CALCULATION OF LEAST DIS'TANC:E BF. TWEEN WELLS Closest Position on ~ell MD TVD his 0.00 E 0.00 0.00 63.76 N 0.00 E ??.97 'F~9.97 63.74 N 0.00 E 200.06 200.06 63.76 N 0.00 E :300.26 300.25 6:3.64 N 0.00 E 400.63 400.63 63.14 N 0.00 E 501.~2 501~1~ 61.04 N 0.00 E 5~.22 599.18 59.77 N 0.00 E 699.22 699.16 58.76 N 0.00 E 799.48 799.40 57.46 N 0~00 E 900.05 899.94 55.84 N 0.00 E 982.95 982.83 54.40 N 0,00 E 982.95 982~83 54.40 N 0.00 E 982.95 982.83 54.40 N .~-M-..-27 EW Re-F : S07836.8MA Distmn,:e Dir-ectio Bet ,weer, Bet~,een Wet i s Wel 1 s 8:3. -,-'-"L, W 1(-~4. .87 N..~.=,'~ 3:3W 83.25 W 104.85 '.':_' N52 34W 83.0:"2: W 104.. 69 -.':] N52 29W 83.01 W 104.59 .::_' N52:2:IW 82.90 W 104.2]. < N52 42W 82.79 W 102.87 ~ N53 36W 83.76 W 102.9] N54 27W 85.54 W !0:3.78 N55 31W 87.17 W 104.40 N56 36W 88.52 W 104.66 N57 45W 89.05 W 105.75 N58 35W 87.05 W 156.~0 N58:35W 89.05 W 240.94 N58 35W ERSTMRN CHRISTENSEN Position on ~ell M-3 MD TVD NS Om 100. 200. 300. 00 00 00 00 0.00 0.00 N 100.00 0.00 N 200.00 0.00 N 300.00 0.00 N 4.00.00 500.00 600.00 00 00 900.00 1000.00 £100.00 4.00.00 0.00 N 500.00 0.00 N 600.00 0.00 N 700.00 0.00 N 800.00 0.00 N 900.00 0.00 N 1000.00 0.00 N 1100.00 0.00 N 200.00 1200.00 0.00 N CALCULATION OF ~.~EAST DISTANCE BETWEEN WEL.LF; Closest Po,~ition on oJeli EW MD TVD his EW 0.00 E -0.25 -0.25 0.,00 E !O0.,tO 100.10 0.00 E 200.15 200.15 0,,00 E 300.42 3(}0.42 68.40 N 68.53 N 6,8.37 N 67.88 N 0,.00 E 399.25 399.25 0.00 E 497.63 497.60 0.00 E ~,~o c)O ~. 92 -. .- .... ._~ ;i ~.. 0.00 E 699.03 698.88 68.05 N 68.88 hi 68.71N 66.15 N 0.00 E 799.73 799.49 0.00 E 899.88 :399.54 0.00 E 999,,39 998.9:3 0.00 E 1019.25 1018.76 63.38 N 59,93 N 56.08 N 55.31N 0.00 E 101~.25 1018.76 55.31N Ref : S07842.8MA Distance Directio Between Between Wells Wells 84.46 W 108.68 N5t OW 84.52 W 108.81 NSO 58W 84.50 W 108.69-{ N.51 OW 84.53 W 108.41C N51 14W 84.44 W 108.45 N51 8N 85.56 W 109.87 N51 10W 88.26 W 111.86 N52 6W 91.44 W 112.86 N54 7W 94.42 W I13~72 N56 8W 97.17 W 1t4.17 N58 20W 10 0.19 W 114. ,_-,'" ."-' N 60 4. 6 W 100.83 W 140.80 N61 15W 100.83 W 214.65 N61 15W ERSTMRN CHRISTENSEN Position on well M-3 MD TVD NS 0.00 100.00 200.00 300.00 0..00 0.00 N 100.00 0.00 N 200.00 0,00 N :300.00 0.00 N 400.00 400.00 500.00 500,00 600.00 600.00 O0 700.00 800.00 800.00 900.00 900.00 1000.00 1000.00 1100.00 1100.00 1200.00 1200.00 0~00 N 0.00 N 0.00 N 0.00 N 0.00 N 0~00 N 0.00 N 0,,00 N 0.00 N EW C:ALCULATION OF LEA?.;T DISTANCE BETWFE.'N WELL.S Closest Position on well MD TVD NS 0.00 E 0.00 0,00 72.55 N 0.00 E 99.97 ??.97 72.47 N 0.00 E 200.37 200.37 72.47 N 0.00 E 300.28 300.27 72.05 N 0~00 E 399.-68 399.67 72.26 N 0.00 E 500.07 500.04 74.03 N 0.00 E 599.36 599.32 74.90 N 0,00 E 697.45 697.40 76.41N 0,00 E 795.0I 794.89 79.03 N 0.00 E 895.56 895.35 81.68 N 0.00 E 997.23 996.97 83.75 N 0.00 E ?99.95 ?99.68 83.79 N 0.00 E 999,,95 999.68 83,79 N Re-F : S07988~8MA Distance Directio Between Betmeen Wells Wells 82.57 W 109.91 N48 4.2W 82.44 W 109,76 < N48 41W 82.26 W 109.63 .C N48 37W 82.19 W 109.30 < N48 46W 81.77 W 109.13 < N48 32W 80.53 W 109.39 N47 25W 80.20 W 109.74 N46 57W 80.83 W 111.26 N46 37W 83.54 W !15.!1 N46 35W 86.79 W 119.27 N46 44W 89.18 W 122.38 N46 48W 89.24 W 158.27 N46 48W 89.24. W '"'~' '-'t ~.._,4,, 76 N46 4.,~,[.~ ERSTMRN CHRISTENSEN Position on well M--3 MD TVD NS 0.00 O. 100.00 I00. 200.00 200. 300.00 300. O0 0.00 N 00 0,00 N 00 0,00 N O0 0,00 N 400.00 400.00 500.00 500.00 600.00 600.00 O0 700.00 O0 800.00 900.00 900.00 L000.00 1000.00 :100.00 1100.00 L200.00 1200.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0,,00 N 0.00 !',.! 0.00 N 0,.00 N CALCULATIOhl OF J.EAST DI'3TANCE BETWEFN WEL,.LS Closest Position on well -:-M.--31 EW MD TVD NS :W 0.00 E 0,00 0.00 0.00 E 100.05 100.05 0.00 E 200.48 200.48 0.00 E 300.22 300.:22 69,, 75 N 69.64 N 6'F;, 40 N 69.11 N 0.00 E 402,~15 402.14 0.00 E 501.5:3 501.49 0.00 E 600.85 600.80 0.00 E 701.27 701.22 67.9! N 65.53 N 64.52 N 0.00 E 802.52 801.45 0.00 E 901.36 901.28 0.00 E 934,95 934.86 0.00~ 'P:34..~=~;..., 734.8&_ 62.03 N 60.66 N 60.25 N 60.25 N 0,00 E 934,.95 934.86 60.25 N 5: 75. 74:, 74, 74. 73. 73,, 73. 72. 71. 7.1.. 71. 71. Ref : ::;07936.8MA Distmnce Dir-ectio Between Between Wells Wells 05 W 102.4,~ N47 6W 15 W 102.45 <: N47 llW 96 W 102.16 ~ N47 12W 86 W !(}1.88 { N47 17W 35 W 100.71 < N47 36W 74 W 98.66 .:C N48 22W 39 W 97.72 4 N48 41W 04 W 96.85 'C N48 58W 25 W 95.24 < N49 21W 53 W 93.80 ~ N49 42W 3:3 W 113.88 N49 50W 38 W 189.72 N47 50W 3:3 W 281.11 N49'-] !--;OW ERSTMRN CHRISTENSEN Position or, well M-3 MD TVD NS O. O0 100.00 200. O0 300.00 0.00 0.00 N 100.00 0.00 N 200.00 0.00 N 300.00 0.00 N 4.00. O0 400.00 500. O0 500. O0 600. O0 600. O0 1 5' 00 700.00 800. O0 800. O0 900.00 900.00 1000, 0C) 1000. O0 1100.00 1100.00 1200.00 1200.00 1300.00 1:300.00 1400.00 1400.00 1500.00 1500.00 1600.05 1600.00 1700. :]::7 t 700.00 1801.25 I800.00 1902.98 1 ':.')00. O0 21'I'0. '-' . · _-,4 '2100 00 ... ,.- 16.70 2.200.00 ")'.'.,'D ~ ~:...::, U Q (] 0 24:37.16 2400.00 0.00 N 0.00 N 0.00 N 0.00 N 0~00 N 0.00 N 0.00 N 0,,00 N 0.00 N O, 00 N 0.00 N 0.00 N 1.z. 7 N 5. 10 N 20.59 N 32.38 N 47,.01 N 64.61 N 85. :'"":8 N CALCULATION OF LEAST OiSTANCE BETWEEN WELL'.q EW MD C'losest Position TVD on u~ell NS EW 0.00 E 0.00 0.00 0.00 E 99.81 7;9.81 0.00 E 200.38 200.38 0.00 E 300.52 :300.52 64.61 N 64.72 N 64.66 N 64.42 N Ref : 0.00 E 400.41 400.41 0.00 E 497.76 497.71 0.00 E 599.82 599.46 O. O0 E 69':?. 50 678.8:3 0.00 E 801.96 801,.24 0. O0 E 8'....'~8. 'T~7 8'.-78. '20 0,,00 E 1001.78 1000."F.¢1 0.00 E 1101.34 lt00.46 63.95 N 62. :35 N 58.43 N 65. :32 N 67..2:6 N 68.71 N 65.47 N 64.55 N S 07'991. :..q M A 0.00 E 1201.25 1200.37 0.00 E 1:300.59 1299.71 0.00 E 14(:).t.02 14.00.14 0. ()0 1:7. 1500,. 92 1500.04 64.27 N 64.42 N 64.61 N 64. :_--:3 N Distmnce Dir-ectio Between Between Wells Wells 64.30 N 64.46 N 64.68 N 64.67 N 76. ':-.¢7 W 100.49 N50 OW 77. 11 W t00.67 N50 OW 76.98 W !00.5:S' '-'.'] N47 58W 76.64 W 100. 12 '::: N4';' 57W 58.21 E 200£).82 1'P'Pg.93 84.50 E 2101.47 2100.59 116.1 ..5 E 2200 ,. 54 2199../;,6 I53., 48 F_" 2:301 ~, 23 2:.:::00. :35 64. 64 64 64 .60 N .72 N .4! N .58 N 76.._,°1 W ':-/'P . F, 6_ -::] N50 2W 77.36 W ?'P.36 'C N51 8W 80.70 W '..-..¢'F.¢. 64 N54 6W 77.69 W 101.51 h14::'~ 56W 75.24. W 101.00 < N48 10W 74.'P5 W 101.70 N47 29W 77.08 W 101.14 <: N4'.:¢ 3':?W 77.47 W 100.84 <: N50 !2W 19~'.., 9:-..: E z. 4.:.) :t, 63 2400,75 64.77 N 7'7.20 W 100.46 <5 N50 13W 77.21W 100.56 NSO ?W 77.22 W 100.67 N50 5W 77,18 W I0C).Zl. 7 E NSO 11W 77.43 W 101.6::: N51 4. OW 77.57 W 105.11 N55 37W 77.54 W 1il.'72 N61:35W 77.76 W 1:22.95 N657 OW 77.7 '-,<'- W i :39 ,, 70 N'76 40 W 77.65 W 16:3.1t N8:3 46W 77.57 W i93.71 S89 56W 77.61 W 232.02 S84 51W ERSTMRN CHRISTENSEN O. 00 1 O0. O0 200. O0 300.00 400.00 500.00 AO0.O0 7 O0 800. O0 900.00 000. O0 100. O0 1200.00 Position on well M-3 TVD NS 0.00 0.00 N 100.00 0.00 N 200.00 0.00 N 300.00 0.00 N 400.00 0.00 N 500.00 0.00 N 600.00 0.00 N 700.00 0.00 N 800.00 0.00 N 900.00 0.00 N 1000.00 0.00 N 1100.00 0.00 N 1200.00 0,,00 N CALCULATION OF LEAST DISTANCE BETWEEN WELLS Closest F'osition on we'll .~.':.M-32 EW M[I ' i TV£ N:S EW 0.00 E 0.00 0.00 0.00 E 100.03 100.03 0.00 E 199.8i 199.80 0.00 E 300.17 300.16 68.84 N 68.77 N ;-~ 96 N 68.75 N Re~ : S07877.8MA 0.00 E 401.51 401~50 0.00 E 500.66 500.63 0.00 E 600.54 600~50 0.00 E 6??.58 6?9.53 67.79 N 65.92 N 64.51N 63.53 N Distance Dir. ectio Bet~eert Between Wells Wells 0.00 E 796.69 796.61 0.00 E 895.!2 894.91 0.00 E 935.95 935.68 0.00 E 935.75 935.6:3 63.58 N 64~34 N 64.55 N 64.55 N 80.4.6 W 105~87 N4~ 27W :30.22 W 105~67 < N49 24W 79.98 W 105,,60 < N4.9 14W 79.98 W 105.47 < N47 I?W 0.00 E 935.95 935,,68 64.55 N 79.86 W 104,~76 < N49 40W 79.87 W 10:3.57 < N50 28W 80.41W 103.09 < N51 16W 80.96 W !02.91 < N51 53W 83.35 W 104-.89 N52 40W 88.31W 109.38 N53 55W 90.49 W 128~42 N~4 30W 90.49 W 1~8.38 N54 30W 90.49 W 286. '74 N54 30W ERSTMRN CHRISTENSEN . 100. 200. 300. 400 500 600 800 ':?00 [000. L I00. Positi,:,n ,:,n well M-:3 TVD N:_:; 00 0.00 0.00 N O0 100.00 0.00 N 00 200.00 0.00 N 00 300.00 0.00 N O0 0. O0 N 00 '?00.00 0., O0 tq 00 1000.00 0,.00 N 00 1100.00 0.00 N 200,00 I200,00 0..00 N L300, O0 t300,00 0,00 N 400,00 14.00.00 0,00 N ~500,00 1500,00 0,00 N I_ 600. ' .=; . t)._ 1600.00 1 27 N [700.37 1700,00 ._,=,10 N CALCULATIF;N OF LEAST DISTANCE BETWEEN WELLS Closest Position on well M-2 EW MD TVD NS EW 0,00 E -0.00 -0,00 0,00 E ?.9.?? 9.9.72 0,00 E 200,01 200,01 0.00 E 300,02 300.02 4,0:=: 4, :30 3,68 :3, 87 4,50 5, 30 S S 0,00 E 79~,60 79~,55 0.00 E 878,7~ 898,55 0.00 E .9.97,25 ~6,4.0 0.,00 E 1094,84 10.92,:34. 7,59 13,53 24,08 41,23 0,00 E 1188,36 1182,79 0,00 E 1277,59 1267..1~ 0.00 E 136!,32 1344,32 0,00 E 1441,~4 1416,08 64,26 122,83 155,72 2.'2'? E 1514.47 1480.50 9. "'-' 5'.-77 '""'= 55 · l,:, E 1 .,::..., 1 1.1'2 Re-F : .S06827.8MA Fi i $ t a n c e D i r- e c t i ,:, Be t ~ee n Be twee n We ! 1 s We I 1 s 0,35 E 3.97 S 5 7F 0,51 E 4, 11 S 7 4E 0,.98 E 4,4.2 S12 5!E 1.47 E 4.~..-'-"-' <:: S:-20 ~__~.'?::: ~ 1.22 E 8,88' '":: S18 16E 0.74 E :3..9'S. 810 .-, ='- ..:,'-'"-c- 0,23 E 4,50 S 2 54E 0,18 W 5,31 S I 57W 0,77 W 7,64 S 5 4~W 0,47 W 13,62 S 2 4W 1, '21 E 24.42 ::, 4..:,.~F. 6,33 E .42,41 S 8 44E 11,81E 67,56 S10 25E 19,75 E ~.57 St2 8E 27,45 E ].38,04 $13 29E 40.:35 E 181,61 S14:3!E ERSTMRN CHRISTENSEN Position ,:,n well M-3 M1] TVD N:S O. O0 100.00 200.00 300.00 400,00 · _ U t~ 0 o 600.00 00 CALCU[.ATION OF LEAST DISTAI~CE B!-ZTWEEN WELLS o00.00 · _.r' 1 c, s e s t F-' C, S ~4 t i 0 ri ,D F~ ~J e i. 1. M- 1 S T ,,. ''* 1 EW MD TVD N:Z: EW 0.00 0.00 N 100.00 0,00 N 200.00 0.00 N :300.00 O. O0 N 0.00 E 0~03 0.03 9.79 N 0,00 E 100~07 100707 ?~4-I N 0.00 E 200.05 200.04 8.62 N O, O0 E :2'~:-?. 98 299.97 8.05 N Re~ : 400.00 0.00 N 500.00 0.00 N 600.00 0.00 N 700.00 0.00 N 0.00 E 399,97 397.96 8.35 N 0.00 E 500.00 499.98 9.06 N 0.00 E 600.01 599.98 9.45 N 0.00 E 677.93 677.71 9.73 N S0677!, 8MA ,__., 3(.) 00 0,00 N 0.00 E 799 .68 799 . A4 10 . ,.,o.=,... N Distance Dicectio Between Betueen W.~I Is Wells 900.00 900.00 L 00C~. 00 1000.00 L100.00 I100.00 L200.00 1200.00 L300.00 1300.00 I. 400. O0 1400.00 [500.00 1500.00 L 600 05 I :,~.) (.~. 00 L 700...:,'-' ""/ 1700.00 L801.,... 1:::00.00 0, 00 hi 0,. 0C) N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 11E:9.68 1185.65 59.16 N 0.00 E 1280.93 1273.37 83.47 N 0.00 E 1368.57 1356.04 1!1.69 N 0.00 E 14.54:,82 1435.57 144~17 N 0 7.;, W ~, o-':, ........ ,_,.. N 4 24W 1.20 W ?.4,:-? -::: N 7 15W '-' 00 W 8 85 <:: NIB 2W · , ._, .':, W 8 46 -C N 17 ~';(')W 2.95 W 8.86 NI? 26W 2.32 W 9.36 N14 23W 1.60 W ?.59 N '.-? .2:6W 1. 10 W 9.79 N 6 26W 0 1'-' W !C),'='~ ,. --", ...... N 0 4-3W I :37 '- ':' 67 E '-': '.-.".? ~. ..... N :'-': 26E 7.08 E 40,,/_-,2 NiO llE 11,,49 E 6!.95 N!I OE 17.44 E 89.33 hill 48E :..'4.2] E 1'22.45 Nt2 14. E :}1.59 E t, 61.06 Nt. 2 21E ':"::' 87 E ..-.,r.-) 2 27 N ] ]. 44 E 4.6.55 E 24..4.. 78 t',l 10 t :3E 5,~', =;'::' E 288. ,':,,'::' N 8 22 E ERSTMRN CHRISTENSEN Position on well M-3 MD TVD NS 0.00 0.00 0.00 N 100.00 100.00 0.00 N 200.00 200.00 0.00 N 300.00 300.00 0.00 N 400. O0 400. O0 O. O0 N 500.00 500.00 0.00 N 600.00 600.00 0.00 N 7C~,0~'~ O. C) O N 800.00 800.00 0.00 N 7,00. O0 .900.00 O. O0 N 000.00 1000.00 0.00 N 100.00 1100.00 0.00 N 1200.00 1200.00 1300.00 1300.00 1400.00 1400.00 1500.00 1500.00 1600.05 1600.00 1700.:37 I700.00 1801.25 1800.00 0.O0 N 0.00 N 0.00 N 0.O0 N 1.27 N 5.10 N 1 ],.53 N CALCUt...ATION OF- LEAST DISTANCE BETWEE'.'N WEI.LS Closest Position on ~.~e!t PI--.1 ST .~1 BiS EW EW MD TVD 0.00 E 0.03 0.03 0.00 E 100.07 I00.07 0 00 E 200 '~ = . . (. --~ 200.04 O. O0 E 299..98 2'.-79..97 9.79 N O. .9.41 N 1. 8.62 N 2. 8.05 N 2. Ref : 0.00 E 3.9.9. 0.00 E .500. 0,,00 E 600. 0.00 E 6??. 0.00 E 7.9.9. 0.00 E 8.98. 0,00 E .9.97. 0.00 E 1094. 97 399.96 O0 49.9.98 01 599.98 .93 699.91 8.35 N 2, '.-?. 06 N 2. .9.45 N 1. 9.73 N 1. S06772.8MA 68 799.64 87 8?8.70 25 996.60 .98 1093.15 10.85 N O. 15.42 N 1. 24 ,, 7.9 N 3. :39.41 hi 7. Distmn,:e Directio Between Bmt~eer, Wells Wells 0.00 E I18.9.68 1185.65 0.00 E 1280.?:3 1273.:37 0.00 E 1368.57 1356.04 0.00 E 1454.82 1435.57 5.9.16 N 11. 83.47 N 17. 111.69 N i::4. 144.1.9 N 31. 75 W .9.82 N 4. 24W 20 W 9.49 <1 N 7 !5W O0 W 8.85 < N!3 2W 5.9 W 8.46 < N17 50W 2.2.9 E 1534. .9.18 E 1611. 20.72 E 16.97. 34 1507.42 11 1575.25 25 164.9.33 177.34 N 38. 212.37 N 46. 255.15 N 56. .95 W 8.86 Nt9 26W 32 W 'P.:36 N14 2:3W 60 W .9.59 N 9 36W 10 W J~.7~ N 6 26W 13 W 10.85 N 0 43W 37 E 15.54 N 5 4. E 67 E 25.2.9 N 8 26E 08 E 40.62 NiO liE 4.9 E 61.95 NIl OE 44 E 89.3:3 Nil 48E :21E 122.45 N12 14. E 5.9 E 161.06 N:I. 2 2iE :.-]:7 E 2(]2.2'7 N ! 1 44E 55 E 244.78 NIO i3E 58 E 288.6.9 N 8 22E ERSTMRN CHRISTENSEN Po s i t i on MD TVD o n we 11 M-:3 his 0.00 0.00 0.00 100.00 100.00 O. 00 200.00 200.00 0. O0 300.00 300.00 0 ~, 00 400.00 O. 00 500.00 500. O0 0. 600. O0 600. O0 0. O0 C' O0 700 O0 O. 00 800. O0 800.00 O. O0 900. O0 900. O0 O. O0 L000.00 1000.00 0.00 L100.00 1100.00 0.00 L200.00 1200.00 L300.00 1300.00 L 4,00.00 L 500,, 00 0. O0 O. O0 0.00 O. O0 L600.05 1600.00 L700.:37 1700.00 L801.25 1800.00 L 902.7,8 1 'PO0,, O0 ?0 2000. O0 :34 2100.00 ':'.216.70 2200 ,, O0 2325.46 2300.00 32.38 4.7. O1 64.61 85.38 N N N hi CALCULATION OF LE.].:,T DISTANCE BETWEEN WEL.L'.:; C!os::,st Position on ~Jetl M-5 ,-W MD TVD NS EW N N N N N hi N N 0.00 E 0..00 0.00 0,00 E 100.03 100,,03 0.00 E 200.05 200.04 0,00 E 300.04 :--:00.02 2.19 0.54 N N N N 0.00 E 400.01 399.99 0. O0 E 499 ,, ::~? 4':7..'9. 'P6 0.00 E 599, 99 5.9'P. 'P6 0. O0 E 6':?:~. 97 /_-,'Pt:?. 94 0, O0 E 799. '.-7,7 7'..?.'F/. :'P3 O. O0 E 899.99 879. ':74 0.00 E 1000.01 'F.~'.:.)':?. 95 0.00 E 1100.03 1099.97 0.45 1.09 I, 73 2.52 .-., 2.93 2.12 1.33 N N N N 0.00 E 1200.08 1200.01 0.00 E 1300. I2 1300.05 0,,00 E 1400.11 1400.02 0 ,, O0 E 1500. Or'-.'.' ! 4'P'P. 'P'P N N N 2,.29 E 1600,10 1~=;79.79 '.:?. ,1 o'-' E 1700. i 6 1 '7 ()0 ,. 04. 20, 72 E :L F,!:O0.27 1800, 14 37,02 E 1900,4.3 1700.29 4, 32 5,, 5':..? 6, :37 8.14 109.55 N 1:3'7.44 N ~._ ':',_,. 2 :t E 2000. :34 2000.2:0 84.50 E 2100.44 2100,,30 !!6,,15 E 2200.56 2:200,,42 ! 5:2:. 48 E 2:2:00.71 2:300.56 9.03 9 ,, 44 'P. :34. 1 'P6. 'P:3 E 240 .I.. :::0 2401.16 24.'7.06 E.,:.'-' ~ <.:, )_t. ,: '='c . .... :,1 ~,-,)1 4/-, 1 I ,, 0:3 N N N N R e ~F : S08 .i. ~-- '~' ..... · :. :':: M A Distmnce Dir-ectio Betueen Between Wel'ts Wells 4 57 W :.i '-'~-. .... --' .-, N60:3:::W 4.20 W 4.73 <.'1 N62 26W 3.58 W 3.. 88 .:.'] N67 5W 2.71 W 2.96 'C N7'P 35W 2,. 96 W 3?:00:' S8i 23W 3.71 W :3.86 S7:3 40W 4,40 W 4~73 S68 34W 5,,03 W 5.62 S63 24W 6.07 W 6.75 S64 6W 7.22 W 7.79 S67 56W 8,26 W 8,,53 S'75 35W 8.95 W 'P.05 S81 34W 7,59 W 10.34 N72 53W 7.30 W i6.48 N88 18W '7.00 W 28.1:f. S80 28W 6.71W 45.46 S74 7W 6.54 W 68.97 S6'P 51W 6.38 W 98.50 S67 l?W 6.22'W 134.23 S65 44W 6.06 W 176.52 S64 40W ERSTMRN CHRISTENSEN - · , F':AtJ.-.:ULAT ION OF LEAST DISTANCE Positi,:,r, on '~ell M-3 MD TVD NS , .,c,C)~.). 00 1500.00 · 600.05 1600.00 L700,37 1700.00 :801.25 1800,00 L 902,98 1C;00, O0 .~005,90 2000,00 :-'110,34 2100.00 70 2200.00 0,00 N 1.27 N 5.10 N 11.53 N 20.59 N 47. C)I N 64.61 N EW 0,00 E ?~18 E 20.72 E 37.02 E 58.21 E 84.50 E 116.15 E BETWEEN WELLS MD Closest Position ,.-,r, well RLF-1 TVD NS EW 1750, 96 1,'546.02 1824.81 1700.12 1896., 92. 1753 ,.-.~ ! 97(') 81 1.:, .)7.75 '--'1 91 16.:36 N · ~":' 48 N ,~)(-) ,r~._T., N Re-F : .:,,..)76:3:5:. oF, A 2042.47 1860,85 2111,(}6 1~11.00 2174~61 1~57.17 2236,~8 2001.47 126.40 N 160.89 N 193.14 N 225.44 N Distmnce Dir'ectio Between Between Wells Wells 219.02 E 264.15 S84 17E No.~ I'F-'E 18 6.4 4 E ~'-: 1 C) . 15 'C ....... .~ .79 162. c} 1 ._ 4 E 4_ -::] N71 .:,,.--,~c,_ ~ .-~ 121.7.5 E 12:_3./:",7 'C N51 .:,.- E 89.36 E 124.37 57.74 E 156~31 N 0 13W 28.3£) E 211.93 N21 2W 1.40 W 281.'~'-'~.~ N36 loW.. ERSTMRN CHRISTENSEN Position on well M-3 MD TVD NS L200.00 1200.00 i300.00 1300.00 ~400.00 1400.00 L500. O0 1500~00 600.05 1600.00 700.37 1700.00 801.25 1800.00 0.00 N 0.00 N 0.00 N 0.00 N 1.27 N 5.10 N 11~53 N CALCULATION OF t_.EAST ~ DISTANCE BETWEEN WELLS Closest Position on well RLF-.1 EW MD TVD hiS EW 0.00 E 1596.88 1431.08 0.00 E 1653.27 !460.13 0,.00 E ]702,.33 1484~49 0.00 E 1751,65 1508.~2 Ref : .S07644.8MA 2,29 E 9.18 E 20.72 E Distmnce Between Wells Dipectio Between We!ls~ 39.14 S i51.1I E 278.86 S75 29E 8.07 S 1t4.08 E 196.78 ~5 S85 57E i9.~83 N 81.93 E 119.35 < N76 24E 48.41N 4.9.~2 E 70.09 C N45 53E 1800.23 1532.78 76.55 N 18.40 E 102,20 i847.31 1555.99 103.82 N 12.14 W 175.87 1892,87 1578.46 I30.21N 41.70 W 2~8.97 NJ2 5E N12 11W N27 44W -ERSTMRN CHRISTENSEN · ~-~ MARATHON OIL COMPANY ~.~ ~'~ STEELHEAB P1 ;ztfr.,prr~ ~.~ ~ McAr. thur. River- Field, Cook Inlet, AK ~ -~.~ ~.~ ORIGINAL /// [~ir'.ectic, nml F'lmn submitted bY :.- EASTMAN CHRI.,_.TEN.=.EN, Ar, chor. m~e, Ale. skin · _,¢' 1 ,:, t r, m m e : - B 2-1 Wel 1 r,a.~,e :.- M-3 Revision r,o :- 3 Pr-e~,,.ar-e,J l-,-.,- :-. T ,_lONE:..-.; Our. r. et: :-F'00448.2MA CFIRISTENSEN Pmme i EASTMAN CHRISTENS;EN, Anchorm~e, A1,.askm 1._0-w~,_,.-.,:..~ ~-:¢lculmtion F'r.e~,ises All depths mr.e in feet and mr.e RKB,. All distmr,,..-.es ~r.e in .Feet . Or-i~in point o.F lc, cml co,:,rdinmtes is slot. Verticml section is cmlculmted ,:,n the r*lmne N71 2E ( 71.03 de~) mr, d is re.Fer-enced slot. ERSTMRN CHRISTENSEN F'~z ~ e 2 Well Pr.o~ile SYnoPsis EASTMAN CHRISTENSEN, Anchor. a. qe, Almskm Memsur-ed Tr,~e Vert Inclir,. Azim,~th Bea. rin~ DePth Depth De~ Min De~rees De~ Min 15-AUG-89 Rect~rl~ljl~r Coordinmtes Verticml Section O. O0 0.00 0 0 0.00 N 0 OE O. 00N O· OOE O. 00 CASING KICK OFF POIhIT 1450.00 1500.00 1450, O0 0 0 1500.00 0 0 0.00 N 0 OE 0.00 N 0 OE O. OON O. OOE O. O0 0.00N O. OOE O. 00 tlLD - BUItD RATE = 2.50OEG / IOOFT. 2967.96 2869.62 36 42 71.03 N71 2E 147.69N 429.59E 4~4.27 71.03 N71 2E 96~.94N 2821.31E 2983.39 ERSTMRN CHRISTENSEN _.HRI.~TEN._P.N, Anchor.~e A] 6$km 15-ALIE~-87 P~e 3 EASTMAN P ' '-' .~- Well Pr. ofile K ICI< OFF pl-I INT Measur-ed Tr'ue Ver't Ir;clir,. DePth DePth De~ Min 0,00 0,00 0 0 475.00 475.00 0 0 500.00 500.00 0 0 950.00 950.00 0 0 1000.00 1000.00 0 0 1450.00 1450.00 0 0 1500, 00 1500.00 0 0 1600.00 1599.97 2 30 1700.00 1699.75 5 0 1800.00 177.~S.¢. 14 7 30 1900.00 1897.97 10 0 2000.00 1 ? S/6.04 12 30 2100.00 2093.17 15 0 2200.00 2189.17 17 :_--:0 2300.00 2:7:8.'9.85 20 0 2400.00 2377.05 22 30 :2500.00 2468.57 25 0 2600.00 2558.25 27 30 2699.98 2645.90 :30 0 2700, 00 ~°~...-.., '~2. . :30 0 '2800.00 2731.40 32 30 2900,00 2814.54 35 0 '..2967.96 2869.62 :36 42 3000.00 2::-.;95.31 36 42 3100.00 2975.49 :36 42 3200.00 3055.67 36 42 3300.00 3135.85 :36 42 :--: 400.00 :3216.03 :36 42 :3500.00 :32'? 6,21 36 42 3600.00. :3376 . .z,~'°,., 36 42 Azimuth Bemr. in~ De,~r. ees De-~ Min O. O0 N 0 OE 0.00 N 0 OE O. 00 N 0 OE O, O0 N 0 OE 0.00 N 0 OE 0.00 N 0 OE 0.00 hi 0 OE 71.03 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.03 N71 2E 71.03 N71 2E 71.03 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.03 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.03 N71 2E Rectangular. Coordinates Vertical Section 0.00 N 0.00 N 0. OON 0. OON 0. OON O. OOE O. O0 O. 00E O. 00 O. 00E O. O0 O. OOE O, O0 0. OOE O. O0 0,0ON 0.0ON 0.71N 2.84N 6. o7N 0.00E 0.00 0. OOE O. O0 2.06E 2, 18 8.25E 8.72 18.54E 19.61 11 17 25 34 44 ,32N ,66N ; 39N .49N .94N 32.93E 34.82 51.37E 54.33 73.85E 78.09 100.31E 106.07 130.71E 138.21 56.72N 69.8IN 84.19N 'P'P .... .'N )9 ~'~-'~' · . ~.~ ---~ I ~ 164. ?SE 174.46 203.06E 2 t 4.7:3 244.8:--:E 25:=:. '.-?5 290.36E 307.04 290.37E 307.05 116.69N 134.75N 147.69N 153.~2N 17:3.34N 3:39.42E 358.92 391.96E 414.47 429, 57E 454.27 447.70E 473.42 504.22E 5:3:3. 18 192, 77N ...17 20N 231.63N 2.=, 1.0 ./:,N 270.49N 560.73E Mg'?.,. ~, 94 617.25E 652.70 673.76E 7]2,46 730.27E 772.2:3 786.79E 831.99 ERSTMRN CHRISTENSEN Pa~e 4 Well F'r-ofile EASTMAN CHRISTENSEN, (cor, t inued) Me.~mur. ed True Ver. t Inclir,. DePth DePth DeM Min 3700.00 3456..56 :36 42 3800. O0 3536.74 36 42 3900.00 3616.92 36 42 4000.00 3/.:,F.~7.10 36 42 4100.00 3777.2:3 :26 42 4200.00 3857.46 36 42 4300 .... 0 ('~ 3 .'F.~ :37 /-,:3 o6'-' 4'2 4400.00 4017.81 36 42 4500. O0 409'7. '.~'~ :_'-:6 42 4.600.00 4178.17 36 42 4700. O0 4258.35 36 42 4.80(3. O0 4338.53 36 4.2 4900.00 4~18.71 36 42 5000.00 4498.88 36 42 5100.00 4579.06 36 42 5200.00 465'?. 24 36 42 5300.00 47:39.42 :_--,'6 42 5400.00 4:_--:17, 60 36 42 · _, ._, 00.00 4 :B 9 '~ .78 .:,'-' 6 42 5600.00 4977'. 96 36 42 5700.00 5060. 13 36 42 5800.00 5140.31 36 42 5900.00 5220.47~ 36 42 6 ¢], (')('~ (:) 0 .=i'-' ' . ........ :,(.)0 67 3/_-, 42 610(:~. 00 53:30. :35 :36 42 6200. O0 5461.03 36 4'.? 6300.00 5541.21 :36 42 6400.00 5621.38 36 42 6500.00 5701.56 36 42 6600.00 5781.74 36 4:...--.' An,:hor~ee, A1 Azimuth Bemr. in~q De~r. ees Oe~ Min 71.03 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71,03 N71 2E 71.03 N71 2E 71.03 N71 2E 71.03 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.03 N71 2E 71.03 N71 2E 71. (}3 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.0:3 N71 2E 71.0:3 N71 2E 71.03 N71 2E 71.03 N71 2E 71.0:3 N71 2E 71.0:3 N71 2E 71.03 N71 2E l 5-AUG-:3'.-} Re,: tmr,~o 1 a r- Coor. dir,~tes Ver. tic~l Sec t i or, ~'-"'="=~,_, ... ?2N 84:3 . :30E 891 .75 309.35N 899.82E 951.51 328.78N 956.33E 1011.27 34.8.21N 10~ 2.85E 1071.03 :367.64N 106'?. :36E I '--'(' 1 .... ). 79 387 406 4.25 445 464 .07N · 50N .92N · 35N .78N 1125.88E 1190.55 1182.3~E 1250.32 1238.91E 1310.08 1295.42E 1367.84 1351.94E 142~.60 484.21N 1408.45E 1489.36 50:3.64N 1464.96E 1549.12 523.07N 1521.48E 1608.8:3 542.50N 1577.99E 1668.64 561.9:3N 1634.51E 1728.4(3 581.36N 1691.02E 1788.17 600.79N 1747.54E 1847.93 620.22N 1804.05E 1907.69 639.65N 1860.57E 1967.45 65~.08N 1~17.08E 2027.21 678 697 717 736 756 .50N .93N . :3/=, N .79N · 22N 197:3.60E 2086.97 203(]. IIE 2146.73 2086.63E 2206.49 2] 42:. 14E 2266.25 217'~. 65E 2326.02 775.65N 795.08N 814.51N 833.94N 853.37N 2256.17E 2385.78 2312.68E 2445.54 2369.20E 2505.30 2425.71E 2565.06 2482.23E 2624.82 ERSTMRN CHRISTENSEN Well P~c, film EASTMAN CHR I STEN'SEN, (cor, tinued) Measured True Ver. t D e P t h D e P t h Anchor-m,.~e, A1 I r, c 1 in. A z i m u t h B e.~ r- i n ~ De~ Mir, De~r. ees De~ Min 15-AUG-8'~ Rectmn~ul a.r. Co,:,r d i n,ste s Ver. ticml Section 6700. O0 5861.92 36 42 6800, 00 5942, 10 36 42 6900.00 6022.28 :_::6 42 7000,00 6102.46 36 42 7024.38 6122.00 36 42 720r~... 00 /-_,2/-,2_ _.,. 81 ._,':'/-_. 42' 7200.00 626:2.81 '-'/-..:, ..., 4.:,,.-..¢. 71.03 N71 2E 71.03 N71 2E 71.0:3 N71 2E '71.03 N71 2E 71.0:3 N71 2E 71.03 N71 ,=E 71.0:'-: N71 2E 872.80N 892.23N 911 · 65N 931.08N .s¢._-,.~. 82N 2538.74E 2684.58 2595.26E 2744.34 2651.77E 2804.10 2708.27E 2863.87 2722.06E 2878.45 ERSTMRN CHRISTENq N STRATIGRAPHIC HIGH RESOLUTION DIP METER LOCATED IN THE APPENDIX AOGCC GEOLOGICAL MATERIALS iNVENTORY LiST PERMIT # o0 .~ - /// WELL NAME 7"~ ~/ COMPLETION DATE ~ ! -'~ tj~o CO, CONTACT check off or list data as it is rcceived,*list received date for 40?, if not drillinQ histo~' sarvcv well tests cored core analysis ditch intervals uircd list as NR core descri ital data I ,~ -¢~nc i ,,,, ~,~Lo SCALE ....... NO, {to thc nearest foot~, [inchl100'~ ,,,, ...................... ~ ...... .~ ...... q ~,~ m,~>~ -q~ ...... N ........ ~2/°: ?o77 ., 91 / / ' -i I ~ ~ .............. ~li I Ii Iiilil I I I I i i ii i iiilli iill ii Memorandum UNOCAL ) DOCUMENT TRANSMITTAL TO: John Boyle LOCATION: 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION October 22, 1990 GEORGE'S COURIER FROM: R. C. Warthen K. D. Kiloh LOCATION: Alaska Region P. O. Box 190247 Anchorage AK 99519 Transmitting as Follows: Trading Bay Unit - McArthur River Field - Steelhead M-3 5 magnetic tapes w/listings ~ ~ ~/~/7~ ~ ~/ ~&.7 ~-] 6 boxes - washed & dried well cuttings ' ; Box 1, set 3: 2740-3730 Box 2, set 3: 3730-4630 Box 3, set 3: 4630-5350 Box 4, set 3:5350-6040 Box 5, set 3: 6040-6760 Box 6, set 3: 6760-7141 copy of dipmeter copy of directional survey 1 blueline & 1 sepia as follows: /Dipmeter Advisor*/Dip Data Analysis ~-Stratigraphic High Resolution Dipmeter ~Oement Bond Tool Run 1 -Cement Evaluation Log Run 1 ~ompensated Neutron-Litho-Density Run 1 /Phasor Induction-SFL Run 1 RECEIVED OCT 2 2 19 0 AJaska Oil & Gas Cons. Commission Anchorage ~-Continuous Gyro (GCT) Run 2 ~Cement Bond Log Run 2 ~ement Evaluation Log Run 2 FORM 1-0C03 (REV. 8-85) PRINTED IN U.S.A. Document Transmittal John Boyle Alaska Oil & Gas Conservation Commission October 22, 1990 Page Two /~DC / CNL/GR Run 2 ~Array Sonic-GR Run 2 /Repeat Formation Tester Run 2 ./~p~ratigraphic Dipmeter/GR Run 2 hasor Dual Induction-SFL/GR/SP Run 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THA~ YOU. OCT 2 2 1990 Alaska Oil & Gas Cons. Commission Anchorage June 25, 1990 Telecopy.. (907)276-7542 Gary Bush Union Oil Company of California P. O. Box 190247 Anchorage, Alaska 99502 Re: Trading Bay Unit M-3 Revised Union Oil Company of California Permit No. 89-111 Sur. Loc. 1039'FNL, 602'FWL, Sec. 33, T9N, R13W, SM Btmhole Loc. 252'FSL, 2357'FEL, Sec. 28, T9N, R13W, SM Dear Mr. Bush Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated November 19, 1989, accompanying the original approved permit are in effect for this revision. V~'~t ruly/yours, / 'i ., ?' , ..." Chairman of Alaska Oil and Gas C~se~ation Co~ission BY ORDER OF THE COP~4ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux Alask, ~_~on Domestic Production Marathon Oil Company RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 June 20, 1990 Mr. Mike Minder Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mike: Re: Well M-3 Permit To Drill Please find attached the revised Permit to Drill revised drilling program. If you have any further questions, please call. Sincerely, G. R. Whitlock Drilling Superintendent \DD13/DD179 Attachment cc: Lynn Woodruff/UNOCAL - w/ attach. for Well M-3 wi th the RECEIVED JUN 2 1 1990 Ataska O{I & Gas Cons. Commission Anchorage A subsidiary of USX Corporation · :' STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION CDMMISSION · PERMIT TO DRILL 20 AAC 25.005 :.~i~!~ la. Type of work Drill ~ Redrill E:]I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen~ Service [] Developement Gas ~ Single Zone [] Multiple Zone I~: 2. Name of Operator UNOCAL (Marathon Oil Company, Sub-Operator) 3. Address P.O. Box 190247, Anchorage, AK 99519-0247 4. Location of well at surface · 1039' :FNL, 602' :FWL, Sec 33, TgN, :RI3W, S,M, At top of productive interval 238' FNL, 3238' FEL, Sec 33, TgN,.R13W, S.M. At total depth 252' FSL, 2357' FEL, Sec.28, T9N, R13W, S.M. 12. Distance to nearest I 13. Distance to nearest well property line 7100' from ! ADL 18730 unit boud~O¥~.. 70 feet 16. To be completed for deviated wells Kickoff depth 1500 feet Maximum hole angle31.~ 18. Casing program size Specifications Hole Casing Coupling 34" R~-.4C 16" BTC 7-1/2" 13-3/8" BTC BTC 9-5/8" BTC 9-5/8" BTC 5. Datum Elevation (DF or KB) 160' Y,~ above HLLWfeet 6. Property Designation ADL-18730 7. Unit or property Name Trading Bay Unit 8. Well nurpber M-3 9. Approximate spud date June 27, 1990 14. Number of acres in property 5116.00 acres 10. Field and Pool McArthur River Field Grayling Gas Sands Pool 11. Type Bond <,. 2o ,~c 25.025) Number 5194234 Equitable Amount $200,000 U.S. 15. Proposed depth(Mo,~ ~D) 7106' MD 6387' TVD feet 17. Anticipated pressure (,. ~ ,,~c 25.035 (ax;q) Maximum sudace 2 1 2 2 ,,lO At total Clel:)th (TVD) 2842 Length 407' 877' 1377' ,, 2651 ' ,, 427' 53001 ,, 14,001 5OO 5800 Settinc, i Depth Top Bottom 731 ,731 4801 73! 73! 950 I 731 7.3! 145o! 73I ,7.31 27241 TVD Quantity of cement (include stage data) 480'Driven 950 1300 sx 1450 900 sx 2646 900 sx 500 1300 sx 5272 6387 * Pilot hole size - 17.'.1/2" ** Pilot hole size - 12/1/4,' Highest known gas bearing zone at 1467' TVD (AC-1 Sand) Cement volumes calculated assuming gauge hole, with top of cement on production casing 500' inside surface casing. 20. Attachments Filing fee L~ Property plat k--'l BOP Sketch I~ Diverter Sketch [~ Drilling program ~ Drilling fluid program ~x Time vs depth plot [~ Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. i hereby certify that the foregoing is true and .correct to the best of my knowledge Signed (~~(~ ~- (~.~..x~ ' ' ' ' ' ,~.~ Title (~5~ ~'r-~ Commission Us~ Only Permit Number "j APl'number ' . j Approval date ! 50- I 0 / -"Conditions of approval Samples required D Yes ~ No Mud log reau~red ~ Yes ~ No Hydrogen sulfide measles ~ Yes ~No Directional su~ey required ~ Yes ~ NO Required working p~u~ fo~O~'~ ~ '' Other: ~ /~/~ ~~ 7 ~SM; ~ l OM; , by order of ' Approved by ~ ~ ~/. ~ ~ ~ Commissioner the commission Form 10-401 Rev. 12-1-85 ISee cover letter for other requirements WELL: M-3 LEG: B-2 SLOT: 10 REVISION NO.: SURFACE LOCATION: BOTTOMHOLE LOCATION: DRILLING AND COMPLETION PROGRAM MARATHON OiL COMPANY ALASKA REGION FIELD: AFE No.: TYPE: Trading Bay Unit, Steelhead Platform 8337 -9 Dual gas producer 1 DATE: 6/20/90 1039'FNL, 602'F-"WL, Sec.33, T9N, R13W, S.M. 252'FSL, 2357'FEL, Sec.28, T9N, R13W, S.M. @ 6387' TVD RECEIVED JUN 2 ]. 1990 Alaska 0il & Gas Cons, Commission Anchorage KB ELEVATION: GL ELEVATION: 160 ft. FORMATION AC-1 A-1 B-1 C-1 D-1 TOTAL DEPTH TYPE CONDUCTOR: AUXILIARY: SURFACE: PRODUCTION: SIZE 20 16 13.375 10.75 9.625 9.625 ESTIMATED FORMATION TOPS: DEPTH(MD) DEPTH(i'VD) 1467 1467 2792 2872 3202 3382 3902 4255 4292 4741 6387 7106 CASING PROGRAM 133 75 GRADE X-56 K-55 THREAD RL-4S BTC 61 K-55 BTC 55.5 43.5 47.0 N-80 N-80 N-80 Page I BTC BTC BTC POTENTIAL CONTENT gas/water gas/water gas/water gas/water gas/water SET FROM Surf Surf SET TO 950' 950'TVD 1450' 1450'TVD Surf 2724' 2646'TVD Sud 500' 5800' 500' 5800' 7106' HOLE SIZE 26" 17-1/2" U/R to 22" 12-1/4" U/R to 17-112" 12-1/4" SIZE WEIGHT GRADE CASING DESIGN SETTING FRAC GR FORM PRSS DEPTH,TV @ SHOE @ SHOE MASP 16" 75.0# K-55 1450' 12.1 716 989 DESIGN FACTORS TENS COLL BURST 5.64 1.35 2.66 13.375" 61.0# K-55 2646' > 14.0 1266 2122 1.46 1.10 3.70 10.75" 55.5# N-80 500' 2180 3.60 13.7 2.96 9.625" 43.5# N-80 5272' 2713 3.04 1.32 2.33 9.625" 47.0# N-80 6387' > 14.0 2842 2842 6.55 1.43 2.42 DIVERTER SYSTEM The diverter system will consist of a 29-1/2" x 500 psi annular preventer, a 30" x 500 psi riser, and two 16" diverter lines each equipped with a 16" hydraulically actuated full-opening ball valve. A preselected diverter valve will open automatically and simultaneously when the annular is closed. The direction of flow can be changed without opening the annular. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 16-3/4" x 5000 psi Hydril type GK annular preventer, a 16-3/4" x 10000 psi Hydril double gate ram type preventer outfitted with blind rams in the bottom and pipe rams in the top, a 16-3/4" x 10000 psi drilling spool (mud cross) equipped with a 4-1/16" x 10000 psi outlet and a 3-1/16" x 10000 psi outlet, and a 16-3/4" x 10000 psi Hydril single gate ram type preventer outfitted with pipe rams. A 16-3/4" x 5000 psi riser will be utilized between the blowout preventers and the casing spools. The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system, both with a readout convenient to the drillers console. The blowout preventers, choke manifold and associated equipment will be pressure tested to 250 psi and to 3000 psi with the exception of the annular which will be tested to 250 psi and to 2500 psi. RECEIVED JUN 2 ]. ]990 Alaska 011 & Gas Cons. ~mm~mor: Anchorage Page 2 MUD PROGRAM DEPTH TO WEIGHT VISCOSITY WATER MUD ppg sec/qt LOSS TYPE 950' 8.8-9.0 60-80 <30cc's Spud 1450' 9.0-9.2 60-80 <30cc's Spud 2724' 9.2-9.4 40-50 <20cc's Gel/Benex 6387' 9.4-9.6 40-50 < 10cc's Polymer Mud discharges will be monitored and reported per EPA requirements MUD EQUIPMENT The solids control equipment consists of an Brandt dual tandem shale shaker, a Brandt 2-cone desander, a Brandt mudcleaner, and a Brandt centrifuge. WELLHEAD SYSTEM STARTING FLANGE: 30" series 300 CASING HEAD: 20" S.O.W. x 21-1/4" 2000 psi FMC segmented clamp hub w/2" L.P. outlets CASING HEAD CLAMP: 21-1/4" 2000 psi FMC segmented clamp CASING HEAD: FMC Unihead Type II, 2 step, 16" pack-off bottom w/21-1/4" 2000 psi clamp hub x 16-3/4" 5000 psi flanged top w/2-1/16" 3000 psi outlets TUBING HEAD: FMC TC-60-ET, SPCL 16-3/4" 5000 psi STD BTM x 16-3/4" 5000 psi FLNGD top w/2-1/16" 5000 psi outlets and four 1/4" SCSSV control line ports RECEIVED JUly 211990 Alaska 0il & ~as Cons. Cold,mission AnChorage Page 3 CEMENTING PROGRAM CONDUCTOR: 20"@ 950' MD LEAD SLURRY TYPE: Trinity Light Weight w/ TOP OF CEMENT: SURFACE WEIGHT: 13.2 YIELD: 1.33 WATER REQ.: 6.7 PUMPING TIME: 5.00 + 3% Cacl2 + .75% Gasban PPg. cu. ft./sk gal/sk hrs:min EXCESS (%): 100 % ESTIMATED VOLUME (Gauge hole): 1360 sx TAIL SLURRY TYPE: Premium cement w/2% Cacl2 + .50% Gasban 750 ft. 15.8 ppg. 1.15 cu. ft./sk 5 gal/sk 3:40 hrs:min 100 % TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME (Gauge hole): 600 sx AUXILIARY: 16"@ 1450' MD LEAD SLURRY TYPE: Trinity Light Weight w/3% Cacl2 + .75% Gasban TOP OF CEMENT: SURFACE WEIGHT: 13.2 ppg. YIELD: 1.33 cu. ft./sk WATER REQ.: 6.7 gal/sk PUMPING TIME: 5.00+ hrs:min EXCESS (%): 100 % ESTIMATED VOLUME (Gauge hole): 950 sx TAIL SLURRY TYPE: Premium cement w/2% Cacl2 + .50% Gasban TOP OF CEMENT: 1150 ft. WEIGHT: 15.8 ppg. YIELD: 1.15 cu. ft./sk WATER REQ.: 5 gal/sk PUMPING TIME: 3:40+ hrs:min EXCESS (%): 100 % ESTI MATED VOLU M E (Gauge hole): 700 sx RECEIVED JL N 2 t 1990 Alaska Oil & Gas Cons. L;ol~rmssion Anchorage Page 4 SURFACE: 13-3/8" @ 2724' LEAD SLURRY TYPE: Trinity Lightweight w/1% CaCI2 + 1.5% Gas Ban and .25% Halad 344 TOP OF CEMENT: SURFACE WEIGHT: 13.2 ppg. YIELD: 1.33 cu. ft./sk WATER REQ.: 6.70 gal/sk PUMPING TIME: 5:30 hrs:min EXCESS (%): 50 % ESTIMATED VOLUME (Gauge hole): 1100 sx TAIL SLURRY TYPE: +.4% Halad 344 TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME (Gauge hole): Premium cement w/.75% Gas Ban + 1% CaCI2 2170 ft. 15.6 ppg. 1.18 cu. ft./sk 5.2 gal/sk 3:15 hrs:min 50 % 500 sx PRODUCTION: 9-5/8"and 10-3/4"@7106' LEAD SLURRY TYPE: Trinity Lightweight w/.5% Gas Stop + .22% LWL + .25% SuperOBL TOP OF CEMENT: 2200 ft. WEIGHT: 13.2 ppg. YIELD: 1.33 cu. ft./sk WATER REQ.: 6.70 gal/sk PUMPING TIME: 5:47 hrs:min EXCESS (%): 3O % ESTIMATED VOLUME (Gauge hole): 900 sx TAIL SLURRY TYPE: Premium cement w/.4% Gas Stop + .07% LWL + .2% CFR-3 + .25% SuperCBL 45OO ft. 15.8 ppg. 1.15 cu. ft./sk 5.0 gal/sk 3:40 hrs:min 30 % TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTI MATED VOLU M E (Gauge hole): 950 sx Page 5 DIRECTIONAL PLAN DESC MD TVD INCL NORTH AZIM COORD EAST COORD SECTION RKB 0 0 KICK OFF 1500 1500 BUILD @ 3.0 deg/100ff. END OF BUILD 2547 2495 TOTAL DEPTH 7106 6387 0 0 0.00N HOLD 0 N60.92E 0.00N 31.4 HOLD 31.4 N60.92E 136.00N N60.92E 1291.00N 0.00E 0 0.00E 0 244.00E 280 2321.00E 2655 POTENTIAL INTERFERENCE: WELL DISTANCE DEPTH M-1 WITHIN 100' 0-1300' M-2 WITHIN 100' 0-1300' M-5 WITHIN 100' 0-2100' M-28 WITHIN 100' 0-1050' RLF-1 70' 1500' LOGGING PROGRAM CONDUCTOR: No logging is planned for this interval. AUXILIARY: SURFACE: No logging is planned for this interval. GR/SP/DIL and FDC/CNL/CAL/GR from 2724' to 1450'. RECEIVED j t., 2 1990 klask~ u~ & 6as Cons. Commission Anchorage PRODUCTION: GR/SP/Cal/DIL/LSS from 7106' to 2724'. FDC/CNL/Cal/GR from 7106' to 2724'. COMPLETION: A Cement Bond Log (CBL/GR) and a directional gyro- survey will be run prior to perforating. Page 6 DRILLING PROGRAM CONDUCTOR: Nipple up diverter and function test same. Drill a 17-1/2" hole to 960' RKB. (Nudge wellbore away from platform while drilling.) Open hole to 26". Run and cement 20" conductor. WOC. Perform top job if necessary. Back out and L/D landing joint. Set wear bushing. Test diverter and 20" conductor to 500 psi. AUXILIARY: Drill a 17-1/2" hole to 1450' RKB. Underream the 17-1/2" hole to 22" from 950' to 1450'. Pull wear bushing. Run and cement 16" auxiliary casing. WOC. Back out and L/D landing joint. Install FMC Unihead w/16" pack-off and test void to 700 psi. Nipple up BOPE. Test BOPE and choke manifold to 2000 psi. Test 16" auxiliary casing to 1850 psi. Set Unihead wear bushing. SURFACE: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg equivalent test pressure. Drill a 12-1/4" hole from 1450' to 2724' per the directional program. Log as per program. Underream the 12-1/4" hole to 17-1/2" from 1450' to 2724'. Pull wear bushing. Run and cement 13-3/8" casing. WOC. Set pack-off and test void to 1100 psi. Test BOPE and choke manifold to 3000 psi. Test 13-3/8" surface casing to 2150 psi. Set Unihead wear bushing. PRODUCTION: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill a 12-1/4" hole from 2724' to 7106' per the directional program. Log. Pull wear bushing. Run and cement 9-5/8" casing. WOC. Set pack-off and test void to 2800 psi. Test BOPE and choke manifold to 3000 psi. Test production casing to 4200 psi. Set wear bushing. COMPLETION: Cleanout casing to PBTD. Run gyro and CBL. Perforate and flowtest the D-16A and D-16BC sand with TCP guns. Kill well, POOH. Set permanent production packer with plug above perfs. Perforate and flowtest the D-3B and D-6 sands with TCP guns. RECEIVED Kill well, POOH. Retrieve packer plug and wear bushing. Run dual JLJfV ~ .~ ~990 strings of 3-1/2" tubing and dual packer. Land tubing. Nipple down BOPE. AI~ Oil 8, $as COns. Nipple up and test tree to 5000 psi. Unload tubing with CTU and nitrogen. AnChorage Page 7 CORING PROGRAM No cores are planned for this well. TESTING PROGRAM No open hole tests are planned for this well. RECEIVFF Jg~ 2 ~ 1990 ~aska Oil & Gas Con~ ~v~,,,,~lor A~chorage Page 8 HOr-ZONTAL PROJECT I ON SCALE 1 IN. = 1000 FEET MARATHON OIL Compmn Leg B2. $1o~: 10. I,/e~l Not M-3 Propoeed STEELHEAD Pla{f'orm. Cook Inlet:. Alaeke z 0 --I "t- I 0 C~ --I 1 000 3000 ~ 2000 - 1000 . 1 000 14EST-EAST 0 1000 2000 , I I I 3000 4000 I , I TD LOCAT ! ON ~ 252' FSL. 2357' FEL SEC. 28. TgN. R13g $ I D-3B TARGET I TVD=4735 TIID=517'1 DEP= 1647' NORTH 801 EAST 1439 D-16ATAR~T TV~6~$ T~=~ ~P=2~1 NORTH 11~ EAST 213,3 D- 16A LOCAT ! ON t 147' FSL. 254,5° FEL SEC. 28. TgN. R13V SURFACE LOCAT ION t 1039' FNL. 602' F#L SEC. 33. TgN. RI31,/ D-3B LOCAT !ON ' 238' FNL. 3238' FEI. SEC. 33. TgN. RI 3g N 60 DES 55 HI N E 2655' (TO TD) .^.^..o. o,c L.,, .~. S,o. ..., .o, STEELHEAD Pl.t:Form, Oook H-3 Inlet:, Propoeed Alaeke 0 . RKB ELEVATION, 160' c I'll rtl ! 000 2000 _ 3000 _ 4000 _ 5000. 6000 _ 7000 CONDUCTOR TVD=475 20' CSG PT TVD=950 16' CSG PT TVD=1450 KOP TVD=1500 TMD=1500 DEP=O 3 9 L2 BUILD-;S DE~ 15 PER 100 FT I 2?EOC TVD=2495 TMD=2547 DEP-280 8" CSG PT TVD=2646 THD=2724 DEP-3?2 ~ AVERAGE ANOLE ,.31 DEG 24 ~IN RGET TVB 47'3;5 T~B=5171 DEP=1647' D-16A TARGET TVDm6035 TMD=6694 DEP=2441 TD / 9 5/8" CSG PT TVD=6387 THD-7106 DEP-2655 I I I 1 000 2000 :3000 VERTICAL SECT[ON 1100_ 1000_ 900 _ 800 _ 700 _ 600 _ 5OO 400 _ :300 . 400 I 500 I 600 I 7O0 I 8400 5400 8000 ;800 I 7800 I i 400 500 600 '~'3400 i 700 8OO I ;800 900 I 1000 1100 1200 1 300 1 400 ~ I I I I I ~ ~ .......... o6'7, 1200 1400 I 8OO 8600 ;ooo ~. "~ :3600 3800 i 9O0 4000 8800 _ 1 000 ~ _ 9OO 800 _ 70O _ 60O _ 50O ~;~,,400 90O0 _ 400 ~-81~[D-~RD I~ 300 I I I I i 1 000 11 O0 1 200 1:300 1 400 2O0 150 100 5O 5O 100 100 I 5O 5O 1 O0 1 50 200 250 :300 350 400 I I ! I I I 2000 1800 6400 )0 4000 ~Jo°° 6OOO ~ 1000 / lO00 / ,"~8oo O0 1 100 / / / / / ~600 / / 1600 / / ! 16oo / / / / I I '"'2600 I I ~ ~"2.~oo ! 8o.~ / i I I I I I I I Y 140~ 1400 / / / / 1200 ,00 600 0 50 1 O0 1 50 200 250 300 350 400 _ 3OO .250 _ 200 _ 150 _ 100 _ 5O _0 5O 1 O0 Alaska, ,on Domestic Production Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 9071561-5311 June 5, 1990 Ms. Lynn Woodruff UNOCAL P. O. Box 190247 Anchorage, AK 99519-0247 Dear Lynn: Re: Wel 1 M-3 Permitting Changes Please be advised that the following changes have been made to the planned TBU Well M-3 from the Steelhead Platform. o Surface Location: Slot 10, Leg B-2 - 1,03g' FNL, 602' FWL of Section 33, TgN, R13W o Production Interval: 238' FNL, 3,238' FEL of Section 33, TgN, R13W o Bottom Hole Location: 252' FSL, 2,357' FEL of Section 28, TgN, R13W at 6,387' TVD o 9-5/8" Casing Depth: 6,387' TVD, 7,106' MD o Maximum Hole Angle = 31.4° Please make any necessary permitting changes. Sinc~j~ely, Bryan J. Roy District Drilling Engineer \DOCS\DD172 Attachments A subsidiary of USX Corporation HOR._'.ON~T AL PROJECT I ON SCALE ! IN. = lO00 FEE'r HAR~THON OiL Leg B2,' Slot 10, · Nos STEELHEAD Plotf*orm, Cook inlet,! _ Propooeod Al eko ~000 2000 WEST-;EAST 1.000 0 ! 000 ; 2000 .... I ,, _1 .... I 000 . 0 _ ~.~,.u~ A~ ! ?VO.,473$ THD,.St:?! DEP'1647 NDR'rH :80! 000 _ EAS,r 1430 3000 4000 I TD LO~ATION t 252' FILL. 2357' FEL SEC. 28. TGN, R13¥ SURFAGE 1030' FILL. 802 Ft/L S~, 33. Tgg. RI31,1~ · D-3B I.OCATIOII · '238' FILL, 3:~'S8' FEL 9EO. 33. Tgft; RI3W- N 60 DEG 55 HI N! E 2655' i ('TO TD)' HARATHOH OiL Compm~ Leg' B2, Slot' lO,:We~l .~o~ STEELHEAD' P'latiform' Coo!k H'3 Pr, opoeed Inlet, 'Alaeka ~/~~'~i, iARAT ON 0 .~ RKB ELEVATIO#' .16D' rq .2000. ;]000 4.00,0 $000. 6000_ ZOO0 0 CONDUCTOR T¥.D-4Z$ 20": CSO PT TVD-9$O .. 16'"i CSG. PT KOP TVD' 1450 TV.D. 1500.:- THD..1500 DEP-O PER 100- FT 21 2?EOC ' TV.D,,2495 THD-2$4.Z DEP'280 13 3/8" CSG PT TVD-2646 THD-2724 DEP-372 AVERAGE ANGLE 3i D.EG~ 24 MIN D-3B TARGET' TVD'4735: THO-St Zl OEP-1647 · : D-I!6A TARGET TVD-6035 ,THD-6694 OEP-2441 TD / g 5/8" CSG PT TVD~6387 TMD~106 D£P-2655 1000 2000 VERT I CAL SECT i ON I :]000. Unocal North Ameri¢ Oil & Gas Division Unocal Corporation P.©. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region JUNE 6, 1990 Mike Minder AOGCC 3001 Porcupine Drive Anchorage, AK 99504 Dear Mike: Please find attached a letter from Brian Roy, Marathon Oil Company, on changes that have been made to the planned TBU Well M-3 from the Steelhead Platform. Please make any necessary permit changes. Sincerely, Ga~~SC~ ~ % Bush Regional Drilling Manager Attachment GSB/lew Alaska Region Unocal North America~., Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL May 25, 1990 Mike Minder AOGCC 3001 Porcupine Drive Anchorage, AK 99504 Dear Mike: Per the request of Guy Whitlock, Marathon Oil Company a review of the drilling program and permit for Well M-3 Steelhead Platform indicates that the slot for this well was incorrectly identified as Slot 1, Leg B-2. The correct slot should be Slot 10 in Leg B-2. The surface location will be 1,039' FNL, 602' FWL, Sec. 33, T9W, R13W instead of 1,036' FNL, 608' FWL, Sec. 33, T9N, R13W as the permit shows. If we can be of further assistance, please call. Sincerely, G~j~y. (~. Bush Regional Drilling Manager GSB/lew 0064d RECEIVED Alaska.Oil& Gas Cons. Commission ~nchorage October 19, 1989 Telecopy.. (907)276-7542 Anton S. Chaplin Manager, Enviroz~nental Affairs Union Oil Compa~y of California P. O. Box 190247 Anchorage, Alaska 99502 Trading Bay Unit M-3 Union Oil Company of California Permit No. 89-111 Sur. Loc. 1036'FNL, 608'FWL, Sec. 33, TgN, R13W, SM Btmho%e Loc. 66'FNL, 1851'FEL, Sec. 33, T9N, R13W, SM Dear Mr. Chaplin: Enclosed is the approved application for parmit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V.e~y trqlY .y~urp, ~ I /f'~/ .' b",':-" // / C. V. ChattertOn Chairman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COI~MISSION dif Enclosure CCI Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamorea~i STATE OF ALASKA ALASKA ~i. AND GAS CONSERVATION CC"-.~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill E]I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenE]I Service [] Developement Gas:~] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNOCAL (Marathon Oil Company~ Sub-Operator) 152' KB above MSL feet McArthur River Field 3. Address 6. Property Designation Grayling Gas Sands P. O. Box 190247, Anchorage, AK 99519-0247 ADL-18730 Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see2OAAC 25.025) 1036' FNL, 608' FWL, Sec 33, T9N, R13W, S.M. Trading Bay Unit At top of productive interval 8. Well nurpber Number 5194234 100' FNL, 1950' FEL, Sec 33, T9N, R13W, S.M. M-3 Equitable At total depth 9. Approximate spud date Amount $200,000 U.S. 66' FNL, 1851' FEL, Sec 33, T9N, R13W, S.M. November 25, 1989 12. Distance to nearest · 13. Distance to nearest well 14. Number of acres in prOperty 15. Proposed depth(Mo a,d TVD) property line 7100' from 7200' MD ADL 18730 unit boun~,~r 63,2 feet 5116.00 acres 6263' TVD feet ,, 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1500feet Maximum hole angle36.7) Maximum surface 2122 psig At total depth frVD) 2842 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 34" 407 ' 73 73 480 480 Driven 26" 20" 133# X-56 RL-4C 877' 73 73 950 950 1300 sx * 22" 16" 75# K-55 BTC 1377' 73 73 1450 1450 900 sx i7-1/2" 13-3/8" 61# K-55 BTC 2627' 73 73 2700 2646 900 sx 12-1/4" 10-3/4" 55.5# N-80 BTC 427' 73 73 500 500 1300 sx 9-5/8" 43.5# N-80 BTC 5300' 500 500 5800 5141 9-5/8" 47# N-80 BTC 1400' 5800 5141 7.'200 6263 * Pilot hole size - 17-1/2" ** Pilot hole size - 12-.1/4" Highest known gas bearing zone at 1467' TVD (AC-1 Sand) .'Cement volumes calculated assuming gauge hole, with top of cement o~o,~duct.io.n_c~asing 500' inside surface casing.~LVED OCT 1 ]989 Alaska OiJ & Gas Cons. C0mmlssr0~ Anch0raoe 20. Attachments Filing fee~ Property plat [] BOP Sketch Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~, ~ Title Manager, Envi po, nmental Affai rs Date lO/] l/ Commission Use Only Per m~::~u ?,,,~/ I APl number 50-- .~,~,.~ ,~--.~O ~----~,,~.// Xpl~r~v/at ¢~t§ 9 See cover letter -- for other requirements Conditions of approval Samples req~ir~ed [] Yes /]~ No Mud log required [] Yes /~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~Yes [] N Requiredw°~F~~; E ISM; i-I 10M; r-I l§M Other: ..... by order of Approved byl~' ~ ,, Commissioner the commission Dst Form 10-401 Rev. 12-1-8~5 su / icate DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: M-3 LEG: B-2 SLOT: I FIELD: AFE No.: TYPE: DATE: Trading Bay Unit, Steelhead Platform unknown Dual gas Ixoducer REVISION NO.: 0~2W89 SURFACELOCATION 1036'FNL, 608'FWL, Sec. 33, T9N, R13W, S.M. BOTTOM HOLE LOCATION: 100'FNL, 1950'FEL, Sec. 33, T9N, R13W, S.M. 6263' TVD KB ELEVATION: 152 ft. GL ELEVATION: FORMATION AC-1 A-1 B-1 C-1 D-1 TOTAL DEPTH TYPE CONDUCTOR: AUXILIARY: SURFACE: PRODUCTION: SIZE 20 16 13.375 ESTIMATED FORMATION TOPS: DEPTH(MD) DEPTH{q'VD) 1467 1467 2872 2792 3382 3202 4255 3902 4741 4292 7200 6263 CASING PROGRAM GRADE THREAD SET FROM POTENTIAL CONTENT gas/water gas/water gas/water gas/water gas/water SET TO 133 X-56 RL-4C Sud 950' 950'TVD 75 K-55 BTC Sud 1450' 1450'TVD 61 K-55 BTC Surf 2700' 2646'TVD 10.75 55.5 N-80 BTC Sud 500' 9.625 43.5 N-80 BTC 500' 5800' 9.625 47.0 N-80 BTC 5800' 7200' HOLE SIZE 26" 17-1 U/R to 22' 12-1/4" U/R to 17-1/2" 12-1/4" CASING DESIGN SETTING FRAC GR FORM PRS$ SIZE WEIGHT GRADE DEPTH,TV ~) SHOE @ SHOE MA~.P 16' 75.0# K-55 1450' 12.1 716 989 DESIGN FACTO.RS.. TENS COLL BURST 5.64 1.35 2.66 13.375' 61.0# K-55 2646' >14.0 1266 2122 1.46 1.10 3.70 10.75' 55.5# N--80 500' 2180 3.60 13.7 2.96 9.625' 43.5g N-80 5145' 2713 3.04 1.32 2.33 9.625' 47.0g N--80 6263' >14.0 2842 2842 6.55 1.43 2.42 DIVERTER SYSTEM The diverter system will consist of a 29-112' x 500 psi annular preventer, a 30' x 500 psi riser, and two 16' diverter lines each equipped with a 16' hydraulically actuated full-opening ball valve. A preselected diverter valve will open automatically and simultaneously when the annular is closed. The direction of flow can be changed without opening the annular. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 16-3/4' x 5000 psi Hydril type GK annular preventer, a 16-3/4' x 10000 psi Hydril double gate ram type preventer outfitted with blind rams in the bottom and pipe rams in the top, a 16-3/4' x 10000 psi drilling spool (mud cross) equipped with a 4-1116' x 10000 psi outlet and a 3-1116' x 10000 psi outlet, and a 16-3/4' x 10000 psi Hydril single gate ram type preventer outfitted with pipe rams. A 16-3/4' x 5000 psi riser will be utilized between the blowout preventers and the casing spools. The choke manifold will be rated 3-1116' x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system, both with a readout convenient to the drillers console. The blowout preventers, choke manifold and associated equipment will be pressure tested to 250 psi and to 3000 psi with the exception of the annular which will be tested to 250 psi and to 2500 psi. OCT Alaska 0ii & Gas C0ns~ (;ommissl0~ Anchorage MUD PROGRAM... DEPTH WEIGHT VISCOSITY WATER MUD TO OOC~ sec/at LOSS TYPE 950' 8.8-9.0 60-80 <30cc's Spud 1450' 9.0-9.2 60-80 <30cc's Spud 2700' 9.2-9.4 40-50 <20cc's Gel/Benex 6263' 9.4-9.6 40-50 <10cc's Polymer Mud discharges will be monitored and reported per EPA requirements MUD EQUIPMENT The solids control equipment consists of an Brandt dual tandem shale shaker, a Brandt 2-cone desander, a Brandt mudcleaner, and a Brandt centrifuge. WELLHEAD SYSTEM STARTING FLANGE: 30' series 300 CASING HEAD: 20" S.O.W. x 21-1/4' 2000 psi FMC segmented clamp hub wi 2' L.P. outlets CASING HEAD CLAMP: 21-1/4" 2000 psi FMC segmented clamp CASING HEAD: FMC Unihead Type !1, 2 step, 16' pack-off bottom wi 21-114' 2000 psi clamp hub x 16-3/4' 5000 psi flanged top wi 2-111 3000 psi outlets TUBING HEAD: FMC TC-60-ET, SPCL 16-3/4' 5000 psi STD BTM x 16-3/4' 5000 psi FLNGD top wi 2-1116' 5000 psi outlets and four 114' SCSSV control line ports (~EMENTING PROGRAM CONDUCTOR: 20' @ 950' MD LEAD SLURRY TYPE: Premium cement wi 15 Ib/sk Thix Lite 373 TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): SURFACE 12.8 ppg. 2.17 cu. ft.lsk 11.9 gal/sk 6:00+ hrs:min 100 % ESTIMATED VOLUME (Gauge hole): TAIL SLURRY TYPE: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): Premium cement wi 3% CaCl2 750 ft. 15.8 ppg. 1.15 cu. ft.lsk 5 gal/sk 6:00+ hrs:min 100 % 1100 sx ESTIMATED VOLUME (Gauge hole): 400 sx AUXILIARY: 16' @ 1450' MD LEAD SLURRY TYPE: Trinity Lightweight cement wl.75% Halad 344 and 1% Calcium Chloride TOP OF CEMENT: SURFACE WEIGHT: 13.6 ppg. YIELD: 1.21 cu. ft.lsk WATER REQ.: 5.85 gal/sk PUMPING TIME: 4:00+ hrs:min EXCESS (%): 100 % ESTIMATED VOLUME (Gauge hole): 700 sx TAIL SLURRY TYPE: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): Premium Class G cement wi 3% CaCI2 1170 ft. 15.8 ppg. 1.15 cu. ft./sk 5 gal/sk 6:00+ hrs:min 100 % ESTIMATED VOLUME (Gauge hole): 400 sx SURFACE: 13-3/8' @ 2700' LEAD SLURRY TYPE: Trinity Lightweight wi 1% CaCI2 + 1.5% Gas Ban and .4% Halad 344 TOP OF CEMENT: SURFACE WEIGHT: 13.6 ppg. YIELD: 1.21 cu. ft.lsk WATER REQ.: 5.83 gal/sk PUMPING TIME: 3:50 hfs:rain EXCESS (%): 50 ESTIMATED VOLUME (Gauge hole): 500 sx TAIL SLURRY TYPE: Premium cement wi 1.5% Gas Ban & 1% CaCI2 TOP OF CEMENT: 2170 ft. WEIGHT: 15.5 ppg. YIELD: 1.19 cu. ft.lsk WATER REQ.: 5.3 gal/sk PUMPING TIME: 3:00+ hrs:min EXCESS (%): 50 % ESTIMATED VOLUME (Gauge hole): 400 sx PRODUCTION: 9-5~8' and 10-3/4' @ 7200' LEAD SLURRY TYPE: Trinity Lightweight w11.5% Gas Ban, .14% LWL TOP OF CEMENT: 2200 ft. WEIGHT: 13.6 ppg. YIELD: 1.22 cu. ft.lsk WATER REQ.: 5.95 gal/sk PUMPING TIME: 4:00 hrs:min EXCESS (%): 30 ESTIMATED VOLUME (Gauge hole): 300 sx TAIL SLURRY TYPE: Premium cement wi .75% Gas Ban, .12% LWL 4060 ft. 15.6 ppg. 1.18 cu. ft./sk 5.2 gal/sk 4:00 hrs:min 30 % TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME (Gauge hole): 1000 sx DESC RKB DIRECTIONAL PLAN MD TV,D,, INCL 0 0 KICK OFF 1500 1500 BUILD ~ 2.5 deg/100ft. END OF BUILD 2967 2869 TOTAL DEPTH 7200 6263 NORTH AZIM ¢OORD, 0 0 0.00N HOLD 0 N71.05E 0.00N 37 N71.05E 147.00N HOLD 37 N71.05E 968.00N EAST (~OORD SECTION 0.00E 0 0.00E 0 429.00E 454 2821.00E 2982 POTENTIAL INTERFERENCE: WELL DISTANCE DEPTH M-1 WITHIN 100' 0-1300' M-2 WITHIN 100' 0-1200' RLF-1 63' 1500' CONDUCTOR: LOGGING PROGRAM No logging is planned for this interval. AUXILIARY: No logging is planned for this interval. SURFACE: Possible GR/SP/Cal/DIL from 2700' to 1450'. PRODUCTION: G PJSPICal/DIL/LSS from 7200' to 2700'. FDCICN L/CaI/G R from 7200' to 2700'. COMPLETION: A Cement Bond Log (CBL/GR) and a directional gyro- survey will be run prior to perforating. DRILLING PROGRA ,M CONDUCTOR: Nipple up diverter and function test same. Drill a 26' hole to 975' RKB. (Nudge wellbore away from platform while drilling.) Run and cement 20' conductor with 1300 sx. WOC. Perform top job if necessary. Back out and L/D landing joint. Set wear bushing. Test diverter and 20' conductor to 500 psi. AUXILIARY: Drill a 17-112'' hole to 1450' RKB. Underream the 17-112' hole to 22' from 950' to 1450'. Pull wear bushing. Run and cement 16' auxiliary casing wi 900 sx. WOC. Back out and L/D landing joint. Install FMC Unihead wi 16' pack-off and test void to 700 psi. Nipple up BOPE. Test BOPE and choke manifold to 2000 psi. Test 16' auxiliary casing to 1850 psi. Set Unihead wear bushing. SURFACE: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg equivalent test pressure. Drill a 12-1/4'' hole from 1450' to 2700' per the directional program. Log if necessary. Underream the 12-114'' hole to 17-112' from 1450' to 2700'. Pull wear bushing. Run and cement 13-3/8" casing with 900 sx. WOC. Set pack-off and test void to 1100 psi. Test BOPE and choke manifold to 3000 psi. Test 13-3/8'' surface casing to 2150 psi. Set Unihead wear bushing. PRODUCTION: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill a 12-114'' hole from 2700' to 7200' per the directional program. Log. Pull wear bushing. Run and cement 9-5~8' casing with 1300 sx. WOC. Set pack-off and test void to 2800 psi. Test BOPE and choke manifold to 3000 psi. Test production casing to 4200 psi. Set wear bushing. COMPLETION: Cleanout casing to PBTD. Run gyro and CBL. Perforate and flowtest the D-16A and D-16BC sand with TCP guns. Kill well, POOH. Set permanent production packer with plug above perfs. Perforate and flowtest the D-3B and D-6 sands with TCP guns. Kill well, POOH. Retrieve packer plug and wear bushing. Run dual strings of 3-112'' tubing and dual packer. Land tubing. Nipple down BOPE. Nipple up and test tree to 5000 psi. Unload tubing with CTU and nitrogen. No cores are planned for this well. CORING PROGRAM TESTING PROGRAM No open hole tests are planned for this well. I! I I I I I I 4- 4- 4- .l- ~kRATHON 0IL CO]~PANY Kill Line Fillup Line 16-3/4' 10,000 psi Doublegate Check Valve Gate Valve Gate Valve Flow Line Hydril 16-3/4' 5000 psi Type GK Annular Pipe Rams h Blind Rams ~ , ~ J Gate Valve HCR Valve I Coflexip Hose Choke Line Pipe Rams ! 16-3/4' 10,000 psi Singlegete 8TEELHEAD pLATFORM Steelhead Blowout Preventer Schematic 16-314° 5000 psi Riser Ball Valve Wellhead STEELHEAD PLATFORM CHOKE MANIFOLD TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS I ! "sw^co CHOKE LINE I A-.._I ALL VALVES IN FLOW PATH ARE 3-1/16' 5000 PSI CAMERON GATE TYPE SECTION AA Plan View STEELHEAD PLATFORM . DIVERTER SYSTEM Rig Substructure I 29-112° 500 Rig Substructure I L~ MSP Annul'r ~ Ceramsilteeefvileled .~ '~ r / Ceramvietse filled 16; Dtverter Line Section View 16' Remote Operated Ball Valve Conductor 16' Diverter Line Riser 29-1/2° 500 psi Flange STEELHEAD PLATFORM CASING AN]9 CEMENTING SCHEMATIC WELL M-3 - PLANNED TOO=SaO0' MDr.':::t'!:'::''~:,~,.~.,.:..~ ;,,._, 4".: :'.~: ::.'...., r..'.': i%° ~:.; ,:.'.: ~::.. ~:: :.'.1 .:'~ .::.~ '..:.', '.:~ ,-.?~ ,;.:; ,o,,. '.'5 :.'1 :; .:'.l ".-:l f.-I .'..:: 34' DRIVEN TO 480' MI) 80' ~ 950' TVD (950' MD) 16' @ 1450' TVI) (1450' ~4D) 13-3/8' @ 8646' TVD (8700' MD) 9-5/8' 8 6863' TVD (7200' MD) HOI ~ZONTAL PROJECTION SCALE 1 IN. = 1000 FEET 3000 2000 _ .......................... t 1 000 C3 -,4 , 1 i SURFACE LOCATION, · : I03S' FNL, 60~' ~ .... · HARATHON OIL COIIPANY Leo B2. SIo~: 1. Well No, STEELHEAD Platfor'm. Cook Inlet aeka 1000 0 WEST-EAST 1000 I 2000 I 3000 TD L(I~AT l ON ' ~' FNL. II)$1' FEI. SEC. 3.3. TON. R I3W TAROT TVD-612,2, TI'ID-?024 DEP-2878 NORTH 936 EAST 2Z22 TAROET Lt:M~ATION' I00' FNL. 1950' FEI. SIEC. 3,3. TgN. R13W N 71 DEG 2 MINE 2878' (TO TARGET) HARATHON OtL Leg B2, Slot 1, Well STEELHEAD PI etform, Cook COnP^NY M-3 Proposed Inlet, Alaska ................ 1000 . 2000 3000 4O00 5000 RKB ELEVAT[ON~ 152' ' ' _ ...................................... 20' CSG PT TVD=950 : ~ TVD= 1450 TVD=1500 TMD=I 500 DEP=O 16= C80 PT KOP $ 0 BUILD 2.$ DEO ....... PER 1 O0 FT ............. 15 20 30 13 3/8' CSG PT TVD=2646 THD=2700 DEP=307 EOC TVD=2870 THD=2968 DEP-454 _ . . AVERAGE ANGLE 36 DEG 42 HI N 6000 - 7000 J I 0 I I 1000 2000 VERTICAL SECTION TARGET TVD-6122 THD=7024 DEP-2878 TD ! 9 5/8' CSG PT TVD=6263 THD-7200 DEP-2983 3000 ~ OCT Alaska Oil & Gas Cons,, Commisslori AnchoraGe CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~ ~./?~ 1. (8) (2 ~.ru, Z3$' ' 10. (10 and 13) 12. 13. (14 thru 22) (5) ovE (23 thru 28) 14. 15. Is the pez-m_it fee attached .......................................... 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acrea§e available in this pool ............ 6. Is well to be deviated and is we!lbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... \ YES NO JREMARZ. S ,,, 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27, 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... ~ , ,, Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... ~ Will cement cover all known productive horizons ..................... ~ Will al! casing give adequate safety in collapse, tension and burst.. .j~ Is this well to be kicked off from an existing wellbore ....... ...... ~ ~ Is old we!lbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ . Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) Add: Geology: DWJ /' - Eng~eering: ..- LCS' rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented ........INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Lease & Well No../~/~ /~;7~0 ' /~-~ NO / REMARKS 2. Is well to be located in a defined pool ............................. 3. Is we~] located proper distance from property line .................. 4. Is w~,l_located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... (8) 9. (3) Admin ' (9-thru 'lj>-' 10. 11. (10 and 13) 12. 13. (4) Cass (14 thru 22) 14. 15. Company /~.z~ //~%3 YES Is the permit fee attached .......................................... ~- Does operator have a bond in force .................................. /{ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... . (5) BOPE (23 thru 28) 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to psig .. Does the choke manifold comply w/API RP-53 (May 84) ....... ' ........... Is the presence of H2S gas probable ...................... · ........... (6) OTHER ~/Vf_~/'~/f~ '~ru' 3i ) (6) Add: Geology: DWJ RPC ~_ For 29. 30. 31. 32. Engineering: LCS BEW MTM RAD rev: 01/30/89 6.011 exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this natUre is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. , SCHLU#BERGER * STRATIGRAPHIC HIGH RESOLUTION DIP#ETER NSD COMPUTATIO'NS COHPANY HELL FIELD. COUNTRY RUN DrATE LOGGED REFERENCE NARATHON OIL CORPANY TBU ~-3 TRADING BAY USA ZT - JUL - 90 73995 RECEIVED OCT 2 2 1990 Ala~im 011 & Gas Cons. Commission Anchorage REPEAT FILE 4" X Zt X 30 HSD LISTING MIC ROFiLMED HARATHON OIL COHPANY TBU H-3 PAGE 1-FILE 1 DEPTH DIP DIP DEV DEV DIAN DIAM Q AZM AZ~ ~-3 6399072 13.1 6401.72 14.8 6403.72 10.8 6405.72 309 6407.72 4.2 6409.72 14.2 6411.72 14.8 6413072 5.9 6415.72 7'0 6417.T2 '6.6 6419.T2"700 6421.T2 "6o0 6423.72. 908 6425~'~ 24. T 6427,72 '. 9.9 6429*72 13.8 643!1'~72 17.9 6433~72 24.8 6435~T2 19.1 6437~T2 19.1 6439.'~2 13.4 6441.72 6.4 6443.72 8 * 1 6445.T2~: 6.4 6449.T2 ~* 6.0 6451.T2 14.9 64530T2 14,7 6455.T2 6457.72 6. 6~590TZ 6461"T2 10.1 6463'"~Z ~ -~T. Z 6465~'72 9.8 646T'TZ' 11.5 6469~TZ ~ 6~710TZ ~ 9.1 6~73.T2; 602 6475.72 ~ 14.0 87 32.5 59 12.1 94 32.5 59 12.2 341 32.5 60 12.1 10 3205 60 12.1 10 32.5 60 12.1 80 3204 60 12.2 89 3204 60 12.2 83 32.4 60 12.2 53 3204 60 12.1 51 3205 60 12.2 50 32.4 60 12ol 33 3204 60 ~1202 13 32.4 60 12,2 202 32.4 60 12,2 57 3205 60 12.2 64 3205 60 12.3 105 32.5 60 12.2 179 32.5 60 12.2 149 3205 60 12.1 119 32o5 60 12,1 138 32.5 60 12.1 57 32.5 60 12'1 61 32.5 60 12.1 82 3205 60 12'0 225 32o5 60 12,0 76 32.5 60 12'1 107 '32°6 60 12-0 116 32o6 60 12.1 126 3206 60 12.1 65 32.6 60 12'1 57 32.6 60 12-1 112 3Z-6 60 12.1 148 32.6 60 12.2 152 32.6 60 12.2 112 32.6 60 12.2 28 32.6 60 12.2 62 32.6 60 I2°1 232 32.6 60 12.2 108 32.6 60 12'2 12ol 12.1 12.1' 12.1_ 12.2 12.1 12.1 12.1 12.1 12.1 12.1 12.2 12.2 12.3 12.3 12.3 12.3 12.2 12*Z 12.2 12.2 12.2 12.2 12*Z 12o2 12.1 12ol 12o0 12.1 12.1 12ol 12ol 1201 12.1 12.1 12'1 12.0 12.1 12.1 A A C A 4: B B 8 A B C C C D :lc C B C A A B A C B C C C D A A D C 6477-72:15o'1 104 32.6 60 12'3 12.1 MARATHON OIL CONPANY TBU Iq-3 PAGE Z-FILE 1 DEPTH ' DIP DIP DEV OEV OlAIq DIAN O ~ AZIq AZM 1-3 2-4, :~ 64,79.72 8.4, 190 32o6 6:48'1:':*'~. XS. 8 167 32.6 6~83~;TZ 7.0 89 3207 6~S~72~ 4 ~ 84 32.7 6487~'72 5~ 133 32.7 · 6&89g*TZ'' ~.9 103 32.7 6~91~TZ~"12.7 120 32.7 6~93.72~ 5.~ 127 32.7 6~.TZ 5.8 289 32.6 &~'~'.: 8.2 30 32.6 &&99.72 9.7 32 6503'72 6.8 129' 32.5 6505'TZ~' 30.Z 190 32-5 6507~72 ~ 19.0 6509'72 17.6 6511.72*.16o7 6513,~72 12-9 6515:.72.i 111.7 6517-72 IZoZ 6519.72111o8 65 ZILT'Z 8.5 6523~TZ '15.3 652~72" 4. Z 6 527.72 7.2 6529.72 6531.72 15.4 6533.72 13.0 6535.72 13.9 67 32.5 75 32.5 73 3205 71 32.5 77 32.5 33 32..5 16 32.5 23 32.5 72 32.5 54 32.5 58 32.5 4,6 3205 68 32.6 88 32.6 8,8 32.7 6537o72:i 5.1 10 32.6 6539.72 18.8 305 32o.6 6541072 22,,8 271 32o5 654,3o72 11oZ 15 3Z.S 6545o72 7ol 15 32.5 654.7o72 3.9 175 3204. 6549.7,?. 6551.72 6553° 72 60 11o9 12ol 60 12.2 12o0 60 11.9 12.0 60 12o0 12.0 59 12o0 11.9 59 11o9 11 09 60 11o9 12o0 60 11o8 11.9 60 11.7 1109 60 11°6 12 o0 60 11.6 12.0 60 12.3 12'5 60 1204, 12o6 60 12o8 13.1 60 12.8 13.1 60 12.1 13.1 60 12'4, 13 60 12.1 13ol 60 12.3 13 o 1 60 t2.2 13.1 60 i'2 o 5 13 60 12.4* 12 o 8 60 12o6 12o9. 60 12a6 12o6 60 12.6 60 .12o6 12o6 60 12-6 12.6 60 12°6 12*6 60 12o3 12.4* 60 12.°4. 12°6 60 12.3 12o4 60 12 °3 12 60 12o3 12~5 60 12o2 12°3 6'0 12'3 12,22 10.1 350 32°3 60 12-1.. 15.7 339 32.3 60 12o2 12.2 IO-2 337 32.3 .60 12-2 C O B A A B O C B A A B C O C A C C A C C C C B C C B A A C O O O B C O C B 6555.72 8°3 357 32.Z 60 12,3 12.3 B 6557.72 4,02 95 3Z.Z 60 12.3 12°3 C MARATHON O[L CONPANY TBU #-3 PAGE 3-FILE 1 DEPTH DIP DIP DEV DEV DIAM DIAH Q · AZ# AZM 1-3 2-4 · 6559072 6.0 55 6561072 708 52 6563.72 10o0 114 6565072 903 105 6567072 902 100 6569.72 11.4 82 6571072 10o8 44 6573.72 12.4, 72 6575.72:14o, 4. 74 6577.72~' 4.2 123 6579-72 ' 7.0 14'8 6581. ?Z':20.7 93 6583.TZ 17.2 95 6 S:~,~'T2 303 6r~; 7 2 ' 5 o 9 659~, 72 9.2 65:~. 72 21.9 6 59'1'- 72 17.0 659~L 72 12o7 6601:~72' ' 8.2 6603.72': 8o0 660.5.72': ~ 4* 0'3 6607.72':' 3.3 6609'72 lol 6611.72 207 6613.72 1.5 6615072: lol 6617.72 9.8 6621o 712 6623.72 ': 507 6 625:~,72, 4'. 3 662Tg'72' 4.1 66219.7 2~ '* 5 o 7 6631-,72 9.8 6633.72 ', 807 6635.72 006 7.3 ,. 14,7 6.1 122 122 5,9 66 80 78 82' 104, 104 119 127' 1 131 95 116 78 34,0 3O3 127 1ZZ 120 111 90 79 318 32ol 60 12o3 32.1 60 12.2 32.1 60 12o2 32.0 60 12.3 31.9 60 12.2 31.9 60 12.3 31.8 60 12.2 31.8 60 12.6 31o8 60 12.4. 31o 8 60 12'8 31o8 60 12-6 31.8 60 12.4 31o8 60 12o3 31o9 60 12o2 32.0 60 12.2 32ol 59 12o2 32.00 59 12.1 32.0 59 12,1 31.9 60 12.1 31o9 60 12.1 31.8 60 12.1 31.8 60 12.1 31o 8 60 12.1 31.8 60 12.1 31.7 60 12.1 31o7 60 12.1 31.7 60 12'1 31.6 60. 12.0 31.6 60 11.9 31.6 60 11o9 31.6 60 11.7 31o6 :60 12o0 31.5 60 11.9 31o5 60 12,1 31o5 60 12.1 31o5 60 12.0 31.5 60 12.0 ' 31o 4 60' 12o4 31.4 60 12.3 12.3 12.2 12.1 12.0 12.2 12.1 12'1 12.5 12o2 12,4 12-4 12.3 12o5 12-4_ 12o5 12.4 12-3 12.2 12.2 12.2 12.2 12.3 12,2: 12.2 12-1 12.2 12.2,, 12'-1 12.1 12o0 12.0, 12'1 12.2 12o3 12o3 12o2 12.2' 12.4 12-3 A A :,lc B A 4: A C C C B C :lc A A A C A A 1) A 1) B A A A A 1) A A A A A A A A 4:. A A A A A A A 6637.72 6.4 32 31o3 60 12.7 12o6 C HARATHON OIL COIqPANY TBU Iq-3 PAGE 6-FZLE 1 DEPTH DIP DIP 'DEV DEV DIAIq DIAIq Q t AZH AZlq 1-3 2-4* ~ 6639.72 664;~'1.72 66~3. T 2 66~5.72 664*7.72 664.9. TZ 6651.7.2 6653.72 6655.72 6657.72 6659.72 6661.72 6663.72 6665.72 6667.72 6669.72 8.4* 8.7 12.1 '26.0 26.5 2.7 0.9 9.2 9.5 7.4* 3.1 4*.2 4*.9 3.8 4*-5 9.0 6671.72 13-8 6673.72 14..7 6675.72 19.2 6677.?Z 2.1 6679'72 2.6 6681' 72 2.4, 6683.72 5.1 6685°72 4..1 6687-72 6.5: 66=89.72 1.6 6691.72 2.9 6693.72 3.8 6695.72 4.6 6697.72 3.3 6699.72 8.2 6701.72 8.5 6703.72 6.0 6705.72 5.2 6707.72 1.9 6709.72'13.4. 6711.7211.8 6713.72 9..6 6715.72 9.5 56 31.3 60 12.4. 12.4. 91 31.3 60 12.4. 12.4* 123 31.3 60 12.1 12.4. 203 31.3 60 12.1 12.4. 205 31.3 60 12.1 12.4. 14.7 31.3 60 12.0 12.4. 80 31.3 60 12.0 12.4. 80 31.3 60 12.3 12.2 83 31.3 60 11.9 12.3 129 31.2 60 12.3 12.2 98 31.2 60 11.8 12.3 89 31.2 60 11.8 12.3 14.2 31.2 60 11.9 12.3 137 31.2 60 11.9 12.3 160 31.1 60 12.0 12.3 93 31.1 60 12.1 12.3 93 31-1 60 12.1 12.3 261 31.0 60 12.1 12.3 24*6 31.0 60 12.1 12.3 112 3;1.0 60 12.1 12.3 106 30.9 60 12.0 12.1 10330.9 60 12.1 12.3 71 30.9 60 12.1 12.2 102 30.8 60 12.1 12.3 70 30.8 60 12'2 12,4. 122 30.7 60 12-1 12.3 156 30.7 60 12.2 12.4. 254* 30.6 60 12.2 12.4* 187 30.6 60 12-2 12.6 161 30.6 60 12.1 12.4. 170 30.6 60 12.2 12o3 111 30.6 60''12.2 12-3 108 30.5 60 12.0 I2,3 113 30.5 60 12.1 12.3 79 30.6 60 12.0 12.2 115 30.4* 60 12'3 tZ,3 115 30.6 60 12'2 12'1 60 30.3 60 12.4. 12'2 58 30.3 60 12.2 12.2 A B B C B B A A A 11: A A A O C A 111: A A A A A A O C A C B A A C A A A A 6717.72 12.3 84 30.3 60 12.0 12.1 MARATHON OIL COHPANY TBU M-3 PAGE 5-FILE 1 DEPTH DIP DIP DEV GEV OIAM DIAM Q , AZM AZM 1-3 2-4 , 6719.72 12.6 672221.72 6.3 672'3.72 3.5 6725' 72 3.9 6727.72 6.1 6729.72 7.7 6731.72. 1.0 6733.72 8- 6735.72 11'] 6737.72 9-5 6739.72 i 19.1 67~,1.72: 8.4. 674.3.72:10.6 674,5.72,:~~,~ 603 6TS 1 '~2 50 Z 675 3'~72' 6.4 6755'72 9.9 67 59,:.T Z 9.9 6761~*72, 4o5 6763'7'2: 5.4 6765.72', 4.08 6767~ 72 8 o 0 6769:.72 · S.0 6771.TZ 6773o72 27.3 6775072 5.2 6777072 608 6779072 808 6781o72. 8-5 6783.72- 8.9 6785.72' 606 6787.72'~ 508 6789072 207 6791.72,. 708 6793.72- 8.0 6795o 72 908 6797072' 9.8 78 30.3 4,O 30.3 90 30.3 84, 3003 4,6 30.3 53 30.22 34, 300 22 111 30.2 81 30.2 38 30. Z 122 30.2 4,5 30.2 52 30.1 79 30.0 82 30.0 74, 30.0 74, 300 0 78 30.0 80 29.9 98 29.9 114, 29.9 100 29.9 93 2909 62 29.9 922 29.8 69 2908 55 2908 281 290 8 14,3 290 8 67 29.8 70 29.8 90 290 8 94 29.8 106 29.8 162 29.8 137 290 8 123 29.8 125 29.8 11~ 29.8 85 290 8 60 11.8 60 11.7 60 11o6 60 I1.5 60 11.6 60 11.5 60 1107 60 11o7 60 11.7 60 11.7 60 11.6 6{} 11.8 60 11.8 60 11.9 60 11.9 60 11.9 60 12.0 60 12.1 60 12ol 60 12.1 60 12.2 60 12.1 60 12'4 60 12.2 60 12.3 60 12 60 12.3 60 12.4 60 12.3 60 122.3 60 12.2 60 12o3 60 12°1 60 12.0 60 11°9 60 11.7 60 11 o6 60 11.6 &0 11o8 60 11.8 12.0 11.8 11.8 11.8 11.7 11.8 11.8 11.8 11.8 11.9 11.8 122'1 12.0 12.3 12203 12.3 12.3 12.3 12.2 12o4. 12.3 12.5 12.5 12.5 1Z,5 12.5 12.4. 12:. 3 12o3 12.Z 12.3 12 -2 12.1 12'0 1108 11.8 11'6 11.9 11o8 A A A A A A B C , B C C A B A A A A A A A B A B A B D D A A A A A B C A A A A HARATHON OIL CO#PANY TBU H-3 SU##ARY DEPTH* * DIP DIP * DEV DEV DIAN DIAN , AZH · AZ# 1-3 2-~ TOP 6399.'72 13.1 8?° 32.5 59. 1Z.1 1Zol 6797.72 9.8 85. 29.8 60. 11.8. 11.8 DIP FREQUENCY BY AZINUTH 0-10 DEGREE DIPS PRESENTATION 210 240 6399- 6400~ 6400- 6500 6500- 6600 6600- 6700 6700- 6797 300 330 N 30 60 E 120 150 5 8 8 1 4 1 1 I 3 5 1 3 6 1 1 1 I 9 l& 10 3 1 9 15 11 · 1 210 PRESENTATION 210 240 6399- 6~00 6400- 6500 1 6500- 6600 6600- 6700 6700- 6797 DIP FREQUENCY BY AZIMUTH 10-90 DEGREE DIPS 300 330 N 30 60 1 1 1 3 2 3 1 3 15 1 1 1 3 120 150 S 210 10 2 Z 1 4 1 1 1 2 3 PRESENTATZON 30 6399- 6400 6400- 6500 8 6500- 6600 5 6600- 6700 2 6700- 6797 9 6O DIP FREQUENCY BY AZZMUTH 0-10 DEGREE DIPS E 120 150 S 210 240 8 I 4 I 1 I 3 6 1 9 14 10 3 1 15 11 4 I 300 330 N 30 5 1 3 1 1 C~ PRESENTATZON 30 6399- 6400 6400- 6500- 8 6500- 6600 8 6600- 6700 2 6TO0- 6797 10 6O :~ · DZP FREQUENCY BY AZ]:NUTH ~ 0-90 DEGREE DIPS E 120 150 S 210 240 1 11 11 6 3 2 2 16 7 6 I 1 9 15 11 3 3 18 14 4 I 300 330 3O mARATHON OIL CO#PANY TBU ~-3 SU#MARY · DEPTH · DIP DIP f DEV DEV DIAn DIAn · · AZN · AZN 1-3 Z-~ · TOP ~ 6399°72 13ol 87. 32.5 59° 12ol 12ol · BOTTOM ~ 6797.72 9°8 85° 29.8 60. 11o8 11o8 END OF LSF - VERSZON 007oE07 1-AUG-90 - 17:28:53 PROGRAM : LSF VERSION : OOToEO7 OATE : 1-AUG-90 TIME : 17:29:16 STRATIGRAPHIC HIGH RESOLUTION DIPMETER MSD COMPUTATIONS CO~qPANY :' I/ELL FIELD : COUNT R Y RUN DATE LOGGED REFERENCE MARATHON OIL COMPANY TBU #-3 TRADING BAY USA 2 Z7 - JUL - 90 73995 MAIN LOG 4~ X 2a' X 30 MSD LISTING HARATHON OIL CORPANY TBU R-3 PAGE 1-FILE DEPTH DiP DIP DEV DEV DIAN DIAM Q AZH AZH 1-3 2-~ 2711.67' 18.0 2713.~ 4.3 2715-.:6~ 26.8 2717-~T 39.7 2719'~7 23.3 272'1,67 19.0 2723.67 17.1 2725.67 11.2 2727~;.67 13.5 2729.67 9.2 2731"67 14.4 2733~67 18.4 2735.67 8.2 2737067. 8.2 2739.67 9.2 2741.67 0-8 2763.67 3.1 2745.67 Z.3 2767.67 lo8 2749.67 6.0 2751.67 ' 4:.7 Z 755~'67 5.5 2757~67~ 8.0 2759'67'~ 3.2 2761.67. 3.7 2763.67 4.0 2765.67 5.4 2767067 12.0 2769.67 5.7 2771.67 3.3 2773.67 8.0 2775.67 3.3 2777.67 3°0 2779067 4°9 2781.67 7-5 2783.67 903 2785.67 15.4 2787.67 506 63 32.4 207 14.3 312 27.3 127 17.2 45 19.8 16 16.5 69 12.1 24 16.1 112 17.3 79 16.9 77 29.6 58 15.3 39 32.8 61 16.1 36 3209 44 16.9 31 32.8 46 14.5 70 32.8 69 13.9 60 32.8 51 13.T 139 32.8 52 13.6 108 32.8 53 13.5 77 32.8 54 13.4 89 32.9 55 13..1 56 33.0 56 13.1 98 33.1 56 12.9 89 33.3 57 12.7 216 33.3 57 12.6 265 33.03 57 12o5 26'3 33.3 58 12.5 250 33.3 58 12o6 251 33.6 58 12.6 27'3 3,304 58 12'6 207 3304 58 12.6 128~33o4 58 12.6 123 33.6 59 12-6 71 33.4 59 12o6 76'33..4 59 12.6 162 33.4 59 12'6 161'33.3 59 12.8 74 33.3 59 12.5 68 33.3 59 12.7 78 33.3 59 12o6 86 33.3 59 12-7 116 33o,3 59 I2*7 157 33.3 5'9 12.7 88 33.3 59 12.6 15.0 17.2 17.3 16.9 16.9 16.6 16.6 16.0 15.8 15.6 15.5 15.8 15.8 15.7 15.4 14.9 14.5 13.9 13-7 13o4 13.4 13.4 .13.4 13'4 13-4 13.4 13.5 13o4 13.5 13.7 13.8 13,9 14,0 :14ol 14'1 14.2 D ' B A B C :lc C A C C C C :lc C B C A A A A A A A 1t: A O B A A A B A A A A A C C C 237 33.6 59 12o6 14.2 O t 2789067 4.8 99 33.¢ 59 12.5 14-2 C 8 MARATHON OIL COMPANY TBU M-3 PAGE Z-FILE DEPTH DIP DIP DEV DEV DZAM OIAM Q flZM AIM 1-3 2-4 2791.67 2.0 193 33.4 2793.67 2.4 195 33.5 2795.67 6.6 205 33.5 2797.67 3.2 332 33.5 2799.67 2.8 301 33.5 2802.67 8.3 263 33.5 2803.67 3.0 14 33.5 2805.67 2.9 15 33.5 2807.67 3.6 123 33.5 2809.67 4.8 115 33.5 2811.67 12-8 91 33.5 2813o67 24*0 141 33.5 2815-6~ ~ 28'9 212 33.5 2817~,~ ::22.3 252 33.5 2819-~' 6.4 33 33.4 2821-~67:'~4.9 71 33.4 282~&7' '1.4 352 33.4 282~L'67 ,. 3.1 247 33 28~*-67 *~.8 215 33.4 2829.67: , 6:.8 ~4 33-4 283I'&T 5.7 I0 33.4 2833'~T 2.2 185 33.4 2837~67 9.7 Z~3 2839.67 9.Z 223 28~1.67, 6.Z 356 2843.67 3.1 185 33.3 2845.67' 2.7 149 33.3 2847.67 Z.3 75 33.3 2849.67 3.4 132 33.~ 2851.67 4.9 98 33.4 92 33.4 59 33.4 4.6 33.4 ,?.9 33.4 65 33.4 68 3,3.4 45 33.4 2867.67 4,.6 276 33.4 2869,;67 2.1 188 33.5 59 12.5 14,,2 59 12.5 14,.3 59 12.5 14,.2 59 12.5 14.3 59 12.4 14.2 59 12.5 14.3 59 12.4. 14.2 59 12.5 14.3 59 12.6 14.4, 59 12.6 14..4 59 12.6 14.5 59 12.T 14..5 59 12.7 14..4 59 12.8 14..4. 59 12-7 14.4 59 12.7 14..2, 59 12-6 14..3 59 12.6 14.1. 59 12.5 14..1 59 12.6 14.1 59 12o5 1¢.1 59 12.6 14..1 59 12.6 14..1 59 12.5 14.0 59 12'5 14..3 60 12.3 14..5 60 12.4. 14.-9 60 12'3 14,,8 60 12,4 60 12.4 14.7 60 12.4 14.-8 60 12.4 14.5 60 12,5 14.2 60 12.5 14~0 60 12~6 13.9 60 12.6 13.9 60 12.6 14.0 60 12.5 14.0 60 12.5 13.9 60 12.5 13.8, A A :1: A A A 4: A A 4: B C C 4: 0 4: C 4: A A A 8 :41: A D 4: 8 4: A C 4: A A A 8 A A A A A -4: A A MARATHON OZL COMPANY TBU M-3 PAGE ,;3-F]:LE 1 DEPTH DZP D]:P DEV OEV DZAM O! AM Q ~ AZM AZM 1-3 2-4, ~ 2871.~~ 1.7 28730'67 2.4 28T5067 6.4, 28TT. 67 ! 2 . 4, 2879~ 67 2.6 ZB81.67 3.9 2883.67 4,. 1 2885- 67 16.2 288!706 7 8.6 2889.67 2891.67 2893.67 2895- 67 2897.67 2899.67 2901.67 2903.67 2905.67 2907.67 2909067 .... '2911.'67 i '2'913'67 2915067'*' 8.6 11.9 2.1 3 - 1 2.9 1.0 6.2 2-9 1.6 0.8 1.1 1.0 2.4 1.9 2919e67 4.7 2921.67 11.0 2923.67 12.8 2925.67 7.1 2927.67 6.5 2929.67 11.8 2931.67 3.7 2933.67 9.3 2935067 8.9 2937..67 10o7 2939.67 11.5 294,1.67: 11o8 294,3.67: 8.7 2945.67 7.3 294,7.67 ~ 503 339 33.5 60 12.5 13.9 29 33.5 60 12o6 14,.0 37 33.5 60 12.5 13.8 24,1 33.5 60 12.6 14,.1 213 33o6 60 12.4, 13.7 228 33.6 60 12.5 13.8 188 33.6 60 12.4, 13.8 107 33.6 60 12.5 13.8 14,2 3306 60 12.5 13.8 158 33.6 60 12.5 13.8 175 3306 60 12.6 13.8 118 33.6 60 12.6 13.8 139 33.5 60 12.7 13.9 347 33.5 60 12.8 13'9 16 33.5 60 12.7 14.0 142 33o5 60 12.6 14-0 159 33.6 60 12.6 13'8 183 33.6 60 12.5 13.8 78 33..6 60 12.6 13-7 26'3 3306 60 1207 13.8. 268 33.6 60 12-8 13-9 333 33.6 60 12.8 13.8 73.33.'6 60 12.7 14.0 290 33-6 60 12.6 13'8 8 33.7 60 12.6' 13°9 4,5 33.7 60 12.6 13.9 256 33.7 60 12°6 13-9 129 33.7 60 12.8 13.8 13:0 33.7 60 12.7 13-9 109 3307 60 12'9 13.7 51 33.7 60 12.8 13-7 39 33.7 60 12.8 13-6 32 33.7 60 12.8 13.8,, 0 33.7 60 12.8 13.7 14 33.7 60 12'7 13.9, 18 33.8 60 12.7 13-9 7 33.8 60 12.5 l't.. 1 ,. 347 33.9 60 12.5 14,,2 34,9 33.9 60 12.6 14,.2' B A A B A A A :lc B B C B B A A :It B A A A A A A A B A C A A C C C B C C B A A MARATHON OZL COMPANY TBU M-3 PAGE 4-FZLE ! DEPTH DIP DIP DEV DEV DIAM DIAM Q t AZM AZH 1-3 2-~ · 29S1o67 3.5 2953067 203 2955.6T 203 2957.67 2°2 2959.67 2961.67 2963.67 3°2 2965.67 3.7 2967o'67: 5.2 2969o67': 5-2' 2971.67' 8.0 2973,,,&Y ,' 4.6 2975o::~ 8.9 2977o~?* 15,. 7 2979-~- 17.2 Z~J~. 67'~ 16.6 Z~85:.o 67 19 2.1 : 10.0 2993.~~ 10.0 2995.67 10.3 2997.67 6.3 2999.67 6.7 3 001.67 5.6 3003.67 &. 8 3005.67 3007.67 3009.67 3011.67 3013.67 &.l 3015.67 5.8 3017.67 5.6 3019.67 3021.67 3023.67 '1.5 3025.&7:~. 1 3027.:~: I 24 16 69 59 22 21 6 9 17 326 262 258 134 130 121 117 115 130 158 136 134. 257 259 196 158 142 139 116 57 93 67 109 14.0 166 173 187 14.3 171 33. 33. 33. 34. 34. 34. 34. 34. 34. 340 3~0 34. 34. 34, o '34* 0 34. 34. 34. 34. 34° 34. 34. 340 34. 34. 340 340 340 34. 34. 34. 34. 34. 340 8 60 12.7 9 60 12o7 9 60 12o7 0 60 12.6 0 60 12.6 0 60 12.6 0 60 12.6 0 60 12.6 0 60 12.7 0 60 12.8 0 60 12.8 0 60 12o7 I 60 12'7 I 60 12.6 I 60 12.6 I 60 12.5 I 60 12.5 2 60 12.6 Z 60 12o6 2 60 12'6 2 60 12°7 2 60 12.7 2 60 12.6 2 60 12.7 2 60 12.6 3 60 12.6 3 60 12o6 2 60 12o7 2 60 12o6 2 .60 12o7 Z 60 12o6 Z 60 12o5 2 60 12~6 3 60 12-6 3 60 1~.7 3 60 12.6 3 60 120T 3 60 12.5 3 61 12.6 13o9 13o8 13.8 13.8 13.7 13.8 13.? 13.8 13.7 13o8 13.9 14.0 1~1 14..0 14..0 13.9 13.8 13.T 13o6 13o5 13o6 13.6 13.6 13o6 13.6 13'6 13o7 13-8 13.8 13o8 13.7 13'6 13°5 13'5 13'4 13'4 '1303" 13o3 A A A A A A A A A B A A ::41: A A A A A A A B A A * 30Z9.67' 10Z 107 3403 61 12.6 13.3 MARATHON OZL COHPAN¥ TBU N-3 PAGE 5-FZLE 1 DEPTH DIP DZP DEV DEV DIAN OIAH Q ' t AZN AZH 1-3 2-4 ~ 3031-67 ' 308 ~ r~ 30~5.67 10.9 3~T.67. 903 '3~9.67 5.4 30'~1.67 2.5 5043 L 67 2.1 ]1~45.67 1.4 3047' 67 6.5 3049- 67 2.7 3051.6T 3.1 305306T 2ol 305~.6T 109 305T.6T. 3-5 3059.6T. 1.4 3061.67 0.5 3063.6T 1.6 3065.6T 3.7 3067.~T 8.6 3~9~67 7.2 31~T3' 6T 6.2 ~75:,6T .: 7.7 30TT-67' 10.4 3079.67 3081.67 3083067 3085067 3087.67 3089.67 3091.67 3093.67 3095067 3097067 3099.67 3101.67 3103.67 3105o6T 803 5.9 703 8.5 9.4 907 6.3 5.8 603 5.8 6.3 6.4 702 3107.67 21.8 3109.67 '1.6 218 52 44 42 169 170 86 78 78 16 11 118 86 89 336 288 171 193 199 196 196 195 208 205 203 200 198 194 201 217 Z23 215 201 287 Z24 230 137 233 68 34.3 34.3 34.3 34.3 34.3 3404 34.4 34.4 34.4 34.4 34.3 34.4 34.4 34.4 34.4 34.5 3405 34.5 34.5 3405 34.6 34.5 34.5 34.5 34.5 34.6 34..6 34.06 34.6 3406 3¢.6 34.6 34.6 34.6 3406 34.7 3407 34.T 34.7 161 34.7 60 12.7 13.3 61 12.6 13.5 61 12.7 13.4 61 12.7 13.7 61 12.6 13.5 61 12.7 13.6 61 12.6 13.5 61 12.7 13.5 61 12.6 13o4 61 12.7 13.6 61 12.6 13 61 12.6 13.7 61 12o8 13 61 12.8 13.6 61 12.T 13.6 61 12.7 13.T 61 1Z.6 13.6 61 12.5 13.7 61 12.6 13.6 61 12.6 13~7 61 12.6 13.7 61 12,6 13.7 61 12.7 13.T 61 12°6 13.7 61 12.6 13.8 61 12'6 13.9 61 12o6 13.9 61. 12o6' 14.0 61 12.5 14.0 61 12'6 14.1 61 12.5 14.0 61 12.5 14.1 61 12°5: 14-3 61 12o4 14.4 61 12.5 14'6 61 12.5 61 12'5 14.T 61 17..5 14.6 61 1Zo6 14.8 A C ac A ac A ac A ac B A ac A A A A A A A A A A A A A A A A A ac A A A A A A A A A D A A D MARATHON OXL COHPANY TBU H-3 PAGE 6-FTLE 1 4: DEPTH DIP DTP OEV DEV DIAPI DIAH Q 4: AZI~ AZPI 1-3 2-4* 4: 3..6 6.7 603 5.2 3.3 300 207 1.5 7.6 8ol 3..9 3! '~ 6,. 5 1.4 67 304 31~S-67· 3-2 3.5 :~, 2ol 206 2.1 3ol 8.0 709 304, lo6 1..1 200 7.8 10.1 12.7 3111.67 3113.67 3115067 3117.67 3119.67 3121.67 3123.67 3125.67 4: 3127067 4: 3129.67 3131.67 4: 3133.67 172 229 210 2O0 175 75 127 187 58 55 45 332 320 268 136 101 221 189 193 202 111 92 72 4,5 136 162 68 321 282 36 61 24,3 229 27;1 262 24,8 4: 3 ~ 3153,67, 4: 3155.67 ~ 3157°67 4: 3159.67 4: 316,1.67 4: 3163067 4: 316,5o 67 '. 4: 3167067 4: 3169067 4: 3171067 4: 3173067 4: 3175.67 '13o4 ~: 3177.o 67 406 · 3179o67 .. 907 · 318106? ~ 18..9 · 3183 o$T 17 o 7 4:3185.6'7 9.0 4: 3187 ~:67 706 34,06 34.6 3406 3406 34.7 34,.7 3407 34.7 34..7 34.7 34..7 3407 34*07 34*07 34.7 34.7 34.7 3407 34°7 34,06 3¢.6 34,.6 34.6 34*.6 3406 3¢.6 3406 3406 3406 34.7 3407 34.7 3406 34,06 34..6 34..6 34.7 3407 3189.67 50¢ 243 34.7 61 12o8 14.8 61 12o8 14.6 61 12o8 14,.7 61 12.7 I¢.7 61 12o5 14..8 61 12.6 15.2 61 12.7 15o0 61 12o8 15o4. 61 13.0 15-2 61 12o9 15-1 61 12o4 15.5 61 12.4 15.6 61 12.1 16,4, 61 12.3 17.0 61 12'3 16ol 61 12.7 16,.4, 61 12°5 15.1 61 12o7 14.8 61 12.6 14,"6 61 12o6 14.o6 61 12.7 14.'5 61 12o8 14,.,5 61 12o9 14,.3 61 12o8 14.ol 61 12°8 14o3 61 12~ 7 14. 01 61 12o8 14,o3 61 12.8 14.Z 61. 12o9 14. o2 61 12"7 14.°4, 61 12,,8 14,o5 61 1Z.7 61 12.8 14.o6 61 12.8 14..4 61 12'8 14,,3 61 12.8 14*.Z 6,1 12,7 14,,1 61 12-6 14-.2 61 12"5 14,.1 61 12o4. 14.ol A B 4: B 4: A 4: A A 4: A A 4: B B 4: B B C C O A A A A A A A A C C A 4: A A B D O C A A C C B A A RARATHON OIL CONPANY TBU ~-3 PAGE 7-FILE' 1 DEPTH DZP DZP DEV DEV DIAM DIAn Q t AZ~ AZH 1-3 2-4 SC 3191.~7 1.9 104 34.7 3193.&T~ 9.0 236 34.7 3195.~: 9.0 235 34.7 319T~1' 7.8 239 34.7 3199L &7 0.2 50 34.7 320~° 6T 3.7 141 34.7 3203':67* 5.3 169 34.7 32'05::&7~ 4°2 153 34.7 3207'~T 9.3 66 34.7 3209'g6T 11.5 85 34.7 3211.67 7.8 219 3213.67 15.1 8T 34.7 3215.67 15.5 94 34.6 3217o67'* 6°9 115 34°5 3219o6T'23o2 256 34.5 3221.67 18.8 122 34.4 3223.67 24o2 147 34°3 3225.67 Z4o& 146 34.3 3227.6T 24.8 145 34°2 139 34oZ 7 125 34.2 ~33'6T ~:~3.1 192 34.1 3~3'5~67 '23.3 154 34.1 323 To 67 i'~20.9 135 34 o 1 3239°6T'22.4 126 3241o6715.0 136 34ol 3243.67 12o8 145 34.1 3245.67 20.7 146 3247.67 18.3 173 34°0 3249.67 20.0 175 3251.67: 18.9 141 34°0 3253.67 17.2 141 3255.67 15.1 131 34.1 3257o67 4.4 Z05 34.0 3259.67, 6.9 200 3261.67 14.3 126 34°0 61 12.5 14.1 61 12.4 14.1 61 12.6 14.2 61 12.5 14.0 61 12.6 14.1 61 12.6 14.1 61 12.6 14.1 61 12.6 61 12.6 13.9 61 12o6 13.8 61 12.7 13.7 61 12.7 13.6 61 12.8 13.6 61 12.8 61 12~T 13-5 61 12.7 6112.8 1'3.5 61 12.8 60 12-8 13.4 60 12°8 13.4 60 12.7 13.4 60 12'7 13.3 60 12'6 13.3 60 12.7 13.2 6:0 12.8 ~3.3 6,0 12.8 3'2 60 12.9 13'2 60 12o8 13-2 60 12.8 13.1 60 12.7 13.2 6,0 12.7 13.1 &0 12'8 13o3 60 I2'7 13.3 60. 12'7 13.4 60 12.7 13*Z 3263.67 12o4 123 34.0 60 12.7 13.3 3265.6? 7.6 124 3~o0 60 12.7 13.2 3267.67 7.0 129 34.0 60 12.6 '13.2 3269.67 7.1 126 34.0 60 12.7 13-2 sc A SC B sc A SC A SC A SC A SC A SC A SC C SC A :41: C * C SC A SC C sc D SC B Sc A SC C sc C t C SC' D SC A 4c A SC C SC C SC A SC A SC D SC A SC A SC A 4r A 4c A 4c A SC A 4c A SC A SC MARATHON OIL COMPANY TBU R-3 PAGE 8-FILE 1 AZM AZ~ 1-3 2-~ · 6.5 107 34.0 6.2 100 3400 7.3 85 340 0 403 66 3400 3.3 57 34.0 207 43 3400 2.5 57 34.0 2.8 60 34.0 2.8 82 3400 302 98 34.0 4,,4 70 34.0 3-9 74 34.1 4.0 88 34.1 109' 34.1 112 34.1 1 34ol 26 3401 20 34.1 94 34.1 70 34.1 55 3401 73 34ol 76 340 2 33 3402 38 340 3 43 34.3 18 340 3 17 34.3 82 340 3 58 34.3 71 34.3 65 340 4 101 3405 86 34,05. 66 3405 3345o67~'i7.0 95 3405 3347067 ;606 81 3404 3349067" 908 59 34.5 3271067 3273067 3275.67 3277067 3279.67 329:1.67 32930 67 3295.67 3287067 3289o67 3291.67 3293.67 3295.67 3297.67, 3299067 .... 330~:°67 ~ 6°3 *3303*67 ' 3.2 33~0'Y. 67 ~6,6 3309. 67 3.1 3311o*67 6.3 3313.67 3315.6]' 404 3317.67 809 3319067 604 3321067 12.8 3323.67 508 3325067 ~ 6ol 3327.67 802 3329o67 Z205 3331.67 9,,4 3333o67 1005 3335067 10o3 333706.7 7'ol 3339.67' 9'9 3341.67 804 3343.67 1,0°4 60 12.6 60 12o7 60 12.7 60 12.7 60 1207 60 12-7 60 12.7 60 12'7 60 12,7 60 12.7 60 12.6 60 12.5 60 12.6 &O 12o6 60 12.6 60 12°6 60 12.6 60 12o5 60 12.5 60 12.6 60 12-7 60 12.6 60 12.? 60 12.4 60 12.6 60 12.4 60 12'7 60 12'6 60 12*6 60 12.6 ' 60 12.6 60 12.6 60 12.7 60 12- 7 60 12- 6 60 12-7 60 1Z.T 6.1 12'7 61 12.7 61 12.9 13ol 13.2 13.2 13.2 13.3 13.3 13.3 13.3 13.4~ 13'3 13.2 13.2 13.2 13,2 13.2 * 13.2 13.5 13.2 13.4 13.2 13.2 13,3 13.4 13.9 15 * 2 15.0 15'2 15.8 15.0 16.1 16.6 16o2 16.7 16o6 ' 16.6.~ 16o6 15.3 14.7. 13.5 13.3 A A A A :lc A A A A A 4: A A A A A A A B A A A 4: A B C A A C A A A C C A A A B C C B A MARATHON OIL COMPANY TBU N-3 PAGE 9-FILE 1 OEPTH DIP DIP OEV DEV DIAN Dian Q * AZM AZH 1-3 2-4 ~ 335~1067 60 8 33~3o 67 700 33*55.67 13ol 3~.67 15o0 3359.67' 110 3 336:1.67 3 363 o 67 3'36 7 o 67 33690 67 3371067 3373°67 3375,;:67 3377067 33790 67 9.9 904 705 6.5 0-6 9.0 9.Z 6°2 6,.8 3381.67 10o8 3383067 15.8 3385067 12o4 3387.67,14o5 33890 67 4o8 3391o67 33930 67":260 8 3395 o 6 T"22 o 2 397-67:16-6 3399,,67'10o8 3401o67.10o8 3403067 906 34050 67 1705 3407°67 12ol 3409.67 '~ 11o9 3411067 609 3413.67 3415.67, 3.8 3417.67. 405 3419,,67: 10o6 3421.67, 3423067 I1.7 3425.67 17o5 3427o67:609 95 34.5 61 12o7 81 34.5 61 12.9 54 3405 61 12.7 41 34.5 61 12.7 115 3405 61 12.7 101 34.6 61 12o8 94 34.6 61 12o8 71 3407 61 12o8 48 3407 61 12o7 156 3407 61 12.6 263 3407 61 12.6 256 34.8 61 12.6 250 .34.8 61 12o5 227 3407 61 12o5 213 34.7 61 12.5 246 3407 61 12.6 65 3407 61 12'5 13 3408 61 12o6 337 34.8 61 12'5 243 3408 61 12o5 223 3408 61 12o5 236 3408 61 12.5 169 34.8 61 12.4 163 34.7 61 12.4 71 3407 61 12o3 183 34.6 61 12.3 85 3406 61 12.3 76 3405 61 12o4 112 34°5 61 12.3 112 34.4 61 12.4 83 3403 61 12.4 88 34.3 61 12.3 92 34.2 61 12.4 72 34oZ 61 12.4 131 34.1 61 12'5 1ZT 34.1 61 12.6 ~149 34.1 60 12o6 211 34.0 60 12.7 72 34.0 60 12°7 13.Z 13ol 13.0 12.9 13.0 13.1 13.4 13.5 13.5 13.4 13.2 13ol 13.0 13.0 13.0 13.1 13.1 13.2 13.3 13.4 13.4 13.6 13.4 I3.5 13.2 1302 13'2 13o3 13o4 13.5,~ 13o5 13.4 13o4 13.5 13'5 13o6 13.6 13.7 13,8 A B B B C C B A B A C C C C B B D C B C C C O O A A C C C B C C C C O 3429.67 5.6 108 33.9 60 12.7 13-6 B * NARATHON OIL CORPANY TBU M-3 PAGE lO-FILE 1 DEPTH DIP DIP DEV DEV DIAN DIAM Q * AZH AZfl 1-3 2-4 ~ 3431.6T. 7.8 3433.67 6.9 3435.67 10.9 3437067 3.3 3439.67 10.8 3441.67 9.5 3443.6T 5.5 3445067 303 3447.67 6.4 3449.67 206 3451.67 lo9 3453.67 4.3 3455067 34 ST. 6T :" ~ 4'7 34 S 9.6.? ~;12' 0 3461 ,ToT 10.2 10.1 34~767 1202 3 4 ?3-67 · 1104 3475':* 67 2.5 341'7.67 20 9 3 4'79.67 3-1 3481067 2,,1 3483-67 1.4 3485,, 67 1.4 348T.67 3489.67 8.5 3491067 11.1 3493067 5.3 3495-6T 349To6T 12o5 3499.67 16.6 3501o6T 18.7 3503- 67 12.7 3505"67 4.6 3SOT.6T 98 3309 60 12.8 94 33.8 60 12o9 50 33.8 60 12.9 166 3308 60 12.8 63 3308 60 12.T 64 33.8 60 12o5 99 33.8 60 1Z.S 128 3308 60 12.4 69 3308 60 IZo5 186 3308 60 12o5 118 33.8 60 12o7 55 33.8 60 12.8 64 3308 60 13.0 109 33.9 60 12.9 120 33.9 60 12.8 129'33o9 60 12.5 96 3309 60 12'7 71 33.9 60 12-4 77 33.9 60 12.4 44 33.9 60 12o5 51 33.8 '60 12.6 50 33.8 60 12o7 77 33.8 60 12.9 49'33.8 60 12.8 42 33.8 60 12.9 351 33.8 60 12.8 42 33.9 60 1207 56 34.0 61 12.7 51 3400 61 12.T 110 34.0 61 12.7 130 34.0 60 12.7 119 34.0 60 12.7 177 34ol 60 12'6 190 34.1 60 12.6 192 3k01 60 12~6 244 34.1 60 12.6 73 34ol 60 12'5 67 34.1 60 12.5 61 34.1 60 12.5 13.7 13.6 13.6 13.5 13.4 13.1 13.2 13.0 13.1 13.1 13.2 13.3 13.8 13.4 14-0 13.6 14.2 14.2 14'4 13.9 13.8 13.4 13.4 13.3 13.3 13.4 13.1 13'3 13.1 13.1, 13-0 13.1. 12*9 13.0~, 13.0 13.0. 13'0 1'3.0' 12.9 B A B B A A A B B B A A C O C A A A A A A A A B B A B B A A A A C A A NARATHON OIL CONPANY TBU N-3 PAGE Il-FILE 1 DEPTH DZ~P DIP D'EV DEV DIAN DIAN: Q , 3523.67 3525:L 67 . 3529.67 3531o 67 3533'67 3535.67' 22.2 3537.67 23.2 3539'67 4.9 3541.67 ~ 4.0 3543.67 21.3 35&5.67 21.6 3547.67 · 25.! 3549.67,1 Z. 3 3551.&~. 6.2 3553-67 3.1 35 55 g~7 35~67 3559~67 356~.67 3.0 3563.67 3565.67 3567.67 3569.67 2,3 3571.67 3573.67 11.6 3575.67 3577.67 28.8 3579.67 3581.67 3583'.67 22.4 3585.67 3587.67 37 34°2 60 12.5 333 34.2 60 12o6 4 34.1 60 12.5 55 34.1 60 12.6 58 3~.1 60 12.5 122 34.1 60 12.6 83 34.1 60 12.5 70 3~.1 60 12.5 255 3¢.1 60 12.6 279 34.1 60 12.6 73 34.1 60 12.6 37 34.1 60 12.6 171 3~.1 60 12.6 175 3~.1 60 12.6 1~6 3~.1 60 12.6 128 3~.1 60 12.7 139 3A.2 60 12'6 133 34.2 60 12.7 86 34.2 60 12.6 73 34°2 60 12o6 98 34.2 60 12.5 151 34.2 60 12.6 220 34.2 60 12o5 134 34.2 60 12.6 173 3~.2 60 12.6. 285 34.2 60 12.6 83 34.2 60 12o6 91 3~.2 60 12.6 56 34.2 60 12.6 5 34.2 60 12.6 175 34.2 60 12.6 174 34.2 60 12°7 72 34.2 60 12.7 206 36.2 60 12.8 311 3~.2 '60 12-7 317 3~.2 60 12'8. 154 34°Z 61 12o6 144 34°2 61 12.6 131 34.2 61 12°6 '3513. 67 ~: 8.9 3515.67 12.6 3 S1,T~'~&7 3.0 3519~67 5.1 ~3522~ &7 6.3 11.9 8.1 3.6 3.8 12.8 12.9 12°8 12.9 12.8 12o9 12.9 12.9 13.0 13~0 13o0 13.1 13.0 13.0 12'9 13.0 12.9 12.9 12°9 12.9 12.8 12°9 12.9 13-0 13.0 13'0 13o0 13.0 13.0 13.0 13.1 13.0 13.1 13.2 13'1 13.3 13°2 13.2 13°3 3589.67 9.3 125 3~..2 61 12.6 13.3 C , MARATHON OIL CONPANY TBU H-3 PAGE 12-FILE 1 DEPTH DIP DIP DEV DEV DIAH DIAN Q * AZ# AZ# 1-3 2-4 ~ 3591.67 6.0 3593.67 11.7 3595.67'12.6 3597-67 14.1 3599.67 13.3 3601.67 11. Z 3603.67. 7-9 3605.67 i~ 5.7 3607.67 3-6 3609.&T ~23'5 3611.~T '9.1 3613-'&7 ' 32.2 3615.~ 25.5 3617. &3' 28.7 3619. ~ST?: 2 3.1 3621 .'~'? 33 o 6 3623"~1"*'12.3 3625 ~&7 O- 4 8.3 3~ ~ 10.1 11.5 363! ~ ~ 4.8 3635':67 ': '18o 9 363'7'.67 · 29.5 3639.67 805 36~1.67 '32.1 3643.67 11.3 3645.6T 13.6 3647.67 3649o67 365,1.67 3653.67 3655.67 3657-67 3659.67 9.0 4..7 3.8 7.6 .3.8 3.8 * :3661.67 3.2 * 3663.67,,~3.9 * 3665.67:~ 3.8 , 3667.67,~'~1.1 107 3~.1 61 12.6 203 3~.1 61 12.6 200 3~.1 61 12.5 191 3~.0 61 12.5 186 3~.0 61 12.5 188 34.0 61 12.5 148 33.9 61 183 33.9 61 12.4 160 33.9 61 12.4 203 33.9 61 12.4 179 33.8 61 12.4 240 33~8 61 12.~ 255 33.7 61 12.4 213'33.7 60 IZ.4 203,~33.6 60 12.4 239 3306 60 12.4 27.'33.6 60 12'5 171 33.5 60 12.5 181 33.5 60 12.5 215 33.5 60 12.5 205 33.5 60 12'5 239 33.4 60 12.5 198 33.4 60 12'5 197 33-4 60 12-4 282 33.4 60 12~4 11 33.4 60 12-3 68 33.¢ 60 12.2 145 33.4 60 12.2 171 33.3 60 12.1 138 33.3 60 12.3 2,11 33.3 60 12o2 141 33.3 60 12.4 25 33.3 60 12o4 208 33.3 60 12.~ 181 33.3 60 12.4 194 33.3 60 12'4 204 33.3 60 12.4 210 33.3 60 12.4 232 33.3 60 12.4 13.4 13.4 13.5 13.3 13.3 13.3 13.2 13.1 13.1 13.1 13.0 13.0 12'9 12.9 12,8 12.8 12.8 12.9 13.0 13'1 13'Z 13'2 13.3 13~3 13o0 12.9 12.6 12.7 12'7 12.7 12.8., 12.8 12.8 12'8 12'8 °9 °8 12.8 12'7 D A A A A A A A A O O C C O O B C B B A C O O D C B C A B C B A B A A A 3669.67 2.8 203 33.3 60 12-4 12.8 A * MARATHON OZL CO#PANY TBU M-3 PAGE 13-FILE 1 DEP'~ DZP DIP DEV DEV DZAM DIAM Q · AZM AZM 1-3 2-~ ~ 3671o67; 1.7 3673.67 ~'1-6 3'6'*'/50 &7:~** 1.4 3677.67~ 202 3;'679.67u 13.2 3;681067 5.8 3683.67 4.0 3'685.67 1.1 3687067, 3.3 36:99067' 105 3691067. 0o5 3693.67 S o 9 3695.67 6-9 3697o67:6.9 3699..67 7.1 3701.6'ir · 2.5 3703.67, 406 370~'67 7.0 3707.'67 8.8 3709o67~11ol 371106'7 8.9 3713.67-10.9 3715.67 3.0 3717.67 4.4 3719067. 906 3721067 9.7 3723.67 9.0 3725o&7 12o5 3727067:10.9 3729.67~15.7 3731067:1108 3733.67111.3 3735.6711.2 3737067 17.6 3739067 22ol 3741067 2008 3743.67 12.7 3745.&7 1102 3747067 705 238 330 3 207 33.3 180 3303 141 33.3 18 33.3 281 3304, 184, 33.4, 267 3304 16 33.4, 11 3304 130 330 4 32 .33.5 63 33.5 74, 3305 71 33.5 108 3305 229 33.6 13 33.6 37 33.6 54 330 6 45 330 7 23 33.7 78 3307 84, 330 8 91 3308 4,9 33- 8 104, 33.8 301 33,0 8 4,3 330 8 30 33.8 34,1 330 7 35 33.7 64, 3307 325 3308 192 33'o8 328 33.8 27 3309 4,8 33- 9 332 34,. 0 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 6,0 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 12o4 12o5 12.5 12.5 12o5 12.4 12.4 12.5 12.5 12.5 12o4 12.5 12o4 12o5 12-4 12.5 12-3 12.5 12.2 12o2 12.3 12.2 12'3 12.2 12'2 12.2 12.3 12.2 12.2 12'2 12.0 12-4 12.1 12o5 12.7 12'4 13.1 12.3 12o5 12o8 13.0 12.9. 12.9 12.9 12.9 12.9 13.0 13.0 13o0 13.0 13.0 12o9 13.0 12o9 13.1 13.2 13.3. 13.3 14.4 14,.8 15.5 15o6 15.3 15°3 15'1 14.0 14.8 14'2 15.2. 15.6 15o2. I5'5 14.8_ 15.1, 14,-9~ 14'7~ 14.5 , 374,9.67 9.3 14,4 34.1 60 12.3 13'9: HARATHON OIL COHPANY TBU N.-3 PAGE DEPTH DIP DIP OEV DEV DIAN DIAN Q AZ# AZH 1-3 3751.67 11.8 44 34.1 60 1Z.O 13o8 A 3753.67 12.5 66 34.2 60 12.2 13.1 A 3755.67 7.6 72 34.2 60 12.1 13.0 B 3757.67 13.3 23 34.2 60 12.2 13.0 3759.67 13.4 20 34.2 60 1Z.1 13.0 C 3761.67 15.0 76 34.Z 60 12.2 13.0 A 3763.67 13.6 69 34.3 60 12.3 12.9 A 3765.67 10.4 58 34-4 60' 12-4 12'9 C 3767.67 Z1.7 284 34.4 60 12.4 12o7 D 3769.67 ~5.9 70 34.4 60 12-4 12.8 A 3771.67 3'.3 198 34.4 60 12.1 12.7 A 3773.67 3-8 207 34.4 60 I2,1 12.7 C 3775.67 14.7 73 34.4 60 12.0 12.7 C 3777.~ ..... 7.3 72 34.3 6'0 12°1 12.7 D~ 3779o:~*~:~ 28.Z 291. 34.3 60 12.1 12.7 C 3781,~: 15.2 84 34-2 60 12.1 12.7 C 3783,'~..13.7 97 34.1 60 12.1 12.7 C 378~*~ 13.4 95 34.1 60 12'Z 12~7 C 37~T~67 15.2 78 3400 60 12.1 12.7 C 378~*~;67 13.4 76 34.0 60 12..2 12.7 C 3791'~&? 6.5 306 33.9 60 12.1 12'7 C 3793°6? 9.1 267 33.8 60 12.2 12.T C 3795.&7 7.1 271 33.8 60 12-1 12.7 3797.67 10..2 303 33.7 60 12.2 12-7 3799.67 31.9 281 33.7 6.0 12.2 12.7 B 3801.67 3.3 Z58 33.6 60 1Z.2 12-6 D 3803.67 16.0 307 33.6 6.0 12'3 12.6 C 3805.6.7 6.1 116 33.5 60 12.3 12-5 A 3807.67* 4.4 127 33.5 60 12.3 12.5 A 3809.67 4.1 146 33.5 60 12.4 12.5 C 3811.6.7 17.0 95 33.5 60 12.3 1Z.5 B 3813.67 14.7 Z7 33.5 60 12.3 1Z.5' C 3.815..67'i1.2 48 33.5 60 12.3 12'5 C 3817..&7 ..'10.4 9Z 33.5 60 12.3 12°5 0 38'19~-67 6.2 3Z 33.5 60 1Z.3 12-5 B 38ZI.&7 11.5 81. 33.4 60 12,3 1Zo5 C 38Z3-67 11.7 69 33.4 60 12.3 12-5. D 38~5.&7 13'7 56 33.4 6,0 12-3 12.4 C 3827.;6.7 10.0 77 33.4 60 12.3 1Z.5,** B 3829-67 8.¢ 3ZO 33.4 60 12.2 12.4 A ************************************************************************ MARATHON OZL COMPANY TBU M-3 PAGE :15-F1'LE' 1 DEPTH DiP DZP OEV DEV OIAM OZAM Q · AZM AZM 1-3 2-4, . 3831.67 9.4 326 33.4 38~. 67 8°2 42 33.4 38~5.67 1.4 148 33.4 3837.67 2.6 186 33.4 3839o67 7,,,7 ZZZ 33.4 '384~. 67 7.3 87 33 . 3 38~4'3.~67 '11.6 3845'67 6.2 3847~,67 2:. 7 3;8~49.67 14.0 38S1.67 14.9 3853067 11.4 3~55.67 8.6 3857.67 3859.67 15.0 86 67 lO.T 386 .67 11.3 86 33.3 TZ 33.3 80 33.3 72 33.3 75 33.3 9S 33.3 85 33.3 75 33o3 63 33.3 39 33.3 43 33.3 3865.67 7.4 120 33.3 3867.67 9.3 131 33.3 3869.67 12.4 81 33.3 3871.67 9.8 109 33.3 3873..67 13.4 75 33.4 3875.67 16o2 15 33.& 3877.67. 26.0 355 33.4 3879.67 8.5 102 33.4 3881.67 6.5 101 33.¢ 3883.67 1Z.Z 51 33.5 3885.67 2.5 128 33.5 388'7.67 6.0 83 33.6 3889.67 Z.4 79 33.6 3891.67 9.9 235 33.7 3893.67 12.6 96.33.7 3895,,67 11.4 83 33.7 3897.67 9.6 81 33.7 60 12.2 12 o4 60 12.2 12.4 60 12.2 12.5 60 12.2 12.5 60 12.2 12.6 60 12.1 12.5 60 12.1 12.5 60 12.2 12.5 60 12.1 12.5 60 12.1 12.5 60 12.1 12.6 60 11.9 12.7 60 12.1 13.4 60 11.8 1,~ .3 60 12.0 13.5 60 11.9 14.0 60 12.1 12.8 60 1.2.1 12.7 60 12.2 12.8 60 12.1 12.8 60 12.2 12.8 60 12'2 12.8 60 12.2 12.8 60 12.3 12'8 60 12.Z 12'8 60' 12.2 12*7 60 12.3 12.8 60 12.3 12.8 60 12.2 12.8 60 12.3 12'8 60 12.1 12,,9 60 12.1 12.8 60 12.2 13.0 60 12.2 13o0 3899.67 14. Z 74 33.7 ~ 60 12.Z 13.1 3901.67 3.6 2 33.7 60 12.3 13.1 3903.67 5.3 79 33.7 60 12'3 13.1 3905.67 11.7 25 33.8 60 12.3 13.0 3907.67 9.6 19 33.8 60 12'4 13'0 3909.67 3.6 195 33.8 60 12.3 13.0 B A C A A D O B C D A C B A A A C C B C B A B A A A C C A A B B MARATHON OZL COMPANY TBU M-3 PAGE 16-FTLE 1 DEPTH DIP DIP DEV DEV DIAM DIAN q ~ AZM AZM 1-3 2-~ · 3911.67 8.8 3913067 12.7 3915.67 6.0 3917.67 602 3919.67 8-0 3921.67 · 8.3 3923067 4./) 3925.67 2.7 3927.67 407 3929067 40'2 3931.67 5.0 3933.67 9,,,4 3935.67 ~ 2~).4 3937.67 ~2'403 3 ~I o 67 1 0 o 4 3~3o&7 201 3gai~S'6T. 13.6 3 I1~' &7 15,o2 3~.&7 5°4 39~ 67 4.9 3953'.67 , 3.3 39550 67 To 5 3957.679.3 3959067 1105 396! 067: 3963.67 3965.67 3967067 3969°67 3971.617 3973 3975.67 3977~T 8.0 1.3 702: 70,5 806 707 70 8 ,70,7 9.3 3979.g=&7, 6.o8 3981~:~?' 504 3983:g!i&.?'''~7.5 7.6 3989,;~6T 7 o 3 77 135 79 81 64 89 79 37 58 70 77 51 281 283 99 2O8 29 2:8 75 69 5O 26 11 73 126 133 336 346 75 109 90 76 78 51 93 84 57 4,9 57 33.8 33.8 3308 3308 33-8 33.8 33.9 33.9 3400 34.0 3400 34.0 ~,4o0 34" 0 340 0 3400 34.1 3/).1 3¢.1 34-1 34.1 3~.1 34ol 34.1 34.2 34.2 34.1 34ol 3¢. 1 34ol 34.0 33.9 33.9 330 8 33.8 33°8 3307 3307 3306 3305 60 12.4 60 12.2 60 12.2 60 12.2 60 12.2 60 12.2 60 12.3 60 12.3 60 12.3 60 12.4 60 12°2 60 12,3 60 12.2 60 12.4 60 12.3 60 12.5 60 12.5 60 12o4 60 12.4 60 12'4 60 1203 60 12.4 60 12.2 60 12,2 60 12ol 60 12ol 60 12o 1 60 12.1 60 12o0 60 12o0 60 1200 60 12.0 60 12ol 60 12o0 60 11o9 60 1201 60 11'8 6,0 12-1 6.0 1ZoO 60 12.1 13.0 12o9 13.0 12.9 13.0 13.0 13.1 13.1 13o2 13.2 13.2 13'4 13.4 13.6 13'8 13.9 13.9 13.9 14o0 14-0 14.0 14.1 14,.0 14,1 14.2 14.2 14.3 14.3' 14.4 14.3 14.3 14'2 14'1 14.2 14.4 14.2 14'7' 14o3, 14.3 14.1 MARATHON OIL COMPANY TBU M-3 PAGE iT-FILE 1 DEPTH DIP DZP DE'V DEV DIAN DIAM Q ~ AZM AZM 1-3 2-~ ~ 3991~6T 11.4 59 33.4 3993~'&T 8.9 63 33. · -3995.6T T o 6 ?0 33. · 399T. &~ T. 1 T4 33.3 3999'&T 11.3 77 33.3 · 001~67 1004 TO 33.3 · 003- 67 903 67 3303 ~'~OOS'&T 5ol 131 33.2 400T067 5.3 195 33.3 4009o6T 8.2 222 33.3 4'911.6.7 7.9 136 33.2 4013.67 4.2 188 33.3 4015.67 6.3 221 33.3 4017.$7 9.1 240 33.3 4019.67 11.9 213 3303 4021.67 12o8 205 3303 4023.67 609 192 33.3 4025.67 703 208 33.3 4027.67 5.1 198 33.3 4029067 3.4 178 3303 403~1,,~: 3ol 162 33.3 40~3~g&7. 2.6 174 33.3 4~g'6T 3.2 179 3303 403¥g~',&T, 4oZ 1~8 330.3 403~9~a~&'T' 4.4 170 33.2 4041.6T 4.3 150 33.2 4043.67 9.1 92 33.2 4045°67 9.7 87 33.Z 4047°67 809 83 33.2 4049067~ 8.0 101 33.2 4051.67 7.2 120 33.2 4053.67 8.3 ~118 33.2 4055.67 8.8 120 33.2 4057.67 22.1 201 33.2 4059.67 17.8 79 33.2 4061.6,7 3.0 45 33.2 4053"67, 3.5 Z3 33.Z 4065.67: 4.4 0 33.2 60 12.2 13.8 60 12.1 13.6 60 12.2 13.5 60 11o9 13.3 60 12o0 13.0 60 12.0 12.8 60 12.0 12.6 60 12.0 12 05 60 12.1 12.6 60 12.0 12.6 60 12.0 12.5 60 12ol 12-6 60 12ol 12-5 60 12.2 12.5 60 12ol 12.4~ 60 12.1 60 12.0 12.3 60 12.0 12o3 60 12ol 12,4 60 12*1 12.4 60 12o2 12.5 60 12.2 12.5 60 12.2 12'6 60 12.1' 12. ,q. 60 12.2 12.5 60 12'0 12-3' 60' 12.2 12.5 60 12.1 12.3 60 12o2 12-4 60 12-1 60 12ol 6:0 12.1 12-2 60 12,.1 12'1 ' 60 11,,9 12'1 60 12.0 I2.1 60 11.,9 12'5 60 11.9 12.7 60 12.0 12.8 A A A B B B C A A A B A A A A A A A A A A A A A A A A A A A A A A A C A A A , 4067.67. 3.7 245 33.2 60 11.9 12o9 A * · 4069.$7 1105 69 33.2 ~ 60 12ol 12o6 C * MARATHON OIL COMPANY TBU N-3 PAGE 18-FZLE 1 DEPTH D[P DIP DEV DEV DIAN DIAM Q t AZN AZM 1-3 2-4 ~ 4071061' 5.6 B 4073.6't' 8.Z C 4075o&~ 13.2 C 4077.67 12o8 A 4079067 15.0 A 4081.67 7.0 C 4083.67 2.2 A 4085067 10o5 O 4087.LTT 6--2 13 4089067 10.1 D 4091.67 15o4 C ' 12.1 C 4093 · o95: A 5.0 c 4099.~'~ ~3.0 ~ B 4101.~, '4.3 A 4103o~ 3 o0 41~r07. 6*7. ! I * 0 4111'67 4113.67 4115o67 ¢117,67 4119.67 4121.67 4123.67 4125.6T .4127.67 4129.67 ~13106T 4133.67 7.0 7.0 3.8 '707 1.3,8 3.4, 24..2 505 7.1 5.6 1.8 3.0 21 33.2 60 12.0 12.6 85 33.2 60 12.0 12.5 67 33.2 60 12.0 12.5 42 3302 60 12.0 12o5 62 33.2 &O 12.0 12.4 117 33,2 60 12.1 12°4 14.9 33.2 60 12.0 12.3. 76 33.2 60 12.1 12.3 81 3303 60 12.1 12.2 51 33.3 60 12.0 12.2 105 33.3 60 12.1 12.2 64, 33,4 60 11,9 12.2 46 33.4 60 12.0 12.4 79 33.5 60 11'9 12.5 91 3305 60 12.0 12.7 359 33.5 60 12'0 12.7 310.33.5 60 12.0' 12.T 287 33.5 60 12'1 12.8 196 33.5 60 12.1 12.7 186 33.5 60 12o2 12o9 28 33.5 60 12.2 12.9 84, 3,3-5 60 12.3 13.0 45 33°6 60 12~4, 13o0 48 33.6 60 12,3 13.0 313 3306 60 12'3 12.9 10, 33.6 60 12.2 12.9 233 330T 60 12°1 12.8 85 33.? 60 12.1 12'9 4,5 3307 60 12'0 13.3 4,3 33.8 60 12-0' 13.7 24,8 33,8 60 12.0 14,-3 211 33.8 60 12.0 14'6 288 33.9 60 12.0 14.5 119 33.9 60 12-0 14.o4. 80 33.9 60 11.9 1~-1~ 68 33.9 60 11'8' 14-2 60 33.9 60 11,8 13"3 53 33.9 60 11.8 13.2 295 33.9 60 11.8~ 12.4 C C O O O A B C C C C A A A C C O C A A A A A , 414996T 13.2 281 33.9 60 11'9 12,2 NARATHON OZL CONPANY TBU #-3 PAGE 19-FZLE 1 DEPTH DIP DIP DEV DEV DIA~ DIAN Q t AZ# AZN 1-3 2-4 ~ 41'51..~67 7.9 3ZT 3~. 0 %153.'&7' 2.5 334 34.0 4155~67~ 9.2 313 3~.0 ~I57~T 8.0 309 3~. 1 · 15~9J67 2.4 2~7 3~. 1 · ~161~67 5.2 252 4163"67 3.6 100 34.2 416~.67. 5.2 88 34.2 416~.67 *3.6 92 34.2 41~1.67 12.5 90 4173~ 67 4.6 102 34.2 4175, 67 1.8 130 34.2 4177' 67 1.1 111 34.2 4179-67 3.1 36 34. 4181.67 8.9 114 34.2 4183:'67 '5-1 142 34.3 4185.67 3.7 196 34.3 4187.67 17.4 160 34.2 4189.67.14.3 154 34'2 4191.67.22.0 343 34.2 4193.67 37.3 203 34.2 41~-67,26.5 210' 34.3 4197.67 1.2 129 34.3 4199.67 1'0 141 34.3 4201.67 9.8 87 34.3 4203.67 18.6 284 34.3 4205'67 16.1 225 34.3 4207.67 5.3 185 34.3 4209.67 4.3 63 34.3 4211.67 6.5 54 34.3 4213.67 ,6.9 75 34.3 4215.67-~*Z0.3 231 34.4 4217.67 8.0 225 4219.67 10.T 139 34.4 4221'67 17.1 108 34-4 4223.~67 1.6 134 4225.67* 10.4 139 4227.67 14.0 120 34.3 60 11.9 12.1 60 12.0 12.2 60 11.9 12.1 60 11.9 12.2 60 11.9 12.1 60 11.8 12.1 60 11.9 12.1 60 11.8 12.1 60 11.8 12.1 60 11.8 12.1 60 11.9 12.1 60 11.9 12.1 60 11o 8 12. O~ 60 '11,9 11.9: 60 11.8 11.8 60 11.8 11.8 60 11.7 11-7 60 11.8 11.8 60 11.7 11.T 60 11'T 11.8 60 11.7 11.7 60 11'7 11'6 60 11.T 11.8 60, 11.7 11.7 60 11.7 11~8 60 11~? 11'8 60 11'7 11.8 60 11..7 11.8 60 11-7 11.8 60 11'7 11.9 60 11.7 11'8 60 11.8 11.9 60 11.8 11'9 60 11.8 11.9 60 11.7 11.8 60 11.7 11'9 60 11.7 11'9 60 11'8 12.2 60 11.9 12.3 B A B A A A A A A A C A A A A B B B C C C C D A A B C A C C B C C C C D A A MARATHON OIL CONPAN¥ TBU N-3 PAGE 20-FILE 1 DEPTH DZP DZP DEV DEV DIAM DIAM Q t AZH AZH 1-3 2-~ , 4231.67 18.4 212 34.3 4233.67 12.6 217 34.3 4235.67 8-0 153 34.3 ~Z37.67 11.1 161 4239.67 16.8 138 ~241.67 18.4 139 4243.67 14.2 14~ 34.4 &Z~5.6T 1A.9 1~5 ~2~7.67 15.7 1A2 3A.3 4249.67~19:'& 158 34.3 · Z51.67 13,8 155 3~-3 · 253.6T 9L2 169 a255.67 1'0 10 4ZST'6T .... 3.6 139 34.2 4259o&T '3.4 115 34°2 4Z&1.67 7-2 122 34.1 · Z~63'~T 10.1 117 3.T 9033.9 3.0 59 33.8 Z.7 7Z 33.8 7.4 TS 33.7 4273°~5~7 7.0 83 33.7 4275.6T 6.4 54 33.6 ¢277.'67' 5.5 68 33.6 4279.67 5.3 95 33.6 ~281.6T 5.5 237 33..5 A283.67 6.8 33 33.5 4Z85.67 6.5 49 33.5 4287,67 10o6 T7 33.4 ~Z89.67 ~.8 109 33.¢ ~Z91.67 6.1 121 33:.4 4293,67 7.4 112 33.4 4Z95.67 4.5: 107 33.4 4ZgT.~T'~ 4.4 97 33.4 4299,~6T 6.7 TO 33.4 4301.67 8.7 63 33o~ · 303'~T~'iillo6 52 4305.67 12.3 50 33.5 4307.67'~:~11,1 41 33.5 4309.67 11.1 53 33.5 61 12.2 12.7 61 12.2 12.7 61 12.2 12.8 61 12.1 12.9 61 12.1 12.9 61 12.0 13.0 61 12.0 13o0 61 1Z.O 13.1 61 11.9 13.1 61 11.9 13.1 61 11.8 13.1 61 12.0 13.2 61 11.9 13.2 61 11.9 13ol 61 11-8 13.0 60 12.0 13.1 60 11.9 13.1 60 12-1 13.3 60 12.2 13.3 60 12-1 13.3 60 12.1 13~3 60 12.1 13.7 60 1Z.1 13.8 60 12'1 1¢.3 60 12.1 1~.2 60 12.1 1¢'0 60 12.0 13.5 60 12.0 13.3 60 12.1 12.8 60 1Z.1 12.7 60 12o0 12.8 60 12.0 12.7 60 12o0 12.7 60 12.0 12.7 60 1Z.O 12-6 60 11.9 1Zo9 60 1Z.O 12.7 60 11.9 13.2 60 11.8 12.9 60 11.9 12.9 D O C O B A A C A C A A B A A B C A a A B B B C A A A A A A A A C A B A MARATHON OIL COMPANY TBU M-3 PAGE Z1-FILE 1 DEPTH D~P DIP DEV DEV DIAM 'D/AM Q 4: AZM AZM 1-3 2-~ · 4311,*~T 11.9 56 33.5 4313~'6T' 7.9 340 33.5 4315g~T 9.6 61 33.5 %317~6T 10.0 40 33.5 · 319~6T 9.5 42 33.~ 4321.~- 900 330 33.¢ 4323.~ 8.1 322 33.5 4~25e67 7.9 316 33o5 432T°67 14.3 22~ 33-6 4329g&7 7.5 34~ 33.6 4331:L67. 6.7 352 33.6 4333.*67 6.2 43 33.6 4335.67~ 7.3 37 33.6 4337.67 11.9 45 33.6 4339.67 7.1 88 33.6 4341.67 7.0 99 33.6 4343.67 '4.3 70 33.6 4345.6T 4o2 72 33.6 4347.67 2.4 205 33.6 43!49. ~ 5,.,1 77 33-6 · 4 ~'1 "~7 9.0 63 33.6 43'53.'67' 6-4 59 33.6 4355.67 5.1 19 33.6 4357.67 8.9 17 33.6 4359.6'7 6-5 76 33.6 4361.67 0.7 270 33.6 ¢363.67 4.7 47 33.6 4365.67 6.0 I 33.6 4367.67 14.T 49 3306 4369.67 804 17 33.6. 43'71.67 9-5 25 3306 ~4373.67 5.8 32 33.6 4375067 5-8 49 33-6 4377-67 4o0 54 33.6 ~379~67 1.9 345 33.6 438~67 6.4 13 33.6 4383°67 10o8 129 33.6 ~385o67 707 10~ 33.6 438.7.67 406 327 33.6 4,389.67 9.4 54 33.6 60 11.8 60 11.9 60 11.7 60 11.8 60 11.8 60 11.7 60 11.8 60 11.7 60 11.8 60 11.8 60 11-8 6,0 9 60 11.9 60 11.9 60 11.9 60 11.8 60 11.9 60 11.8 60 11'8 60 11.8 60 11.7 60 11'8 60 11,7 60 11'8 60 11o8: 60 11'9 60 60 12o0 60 12'1 60 12.0 60 12°0 60 12o0 60 12~0 60 60 12.1 6O 12.0 60 12'1 60 12.1 60 12.1 12.6 12.6 12.4 12.4 12.3 12.0 12.1 11.9 12.0 12.0 12°0 12.1 12.1 12.1 12.1 12.2 12.1 12.1 12.0 12.0 12,0 12-0 12°1 12,1 12'2 12,3 12.3 3 12.4 12.3 12.2 12'4 '12.3 12.5 12.5 12-6 12o6 12.6 12°T A :4: C A A A B A A 4: C A A 4: A A B A A A A C A A A A 4: A 8 A A 6 C A 6 B A 6 C 4: D C 8 NARATHON OIL COMPANY TBU M-3 PAGE 2Z-FILE DEPTH DIP DIP DEV DEV DIAN DIAN Q AZM AZN 1-3 2-4 4391.67 13.8 4393067 6.6 4395067 14.8 4397o67 11.6 4399.67 7.5 4401.67 5.3 4403.67 5.0 4405.67 6.8 4407067 9.1 4409.67 7.1 4411067 2.2 4413.67 2..3 4415o67. :2.4 ' 4417~:67': ': 3.9 441,9o 67 4°4 4421.67.: 703 4~423.. 67 7.0 ~25, 67 11.8 4~'~:r.. 67 6.0 4 · 31~67 ~ S. 0 4433;67' 2.~ 4435~:67 2.0 4437.67 2.7 4439.67 7.6 4441'67, 2-9 4443°67 8.3 4445.67. 3.7 4447.67 4.5 4449.67. 3o:8 4451.67 4.1 4453.67 40 9 4455,67 7.7 4457"67 13.4 44.59.67 · :3'7 4461°67 2.8 4 463 o 67 305 4465~67 446T.67 8.7 55 33.7 60 12.0 4*6 33.7 60 12o0 89 33.8 60 11.9 70 33.8 60 12.0 61 33.9 60 12.0 56 3309 60 12.0 78 33.9 60 12.0 112 33.9 60 12'0 134 33.9 60 12.0 85 33.9 60 12.0 42 34°0 60 12.0 12 3400 60 12.0 19:34.0 60 12ol 35 34,0 60 12ol 25 34.0 60 12ol 44 34.0 60 12.1 51 34..0 60 12.1 45 34.0 60 12.1 98 3400 60 12~0 103 3400 60 12.0 78 33.9 60 12.0 85 33.9 60 12o0 79 33.9 60. 12.1 72 33.9 61. 12.2 80 33.9 60 12.2 94 33.9 .60 12.2 104 33.9 60 12o2 78 33.8 60 .12.2 77 33.8 60 I2.1 84 33.8 60 11'9 74 33.8 60 12.0 67 33.8 60 11.8 53 33.8 60 11-8 46 33.8 60 11.8 49 33.8 60 11.7 61 33.7 60 11-8 50 33.7 60 11.9 140 33.7 60 '11.9 93 3308 60 12.0 12.6 12.6 12.6 12.7 12.7 12.9 12.9 13.0 13.0 13.1 13.0 13.1 13.1 13.1 13-2 13.4 13.5 13.7 · 13o6 13'8 13.4 13.6 13.2 13o3 13'3 13.3 13.3 13-4 13.4 13-3 13.7 13o8 14'I.. 14.1 13.7 13.3 13.1 12.9 13.0 4469'67 1.7 61 33.8 60 11.9 13.0 C , MARATHON OIL COMPANY TBU ~-3 PAGE Z3-FILE 1 DEPTH DZP DIP OEV OEV DIAM DIAM Q * AZM AZH 1-3 2-~ f 4471-67 4473~'&7 447~67 1X.9 705 1.0 3.1 2.8 203 803 7.0 8.9 11.2 20 33.8 73 33.8 82 33.7 70 33o7 42 33.7 111 33.7 94 3307 44. 330 7 37 3308 82 33.8 62 33.8 68 33.7 56 33.7 58 33.7 69 33.7 34 3307 65 33.7 90 33.T 62 33.7 52 3307 120 33.8 184 33.8 63 33.8 62 33.8 57 33.8 69 3308 82 33.8 101 33.8 ~1 33.8 59 3309 75 33.9 83 33.9 94 3309 100 33.9 103 34o0 106 3400 6,9 34.0 16.1 32 36.0 9.0 49 3600 904. 57 34.1 45'I3'&7 11.6 ¢ 5t70 67 1601 4.51'9o 6~t~'~'r~ 6521067 12-5 4523.67 14.4 4525.67 14.8 4527067 10ol 4529.67 4531.67 900 4533.67 8 4535.67 11.8 4537067 12.1 6539.67 13.4 . 4541.67 12.0 4543067 600 4545.67 4547.67 6569.67 60 11o9 13.0 60 11o8 13.0 60 11.9 12.9 60 11o8 12.9 60 11.9 12o8 60 11o9 12o9 60 11o9 12.8 60 11.9 12'8 60 11o8 12.8. 60 11.9 12.8 60 11.8 12.8 60 11.9 12.9 60 11.9 12.9 60 12o0 13'1 60 12.0 .13.0 60 11,9 13.0 60 12.0 12o9 60 11o9 12'8 60 12.0 12°8 60 12.0 12.7 60 12o0 12o7 60 12*0 12.7. 60 11-9 12.6 60 11o9 12o7. 60 11.9 12'6 60 11.9. 12o9. 60 12.1 13.0 60 12'3 13.1 60 12.3 13.2 60 12.4 13o2 60 12*3 13.1 60 12.3 13.2 60 1203 13-3 60' 12-3 13-3 60 12.3 13-.6.. 60 12.3 13.3 60 12.2 13-2 ,. 60 12'1 13.2 60 12°3 13.5 60 12'1 13'3 HARATHON OZL COMPANY TBU M-3 PAGE OEPTH DIP DIP OEV DEV OIAM OIAH Q AZM AZM 1-3 2-4 4551.67 12:.4 214 34ol 60 12.3 13.6 D 4S53.67 4*.9 106 34.1 60 12.3 13.4 C 4,555.67 2:.6 90 34*.Z 60 12.2 13.4. A 4557.67 10.7 34 34.Z 60 12.2 13.7 C 4559.67 12:.3 Z? 34*.2 60 12ol 13.4 B 4561067 10.4 31 34..2 60 12.2: 13.6 A 4*563.67 8.2: 4*6 34*.2: 60 12.3 14-4 A 4565.67,~ 9.1 32:34.2 60 12.3 14..6 B 456T.&T ~& 19 34..1 60 12.4 16'0 D 4569.&T, 34~6 216 34..1 60 12:'4. 17'4 B 4571.6'1' '4192 99 34.0 60 12:.6 .16.1 D 4.573.'6T T';,2 64 34..1 6.0 12e4 17.1 C 61 34*.Z 60 12.6 15.3 A .4~ ST ~&7 ?. & 4.1 3,4,. 3 60 12.3 13.6 A 4.~1,~T~ 2. S 62: 34*.4* 60 12-2 13.Z B '~ 4~'&? 2.6 64* 34.4 60 12.2 12.4, B 4Sll~5L&T 4.& S 34.3 60 12,;3 12.7 A 4. ~T.:~7 4*.4 77 34.3 6.1 12.2: 12.3 A ~, 581~-~67 6.7 109 34.3 61 12'2 12'5 A 4 S 91";6 ? &. 3 89 34 o 4 61 12.2 12 ' 6 A 459],,:~'~ 7 5.0 ST 34.5 61 12.2 120T A 459Sg167 11.9 32:34.5 61 12.2 12:.T B 459?'67 6.9 62:34.7 61 I2.4~ 12.8 A 4599.&7 4.4 73 34.7 61 12.2 12'6 A ~601o67' 4*.7 195:34,,7 61' 12'4. 12'8. A 4.603.67 T.1 186 34.6 61 12'3 12°T A 4605.67 6.,6 78 34..6 6'1 12.3 12.7 A 4607.67 3.5 T1 34.6 61 12.3 12'5 A 4*609.67 Z.O 117 34.6 61 12'2, 12-5,. A 4611.67 1.0 71 3ao6 6'1 12'2 12.2 A 4613.67 12:.5 77 34.6 61 12:oZ 12:.Z a 4.615,,67 0'5 141 34.6 61 12:. 2: 12:.1 A 4617.6T, 14.6 264 34.7 61 12.3 12o,2 C 4619.67,16.1 87 36.7 61 12.2 12.1 C 462:1.67 1,1.2: 83 34.6 61 12o2 12,,2 A 4623.6T~ 5.7 85 34.6 60 12.1 12"1 B 4.625067" 3.9 85 34.6. 61 12.1 12-1 C 4627.&7' 6.4* 82 34.6 61 12.1 12:ol C 4*629.67 6.3 11 34.5 61 12o2: 12.1 A MARATHON O]:L COMPANY TBU Iq--3 PAGE ZS-F]:LE 1 DEPTH DIP DIP DEV DEV DIAN OI AH q ~ AZH AZH 1-3 2-4 ~ ~ 6631 - 67 7.7 6633 ~'~ 803 6635~ 6? 16.0 663?06? 15.1 · 63'9~ 6T 18,6 66~".:, 6T 9.5 46~3'6T ' 16.6 · 663~ 6T 12.8 46~'~6T *'~ 13. 6 465X-.6T 465 306T'*~ *' :8 - 1 4655.6T: 15o2 4657067 4659'67 4661.67 4663.67 4665.6,7 66670 67 66690 67 66T1.67 6,~. 67 6 675 o 67 6677°6? 4679067 6681067 6683067 4685.67 66870 67 46890 67 4691067 6693.67 6695067 6697.067 4699067 4701067 6T03o67 4705.67 10.6 6.1 8.5 7.1 706 16.9 006 2.1 5.9 6.T 6.6 607 3.¢ 11.4 13.5 10.9 6.7 3.8 3.8 6.9 lo8 lo7 12.9 14.o9 1.6 50 34..5 60 12.1 12.1 353 34..6 60 12o2 12.2 11 34..6 60 12.1 12.1 7T 34..3 60 12o2 12.1 97 34*03 60 12.1 12.1 116 3602 60 12.1 12.1 196 34.2 60 12.1 12.2 95 3602 60 12.1 12.2 90 34..1 6:0 12.2 12.2 82 36.1 60 12.2 12.2 86 36.1 60 12.3 12.3 318 36.1 60 12o2 12.2 70 36.1 60 12.2 12.2 64. 36.1 60 12.2 12.2 203 34.ol 60 12o2 12.2 184. 36.0 60 12.2 12.2 51 34*.0 60 12.2 12.2 53 34.0 60 12.2 12.2 72 36ol 60 12o2 12.2 223 34..1 60 12'2 12-2 191 34..1 60 12.2 12.2 53 34..1 60 12.2 12.2 350 36.1 60 12.1 12-2. 108 36.1 60 12.1 12o2 123 34..1 60 12.0 12.1 139 34.1 60 1Z.O 12.1 113 34.1 60 12.0 12.1 116 34.ol 60 12.1 12ol 90 34..1 60 12-2 12.2 136 36ol 60 12.1 12.1 126 34..1 60 12-2 12'2 38 34..1 60 12.2 12.1 68 36.1 60 12.1 12.1 168 34..2 60 12.2 12.2 116 36.2 60 12-1 12.1: 18 34.2 60 12ol 12.2 16 34*02 60 12.2 12.3 133 34.2 60 12.2 12.2 4707067 6.8· 27 34.2 60 12.3 12.3 A 4709067 4*07 27 36.2 60 12.2 12.3 A MARATHON OIL CONPANY TBU M-3 PAGE 26-FILE 1 DEPTH DIP DIP DEV DEV OIAM OZAM Q . AZM AZM 1-3 2-4 · · 711o 67 304 6 34.2 60 12.3 120% ~713067 26.6 356 3403 60 12,.1 12.3 4715.67 NO CORR 34.3 60 12o2 12o3 471706T 502 89 3403 60 12.1 12.1 4T19.6T 7.2 74 34.3 ' 60 12o2 12,,,2 4721067 11.9 79 34.4 4723067 702 74 34,,,4 4725.&T **r609 96 34.*4 41'27067 ~8'7 91' 34'4 4729'&T ~ 10'9 81 3404 47310*6T'. 4oi6 156 34.4 4733., 67 7ol 59 3404 4735~T 13o2 344 34.5 473T?&T ~ 11.5 52 34.5 47~;~67 19o0 70 34.5 47~..67 507 4 34.5 47'4~L~67 14.4 111 34.5 4T~Sg67 7.2 101 34.5 474T~:&7 9.3 310 34.5 4749~67 900 89 34.6 475I°67 13o6 105 34.6 4753~67 5.4 63 34.6 4755-67 402 17 34.6 4TST-67, 508 69 34.6 4759.67 7.1 122 34.6 4761.67 2.9 7 34.6 4763.67 3.1 351 34.6 4765.6T 16.5 122 34.7 4767.67 15.9 1Z1 34.7 4769067 17.6 107 34.7 4771.67 17.4 115 34.7 4773.67 20.7 109 34.7 4775.67 17.3 108 34.7 .477706T 13.8 104 34.T 4779.67 SoS 316 34.7 4781.67 21.8 Z60 34.8 478306.7 ~ 12.8 100 34.8 4785.67 i9.5 98 34.8 478To67 3.9 8T 34.8 4789.67 15.9 119 34.8 60 12.1 12.1 60 12.2 12.2 60 12.2 12.2 60 12.2 12.2 60 12.1 12.2 60 12.2 12.2 60 12.1 12.1 60 12.2 12.2 60 12.1 12.1 60 12.2 12.1 60 12.1 12.0 60 12,1 12.1 60 12.1 12.0 60 12.1 12.1 60 12.0 12.0 6O 12'0 12.1 60 12.0 12.1 60 12.0 12.1 60 12.0 12ol 60 1Z.O 12.1 60 12.0 12.2 60 12.0 12.1. 60 12.0 12.2 60 12.0 12.2, 60 12'0 1Z.2 60 12.0 12.2 60 12.1 12,3 60 12.0 12.2 60 1Z.1 12.3 60 12'0 12.1 60 12.0 12.1 60 11-9 12-0 60 12,0 12.1 60 12.0 12.0 60 12.0 12.1 A O B B B B A B O C O C A A A B B B B C A A A A A A A A A A A O C O C C D DEPTH DIP DIP DEV DEV DIA~ DII~ Q t AZH AZM 1-3 2-4 · 479! ~g*'dST **8.3 479906T .... 6.5 4795.6~1' 600 479T~ 67 7.4 · 799.67 7.7 4801 ,~67 8.8 4803'0'~7 14.7 4805067 12.5 ~4807,67 804 4809.6? 6.3 4811.67,10.1 4813.67 9.6 4815.67, 5-7 4817067 5.1 48,19o67. 708 4821.67 3.5 4823067, 3.9 4825.6'T 5.5 4827o6T~ 5.0 4829067 5,4 4831.67' 8,1 4833.67 8.5 :4835.67 8.5 4837.67 19.8 4839.67 11.3 4841.67, 9.9 4843.6711007 4845.67~13.8 4847.6719.7 4849.67 12.Z 4851.67 13.0 4853067~13.6 485:5067' 8*5 37 34.8 60 12.0 12.1 43 34.8 60 12o0 12.1 132 34.9 60 12.0 12.1 133 34.9 60 12.0 12.1 78 34.9 60 12.0 12.1 79 34.9 60 12o0 12.1 110 34.9 60 12.0 12.1 152 3409 60 12.0 12.1 8 3409 60 12o0 12.1 54 34.9 60 12.0 12ol 78 34.9 60 12.0 12o2 58 34.9 60 12.0 12.1 110 34.8 60 12.0 12.2 97 3408 60 12.1 12'2 61 34.? 60 12.0 12o2 44 34.6 60 12.1 12o6 120 3406 60 12-3 12.7 136 34.5 60 I2.3 13.0 164 3404 60 12.6 13.2 189 34.3 60 12.5. 13.1 209 34.3 60 12.4 13~1 229.34.3 59 12.6 13.1 239 34.2 59 12.4 12.9 244 34ol 59 12.3 12.7 239 34.1 59 12.3 12.7 224 34.1 59 12.2 12.6 225 34.0 59 12.2 12.6 229 34.0 59 12.3 12.? 233 34.0 59 12.4 12.T 225 33.9 59 12.4 12.9 248 33.9 59 12'3 12.6 241 34.0 59 12*4 12'8 229 34.0 59 12-1 12.3 222 34.0 59 12°Z 12.3 219 34.0 59 12.0 12.2 224 34.0 59 12ol 12.Z 217 34.0 59 12.0 12.1 210 34.0 59 12°1 12ot 191 34.0 59 12.0 12.0 1.63 34.0 59 12.0 12.0 4857067: 7.5 4859.67 8.3 4861.67 8.6 4863.67 ~ 700 ~865067 6.6 4867067 405 4869.67 A A A A A A A B B C B B A A C A A A 10c A 41: A A A A B B A A A A 41: A A A A A A A A A A HARATHON OIL COHPANY TBU H-3 PAGE DEPTH DIP DiP DEV DEV DIAN DIAN Q AZ~ AZH 1-3. 2-~ 4871.67 4.9 159 3~.0 59 12.1 12.1 A · 87].67 3.~ 233 3~.0 59 12.0 12.1 A · 875.67 5.8 221 3,.0 59 12.0 12.2 A · 8T7.67 5-5 288 3~.0 59 11.9 12.1 A · 879.67 12.5 32. ]~.0 59 12.0 t2.2 A · 881.67 11.8 ,0 3~.0 59 1~.9 12.1 C ~883.67 8.2 279 3~.0 59 22.0 ]2.1 C ~885.67 ].9 5~ 33.9 59 22.2' 12.6 A ~887.67 5.9 57 3].9 5~ 12.0 12.7~ A · 889.67 ]1.* ~7 ]3.8 59 22.2 ~3.6 A ~891,67 11.3 55 ]3.8 59 12.2 1..1 A · 893.67 10.8 79 33.7 59 12'2 I*.5 A · 895.67 ~.7 51 3~.6 59 12.3 2~.5 C · 897.67 5.9 229 ]~.6 59 12.2 2~.1 8 ~901.6T'*~'~I:~Q 88 3305 59 12'1 13~7 A · 903-67 I~;7 7~ 33.5 59 12.2 2~.3 B 4905-'67 ~'::~*S 19 33.5 59 12.3 15.0 B 490T.67 1~'3 173 33.4 59 12.a 15.8 C 4909.&T '!0.8 173 33.4 59 12.5 15:L8* C 4911-~&T* 13.3 326 33.3 59 12.6 15-5 0 4913,:~T 7.3 79 33.4 59 12.6 15.4 B 4915.67 11.0 28 33.4 59 1Z~4 14.8 B &9lT.67 1Z.1 38 3305 59 12.6 15.5. A ~9t9~ 67 8.6 55 3305 58 12.6 15.6 A &921.&7 a.1 31 33.6 58 12.5 15-9 C agz3.6T 11.T 72 33.& 58 12'6' 1601~ C · gz5.6T 17.~ 152 33.6 59' 12.7 15.7.~. D · gZTo6T 28.7 180 3307 59 12'& 15.6 D &929.67 9.5 68 33.T 59 1Z.8 15.2 B ~931067 8.3 58 33.7 58 12.5 1~.6 C ~933.67 a~-7 82 33.8 58 12.6 1&.1 A ~935067 6-0 83 33.8 58 12.S 13o7' A a93'T. 67 6.6 3al 33.9 58 12-7 13~ B ~939.6T: 60& ~1 3~.0 58 1Z.6 13.3 B ~9~1.6T. 7.0 57 3&.1 58 12.5 13i3 A ~9~3.6T 6.5 71 3~.1 58 1Z.a 13-1 A ag&S' 67 S.1 61 3&.1 58 12.3 12'9*~* A ag~T~ 6T 5.~ 5a 3~.1 58 12.2 1Z.8~ A agag. 67 1.8 119 3~.1 58 12.2 12-7 A MARATHON OIL'COHPANY TBU R-3 PAGE Zg-FILE 1 DEPTH DZP DIP DEV OEV DIAN DIAH Q t AZ# AZH 1-3 2-~ ~ 4951,6T* 2.6 137 34.1 4953'6T 3.2 T2 34.1 4955'~&T~'', 3.6 61 3~.1 · 957~-~ 8.3 169 3~.1 ~959~*'6T ..... 9.1 12~ 3~.1 · 96T~6T 8.3 126 34.0 ~963~6~ 1.9 118 3A.O 4~'~67' 5-8 205 33.9 49~67 5.7 218 33.9 4969~67 4.1 71 33.8 4971.67 3.2 55 33.8 49'T3.67 3-4 49 33.8 4975-67 4.4 60 33.8 49T?-67 12.4 56 33.8 4979-67 4.4 111 33.8 4981-67. 3.9 94 33.8 4983.67 8.4 66 33.8 4985.67 5.8 38 33..8 4987.67 8°2 58 33-8 4989.67~ ~? ?6 33.8 499'1.67 12".3 131 33.8 4993.6?23.2 172 33.8 4995~67' 12.7 58 33.8 4997..6T.:~1.4.2 57 33.8 4999.67,;~I2.0 ?0 33.9 5001.67.13.0 35 33'9 5003.67.11.1 108 33.9 5005.67~20.2 131 33.8 500T.67 4.5 248 33.8 5009o&T 10.8 242 33.8 5011o67 7.5 95 33.8 5013.67 4.1 36 33.8 5015.67 4.9 112 33.8' 501T-6T 3.6 92 33.8 5019.67: 3.6 163 3307 5021067 5.6 ~ZOZ 33.7 5023.67 21.5 256 33.7 5025.67 7.5 127 33.07 5027.6.7 18.6 161 33.7 58 12.3 12.8 58 12.3 12.8 58 12.4 12.8 58 12.3 12 58 12.3 12.7 58 12.2 12.6 58 12.3 12.6 58 12.3 12.8 58 12.~ 12..8 58 12o~ 12.9 58 12.6 13.0 58 12.2 12.6 58 12.5 12.9 58 12.2 12.6 581 12.2 12.6 58 12.1 12.5 58 12.0 12.2 58 12.0 12.2 58 12.0 12.3 58 12-1 1.2,4 58 12.1 12.7 58 12'3 12.6 58 12.2 58 12.2 12,~ 58 12.0 12.1 58 12.0 12'0 58 12.0 12.0 58 12.0 12.0 58 12.0 12o0 58 12.0 12.0 58 12-0 12.0 58 11.9 58 12'0 12~1 58 12.1 12.3 58 12.1 12.4 58 12.3 12.8 58 12.2 12.7 58 12.3 12.8 58' 12.2 12,7 A A A C A A A A A A A A A B A A D C A A D C D C A A D B D D A B A A D D D C C NARATHON OIL CONPANY TBU N-3 PAGE 30-FILE 1 DEPTH DIP DIP. DEV DEV DIAN OlA~ Q t AZM AZM 1-3 2-~ · 5r031.67 808 38 33.7 5033.67 6.4 64 33.7 5035.67, 309 142 33.7 503T.&T 10.9 271 33.7 5039.67 9.0 308 33.? 5041.67 10.9 96 33.7 5043.6T 10.7 83 33-7 5045.67 5.7 98 33.T 504?.67 505 75 33.7 50~9.67 6.9 56 33.8 5051.67 ~.0 74 33.8 5053. &7 4.0 75 3308 5055067 806 288 3308 50~aTT' 7.4 240 33.8 506t~a7 4.5 160 3308 ~3 -~67 20.8 263 33.8 3q~65-0 67 6-9 181 33.8 5~o67 13.5 12~ 33.8 5 0~,. 6T 6-1 337 3308 50T1'TT ~9.0 26 33.8 5073067 6.7 307 3308 5075.67 ¢.7 12T 33.8 5077067 11o3 250 33.8 5079.67 8.2 71 33.8 5081.67 8.8 30 33'8 5:083067 9.7 44 33.8 5085.6T 6.9 65 33,,,8 5087.67 7.5 69 33°8 5089.&7 13.7 92 33.8 5091.&7~.13.8 75 3308 5093.6T 18o2 ~ 67 33.8 5095.&T,~'12.9 314 33.8 509T'~&T' 9.0 117 33.9 5099'~6T '7.2 97 33.9 510I'67. 9.5 128 33.8 5103-&7 ~. 1 3 ~ ~ 33.8 5105.6T 10.1 a6 33.8 5107°67 7.¢ 58 33.8 5109'~:~? 9.2 69 33.8 58 12.4, 12.8 C 58 12.3 12 -7 D 58 12.5 12.7 C 58 12.2 12.5 B c 58 12o3 12.5 C 58 12.2 12.4, C 58 12.3 12.4, B 58 12.3 12'5 C 58 12.3 12.4, C 58 12.2 12.5 D 58 12.2 12.5 D 58 12.2 12.6, C 58 12.2 12.6 A 58 12.2 12.6 C 58 12.2 12.7 O 58 12.2 12,,7 0 58 12.2 12 .T D 58 12.2 12.6 C 58 12.2 12.5 D 58 12.2 12.6 D 58 12.2 12.5 D 58 12.1 12'5 C 58 I2.2 12.6 A 58 12.1 12.6 A 58 12.0 12.5 O 58 12.0 12.5 D 58 11.9 12.~ ' D 58 12.0 12'4 B 58 11.9 12.4 C 58 11.9 12.4, C 58 11.8 12.3 0 58 11.8 12o3 C 58 11.7 12.2 C 58 11.7 12.3,. D 58 11.8 12,T D 58 12.0 13. '6 ,. B 58 11.9 14'2 A 58 12.4, 15-2 C MARATHON OIL COMPANY TBU H*-3 PAGE 31-FILE I DEPTH DZP DZP DEV DEV DZAM DZAM AZM AZM 1-3 Z-4 2.0 293 33.9 58 12o5 15.4 12.3 34.4 7.7 302 8.8 107 7.7 93 14.7 286 10.8 63 9.6 54 11.8 128 708 115 9.5 76 2802 313 13.4 61 16.5 68 13.1 62 11.1 0 10.8 37 8.9 56 9.1 65 6°0 105 8'6 118 .... 801 116 4.9 53 11.1 120 9.Z 118 7.9 115 508 92 3.6 60 3.1 3a 4.9 10 2.1 99 Z. 1 66 13.4 186 13.0 186 10.1 111 6-~4 328 19'9 301 NO CORR 5111.67 5113g~7 5115g:67 5117~ 67 5119g 67 5121L67 5123~67 51 Z5.67 51ZT.67 5129' 67 '5131.67 513'3.67 5135.67 5137067 5139.67 51~1067 51~3.67 5145067 5147.67 5169.67 5~51.67 5Z~;3.,67 51'55 "67 5157"67 5159.67 5161.67 5163.67 5165.67 5167.6T 5169.67 5171.67 5173.67 5175.67 5177.67 5179.67 5181.67 5183.6T 5185.67 5187.67 5189.67 33.9 58 13.1 15.4 3309 58 12o4 15.2 33.9 58 12'9 14.9 33.9 58 11.9 15o0 33.9 58 12.0 14.7 33.9 58 12o0 15.0 33.9 58 12.0 15.0 33.9 58 12.0 14.8' 33.9 58 12.1 1~.2 3¢.0 58 12.0 13.8 3~.0 58 12.0 13.5 3¢.1 58 12.0 12.8 34.3 58 11o9 12.8 34°4 58 11.8 12,7 34.5 58 11.9 34.5 58 11.9 12.9 3~.5 58 11o8 13.3 34.5 5;8 12.0 13o2 34.5 58 11o9 12.9 34.5 58 12ol 13o0 3~06 58 12ol 12.4 3¢.6 5'8 11.9 12.3 34.6 58 12.1 1Z.2 34.6 58 11.9 12.2 3¢.5 58 12.1 12o3 34.5 58 12.2 12.~ 34.5 58 12.0 12.2 3¢.5 58 12ol 12.2 3404 58 1.1.9 11,9 34.~ 58 12.0 11.9 34.5 58 12.0 11.9 34.5 58 1Z.O 12.0 34.5 58 12.0 11.9 3¢.5 58 12o0 12o0 3~.~ 58 12.0 11o9 34.4 58 11.9 11.9 34.4 58 11.9 11'9 34.4 58 11.9 11.9 D O C C O O D O C C B B B ' O O A A 1t: B B A A B A A A A A A A A A A 11: A C C C MARATHON OIL COMPANY TBU M-3 PAGE 32-FILE 1 DEPTH DIP DIP DEV DEV DIAM DIAN AZH AZPI 1-3 2-4 5191.67 15.6 5193.67 6.3 5195067 19.1 5197.6T 14.4 5199.67 11.8 5201.67 11.4 5203.67 6.0 5205.67 13.T 520T~67 14-8 5209' 6T 24.8 5211.6T 5213.6T 5215.6T ToO 5217.~ 9.0 5219.67 '*'8.0 5 Z 2~;' 67 9.2 5223' 6T 3.6 52 ZS~' 67 6.3 522rr~67 13-6 5Z2~67 10'9 523~;;~ 5233.67 5235..67 5237'67 5239.67 5241.67 5243.6T 5245.6T 5247.6T 524*9.67 5251.67 5253.67 6.01 8.9 8.4 9.2 3.9 4.3 3.5 2.8 4.6 7.? 9.8 5255.6T: 12.Z 52 ST' 6T:.28'. 1 5 Z 59'.' 6T?'1 6.1 5261.6T 13.6 5263.6T ":i:'i 6.1 5 Z~6T'67 ~'~10.5 261 211 94 120 25 26 107 293 211 208 91 53 49 344 ~5 330 55 34,6 11 22 79 67 56 358 34.T 18 351 331 31T 341 335 328 328 32T 332 336 331 34*.4* 58 11.9 11.9 34*.5 58 11.8 11.9 34..5 58 11.8 11.9 34,.5 58 11.8 11.9 34..5 58 11.8 11.9 34.-5 58 11.8 11.9 34.5 58 11.8 11.9 34..5 58 11.8 11.9 34,.5 58 11.8 11.9 34..5 58 11.8 11.9 34.5 58 11.8 11.9 34,.6 58 11.7 11.9 34.6 58 11.7 11.8 34..6 58 11.6 11.8 34,.6 58 11.7 11.8 34.6 58 11.6 11.8 34.6 58 11.6 11.8 34.6 58 11.6 11.8 34..6 58 11.6 11.8 34..7 58 11.6 11.8 34,.7 58 11.T 11.8 3¢.7 58 11.? 11.9 34.7 58 11.9 12.1 34.T 58 11.9 12.Z 34,.7 58 12.2 12.5 34..7 58 12.1 12.4. 34..? 58 12.2 12,5 34.7 58 12.2 12.5 34,.7 58 12.2 12.6 34,.7 58 12.2 12.5 3¢.7 58 12.1 12.5 34.8 58 12.2 12.5 34..8 58 12.0 12.5 34*.8 58 12.2 12,5 34.8 58 12o0 12.4. 34.8 58 12.Z 12.5 36.8 58 12.2 12.5 34*.8 58 12.1 12.5 34.8 58 12.2 12.5 D D D C A B O C B B A A C B A A O C C C B C B B A A A A A A A A A A A A A A A NARATHON OIL COHPANY TBU N-3 PAGe' 33-FILE 1 DEPTH DIP DIP DEV DEV DIAN DIAN Q ~ AZN AZN 1-3 2-4 · 5271067: 15ol 320 3409 5273o&?::'15o8 325 3409 5275°6?: 800 323 3500 5277a67 8.0 329 3500 5279~,67 902 328 3500 5281,,'~67 12o9 320 3500 5283:~'i67 11.6 328 3500 5285067 10o9 324 3500 528?°67 17o0 314 35.0 5289~67 21o8 315 3500 5291067 2709 3~7 35.0 5293.67 30.0 310 35.0 5295.67 2T.7 31~ 35.0 5297.6T 23.6 319 35.1 5299.67 20.9 3~9 35. 5301.67 25.4 3~7 35.0 5303.67 29.2 316 5305.67 12.0 355 35.0 5307.67 10.6 19 5309.67 ~.2 318 35.0 53110,67 21~6 5313g':~7 504 5315'°67 6.6 5317°67 16o5 5319.67 5.5 5321067 309 5323067 3.9 5325.67 7.1 301 35.0 92 35.0 96 3409 320 34.9 60 34.9 60 340 9 96 34.9 73 34.9 5327.67 10o0 101 34.9 5329.67 I0.5 137 34.9 5331.67 3.4 97 34.8 5333°67 8.02 36 34.8 5335'67 707 33 3409 5'337.67 8°3 18 34.9 .5339.67 5.1 250 34.9 5341.67. 9.8 1ZT 3409 5343.67: 8.4 131 34.9 5345°67 11.5 210 35°0 5347067 10.9 95 3500 58 12o2 12o5 A 58 12ol 12o4 A 58 12.1 12o4 A 58 12.1 12o4 A 58 12.0 12.4 A 58 12ol 12.5 A 58 12ol 12.4 A 58 12o2 12o5 A 58 12o0 12o3 A 58 12o0 12.3 A 58 12o0 12.2 A 58 12o0 12o3 A 58 12o0 12.2 i 58 12o0 12.3 A 58 12.0 12o4 A 58 11,.8 12.5 A 58 12o0 12o6 A 58 1107 12.8 O 58 12.0 12.8 C 58 11o8 12.8 O 58 12.0 11.8 C 58 12.0 12o8 B 58 12o0 12o9 C 58 12.0 12.8' B 58 12.0 12'8 C 58 12.0 12o7 B 58 12.0 12.8 A 58 12o0 13°2 C 58 11o0 13..2 C 59 12.2 13o5 C 59 12.1 13.5 D 59 12.4 13-4 A 5.9 12-5 13'6" A 59 12.5 13o6 B 59 11.6 13,8 D 59 12°3 13.7 D 59 12.3 13o8 D 59 12ol 13-5 O 59 12.1 13.3 C 5349067 13o0 55 35.1 59 12o0 13~0 A * MARATHON 9IL COMPANY TBU M-3 PAGE 3.4-FILE 1 DEPTH DIP DIP DEV OEV OIAM DIAM Q * AZ# AZM 1-3 2-a * 5351.67 11.5 42 35.Z 5353.67 7.7 50 35. Z 5355.67 7.2 50 35.3 5357.67 9.8 44 35.3 5359.67 15.7 57 5361.67 7.3 118 35.5 5363.67 9.9 138 35.5 5365.67 5.9 176 35.5 5367.67 16.1 174 35.6 5369.67 14.0 187 35.6 5371.67 ~2.9 253 35.6 S373.~ 9.~ 323 3S.& 5375.~T 2.4 302 35.5 S377~&7 6.7 75 .5383-~T '5385~&7 53 g 3 5395.~&7 9.9 76 35.4 4.4 58 35.4 8.6 84 35.4 8.5 96 35.4. 1.0 200 35.4 7.0 342 35.,~ 6.0 315 35.4 0.5- 170 35.4 1.4 135 35.4 5397.,67 3.4 111 35.3 5399.67 3.0 115 35.3 5401.6'7 2.1 119.35.3 5~03.&7 8.4 238 35.3 5&OS.&7 1.6 329 35.3 54~07.67 2,.2 317 35.3 5409.67 1.6 359 35.3 5411.67 1.9 20 35.3 5~13.67 1.¢ 29 35.3 5415.67 3.3 14 35.3 5~17.67 .'10.3 354 35.2 5~19.61" 5.4 312 35.2 5421,.:~T :13.4 348 35.2 5423-~6~T: 5.8 4.7 35.2 5:42'5,'~67. 6.4 49 35.2 54,27g~7 7.0 58 35.3 5429~7, 3-1 19 35.3 59 12.0 12.7 58 12.0 12.6 58 12.0 12.7 58 12.0 12.5 58 12.0 12.6 59 12.0 12.7 59 12.1 12.7 58 12.2 12.8 58 12.1 12.8 58 12'1 12.7 58 12.0 12.7 58 11.9 12.6 58 12.0 12.7 58 12.1 12.7 58 12.2 12.7 58 12.1 12.8 58 12.0 12.7 59 12.1 12-8 59 11.9 12.8 59 12-2 12.8 59 12.0 12.7 58 12.1 12.8 59 12.0 12.8 59 12.0 12.8 59 12.0 12.8 59 12.1 12.8 59 12.1 12.6 59 12,2 12,7 59 12.1 12.6 59 12-1 12.7 59 12-0 12.6 59 12.0 12.6 59 12.0 12.5 58 12.0 12-4 59 12.0 12.3 59 12.0 12.3 59 12'1 12.3 59 12.1 12.4 59 12.1 1Z .4 59 12.1 12.5 B A A A C C B B C C 0 B A B C B C A C A A C B C B A B HARATHON O]:L COHPANY TBU lq--3 PAGE '35-FILE 1 DEPTH DZP DIP DEV DEV DIA~ AZM AZH 1-3 Z-~ 5~3196T' 2.6 28 35.3 5433:g:6T Z. 7 59 35.3 2.2 91 35.3 2.5 87 35.3 2.6 73 35.3 3.6 41 35.Z 3.4 59 35.2 3.1 64 35. Z 7.7 103 35.2 5.6 85 35.2 10.1 18 35.2 4.2 262 35.2 8.0 353 35.2 T.Z 103 35.2 2.4. 87 35.2 6.0 65 35.2 6.1 75 35.1 92 35.1 97 35.1 76 35.1 84 35.1 77 35.1 53 35.1 265 35.1 37 35.1 30 35.1 157 35.0 14.1 35.0 102 81 35.0 84 35.0 142 35.1 106 35.1 74* 35.2 60 35.3 236 35.3 312 35.3 289 35.4 62 35.4 5509.67 11.9 78 35.4. '543'5. 6T 54.39g :67 5~4.3.6T 544*5067 Sql4?.6? 54.q~g:.6T 545t.6T 5453.67 5455.67 5457.67 54.59.6T 5461.67 5463.6T 5465.67. 5~6 7.6 T · 3 9.6 ?, '" 3.5 · ~71.67'* 3.2 :~73.6 T 3.2 S~So 6T; 5,,6 54*Tg,~'~6T 6.8 5481.167 8.6 5483°6723.8 5485.67 16.0 54*87.67 7.9 S 4. 89. ,67 9.8 54.91.67. 54*93.67 ,, 17.7 5495.67 3.9 54*97.67 8.1 54*99.67 8.6 55101.67 11.1 5503.67 5.7 5505:.67 6°5 5507.67 IO.Z 59 12.0 59 12.0 59 11.9 59 12'0 59 12.0 59 12.1 59 12.1 59 12.1 59 12.1 59 12.2 59 12.0 59 12.1 59 12-0 59 12.0 59 12.'1 59 12.0 59 12.0 59 12o0 59 12°0 59 12.0 59 12.2 59 12.1 59 12.2 59 12'2 59 12.3 59 12.4 59 12.4. 59 12.5 59 12.2 59 '12.3 59 12.2 59 12.-2 59 12.1 59 12.1 59 12.0 59 12.1 59 12.1 59 12'2 59 12.1 59 12-2 12o4. 12o3 12.5~ 12.5 12.7 12.8 12.6 12.T 12.6 12.6 12.5 12.6, 12.5 12.7 12.T 12.8,, 12.8 12.9 12.9 13 o0 13.2 13'5 14. o2 14..2 14.6, 14..9 14..8 15.6 15.2~ 15-6 15.0 14-7 1&'3 13'8 13.4. 13.3 13.2 13.4 13.7 A A · A A :ulc A A 41: A A B B C O C B A A A A A A A A B A D C D D 6 A A D C MARATHON OIL CONPANT TBU N-3 PAGE 36-FILE DEPTH OZP DIP DEV OEV DIAH OIAfl Q AZH AZ# 1-3 2-4 5511067 2.0 25 3504 SS13.67 l&.O 104 S5150'6T 14.S 205 35.5 SS17-~T 605 241 35.6 SSlgo6T 6.8 93 35.6 5521o6T 17.0 32~ 35.6 SS23o6T 13.7 61 3506 SS2So6T ~08 41 35o6 5527.67 20.7 145 3506 5529.67 6o.1 105 35,.6 5531067 504 91 35.6 59 12o6 13 03 59 12o3 13.8 59 12.8 13.4 59 12.4 13o9 59 12.3 14.0 59 12.2 13.9 59 12.1 13.2 59 12.0 13.3 59 12.0 12.7 59 12,1 13.0 59 12ol 12o9 5533067 3.7 5535.67 1-5 553~.6T: ~9o'6 88' 35.7 553aJ~o&7 .. ¥. 7,.0 105 35.7 554~1o67 ~1T, 6 145 3 5.8 5543067 ,'16. 8 141 35.8 55~S~-6T *~;2.9 135 35.8 55~'Tg'67 1.'4.7 146 35.8 554996T '22.4 149 35.8 555Ig67 16.~7 328 35.8 5553-:67'~ 13.8 336 35.7 5555,&T~: 8.5 108 35..7 555To&T..12.4 72 35.6 555906T '710.4 68 3 5.6 5561.67 12.8 85 35.6 5563.67 3.1 355 35'6 5565.67 2.Z 339 35.6 5567.67 4.6 78 35.6 5569.6T 5.4 2 35.5 55T1.67 307 80 35.5 5573,67 Z.9 83 35.5 5575.6T 7.1 350 35.5 5577..6T~' 608 11 35.5 5579-67 6.3 10 35.4 5581067* 11.T 30.6 35.~ 5583'67 3.4 326 35-4 55850.67 4.1 322 35.4 l: 35.6 '59 12.0 12o9 35.7 59 12.2 12.9 59 12,1 12.9 59 12.2 12.9 59 12.1 12.9 59 12.1 '1209 59 12.1 12.7 59 12.1 12.8 59 12-1 12-6 59 12o0 12-6 59 12.1 12.5 59 12,1 12.6 5g 12.2 12-7 59 12.2 12.8 59 12.2 13.0 59 12.5 13.2 59 12.4 13.3 59 12.5 13'2 59 12.7 13.6 59 12.5 13.2 59 12,7 13"5 59 12.6 13o5' 59 12,7 13°4, 59 '12.6 13.4, 59 12.6 13.3 59 12o5 13o4, 59 12'4, 13'3 C * D ~ D · D , D * C , C , C , A ~r A , A * A , A , A , A , B * C , A * A , A ~ A , C * D . 5587o67':17o8 127 35.4 59 12.3 13.6 55'89067'10.3 102 35.4, 159 12o3 14,0 MARATHON OIL COMPANY TBU M-3 PAGE 3T-FILE 1 DEPTH '9IP DIP OEV DEV DIAN DIAM G · AZM AZM 1-3 2-¢ · 5591o67 ~;'10.9 52 35.4 ~593.'6T: 8.3 44 35°4 5595.67 6.4 6Z 35.4 '5597.6T .... 7.7 83 35.4 5599.:6T~:i 2.2 71 35.4 S 601:e~6T 10.7 75 560396T ~.7 IOZ S605.67 6.5 10~ 56~.67:' 6.8 90 3505 56~9067 508 83 35.5 561106T 306 66-35.5 5613.67 4.1 260 35.5 5615.67 32.2 223 35.5 5617.67 705 189 3505 5619.6T 6.9 214 35.5 5621.67 S08 44 35.6 5623.67 ~: 3.7 30 35.6 5625.67 3.7 1Z7 35.6 56ZT.&7, 3.5 241 35.6 S629'6T~ ;3.1 51 35'5 **~631.67 202 92 35.5 **5~&3,,3'o6.T~ 1.1 355 35. S ~S&35.*6T: 11.2 85 35.6 5637'6T~11.4 89 35.6 5639.6T: 4.8 169 35.6 5641.6T: 6.9 85 35.6 56430.6T: 1.7 167 35.6 5645.67 4.2 215 35.6 5647.67 1.6 157 35.6 564.9.67 11.4 40 35.7 5651.67 9.1 T6 35. T 5653.67 7.2 77 35.7 5655.67. 30.5 134 35.7 565T.67 1Z.6 107 35.7 5659.67 9.0 110 3507 59 12o4 14.1 59 12.4 14.4 59 12.8 14.7 59 12.5 14.1 59 12.8 14.1 59 12.5 13.7 59 12.5 13 59 12.6 13.3 59 12o6 13 59 12.7 13o3 59 12.7 13.3 59 12.8 13.1 59 12.8 13.1 59 12.5 13.3 59 12-5 59 12.4 13 ol 59 12.4 12.9 59 12'5 12.7 59 12.5 I2 59 12.7 1Z.8 59 12.4 1Z'8 59 12.7 13.1 59 12.2 12.5 59 12o3 12.8 59 12.2 12'3 59 I2.1 12.3, 59 12ol 12'2 59 12.2 12,3. 59 12o2 1203 59 12o2 12.3 59 12o2 12o3 59 12o2 12.3 59 12,,1 1202 1Z°I lID2 5661.6.7 10.9 ¢0 35.7 5'9 12.1 12.1. 5663.67 808 151 3'5.7 59 12.1 5665.67 11.S 157 35.7 59 12'1 1Zoi 5667.6T'13o4 303 35.7 59 12.1 12.2, A B O C C C A A A A A O B B B A A C B A A A A A C B A A A A A A A C A O A B C ~ 5669.67 18.8 263 3507 59 12.2 12-2. B MARATHON OIL COMPANY TBU #-3 PAGE 38-FILE 1 DEPTH DIP DIP DEV OEV OIAM OIAM Q * AZM AZM 1-3 2-~ ~ 265 35.7 59 12.2 110 35.7 59 12.2 66 35.7 59 12.3 109 35.7 59 12.3 92 35.7 59 12.5 46 35.7 59 12.6 72 35.7 59 12.7 162 35.7 59 12.8 304 35.7 59 12.7 30 35.7 59 12.6 12 35.7 59 12-6 66 35.7 59 12.5 71 35.7 59 12.5 67 35.7 59 12.7 25 35.7 59 12.6 50 35.7 59 12.7 34 35.7 59 12.5 42 35.7 59 12.7 54 35.6 59 13.0 31 35.6 519 12.7' 27 35.7 59 13o0 30 35.8 59 12'6 73 35.8 59 12.6 257 35.8 59 12-5 74 35.8 59 12.5 72 35.8 59 12o5 60 35°8 59 12.6 109 35.8 59 12,7 332 35.8 59 12'8 354 35.8 59 12.8 38 35.8 59 12.9 51 35.8 59 12.6 61 35.9 59 12,6 44 36.0 59 12-4 84 36.0 59 12.5 101 36.1 59 12.5. 163 36.0 59 12'5 94 36.0 59 1295 73 36.0 59 12.5 70 36.0 59 12.4 5671-'67 17.6 5673.67 14.6 5675.67 10.6 5677.67 13.3 5679.67 8.3 5681,.67 T.4 5683 o 67 2.7 5685.67 1.2 5687.67 ~I1.3 5689.67 · 12L 1 5691.67 5693.67 5695.67 ~3.1 5~,g 67 ~ 2,,8 5~:'67 5.2 5701,~67 · 2.9 570'3L~:6~ 7 3.5 ..... 570~:~67' 500 ~O.T. 67 7.3 ~09L67 5.7 ~'1.67 4.9 5T13.67 3.0 5715.67 . 5717.67 13.Z 5719.67 5721.67 3.8 5723.67, 5725.67 4°0 5727.67 5729.67 13.8 5731,,67 5733.67 6.2 5735.67 6. Z 5737.67 6.0 57'39.67' 6.3 5741.67 5.0 5743.67 3.0 5'745.'67~' 7.0 5747.67 14.2 5749 o ~gT 13.8 12.3 12.4 12.4 12.7 12.8 12.9 13.0 12.9 12.9 13o0 13.0 13.1 13.2 13.3 13-3 13.2 13.2 13-8 14.0 13.8 13.9 13.1 12.8 13'0 12.9 12~9 13~0 12.9 13.1 13.0 13.0 13.0 12.9 12.8 1Z'T 12.8 12.8 13.0 12.9 12.9 C C B B B A A A O O A A A A A A A C A A B A A A A A A C D A A A A C B B MARATHON OIL COM,PANY TBU N-3 PAGE 39-FILE 1 '~DEPTH DIP DIP DEr DEV DIAM DIAN Q 4: AIM AIM 1-3 2-4 4: 5751.67 4.8 '~5753.67 2:.8 5755.67 '4.3 5~T. 67 Z. 9 57 59", 6T ~; 3 o 4 '5761,67' ~ 0o6 5763.67 3°0 5765.67 3.4. 5:769.57 1.9 5771.67 4.2 5773.67 5775.67 3.9 5777.67 5.0 5779.67 7.0 5781.67. 6.9 5783o~67 5o 9 111 36.0 59 11o6 12.9 77 36.1 59 12:o5 12.9 108 36.0 59 12.7 13.0 80 36.0 59 12.7 13.1 35 36.0 59 12.8 13.2 147 36.0 59 12.6 13.1 133 36.0 59 12.8 13.4 137 36.0 59 12.6 13.2 116 36.0 59 11.6 13.2 214 36.0 59 12.5 13.2 259 36°0 59 12.8 13.2 89 35.9 59 12:.6 13.1 97 35.9 59 12.8 13.1 112 36°0 59 12.8 13.0 61 36.0 59 12,7 12.9 98' 36.0 59 12.6 12.7 87 36.0 59 12:.5 12'6 271 36.1 59 11o4 12.5 250 36.1 59 12'4 12.5 113 36.1 59 12.4 12.5 38 36.1 59 12'4 12.& 297 36.1 59 12-4 12.6 23 36.1 59 12.3 12.5... 86 36.1 59 12-3 12.4 25'1 36.1 59 12.1 12.3 79 36.2 59 12.1 11.3 63 36.2 59 12.0 12.3 70 36.2 59 11.0 11'4 76 36.Z 59 12.0 12.2 79 36.1 59 12.0 12'7 39 36.1 59 12.2 12.7 29 36.1 59 12oZ 13.0 77 36.1 59 12.4 13'2 111 36.1 59 12°4 13.1 99 36.1 59 12.3 13.1 81 36oZ 59 12.5. 13.2 15 36.2 59 11'3 13'1 293 36.Z 59 12'6 13.2 36.2 59 11.5 13ol 5785.67,20.5 5787.67 11.7 5789.67. 3.Z 5791.67 10.2 5793o 67 21-2 5795.67 6..9 5797o67 3.4 5 799 o 67 1 5801.67 5.5 5803-67 5-2 5805.67 5.6. 5807.67 ~ 8.6 5809.67 7.Z 5811.67 11.5 5813,,67 8.3 5815.67 5.9 5817.67 18.2: 5819.67 10.1 5821.67 14.1 5813.67 11.1 5825.67 4: 5627.67 4.7 278 A A A :lc A A :lc A A 4: A A A A A :lc A A A A B B B B C B A A B 4:, A 4: A A D A B A A 5829.67 7.2 306 36.1 59 12.5 13,.1 C , 4: NARATHON OIL CORPANY TBU N-3 PAGE 40-FILE 1 DEPTH DIP DIP DEV DEV DIAN DIAN Q t ~ZN AZ# 1-3 2-~ · 5831.6T 5.1 73 36.1 5833067 ToO 75 36ol 5835.67 1.6 342 36.2 5837.6T' *~.4 54 36.2 5839.6T 6.4 75 36.2 5841067 7.8 6~ 36.2 5843.67 606 76 36.3 5845067. 9.4 43 3603 5847067 13.3 46 36.2 5849.6Ti 803 93*36.2 5851.67, 4.7 109 36.2 5853.67 3.5 139 36.2 36 36.1 37 36.1 46 3601 64 36ol 68 3601 55 36.1 98 36.1 101 3601 14 3601 · 58T3.6T 13.1 133 36.0 60 12.6 13.3 60 12.6 13.2 60 12o6 13.A 60 12.6 13.3 60 12.5 13.2 60 12.6 13.1 60 12.5 13.1 60 12.5 13'o0 60 12.5 13.1 60 12.5 13-1 60 12o5 13.1 60 12o5 13.1 60 12°~ 13o0 60 12.~ 13.0 60 12~4' 12.9 60 12.~ 13o0 60 12.5 13'0 60 1204 12.9 60 12~5 13.0 60 12.5 13.0 60 12.6 13.0 60 12.5 13.0 5875.67 1.7 332 36.0 : 60 12'5 12'9 5877.'67.~ 1.6 355 3600 5879.67 3.¢ 303 36.0 5881.67 ~.9 272 35.9 5883.6T 1.2 18 35.9 5885.67 2.1 359 35.9 5887.67 6.4 48 35°8 588906T 5.Z 49 35.9 5891.6T 6.4 71 35.9 5893.67 11.7 141 3509 5:895.6T 3.9 70 35.8 5897,~7 6.6 86 35.8 5899.6T 5.8 106 35.8 5901067 7.9 72 35.8 5903.67, 5.4 6:1 35.8 5905.67 2.9 68 35.8 5907.67 805 89 35.7 5909067 7.7 80 35.7 60 12.5 12.8 60 12-~ 12.9 60' 12.4 12o9 6,0 12.4 13.7 60 12-6 13'2 60 12-5 13-7 60 12-7 13'3 60 12.6 13-1 60 12~6 13.1 60 12.6 13.1 60 12.6 13'1 60 12.6 13.1 60 .12.6 13.0 60 12.5 13.0 60 12.5' 13.1 60 12.~ 13.3 60 12.5 13ol B · B · B · A 4~ A 4~ B ~: f D f D I~ D f B f B 11[ A f B · A ~ A ,4~ B · C · C f B f A f A f A · A f A f A f D f B 1~ 8 f A ~. A f A · B ~ B f MARATHON OIL COMPANY TBU M-3 PAGE 41-FILE 1 AZH AZM 1-3 2-4 4: 5911'~ 6T 4.3 87 35.7 5~3.67 3.6 78 35.7 59~15.67 5.1 71 35.8 ~T.&T 9.7 50 35.8 5919.6"r 409 52 35.7 5~21.6T 4.9 115 35.7 5923.6T 6.3 101 35.7 5'925.67 5.T 91 35.6 ' 592To6T 409 105 35.6 5929.67 8.2 73 35.6 5931.67 10o4 71 35.5 5933.67 5.8 33 35.5 5935.67 8ol 54 35.5 5937.67~ 9.2 76 35.5 5939.6,7. 8.5 73 35.5 5941.67 4.1 83 35.5 5943.6T, 4.1 35 35.5 5945.67 5.4 53 35.5 5947.67, 6.0.8 72 35.4 5949o6T~.: 6.5 60 35.4 5951'67' 1.4 349 35.4 5953°67 10.2 137 35.4 5955,o67 6.6 106 35.4 5957°67 5.1 90 3504 5959.67 3'5 74 135.4 5:961-67 7-7 103' 35o~ 5963.67 17.7 292 35.4 5965.67 10.4 93 35.~ 5967.67 9.5 83 35.4 5969.67 3,,1 102 35.4 5971.67 ~.4 87 35.4 5973.67 ~o8 69 5975.67 3.4 77 35.4 5977.67 8,,5 140 35.4 5979.67 4.0 83 35.3 5981.67 8.0 57 35.3 5983..67 6.7 356 35.3 5985.67 8'.9 6 35.3 5:987.67 3.9 66 35.3 5989.67 6.0 84 3503 60 12.4 13.3 60 12.6 13.0 60 12.6 13.3 60 12.6 13.0 60 12.6 13.3 6O 1Z.5 13.0 60 12.6 13.0 60 12.5 13.0 60 12.5 13.0 60 12.¢ 13.0 60 12.4. 13.0 6O 12.~ 13.0 60 12.5 13o0 60 12.5 13.1 60 12.& 13.1 60 12.6 13'3 60 12.7 13-3 60 12.5, 13.3 60 12-5 13.1 60 12o4 13.0 6~0 '12.4 12.8 60 12.4 12.7 60 12.~ 12-7 60 '12.3 12.6 60 12'¢ 12.6 60 1Z,,3 12.5 60* 12.~ 12 ' 5 60 12.3 12.4. 60 12.3 12.4* 60 12.2 12.4 60 12.Z 1Z.3 60 12.2 12.3 60 1Z.2 12.3 60 12,2 12.3 60 12.2 12 .Z 60 12.2 1Z'2 60 12"3 12.3 60 12.2 1Z.2 60 12'3 '12.3 60 12.3 12.4* A A 4: A A A A A A A A A A A A 4: A A A 4: A A A A A C D B D A A B B C B A B TBU M-'3 PAGE DEPTH O/:P D~LP OEV DEV D~API DJ:AH 1-3 Z-4 B "5~1.67 11.4 113 35.3 60 12.3 12.3 ~3.6T ~.1 77 35.3 60 1Z.3 12.~ B 5995.67' 6.9 78 35.3 60 1Z-3 12.3 C .5~7.67 E.5 1~2 35.2 60 12.3 1Z.4 C 5.~9.67 ~.9 9~ 35.2 60 1Z.3 1Z.6 6001.67 5.1 80 35.1 60 1Z.3 12.7 6003.67* 7.~ 7E 35.1 60 1Z.4 12.8 6005.67 8.5 6Z 35.1 60 1Z.4 13.0 6007.67 9.0 85 35.0 60 1Z.5 1Z.9 6009.67 8.7 86 ~5.0 60 IZ.5 13-0 6011.67 E.6 5E 5.0 60 1Z-5 13-0 D 6013.67 ~.3 91 35-0 60 12.5 13.0 6015.67 5.6 86 3~.9 60 I2.5 1Z.8 B 6017.67 ~.4 91 3~.9 60 1Z.5 12-8* 601'9~:67~:, '3. Z 107 3E.9 60 12.5 12.T 60ZI'-67..'".~ 0.3 86 3'~.9 60 1Z'5 1Z.7 60Z3.;6T".' 3.1 1ZO 34.9 60 12.6 12.7 60Z~.6T~ ~.8 115 3~.9 60 1Z.4 12.6 602~,~67~ 4.0 103 3~ 9 60 1Z.4 1Z.6 603'~'~67. IO.Z 115 34.9 60 12.2 12.~ · 6033~;~7 I~.T 109 3~.9 60 1Z,3 1Z.6 6035.~,~67 11.0 93 3~.9 60 12.3 1Z.5 60.3T-~'67 17.3 1Z6 34.9 60 12.4 12.8 6039.6T 1Z.4 140 34.9 60 1Z.~ 1Z-6 6041.67 1~ 6 135 34.9 60 1Z.~ 1Z-~7 C 6043.67 3.~ 70 34 9 60 1Z'3 1Z 6. 6045-67 5.Z 8Z 34.9 60 12.3 12'5 60~T.67 ~.5 115 3~.8 60 12.2 12.~ 6049.6T 3.2 95 3~.8 60 12.Z 12.3 6051.67 3.0 57 3~.8 60 12.2 1Z.3 6053.67 7.5 1~1 3~.8 60 1Z.Z 1Z.2 C 6055.67 7.5 190 34.8 60 12'2 12'2 C 605T-6T 1Z.O 105 3~-8 60 1Z.1 12.Z D 6059.67 17.3 1ZO 3~.8 60 12'1 12.2 C 6061.67 10-~8 Z09 3~.7 60 1Z.1 1Z.Z 6063.67 7:~ 160 3~.7 60 1Z.1 1Z.3' 6065.67~ 5'6 78 34'8 60 12.Z 1Z.4 C 6067'~6T 6.2 122 34.8 60 1Z.Z 1Z-5: C 6069-67~11.6 105 34.T 60 1Z.5 12,9 MARATHON OIL CONPANY TBU R*'-3 PAGE 43-FZLE 1 DEPTH DIP DIP DEV DEV OIA~ DIA~ Q t AZM AZM 1-3 2-~ 4: 60711"67 10-3 6073*':67 9.7 6075'67. 5.~ 6077:' 67 6.5 6079'~67 2.9 608'I"67 16.0 6083.67 18.4 6085 ~6 7 6.7 608T~67 11.0 6089L67 6.6 6091,67 6093.67 4.9 6095.67 2.8 6097.67 4.3 6099.67 3.8 6101067, 6103.67 7.8 6105.67', 13'0 6107.67 9'8 6.109' 67 10. ? 6~I 1 ' 67 61t5.67 4.3 6117.67 O. 1 6119.67 11.9 6121.67 6123o67~ 3.6 6125.67' 5.3 6117.67. 3.8 6129.67 6.8 6131.67 8.0 6133.67 1.9 6135.67 10.9 6137.67 7.2 6139.67 3o~ 61~1.67' 7.8 61~3.67 ~.6 6145.67 3.Z 130 34.7 60 12.4 152 3~.7 60 12.4 135 3~.6 60 12.4 71 3~.6 60 12.3 91 3¢.6 60 12.4 348 34.5 60 12.5 356 3~.5 60 12.5 329 3~.5 60 12.6 333 34.5 60 12.7 111 34.~ 60 12.6 116 34.4 60 12.7 151 3~.~ 60 12.5 150 3~.~ 60 12.5 179 3~.~ 60 12.~ 299 3~.~ 60 12.5 322 3~.4 60 12-~ 99 3~.~ 60 12.~ ~7 3~.4 60 12.4 110 34.4 60 12.4 132 3~.4 60 109 34.3 60 12.~ 85 34.3 60 12.4 87 3~.3 60 12.4 111 34.3 6,0 12.~ 125 3~.3 60 12.3 110 3~.2 60 12.4 94 34.2 60 12.4 111 34.2 60 12'4 1~1 34.2 60 12,4 95 3~.1 60 12.3 90 3~.1 60 12.3 173 3¢.1 60 11.3 102 3¢.1 60 12.3 109 34.1 60 12.3 60 3¢.1 60 68 3~.1 60 12,3 80 3¢.1 60 12,¢ 70 34.0 60 12.3 34o0 60 11.3 34.0 6'0 11,3 4: ,6147.67 4,.9 359 · 61~9o67 1.3 204 13.0 13.8 13.2 13.5 12.9 12.7 12.8 12o8 12.9 12.8 12.9 12.8 12.7 12.7 11.7 12.7 12.7 12.7 12.6 12.6 12.6 12.6 12.6 11.6 12.6 'I2'6 12o6 12.6 12.6 12.5 12~5 12.¢ .., I ~ 12.5 12o4 12.5 12o4 A A A B B C C D D A A A A A C C C A A B B A A A A A A A A B B A HARATHON OZL COHPANY TBU H-3 PAGE 44-FZLE 1 DEPTH DIP DIP DEV DEV DZAH DIA~ Q ~ AZH AZH 1-3 2-¢ 4: 6151.67 1 6153.67 6155.67 7.6 61'S7.67 8' 9 6159o67 TL3 6161.67 809 6163.67 9.~ 6165.67 10.9 6167.. 67 2 5. 8 6169.67 10,.6 6171.67 6.5 6173.67 9°0 6175.67 617 7.67'~?* 4.3 6! T 9. &T:!'? -8.3 6181.67:~ 5.7 6183,~67 7.5 '6~ 8 T ~;67,10. 6 6189.67,11.3 619~' 67~ 1 ~. 1 6193.67 11.5 6195'67 7.6 619T-67 13.8 6199.67 13 6201.67 13.6 6203.67 15.3 6205.67 6207.67 6209.67 1 6211.67 10.1 6213.67: 6.7 6215.67 3.5 6217.67 6°5 6219.&T, 3.8 6221o67~ 8.8 6223~"67~ 4o7 622 5.'67 5.7 6227.67 4.0 6229.,67 T.1 192 34.0 60 12.2 12.~ 141 34.0 60 12.2 12.~ 123 34.0 60 12.3 12.¢ 118 3~.0 60 12.2 12.3 99 3¢.0 60 12.5 12.5 11~ 3~.0 60 12.3 12.~ 124 34.0 60 12.6 12.7 210 34.0 60 12.5 12.6 170 34.0 60 12.7 12o6 10~ 3~.0 60 12.5 12.5 106 33.9 60 12.5 12.5 89 33.9 60 12.~ 12.~ 97 33.9 60 12.~ 12.~ 78 33.9 60 12.4 12.3 lA 33.8 60 12.3 12.2 110 33-8 60 12.3 12.2 108 33.8 60 12.2 12ol 118 33.8 60 12.3 12.1 102 33.8 61 12.2 12.0 84 3307 61 12.2 12.1 78'33.7 61 12.2 12.1 137 33.7 61 12.2 12.1 78 33.7 61 12.2 12.1 78 33.7 61 12.1 12.1 80 33.8 61 12.1 12.0 96 33.7 61 12.0 12.0 109 33.7 61 12.1 12.1 82 33.7 61 12.1 12.1 130 33.7 61 12o2 12.1 112 33.7 61 12.2 12.1 75 33.7 61 12.2 12.1 76 33.7 61 12.1 12.1 105 33.7 61 12'1 12.o0 1¢1 33.6 61 12.1 12-0 7& 33.6 61 12ol 12'0 99 33.6 61 12.1 12.1 101 33.6 61 12.1 12.0 118 33.6 61 12.1 12.1 99 33.6 61 12.0 12.0 92 33.6 61 12.1 12.1 A A A A :lc A A A O C A A B 4: B A C A B B A A C B B B A B A 4: C A A B A A B A 4: A MARATHON OIL COMPANY TBU M-3 PAGE 45-FILE 1 DEPTH DZP DIP DEV DEV DIAM DZAM Q · AZM AZM 1-3 2-4 ~ 6231067 ...... 707 6233.67'~ 606 62350~:~ 8.1 6237~67 200 623~°~~:: lo3 6~30&T 3.3 6245.67 1.0 62~7967 Z002 6249967 · 6251g167 6253g&7 6255.~7 6257067 625906? 6261.67 6263.67 6265*67 6267067 6269067 6271~67 504 2.1 6.3 8.8 703 1.8 2.4 208 3-7 3o 1 305 6273o67.. .... 7.5 62750 67~ 1002 6 Z 7'70~6,7 8.7 6279°67 5. 6281067 9.3 6283067 11o5 6285.67 12.6 6287067 907 6289.67 10o9 6291067 11.6 :6293.67 9.8 6295.67 5.1 6297.67' 505. 6299.67, 404 6301.67 4.4 6303067, 4.9 6305067 8.1 6307067, 8.2 96 33.6 61 12.1 12.1 155 33.6 61 12.0 12.0 182 3305 61 12.1 12.1 175 33.5 61 12.1 12.0 175 33.5 61 12.1 12ol 107 33o5 61 12.1 120 185 3305 61 12.1 12.0 229 33.5 61 12.1 12.0 135 33.5 61 12ol 12.0 227 33.5 61 12.1 12.0 254 33.5 61 12ol 12.0 120 33o5 61 12.1 12 80 3305 61 12.2 12.3 70 33.4 61 12.3 90 3304 61 12.4 12.6 70 33.4 61 12o4 12.7 38 3304 61 12.4 12.7 10 33.4 61 12o4 12.6 358 3304 61 12.4 12.7 108 33.4 61 12.4 12.7 106 33.3 61 12o3 12'7 132 3303 61 12.3 12.8 70 33.3 61 12.3 12.7 83 33.2 61 12.4 12.7 65 33.1 61 12.5 12.8 5~ 33.1 61 12-8 12'8 76 3300 61 12°4 1303, 9:4 33.1 61 12.6 12.9 75 33.1 61 12.1 13.1 65 33.1 60 12ol 12*6 66 33.1 60 12.0 183 33ol 60 12o2 12.6 94 33.1 60 12.2 12'7 112 33.1 61 12o2 12.8 95 33.1 61 12.2 12'8 98 33ol 61 12.2 12.8 110 33.0 61 12.3 12.8' 84 33.0 61 12.3 12.9 73 3300 61 12.3 12-7 6309067 500 99 33.1 61 12.3 12.9 A * MARATHON OIL COMPANY TBU M-3 PAGE 46-FILE 1 DEPTH DIP OZP DEV DEV DIAM DIAM q 8 AZH AZM 1-3 2-~ * 6311.67 7.8 144 33.1 6313.67~15.9 80 33.0 6315o67 11.2 78 33.0 6317.67 9.5 118 32.9 6319.67 6.3 101 32.9 6321.67 4.9 126 32.8 6323.67 5.6 126 32.8 6325.67 5.3 79 32o7 6327.67 3.6 26 32.? 6329.67 4.7 26'32.6 61 12.3 12 ,.7 61 12.3 12.7 61 12.3 12.7 61 12.2 12.5 61 12.3 12 o5 61 12.2 12.4 61 12.1 12.5 61 12.0 13.7 60 12.2 14.T 60 12.1 15.7 6331.67 23.2 301 32.6 60 12.3 15.6 6333.67 5.8 107 32.7 60 12.3 14.4 6335.6~ 7.3 73 32'7 60 12.2 13.4 633'7'~' 7.5 109 32'7 6339.67:7-0 84 32.7 63~4{,.67~'10o2 76 3'2.7 63~.:67' 12-8 103 32.7 63~,6.7 5.9 103 32.6 634~67 4.9 152 32.6 63~.:67 6.,8 161 32.6 63~*.67' 6.0 101 32.6 6353°67 5.0 97 32.6 6355.67. 5.9 61 32.6 6357.67:~ 1.8 78 32.6 6359.6.7 1.3 350 32.7 6361.67 5.4 92 32.7 6363.67 5.5 1~4 32.7 6365°67 2.6 195 32.6 6367.67 18.8 20 32.6 6369.67 16.8 3 32.5 6371.67 19.0 70 32.5 6373.67 2.8 133 32.5 6375.67 3.5 111 32.5 6377.67 6.7 52 32.5 6379.67 9.3 18 32.5 6381.67 24.9 326 32.5 6383.67 10-8 42 32.5 6385.67 26.T 120 32.5 6387°67 11'9 312 32.5 60 12.Z 12.5 60 11.9 12.5 60 12'2 12'6 60 11.8 12.5 60 12.2 12.6 60 12.0 12-5 60 12.1 61 11.9 12.5 61 12~0 12-6 61 12.1 12.6 60 12.1 12.6 60 12'2 12,7 60' 12.2 12.6 60 12.3 12 60 12.2 12.8 61 12o2 12.7 60 12.3 13.1 60 12o0 12.6 60 12.3 12.9 60 12.1 12.5 60 12.2 12.5 60 12.2. 12.¢ 60 12.°2 12-4 60 12.2 12.3 60 12.I 12.4 60 12.0 12.2 A C A B B A B A A A O C A A A C A A A A A A A A A B B A A A C A A A C O O C B , 6.389-67:I~ 7-2 297 3,?..5 60 12-0 12.3 A · . HARATHON OZL COHPANY TBU #-3 PAGE 4?'FZLE 1 DEPTH DZP DIP DEV DEV DZAH OIAN Q " t AZ# AZ# 1-3 2-~ t 6391o6T:''~ 506 51 3205 6393'~6T 11.5 85 3205 6~.~ 1107 46 32.4 6~T.6T 10o4 60 3204 63'99067 13.4 84 32.4 6~01.67 15.5 105 32.5 6~03o67 13.9 262 3205 6~05067 ~.5 29 32.5 6~07,~T ~.9 28 32.5 6~09.'67 10.8 80 32o~ 6611.67 15o8 96 6613.67 607 35 661S. 67 6.& 32 6~lT-6T 7.5 122 6~19.67 5.1 33 6621.67 &09 25 6~23.67 13o3 3~2 6625.67 &.~ 31~ 6~27.&7 1008 ~ 72 320~ 6~29~ 6T 1~.2 ~7 6~']:i~i67 26 o 9 187 32 6~'~'~&7 27.7 170 6~3~ &T 18.6 116 663T.67 12o6 106 6~39.&T 15.0 132 32.~ 6&&1o67 8.6 100 6~¢3o67 13.2 103 32o~ 6~&5.67 2.0 223 320~ 6&&?.'67 503 69 6&a9.67 7.8 106 6~51o67 17o3 113 32°5 6653o67 1~.5 117 32.5 6655o67 5:08 ZS 32o5 6657o67 509 26 3205 '665906T 11ol 79 32.5 6661o67 13.1 10'9 3205 6~63.6T 9.0 81 32o5 6665o67 .... 8-3 100 3205 6~67.67 10o3 130 32.5 6~69.6T 606 ~7 3205 60 11.9 12.2 60 11.9 12.2. 60 12.0 12.3 60 12o0 12.3 60 12o0 1203 6O 12ol 12o3 60 12.0 12.3 60 12o0 12o3 60 12.1 12 60 12.1 12 60 12.1 12.5. 60 12.0 12.~ 60 12.0 60 11-9 12.2 60 12ol 12o3 60 12'0 12.2" 60 12.2 12.&. 60 12.1 12.~ 60 12.1 12.5 60 12.2 12.6 60 12ol 12o5 60 12.1 12.5 60 12.1 12.a 60 12ol 12o~ 60 12.1 12-5 60 12.1 60 12ol 12,4 60 12.1 1205.. 60 12o0 60 12ol 60 11.9 12°5 60 12o0 60 12°0 12°5 60 12.1 12.6' *60 12ol 12°6 60 1201 12o7 60 12°0 12°7 60 11o9 12o6 60 11°9 12.7 60 11'9 12.5 A C A A A D A A B B D D D D C C C B A C C C C A MARATHON OIL COMPANY TBU M-3 PAGE DEPTH ' DIP DIP DEV DEV DIAH DIA~ AZM AZH 1-3 · 6471.67 8.4 53 32.5 60 12.0 12.7 A & 6473067 14.6 89 3205 60 12.1 12.8 C · 6475.67 15.7 97 32.5 60 12.1 12o8 · 6477.67 11.0 101 32.5 60 12.2 13.0 B · 6479.67 2.6 102 32.5 60 12.1 12.9 · 6481.67 5.8 126 32.5 60 12.1 13.0 B · 6483.67 1.2 59 32.5 60 12.1 13.0 · 6&85.67 5.3 95 32.5 60 12.1 13.1 · 6~8T.67 S.O 128 32.5 60 12.1 13.1 A · 6489'.67 3-6 90 32.5 60 ~12.1 13.0 B · 6491067 5.5 95 32.6 60 12-1 13.0 C · 6493067 12.6 123 32.6 60 12.1 13.1 · 6~95067 3.3 170 32.6 60 12-2 13.2 · 649T~67 '7.2 59 32.6 60 12o0 13.S B · 6 ~99 ~:~T '":' 15.8 70 32.6 60 12 - & 14.0 B · 6501-67 13.3 71 32.5 60 12.1 14.2 C · 6~03::~,67 18.8 30 32.5 60 1Z.~ 14.2 D ~ 65~- 67 9.~ 29 32.5 60 12.3 14.4 D · 6~.67 15.~ 52 32.5 60 12.3 14.2 B · 65~;~67 15.8 50 32.6 60 12.3 14.5 A '~ 6511,6T 15.9 59 32.5 60 12.3 14.6 · 6513.67 15.8 59 32.5 60 12.3 14.6 A ~ 6515'67 13.0 71 32.5 60 12.4 14.6 A · 651T,6T': 3.7 116 32.5 60 12.3 14.4 0 · 6519.6T' 11.6 67 32.5 60 12.6 14.3 0 · 6521'67~: 8.6 54 32.5 60 12'4 14.0 C · 6523.67 9.0 42 32.5 60 12.6 13.8 ~ 6525.67.13.2 71 32.5 60 12'5 13.6 C · 652T. 67:10.4 62 32.5 60 12-4 13.4 B · 6529.67 14'7 58 32.5 60 12-4 13.3 D ~ 6531.67 14,.0 51 3Z.6 60 12,3 13'2 C · 6533. 67 :,1~. Z 76 32.7 60 12.3 13.2,. ~ 6535.&T "I4.1 72 32.7 60 12.1 12.9 · 653T.6T ' 8.6 ~3 32.6 60 12.2 13.2 C · 65~9:.67; 5.5 293 32.6 60 1Z.O 12.8 · 6.S~I. 67 9.3 261 32.5 60 12.2 13.0, D , 6543.67 11.5 Z1 32.5 60 12.2 12.9. D · 65~5,.67~ 9.2 358 3Z.4 60 12.3 12.9 C · .6547-67 12.9 271 3Z.& 60 12.3 12,8 C ~ 6~'6'7,1~.9 326 32.& 60 12.4 13.1 C MARATHON OIL COMPANY TBU M-3 PAGE 49-FILE 1 DEPTH D/P DIP DEV DEV DIAN DIAM O · AZM AZM 1-3 2-4 · 6 SS/. 6T 65'~ g'6T 6SSSg*6T 65~g:6T 6~'59 ' 6 T 6563'67 6~ 65 656T.~6T 65 69g~6T 6571'67 6573,~67 6575-~6T 6577.67 6581.67 6583.67 6585.67 6587.67 658~.67 6591.67 6~3.67. 6595.6T 6597.67 6599.67 6601.67 6603*67 6605.67 6607.67 6609.67 66~1.67 6613.67 6615.67 . 661T. 67 6619.67 6621.67 6623.6T 6625.67 6627-67 13.2 330 32*3 60 12.3 706 24 3203 60 12.4 2.5 79 32.2 60 12.3 708 65 32.2 60 12.3 2.9 91 32.1 60 12.3 500 113 32ol 60 12-3 7.0 121 32.1 60 12.Z 10o0 127 32o0 60 12.3 9-8 131 32.0 60 12.3 15.4 109 31.9 60 12o3 11.1 30 31.9 60 12.3 13.0 19 31o9 60 12.6 9ol 239 31o9 60 12.2 6.~ 156 31.9 60 12.6 806 157 31.9 60 12.4 6.8 139 31o8 60 12o4 5.4 108 31.8 60 12.6 7.9 115 31o8 60 12.6 8.3 117 31o8 60 12o6 4.4 115 31.8 6'0 12.4 9.3 80 31.7 60 12.5 5.0 175 31.7 60 12.3 12.6 69 31.7 60 12.3 18:°4 75 31.8 60 12.3 13.2 92 31.8 60 12'2 5.9 133 31.8 60 12o3 6.7 137 31.8 60 12.2 4.7 140 31.8 60 12.2 4.4 144 31.8 60 12.2 4.9 13'5 31o7 610 12,1 1.5 96 31.6 60 12.2 1o3 174 31.6 60 12.0 2.8 Z02 31o6 6.0 12.0 1..6 298 31.6 60 11.9 3.0 326 31.5 60 12'1 0.6 85 31.5 60 12'1 4.3 122 31.5 60 12.3 ~.4 129 31.5 60 12.3 4.5 131 31.4 60 12.3 12o9 13.3 13.0 13o3 13ol 13.2 13o2 13o9 13o8 13o9 13.T 13.9 13o7 14o2 13~5 '13.3 12.6 12o6 12o6 12o4 12o& 12.~ 12.4 12'5 12.6 12o5 12,5 12o5 12~ 12.4 12o2 12.2 12,2. 12.3 12.5' 12'7. 12.T . 12'6 C C B C B ::41: A :41: A A :41: A C B A O ,,It C 8 A A A :41: A A A O C A A A A A A A A A A A A A A A · 6629.6T 5.1 139 31o4 60 12.3 12o6 HARATHON OZL COHPANY TBU N-3 PAGE 50-FZLE 1 DEPTH DIP DIP DEV DEV DIAN DIAN Q 4: AZM AZM 1-3 2-~ · 6631.67 11.0 6633.67 7 6635.67 5.5 6637.67 11.8 6639.67 '9.8 6641.67 11.4 66~3.67 S.O 66~S.67 10.6 66~7.67 -17o8 66~ 9.67 ' 6651o 67 · 6653.67: 8.-0 6655.67 6~' 67'~~ 6.3 6&~. 67 9.5 66~f~J. 67 5.0 6~.67~ 3.7 666~T. 67 5 o 0 6~9.67 10.7 6671.67 13.7 6673.67 21o6 6675.67 3.3 6677.67 2.0 6679.67 1.7 6681.67 2-8 6683.67. 3.7 6685.67- 2.6 6687.67 ~.3 6689.67 3.5 6691.67 1.8 6693.67 12'6 669'5.67 3.1 6697.67 10.2 6699.67 3.8 67~.67,, 7 6707-67, 6.7 80 31.& 53 31.~ 13 31.& 57 31.~ 78 31.3 91 31.3 135 31-3 210 31.3 219 31.3 61 31.3 125 31.3 81 31.3 90 31.3 127 31.3 99 '31.2 63 31.2 1~6 31.2 170 31.2 14~ 31. Z 102 31.1 106 31.1 271 31.0 1¢6 31.0 112 31.0 119 30.9 86 30.9 94 30.8 77 30.8 91 30.8 125 30.7 82' 30.7 4 30.6 10 30.6 155 30.6 123 30.5 120 30.5 112 30.5 79 30.5 · 103 30.¢ 60 12.1 60 12.4 60 12.3 60 12.5 60 12.5 60 12.5 60 12.~ 60 12.5 60 12.4 60 12.5 60 12.~ 60 12.3 60 12.3 60 12.2 60 12.3 60 12.3 60 12.3 60 12.3 6.0 12.3 60 12.4 60 12.~ 60 12.a 60 12.a 60 12.3 60 12.3 60 12.3 60 12.2 60 12.~ 60 12'3 60 12 .a 60 12.5 60 12'a 60 12.5 60 12.4 60 12.4 60 60, 12.3 60 12.3 60 12.2 12.6 13.2 13.0 13.6 12.9. 12.9 12.~ 12.5 12.~ 12.5 12.3 12 -5 12.2 12.5 12.3 12.2 12'~ 12.3 12.~ 12.4 12.5 12.4 12.5 12.~ 12.3 12.~ 12 .~ 12.5 12.5 12-5 12.5 12-5.. 12.5, 12.4 12'4' 12.4 12.3 12.3 A 4: A 4: A 4: B 4: A 4: A 4: B 4: C 4: C 4: C f B f A 4: A 4: A :lc A 4: A 4: A · A ~c A · A · A · A · A 4: A · A · A 4: MARATHON OIL COMPANY TBU M-3 PAGE 51-FILE 1 DEPTH DIP DIP DEV DEV DIAN 02AH Q 4: AZ# AZN 1-3 2-~ _ _ ~ 6711,67 709 108 30,3 60 12o2 12,7 I · ~6713.67 9,1 67 30,3 *'6715,67 10,4 8~ 6717~67 12.5 88 3003 '67191,67 0,8 141 30.3 6721'.67 1,8 110 30.3 67230 67 4o2 103 30.3 6725067 5,7 81 30,3 6727067 5°6 5~ 30.3 6729.67 600 51 3002 6731067 21,3 2~1 30,2 6733067 8,7 95 30,2 6735067* 8,2 71 30,2 6737067 11,2 0 30,2 6739,67 17,8 12 30,2 6741,67 9,0 ~ 67 30,2 67~3,67. 7,9 58 30,1 6745,67:* 4o4 121 30,1 6747,&~ .... 600 55 30-0 '67490~lg**tr;~: 5,1 85 30,0 6751.67 5.3 74 3000 6753,67. 6,6 55 2909 67S5,67' 908 68 2909 67~T~67 709 9~ 29,9 67'5~'67 807 10~ 2909 6761o~67 5,1 88 2909 6763067~ S07 100 2909 6765-67.10.6 5~ 2908 6767.,67 8°7 53 29,8 6769.67, 608 97 29,8 6771o67:10.6 89 29.8 6773,67~I3. ol 33 29.8 6775,67'~7'0 89 2908 6777,67~ 907 67 2908 6779067' 8.0 80 29,8 6781067 ~9,6 96 29.08 6783067~ 8,0 95 29,8 6785,67 6.6 110 29.8 6787,67 138 2908 6O 6O 60 60 6O 60 6O 60 60 6O 60 6O 60 &O 6O ~60 6O 6O 60 60 6O 6O 60 60 6O ~0 6O 60 60 6O 60 6O 6O 6O 60 60 6O 60 12,2 12,2 12ol 1Z.O 11.9 11o8 11,8 11o9 11,9 11.9 12,0 12o 0 '12o 0 12,0 12ol 12,1 12,3 12,3 120~ 12,3 12o3 1202 12.~ 12.3 12,5 12o5 12o5 12o4. 12.5 12.5 120 ~ 12o2 12o3 1201 12'o3 12ol 12.0 11,9 12,9 12o7 12o3 12ol 12o0 11,9 11o9 11o9 11-9 12,0 12o0 12,0 12o0 1200 12,1 12.2 12,2 12.2 12o3 12,3 12,4. 12o5 12,3 12.5 12.5 .. 12,5 12,5 12,5 12o6 12o7 12,7 1207 12-6 12,5 12o6 12~Z · 12~2 12ol A B A A 4: A 4: A A A A A 4: B C B A A B A A A A A A A A A C C A' C O O :lc A A A A A 6789.67 5 ' 114 2907 60 11,8 MARATHON OIL COMPANY TBU M-3 PAGE 52-FZLE DEPTH DIP DIP OEV OEV OIAM OIAM Q AZM AZM 1-3 2-4 6791.67 5.7 118 6793.67 5.0 130 6795.67 11.1 92 6797.67 10o2 85 6799.67 11o6 24 6801067 8.1 22 6803.67 6.3 73 6805.67 11.1 82 6807067 5.7 85 6809.67 6.2 84 6811.67 14,.6 110 6813o67, 6.5 103 6815'&T' 3.2 242 6817.~&T ~ 5202 199 69~9-'&7:,':4~8°'0 201 6821.,67 3 5- 8 342 6~3*::67 7.7 205 6112'5o67 9.2 174 68~T. 67 1.3 144 68::~°67 309 336 6831.67 11.8 350 68~3.67 3003 Z40 6835.67 29.4 240 6837.67 9.6 80 6839.67 13o5 86 6841.67. 308 59 6843067 8.8 359 6845.67 6.7 98 6847067 14o2 9'9 6,849.67 9.09 116 685,1.61' 5.3 92 6853o 67 ':7.6 71 68'55o 67~ ...... 305 150 6 857.&7 ~ 306 15'3 6859067 15o0 177 6,861.&T'117.7 '178 6863' 67~ 190 Z 99 6865*67: 12ol 95 6867~67 4.7 98 29.7 60 11.8 29.7 60 11o8 29.7 60 12.0 2907 60 12o0 29.7 60 12.1 29.7 60 12ol 29.7 60 12.2 29.6 60 12ol 2906 60 1Z.2 2906 6O 12.1 2906 6O 12o0 2905 60 12.0 29.5 60 11.9 2905 60 12.0 29-,4 60 12-0 29.4, 60 12o0 29,,3 60 12.0 29.3 60 11o9 29.3 60 11,,9 29.3 60 12.1 29'3 60 12.0 2903 60 12.0 29.3 60 12.0 2903 60 11.8 2902 60 11.9 290 2 60 11o9 29.2 '60 11o9 29.1 60 11o9 29ol 60 11.9 29ol 60 11.9 29.1 60 11.9 29.1 60 11°9 29.1 60 11.9 29.1 60 11.9 29-1 60 11.9 29ol 60 11o9 29.0 60 11o9 29.0 60 11o9 29,,0 60 11o9 12.0 11.9 12.2 12 .Z 12.5 12.5 12.5 12.2 12,2 12.1 12.0 12.1 12.0 12'1 12o0 12.1 12.0, 12.0 12.0 12.1 12.1 12.1 12ol 12o0 11' 9 11:o9 11-9 11.9 11.9 12.0 11o9 11.9 11'9 11.9 11~9~ 11.9 ' 11 -9 11.9 11 -9 A · A · A f A ~c A f A ~c A · A · A t~ A ~c A · B f A * B * * C f B ~c B f A * A ~r A ~c A f A · A f 8 · B ~c B f B ~c C · B * A · A ~r A ~c B f A ~c ~c A f B ~ 6869,-67. 8.5 60 29.0 60 12.0 12-0 A * MARATHON OIL COMPANY TBU N-3 PAGE 53-FZLE 1 DEPTH 'DIP DZP DEV DEV DIAM DIA~ Q t AZM AZM 1-3 2-4 4: 6871.'67 8.4 6873.67 13.5 6875.~&T 5.3 6877~67' 2. Z 6879.67 2.6 688:1.67 Z. 8 6883'67 2.1 : 6885.67 8.7 6887o67 2.0 6889.67 10.6 6891.67 13.8 6893.67 4.3 6895.67 10.5 6897.67 13.7 6899.67 3.8' 6901.67 7-3 6903.*67' 10.7 6905.67,24-1 6907.67 *~. '13.3 6909'617., 12.0 6911.&T" 14.4. 6913.67 ~ 11 o 9 6915~:'67 ' 6- 3 6917767 ' 10. 0 6919~'6'7: 8.6 6921o67 7.9 6923.67 15.3 6925.67 ' 12.4. 6927.67 7.8 6929.67 9.8 6931.67 7ol 6933.67 7.3 6935.67 5.6 · 6937.67 5.1 6939.67 7.6 6961.67 6,,9 6963.67 7.4* 6965,,, 67 7.6 6967.67 6.5 71 29.0 153 28.9 162 28.9 51 28.9 69 ZS. 9 119 2~. 8 130 28.8 14,0 28.8 240 28.8 68 28.8 78 28.7 82 28.7 14 28.7 S 28.7 14.2 28.7 126 28.7 116 28.7 236 28.7 185 28.7 239 Z807 69 28.6 84* Z8.6 86 2806 80 28.6 83 28.6 75 28.5 3 28.5 69 28.5 93 28.5 88 2805 81 28.5 5 28.4 171 28.6 211 28.4 188 28.4 161 302 28.3 306 Z8.3 260 28.3 60 12.0 12.1 60 12.0 12.0 60 1Z.1 12.3 60 12.1 12.2 60 1Z.1 12.3 60 12.3 12.4 60 12.2 12.4 60 12.3 12.4 &O 12.3 12.5 60, 12.2 12.4 60 12.3 12o3 60 12.3 12.5 60 12.6 1Z.4. 60 12.4. 12.6 60 12.3 12 06 60 12.3 12.5 60 12.1 12.2 60 12.2 12.3 60 12.2 12.1 60 12o2 12.3 60 12.3 12.2 60 12.3. 12.1 60 12.3 12.3 60 12.2 12.3 *60 12.4 13.3 60 12.T 13.5 60 12.3 13.7 60 12.8 13.4 60 12.2 12.8 60 12.2 12.4 60 12.3 12.4 60 12.4 12.5 60 12.3 12.5 60 12.4. 12.5 60 12-6 12.6 60 12.4 12.4 60 12.6 12o6 60 12.1 12.0 60 1Z.3 12.3 A B A A C C C C · C · A · A 4: B · C · B 4: 0 4: O 4: C 4: C * B 4: A · A · A 4: B 4: O 4: A · B * B * A :Ir C * A · A 4: B * B * B 4: 6969.67 8°2 323 28.3 60 11.9 11.7 NARATHON OIL COMPANY 'TBU M-3 PAGE 54-FILE 1 DEPTH DIP DIP DEV DEV DIAN DIAN Q f AZN AZ~ 1-3 2-~ ~ 6951.67 8.1 6953.67 6.9 6 955.67 8.1 6957.67 7.8 6959.67 6.5 6961.67 1.8 6963.67 4.0 6965.67 12.1 6967.67 10.~ 6969.67 6.5 6971.67 18-.2 6973.67 I9-S 6975o:~7 39.~6 ' 69T'9~T 9.5 6981~ 67 8.6 6~S. 67 1~.6 69~' 67 16.7 69~.67 11.1 699~3.67 2.9 69'9S. 67 9.7 6997.67. 8.3 6999.67 6.8 7001.67 15.Z 7003.67 7.2 7005.67 7007.67 7009.67 8.6 7011.67 7013.67' '5.6 7015.67 .~ 6.3 7017.67~'~' 7.2 70'19.67 ~ 7021.67 8.8 7023.67, 9.9 7025.67 13.0 7027.67 8.0 7029'67 344 136 148 13,~ 120 85 102 76 73 7 79 78 241 116 111 158 122 85 51 258 253 256 151 181 122 100 94 87 93 238 106 83 73 8~ 91 9 357 79 75 28.3 28.3 28.2 28.2 28.2 ZS.Z 28.2 28.1 28.1 28.1 28.1 28.1 28 28' 0 28'.0 28.0 :28' 0 27.9 27.9 27.9 27.9 27.8 27.7 27.7 27.7 27.7 27,8 27.8 27.7 27.7 27.7 27.7 27.7 27.7 27.6 27,,6 27.7 27.7 27.7 27.6 60 12.0 60 11.9 60 11.9 60 11.8 60 12.0 60 11.8 60 11.9 60 11.8 60 11.8 60 11.7 60 11.7 60 11.6 60 11,6 60 11.6 60 11.6 60 11.7 6.0 11.7 60 11.7 60 11.7 60 11.6 60 11.8 60 12.1 60 12 "2 60 12.5 60 13.0 60 12.3 60 12.8 60 12.1 60 12.3 60 12.2 60 12.2 60 12.2 60 12.2 60 12.Z 60 12.2 60 12.2 60 12.1 60 12.2 61 12.1 60 12.Z 11.9 11.8 11.8 11.7 11.9 11.8 11.9 11.9 11.9 11'8 11.8 11.7 11.7 11.7 11,8 11.9 11.8 11.9 11.9 12.1 12'7 12.9 13'9 13.6 1~.9 13.3 13.9 12.5 12.¢ 12.2 12,~ 12.1 12.3 12.3 12.3 12.~ 12.6 12.6 12.9 12.9 A t C · A ~r A 4r A 4r A · A ~c A f A ~ C ~: A · A ~c C · A * A f C f C * A f O · A · B 4~ B · C q[ C f D · C · A ~c A f A · B · A 4~* A f A ~c A 4c A · 8 ~ B qc C · A · PIARATHON O]:L CONPANY TBU 1"1-3 PAGE 55-FZLE 1 DEPTH DZP DTP DEV DEV O]:AH OIAH Q t AZ# AZlq 1-3 2-~ , 7031.67 ';10.5 73 *' ? 033'J~&T 12.3 T 035*&:~t~T 11.7 38 703?,g:~T 8.9 65 7039~67 12.0 69 70~'I ~ 67 5.1 59 70~3' 6~* 11.8 56 7 0~5.67 11.0 50 7~%9.67 33.2 31~ 7051.67 1~.7 7053.67 10.3 113 7055.&7.11.& 94 7057.67 5.2 144 70,59.6'T ~ 6.9 102 7061.67 5.9 88 T063.&7 7.3 125 7065.67; 10.5 103 7~69..6 7, ~ 5.5 115 7071.67 6.0 118 ?~ 3.67 7.3 ? 1 70?5.67 9.6 87 7077.67 12.6 122 7079.67 11.6 11~ 7081.67 3.0 77 27.6 60 12.0 12.8 27.5 60 12.4. 12.9 27.5 60 12.2 12 27.5 60 12.3 12.9 27.5 60 12.5 12.8 27.4., 60 11.9 14.o7 27.3 61 12.7 27.3 60 12.5 17.2 27.2 60 13.0 16o7 27.2 60 12.5 16-7 27.2 60 12o4 16.3 27.3 60 12-2 14..0 2704. 60 12.1 13.5 2704. 60 12'2 12.3 '27.4. 60 12.0 12.1 27.4. 60 11.8 1108 27.4. 60 11o7 11.8 27.4, 60 11.7 11 08 2704 60 11.8 11°8 Z7.4 60 11.8 11.8 27.4 60 11-8 11'8 27.4. 60 11.o7 11°7 2704. 60 11.7 11.8 27.5 60 11.7 11-7 27.4, 6,0 11.6 11.8 A A A B B A A C B C A A A A B B A A A A 27.3 60 11.7 11.7, C , 7083.67 7.6 238 27.3 60 11.7 11.7 C , MARATHON OIL COMPANY TBU M-3 SUMMARY t DEPTH · DIP DIP t DEV DEV DIAN DIAN ~ ~ AZH · AZM 1-3 2-~ · TOP ~ 2711.6T 18.0 63° 32o~ 20T. 14.3 15.0 · BOTTOM · 7083°67 7°6 238. 27.3 60° 11o? 11o7 PRESENTATXON 210 240 2711- ZSO0* 2 2800- 2900 4 2900- 3000 3000- 3100 4 3100- 3200 8 3200- 3300"' 1 3300- 3400 Z 3400- 35OO 3500- 3600 1 3600- 3700 4 3700- 3800 1 3800- 3900 1 '3900- 4000 4000- 4100 3 4100- 4200 1 4200- 4300 2 4300- 4400 4400- 4500 4500- 4600 4600- 4700 I DIP FREQUENCY BY AZXRUTH 0-10 DEGREE DIPS 4 3 4 300 330 N 30 60 2 I I 9 4 6 6 4 I 4 9 4 3 I 2 3 T 2 I 5 3 4 I 4 1 2 1 2 1 1 1 1 2 Z 4 3 2 5 2 2 1 4 4 6 4 2 I 2 4 7 5 9 6 9 4 5 I 3 3 5 2 8 8 19 I 6 6 6 5 9 10 9 14 18 10 16 5 8 120 150 4 3 2 5 4 1 5 3 5 4 7 4 5 4 6 4 2 6 1 9 I 2 2 6 2 5 5 3 1 5 6 3 2 7 5 5 6 4 6, 4 Z 2 8 Z 4 5' 1 210 4 4 2 13 6 2 10 2 1 2 5 2 1 1 MARATHON OIL COHPANY PRESENTATION 210 240 N 4700- 4800 4800- 4900 4900- 5000- 5000- 5100 5100- 5200 5200- 5300 5300- 5400' 5400- 5500 5500- 5600 5600- 5700 5700- 5800 5800- 5900 5900- 6000 6000- 6100 6100- 6200' 6200- 6300 6300- 64400 64400- 6500 6500- 6600 660.0- 6700 :6700- 6800' 6900 6900'- 7000 7000- 7083 . I 1 1 2 2 300 330 2 1 1 2 1 2 5 3 3 1 3 3 2 I 1 1 1 1 1 1 1 TBU lq-3 N 30 1 6 3 1 5 1 1 11 1 2 44 1 1 8 7 3 44 I 1 8 2 6 9 3 44 2 1 3 3 1 3 10 44 2 44 2 1 8 2 1 1 1 I 1 2 1 3 2 5 7 1 2 3 2 1 6 2 1 3 I 2 1 1 1 1 6O 8 2 11 7 2 12~ 7 10 11 16 24. 11 9 10 7 3 3 9 12 8 6 11 120 150 S ZlO 3 4 1 3 3 44 44 3 1 1 6 4 2 2 10 1 2 1 8 4 2 1 8 5 5 2 5 1 8 44 1 5 1 8 2 12 4. 4, 1 15 44 1 2 13 3 3 3 12 5 Z 1 6 3 7 3 3 6 17 Z 1 IS 6 5 3 1 4 6 44 Z 8 2 DiP FREQUENCY BY AZIRUTH 10-90 DEGREE DIPS PRESENTATION 210 24,0 2711- 2800 Z800- 2900 I 2 2900- 3000 3 3000- 3100 3100- 3200 1 3200*- 3300 1 3300- 34,00 2 1 34,00- 3500 1 3500- 3600 1 3600- 3700 4- 1 3700- 3800' 3800- 3900 3900- 4,000 4000- 4,100 1 4100- 4,200 1 4,200- 4,300 4,300- 4400 1 4400- 4500 4500- 4600 2 4600- 4700' I 300 330 N 30 60 3 3 4 I 5 I I 2 3 1 1 I I 120 150 1 1 2 1 3 4, 1 2 I 16 3 4, 4, 2 2 4, 4, 4, 5 2 5 I 3 5 I 1 6 8 2 5 11 I 2 1 3 T 1 I I Z I 3 8 3 9 2 1 2 6 3 5 10 210 1 3 5 6 1 2 3 #ARATHON O~L CORPAN¥ PRESENTATION 210 240 4700- 4800 4800- 4900 5 4900- 5000 5000- 5100 5100- 5200' 5200- 5300. 5300- 5400. 5400- 5500 5500- 5600 1 5600- 5700 1 5700- 5800 5800- 5'900 5900- 6000 6000- 6100 6100- 6200 6200- 6300 6300- 6400 6400'- 6500 6500- 6600 6:600- 6700 1 6700- 6800 6800- 6900 2 6900- 7000 2 7000- 7083 TBU 1'!-3 300 330 N 30 60 E 2 2 I 3 10 I 4 3 1 I I 4 4 1 I I I 3 3 2 2 1 2 2 4 4 1 15 5 2 2 5 I I 3 2 2 I 1 3 I 2 7 2 2 I 2 4 3 I I 2 2 6 1 Z 2 I 2 1 3 6 4 I 4 5 3 5 5 1 3 2 3 6 2 I I 5 10 3 2 4 6 9 2 1 I I I 3 3 2 4 3 2 2 4 4 I 9 2 I 1 5 2 5 I 120 150 2 210 I 1 Z 7 I I I I PRESENTATZON 30 2711- Z800 1 2800- 2900 6 2900- 3000 4. 3000- 3100 3 3100- 3200 5 3200- 3300* 4. 3300- 34.00 5 34.00- 3500 6 3500- 3600 4. 3600- 3700 1 3700- 380,0* 3 3800- 3900 2 3900- 4.000* 8 4.000- 4100 1 4.100- 4.200. 6 4.200- 4.300' 5 4.300- 4.400' 10 4.400- 4.500 14 4.500- 4.600 10 4600- 4.700 5 6O DIP FREQUENCY BY AZIMUTH 0-10 DEGREE DIPS E 120 150 S 9 4. 3 2 4. 5 4. 1 3 5 3 7 5 4 7 3 4 5 7 6 4. 2 9 6 1 9 9 I 2 5 Z 6 2 3 5 5 5 3 1 8 5 6 19 3 2 6 7 5 5 6 6 9 6 4 2 9 2 18 8 2 16 8 4 5 I 210 24.0 M 300 330 N 4 2 4. I 2 1 4 4. 3 1 2 4 I 1 13 4. 2 1 6 8 5 I 2 1 2 1 2 4. 1 I 1 1 1 2 1 10 4. I 2 2 I I I I 1 I I I 2 2 5 3 1 2 I 3 Z 5 Z 1 1 1 4. 5 1 I 3O RARATHON O~L CONPAN¥ TBU PRESENTATION 30 60 E 120 150 S 210 ~0 4700- 4800 3 8 3 4 1 4800- 4900 5 2 3 3 4 4 9 ¢900- 5000 11 11 4 3 I I 1 5000- 5100 4 7 6 4 2 2 I 1 5100- 5200' 8 4 10 I 1 5200- 5300 4 2 2 I 1 5300- 5400 8 4 8 4 2 I 2 5400- 5500 9 12 8 I Z 5500- 5600 2 7 5 1 5600- 5700' 3 10 5 2 5 I 2 Z 5700- 5800 10 11 8 4 I 2 2 5800- 5:900. 4 16 5 1 5900- 6000 8 24 8 2 6000- 6100 2 11 12 4 4 1 6100- 6ZOO I 9 15 4 I 2 6200.- 6300 2 10 13 3 3 3 2 6300- 6400 2 7 12 5 2 1 6400- 65:00 7 3 6 3 I 1 6500:- 66.00 3 3 7 3 3 I 1 6600- 6700 I 9 6 17 2 1 6700- 6800 6 12 15 6800- 6900 3 8 6 5 3 I 1 6900- TO00 I 6 4 6 4 2 1 7000- 7083 I 11 8 2 Z 300 330 N 2 I 6 I 1 I 1 I 2 I 2 I 2 I 1 5 7 3 3 I 1 3 2 6 I 3 3 4 I 3 I 3 3 2 4 2 2 I 1 1 1 1 1 1 1 1 1 3 I 5 1 1 ,2 1 1 2 Z 1 I Z 1 1 3O PRESENTATION 30 2711- 2800 ?.800- 2900 2900- 3000 3000- 3100 3100- 3200 3200- 3300 3300- 3400 3400- 3500 3500- 3600 3600- 3700 3700- 3800 3800- 3900 3900- 4000 6000- 4100. 4100- 4200 6200- ¢300' 4300- 4400 4400- 4500 4500- 4.600 4600- 4700- 6 6 5 4 6 4 9 10 6 1 7 9 T 5 19 16 16 5 6O DIP FREQUENCY BY AZINUTH · 0-90 DEGREE OIPS · E 120 150 S 14 5 4 2 4 7 5 2 3 3 9 3 7 5 4 7 4 4 5 4 9 7 20 5 13 8 3 13 13 6 2 10 3 9 7 4 6 5 13 5 1 19 9 6 21 3 3 13 8 5 5 7 6 4 2 10 9 12 5 11 2 1 20 8 2 19 9 18 8 5 I 210 240 4 2 4 5 5 2 7 14 4 6 9 5 3 I 1 4 5 4 1 5 I 2 16 8 2 3 I 1 I I 1 2 7 6 1' 5 2 3 I 6 I I : I 1 Z 6 1 300 330 2 2 2 2 4 5 3 2 1 6 12 2 1 I 6 1 I 2 6 2 6 I 2 2 8 3 3 2 1 4 6 3 2 2 30 NARATHON OIL PRESENTATION 4700- 4800 6800- 6900- 5000- 5100- 5200- 5300- 5600- 5500- 5600- 5700- 5800- 5900- 6000- 6100- 6200'- 6300- 6400- 6500- 6600- 6700- 6800- 6900- 7000- 6900 5000 5100 5200 5300 5600 5500 5600 5700 5800 5900 6000. 6100 6200 6300 6400 6500 66,00' 6700 6800 6900 7000 7083 30 60 4~ 11 9 5 15 15 5 10 10 8 6 2 11 9 13 6 5 11 13 10 17 8 25 2 11 2 13 Z 15 5 13 8 8 9 12 2 10 8 16 3 1Z I 15 6 13 C011PANY TBU 11-3 E 120 150 S 210 24.0 13 6 1 1 6 3 5 4 14 3 4. 6 6 1 1 9 6 3 2 I 5 16 2 2 I 1 2 I 1 10 5 3 3 2 8 2 I I 2 7 T I I 1 8 2 6 I 3 6 8 6 I 2 4 7 3 10 3 18 8 6 2 20 7 2 3 18 6 3 3 2 1 16 5 2 1 16 6 2 I I 1 9 4 3 I 1 9 17 3 2 1 18 4 1 10 5 6 3 3 1 6 6 6 3 3 5 13 3 2 I 300 1 2 2 1 1 330 2 1 1 3 20 8 3 6 2 1 2 Z 12 2 1 2 2 3 1 1 1 1 1 4 3 1 1 2 8 1 2 2 3 5 2 7 4 3 1 3O HARATHON OIL COHPANY TBU H-3 SUHMARY DEPTH t D~P D~P f DEV DEV D~A# D~AM ~ QUAL t ~ AZM · AZM 1-3 2-4 ~ ~ TOP · 2711.67 18.0 63. 32.4 ZO7. 14.3 15.0 D · BOTTOM f 7083.67 7.6 2380 27.3 60. 11o7 11o7 C · ALASKA COMPUTING CENTER OMPAN¥ NA~g : .ARA?HO. OZL FIEbDA g ~'TRADI~G BAY BOROUGH ; KENA! REFERENCE: NO 7407 COMPANY HICR OFI LHED Tape Verification bJ, st~nq chlumeerqer Alaska Computlnq Center 25-SEP-1990 08=48 SERVICE NAME I EDIT DATE : 90/09/25 ORIGIN ~ FLIC REEL:NAME I 74078 C~NTINUATION # : PREVIOUS REEL l COMMENT I MARATHON, TRADING BAY~ TBU M-3, AP! #50-733-2041~ t,~, TAPE HEADER SERVICE NAME ! EDIT DATE I 90/09/25- ORIGIN I TAPE'NANZ 1.740 8 CONTINUATION # I P~EVIOUS TAPE COMMENT I MARATHON, TRADING BAY~ TBU ***~ FILE.HEADER. ~*~* FILE. NAME I ~DIT .,001 S~RVICE I rblC VgRSION ~.00~1A06 D~TE ~'90/09/25 NIX REC...8~ZE' ~ 1024 ~F[LE TYPE ~ LO 'LAST FiLE I PAGEI SCHLUmBERGeR ~ELb sERVIcEs ******************************************************************************** ******************************************************************************** FIELD: BOROU ! E l NUMBER LOCATIONI . SECTIONt cOMPANY NAMEt MARATHON OIL COMPANY' ?BUNo3' ?RADING BAY KENA! A~ASKA ELEVATIONI~.O .. RANG~I IS TaPe verX~tcat~on Listing chlumberqer Alaska Computlnq center 25-$EP.1990 08~48 LOG MEASURED FROH KELLi60 ELEVATIONS KBI 160 DATE LOGGEDi 25-JULY-90 RUN ~ DRIbLIERI 14 bOGGlER! 709 CASING ABOVE PER#ANENT DATUM DEl 13 3/8" La DRIbblER DEPTH Or 2713- AND LOGGER DEPTH: OF 2710 TYPE FLUID IN HO~E~ pO~¥ PLUS G · DENSITY. 9.55 VISCOSITY: 46 FLUID.LOSS1 6.5 #UO RE$ISTIVIT~ 4,~9 84 sxs xvx Y= T~#E:cXRCULATXON ENDEDi : .Or2 35 25-dUL 26~JU~ MAXIMUM TEMP RECORDgDt LOGGING, DISTRICT LOGGiNG.ENGINEER: SM'TH WITNESSI BO4DEKER/UNDERNOOD TOOL NUMBERS't DIS 139 aDC 84 ~bS.26. SGTL.577 TCM:ll6 WDM 491 DiC, 86 SbA: 44 TCc,,A .~2 AM~:~ 957 DATE JOB,=STARZ'ED= 22-$EP"90 OOBi. RE:PERE:NCE~. NO: 74078 bDP/ANA! KOHRXNG PAGEt '*- FI'LE'-"EDIT'*O0! "~ *' MARATHON OIL, cOMpANY TRADING. BAY ChlUm erger Alasl<a Comput ~ Center 25-SEP-!990 08~48 TBU 50-733'2041! MAIN PASS LOG DATA DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED TOOL EXTENSION TOOL TYPE USED NANE D!T"E .DTE .PTE.,iTP,,REC bDT .,bDT CNT-A/D/H ,CNL PHA$OR DUA~ I_NDUCTION AKCC STC~ PR_OCE$SING ARRAY SONIC LITHO DENSITY COMPENSATED NEUTRON ?080~ TO 2709' 7092f TO 4900' 7092f TO 2709' · ?Oe2~ TO 2709' 7082' TO 2?09' PAGE= 3 TABLE TYPE = CONS TUNI VALU DEFI TYPE CN MARATHON OIL COMPANY FN TRADING BAY WN TBU M COUN KENAI TAT ALASKA AT! USA BOEDEKER/UNDERWOOD S N 5?2526 PDAT MSb E~D "FT o b~.r K~bbg BUSHING 160.i EKBAPO !~ 160.I :Dr ' -999~25 ~GL FT. -999,.25 TDD' FT. TDL FT BLI PT ?~4.; DFPH DFV S' 46'.' Company Name rteid Name~ We~.l: Name AP,T 'Serial:'. Number ~j;eld' bocatZOn aectton ToenSh:tp OU .fY .... Sta~e, or Province Nat~on : Witness.' Name:- serv'~ce': Order Number' Permanent datum E~evat~on o~, Perm, Da bog ~eamured: From ABOVE.. PERMANENT DATUM E'l~eva~on ct' Ke~y Bu ~levat~on o~ DerricK. Tots Depth-.Driller Tots bePt'bz- bogg~r Bott m. b~gtlnterva~ ToP' cg xn erva~: .~ r ng"F u d Type ~,' I ...nq F. U' d. ZONE cl~lumberger Alaska Compute, rig CanCer TUN! VALU DEFI TYP~'. aMS OHMM 4.29 ResiStivity ot MUd Se DEGF 84.. Mud.:. ample Temperatur RMFS OHMM 5.24 ReS~stlv~ty ot mud.ti. MFST DEGF 76. Mud,.Ftltrate Sample T RMC8 OHMM 3.06 ae$1st~vit¥ o~ M~d Ca- MCaT OEGF 750. . Nud.CaKe, Somp~e Tempe. TcS 20t35 25-J~L Ttme~Ctrculet~on ~top TLAB 03ZOO 26-~UL -Ttme~Logger~At. SottOn BHT .... DEGF .... ~320~ . .~8ottomHole:Tempera~u TABLE TYPE i'ZONE De: t~..:Channe! Name,. .-. Me lum,lnduc~lon Standard~Processed:~e~s~Av~ De~:p.' Induction $~endard ProcesSed $~,nteneoum~:Potent~al i~I;UCTION:DEEP PHASOR.,RESlSTIVI~Y. XNIUCTXON MEDIUM PHASOR, RESi~'TZVXTY 'In,,uCtLOn CalLbreted F~e~uen,: _.., M~F MED. ~NDU,T.ON.~ A :i.T',, F,) XNtUCTION MEDIUM PHA ORCOND!I rXV~TY @eep:'Zn~uc~$on ~eel nteFmedL ~e~:~onduettv$~¥ Me.d~m~Ind~C~on ~ea In~eFmi Le~e Gamm~,:Ray ' Tension. Mud Tempero~re, ead ?ens on DEL~A"T DEL~A.T'LONG. SPACING· DELTAmT LONG SPACING NEAR DTLF,, TRANSIT TINE ! TRANSIT, TIME T~ANSIT',TINE TRANSIT TINE 4 Tape Ver~fication L~S.t~nc~' ~hlumberqer AlasRa Compvtxnq Center 25-$Ee-:t 990 08 = 48 DEr! LTT2 LONG SPACING TRANS/T TINE MODE LTT LONG SPA¢! TRANSIT TINE NODE 4 sP Spontaneous PotenCta! GR. ~amm~ Ray TENS Tension HTEN Head Tensxon DT DELTA"T DT DELTA"T DTSN DTSM DTSN DTSM RSHC RATIO SHEAR TO COMPRESSIONAL' DELTA T QFCO QUALXTY FLAG COMPRESSXONAL: : QFSH QUALITY FLAG SHEAR DPH! DenSity Porosity RHOB Bulk~Density DRHO Delta RHO , . PEF -Photoe~ectrtcFactor: .... : ~. _ QLS Qua~ty'controX. o~' Xong s~ac~g QSS Oua'X~¥ cgntr~l~ on:shoFt~lpacxng ~oF..~DT LS ~ong ~paCxng.comPu~ed;~ount Rate L~ LiTH Lltholog ~tndow.Count;Rate:. . Short S~aclng.l.~tn~o~ ~ount:aa~e S g' "~Y ed L iRS L~n~ ~pae~ne'RnOB ~ncorrec~ LiaRS ~o~g~upper RHOB · Gll Gamma, RaY TENS Tension MTEM Mud Temperature: ~RES MUD:ReSistivity NPg! NeUtro~ ~oros~t¥_ ,. - TNP~ Therma~.~eutr'o:n ~oros~c¥ ":o TNRA cel~brated Therma~ Neutron Rat~ .. NPOR Neutron ~oros~t¥ output From an APpZZcat~on Pro,ram RCNT ReNT ReFT RCFT CNTC CNTC CFTC CFTC GR Gamma TENS Tens ~RES ~UD Res~st~v~¥ HTE~ ~ud Temperature I$ Tape Verification bisting ChlUmDerger Alaska Computing Center 25-$EP-1990 05=48 DEFI HTEN Head Tension PAGE= DATA FORHAT SPECZFZCATZON RECORD SET TYPE - 64EB TYPE REPR CODE ~ . VALUE momgammmsammugmmmggemgm~meBmmm 1 66 o 65 SET TYPE- CHAN $$ ORDER ~ bOG TYPE': CLASS':' N. D N NS SAMe.,ZbEM ~ CODE ~ 4' se oo~ooooooo ' ,'1 ! 68 ~0 _ OOOOO00 : ', ' ': O0 0 0 0 t. . ~ , .,gooooooooo s, 2, ooooo oo _, , ~ , 6.oooooooooo ·r 6 O 0 O0 0'0 0 ~ ~ t 4 68 0000000000 ,,.,oo ooooooo .M~o 6 oo 0o~ oo o ,. o oo ~6 oo o ~ ~ 4 68 oo ooooooo ~o s~ ,'26 oo ooo ooo ~ ~ .~4 6e oooooooooo ~o sy 26 oo ooo. oo ~ ~ ~ ~ ~ 68-oooooooooo ~o.~ 26oo ooo oo... ~ ~ ~ ~ . ~ooooooo.ooo ~o s~ 26 oo ooo ooo.~ ~ ~ 4 6e oooooooooo o~e~.s~ 26 oo ooo ooo ~ ~ ~ 4 oe oooooooooo 's~ ~o oo ooo oo~ ~ ~ ~ 4 68 oooooooooo o~or..s~ 26 oo ooo oo· ~ ~ ~ 4 60 oooooooooo IS ?a~e ver!ttcat:ton Listing chlum erger Alaska Computing center 990 08148 PAGE~ ? NAME SERV UNZT SERVIC~ APZ AP! API AP! FILE NUI/B NUI/B SZZE REPR PROCESS . , NUN lO- ORDER # LOG TYPE CLASS NOD B SAMP EbEI/ CODE (HEX) i/RE& DTI/ Of/NM 5' HTEN DTE: LB ~6 DT SD~ DTL SDT D?LN SOT U$/F DTbF SDT US/F SOT US bTT2 BDT US' ~ T SDT US Gn SDT GAPI OHMM OT,,~ uS/F o~$ us/r DT8 US/r GtCO D~HI PU. b~ V .bDT V 8~HV bDT V .. · ~H . MTE~ bDT ~RES LOT OHNN H~EN . D~ · O0 000 O0 6~ 00' 000 O0 68 O0 000 O0 68 oo ~ oo O0 000 O0 O0 000 O0 ~ ooo oo 000 O0 00~ O0 O0 O0 O0 0 000 O0 0 000 O0 o o~ oo ~00 O0 0 1 o 0 1 0 °t 0 0 0 0 0 0 0 0 ~ 1 0 0 °i o 0 0 0 0 0 0 1 0 0 0 0 1 1 1 1 1 1 .~, 1 1 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 68 68 68 68 68 $8 0000000000 0000000000 0000000000 0000000000 0000000000 00000~)0000 00000~)0000 00000~0000 000001~0000 00000(I0000 O0000l~O000 00000~0000 O0000l~O000 o00001)0000 000004)0000 00000~0000 00000~)0000 O0000l)O000 000001)0000 000001)0000 00000~)0000 00000t)0000 0000000000 ~00000~000 00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ~000000000 ~ 000000000 0000000000 000000000~0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 68 0000000000 .0000000000 0000000000 0000000000 0000000000 6B 0000000000 0000000000 iS Tepe verification_ b~s~t~ng chlumoerger AlasKa compuczng center ....ID- ORDER ! GOG. TYPE CbAS$ MOD NUMB SAMP-EbEM CODE (HEX) T~PH CNG PU TNRA Nb NPOR ~Nb PU RCFT CNG MRES MTEM CNG DEGF'5? HTEN.CNL, .LB ~6 ~6 6 5725 '6 :~00 O0000 O0 0 } ODooo OD oI I ~ ~I ooooo oo o~ ~.~ , .~ ooooo oo o~ ~ ~ , ~ 000 O0 0 ~ 0 I · 4 68 O0 000 O0 0 I I 1 4' 68 O0 000 O0 0 I t ~ 4 68 O0 000 O0 0 ~ ! 1 4 68 O0 000 O0 O. 1- 1 X 4 68 000. O0 0 X I 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ~m#~~m~~m~mmmm~mmm~m~wmmmmm~m~m~m~m~mmmm~mm~#~mmm~#mmmmmm~mmm~m~mmmm# PAGEI DATA DEPT, sP,DTE I~RD,DTE T~NS..DTE DT ~DT TT~ SDT LTT ! SDT SP SDT MRES SDT ors. REC PEr 8 ~bDT ',CNG TEN ~ DT, SDT TT~.SDT LTT~SDT SP~SDT MRE~,:SD DTSM~.PT~ '~2~ ooo - 750 3 000 95 750 ~o~ ~0 3 i 800 ?0 99 SFLU.DTE IDPH.DTE X~Or.o~r IIXD,D~E DTG.SDT TT SDT HTEN SOT D~SM ,ITP DPHX bi bDT RCFH TE~ . DTE 'F, DTE XIXD, DTE HTEM..DTE D h~ SDT ~?, ~SDT' 9 9 '1~5, ILM.DTE 484 IMPH,DTE 000 :IDP,DTE O6 511 XIRM,DTE MRE$,DTE 6~0 DTGN,SDT 6~0 TT3}SDT 2 0 GTT~,~DT 563 TENS~$DT ' ~0 RSHC,REC ~0 RUOB~:.'DT ~'0 ~RES, .1~0 C~TC,,CNb ~0 TENS!CNG= ~0 ~ 0 ,DTE ZFRE, !05 375 106.000 GR,,DTE DTLF,,$DT 1054,400 TT4.~SDT ~60,625 :999,25~ 999,250 -999.,~250 -999~:250 SSZ',LDT ~999,250 mggg.,250 'GR.L. DT -9 ;~; ,50 NPOR.CNL -9 .. 50 CF~C.C~L *egg,250 MRES,CNL ,0~8 IFRR DTE 105,500 CIHP DTE :1.06.000 ,I ,.~.~07 HT~:DTEDTE ,~00 DILl SDT x~; TT ,400 [~A3:.200 bTT4 SDT ,250 QF~[ . ,REC g 266 20 000 ilO 063 78 900 810 800 1376 000 '1,28 581 -999~250 -99g,250 '999;250 ~999~250 '~999~250 g999.~250 :999,250 .gg9,250 'gg9~,250 -g99,:250 w999~250 ,9,266 20,000 110,063 61,563 g28,000 78,900 810,800 1376.000 .128.,.58! 999,:250' 'gg9,250 IS Tape ver~j~cetton bls.ti, nE cl~lum~erger A].astca 'Compucxng Center 08=48 PAGE= OFSH REC -999.250 DPHX:bDT 54, 99- RHOBabDT t.747 DRHO.LDT -0,003 882PEFLOTLU bDT LOT 80~:~ 369.250 bSHV'LDT OLS.LDT'LL.LDT t3, 44 ~ii~ ' &SHY,bDT bXTH.~OT O&$~DT 13570000289.000 0.006 StRHeLDT $$toLOT L$.LDT 213=750 850.0001:~759 LSRH LOT _ t,?44 ~0 TENS LOT 325 o0004 ~T~M,LDT MRESeLDT 1.92~ HTENeLDT 6t8500 NPH! RCNT Cab 92~ ~R cab ~0.6~- ~ALI.CNL CNTC,CNL CFTC.Cab 904,985 MTn# CNL TE ,CNL 70 ~009 SFLU~DTE: 353.7~0 XL#VDTE. 65.939 ILDvDTE 62689 DEPT*' -l~g$~ XDPH,OTE i~2,87S 20000 ZFRE,DTE SP*DTE X#PH*DTE. X~GF,DTE O*r0 XMGF,DTE 00000 CXDP.DTE 6,85 CXNP.DTE t2664 'XIRD..DTE 18.~50 "XXXD.DTE 3,465 XXR#e'DTE 1'3~81~ GR..DTE 33031 HTEN,DTE 000 DT~SDT -t2S~400 DTbtSDT S~,090 12~'900 DTLF,SDT b?~l,&O~ ~4&~;~O0 ~$40.800 1460 400 RHOB bDT ~*'355 DRHO.LDT -0 Or4 OFSH,'RE¢ ~lO,O00 DPI~LDT PEr;bDT tv250 GL$,LDT 8~9,5~0,007 LiTH~LDTGS$'LDT 0.00~ L:S.LDT 1707 .000 LU.;bDT 1654~:000 Lb,bDT ~~ 702~50o SS~.L.DT 2X3:875 SSHV.LDT~ i357..000 S1RH,bDT I.~425 TN$~'LDT :3374;000 MTEM',LDT' MRES,LDT 1.905 HTEN*:LDT 522r000 NPHZ,:CNb .63,685: TNPHiCNb. 74..208 TNRA~CiLN 5.:005 NPOR,.CNL 76,513 RCNT,CNb i503,~t4 RCFT.CNb :284.3~6 CNTC:CNL 1371.609 CFTC.Cab 282,923 GR,CNL 31..,656: :~ALZtCNL .t.8,578 TEN$.CNL~ 3374*000 MRES.CNL 1:.905 MTEM.CNL ~30"~19' H. ~ENeCNb: '522,~000 · :$P'DTE "97,875:~ LT~!~SOT 0 [267;600 t125~600 . GFCOeREC 0.,000 '9 ~ RHO bDT' OFSH*REC tO,O00 DPHX*LDT , 00013: 0.003: L$*bDT 240,250 135~.,000 &~RH*bDT :2,408 MTEM,b~T .OR,bDT N~Hi,.~NL ~37868 TNPH.Cb 702.4~$:. CNT,TNRi CNbC#b: ~ : NPOR.CNb :34.767 RCNT.CNb .2615 913 eCrT,:Cab. 22 ~ CFTC,Cab 694,666 GR,.CNL 65 750 CALX,Cab IS ?&ps verification L,t$tlng ch].umt~er~er A{.as!<:a ~Computlnq Center 990 08 i48 PAGEt 10 DEPT, IDGF DTE IXRD DTE TENS DTE DT SDT TT! SDT LTT~ SDT $ SDT Mn~SSDT PEF,LDT L~,LDT NPH~vCNL RCNT~:¢NL MTEM,(Nb ZDOF 'i~RD TENS DT DTSM RCNT DT DT T' .CNL 68000000 SFLU"DTE 100299 XLM,DTE. 8,92~ -XLD.DTE I0.023 -112.688 XDPNuDTE XO,2e9 XMPHvDTE: 8,992 !FRE,DTE 20,000 0.000 INOF,DTE O.OCO CIDP, DTE 97,125 CI#P.DTE 111.063 461,{S0 MTE#,DTE MRE$,DTE 2,014 HTKN.DTE 986.000 90,000 'DTL,SDT 86,690 DTLN,SDT 88,300 DTLF,SDT 89,400 646,400 TT2~SDT 4~t,600 TT3,SDT 862,ooo TT4.SDT 655,200 1166~400 LTTZ~SDT 959,6~:0 LTT$,SDT 1388,800 ~TT4,SDT II?t,600 i;{:l~ OSS,L T' 0.02~ _~$.LDT 274.750 LSNV,~DT 134~,0~.0 SSHVkLDT 1357,000 SIRH,LDT ,6.000 311§.~0'~ ~ LURH*LDT 9v~'5 :CALX,LDT 12~95~ OR.LDT 84.625 M~ M,.DT tZ~,.~i~ MRE$~LDT ~9...0 HTEN,LDT 504,5-00 NPOR,CNL 2180 255 RCFT,CNL 559,0~'2 ~i-2'8'16 CNTCJCNL {933,001 CFTC.CNL 560'659 12984625931 CALX,CNLHTEN,CNL 54,5'0 TENS,CML 3110,O00 MRES'CN~ 1.910 DE~T, 0600 :SP,DTE IDOF,D?E~ 0 I{RD;DTE 1'5 TTI*SDT 660 LTT!,SDT SP,~SDT -6~ MRESi~SDT 2 000 SFbU~DTE 4 8'3 IDPH,DTE ,0~0 0 'XMQF,DTE 875: iIXD.DTE 250. MTEN,DTE 1 i00 :000 LTT2,SDT 813 GR~SDT '99 027 HTEN'$DT 916 GR NTE ~DTE DTE E. DT SDT SDT .SDT ITP 7'750 '20.000 ,~,00 68~,~,00 .(.00 ?0 92;875 5Z7,000 50,07:9 461,246 I:, 938 2~ 527 000 9 6000 ~2r~200 ~5~,~00 ~59,200 9O6 022 chiumeerger Alaslcs Computinq (:enter 25-$EP-1990 08148 DT$~,PTE -999,250 DTTM ZTP "999. QFSH,REC 10,000 DPHX bDT PEF,GDT 3.014' Qb$ bDT 0 28 ~000 bb bDT SS2,bDT bSHV bSRH.bD? 2,318 bURX bDT TENS.bDT 30 ,000 NT/~ bDT 'i'°'' M?E~,CNG 12 536 DEPT~ 6500*000 8FLU,DT~ SP,DTE 095,8?5 XDPH,DTE XDOF,DTE '78,~5 XXRD, DTE OffO O* XXXDsDTKX#OF*DTE · '0, LT~I,~SDT LTT2*~DT t 8P~SDT 095,e?5 GR,$DT MRES~SDT 2.029 HTEN,SDT DTSM.P~E :-999,250 DTSM,~TP 536,000 RCNT,CNG G~,.CNL 7'7,500 CAbI~:CNL HTE .,CNL 128,188 XTEN~CNL 5~1 TENs,DTE. 84,563 · BDT65,600 ,,,,ooo ':,~OT 598~000 D 1046~000~ 0112:i875:. LSR bDT T~N~LDT NPHX. G~:CHb 43,844 MTEM CNL t27'906: 030 855 ~0 242 000 RSHC RHOB LITH $HV AL~ TNRA~ CNTC~ REC .bDT bDT bDT .bDT .bDT ,[~DT CNt, -999-50 REC DRHO bDT 007 438 $61 356. S1RX .91 ;414 NPOR 300HRE$ bDT LOT bDT bDT bDT CNL CNL XLN:DTE 10,81~ XLD,DTE : XIRM, DTE 87,563 ,DTE #R~$~OTE 12~.4~0 HT~N.OTE DTbN!&DT. '0 9 OT~F,SDT TT~SD. ~ TT4,'$DT LTTI~&D;~ 1007,600 1618,400 LTT4,~DT TEN$SDT~ 446~250 RHOB:eLD~ 1 DRHO*LDT CbI,~ T i.4.,242 GR.~:LDT CNTC~CNL 174.6,.~!~ CFTCi;CNL TENS,CNb 2984,000 SlrLU:*DTE 13:.6~6 ! M.,DTE~ · .' X IXD' DTE l I. RM, OTE , *~ 2~7,3'~ 5 HTEN,~ OTbNvS~T~ ~ ,(,00 DTLF,*$DT GR ~80T 438,(~00 HTEN~;~DT 942,:000 DT~,.PTE . ~7,735 DT~TP DTSMvZTP -999'250 RSHC,'REC 999,250 arco, R.EC: DBHI*LDT ~15.986 RHOB*bDT 2*386 DRHO,LDT OL&eLDT 0 0~8 OSSiLDT 0,004 Lb* LDT bi. TH'bDT* ~ 96;.7 0 MTENvLDT. ~ MRE&ibDT RCFT,~ CNL : CNTC* C b C 4 H PAGE= 11 0 000 0 025 307 000 200 500 2 240 37 469 648 470 I 944 000 313 71.750 945~000 129,.000 765,200 1364,400 1~7~512 I 6.775 o;ooo -0,003 585,500 206.000 1,970 77.1500 51~.;000 :'64,338 391,843 .1.946 11.*000 20,000 83.563 44,375 943,000 :. 61., 200 .597,200 1041,600 :127,23'1 .87,735 .0,000 0:,011: 285,000 193,250 2,320 '43,844 .~ 0~? I ' Is Tape veri~ice~ion ~s~nq chlumoerger ~Iaska Computing Center 25"8EP-1990 09148 PAGE= DEPT ID~F DTE ZIRD ITl NRE$,SDT OTS#,PTE QFSHvREC SS~,LOT L~RHeLDT TENSeLDT ..CNL DEPT TENS DT 'TTI bTT~ iT DTSH LU L~RH TENS NPH! MTEM CNL XDQF DTE I~RD DTE TENS DTE DT SDT TTI SDT LTTI SDT MRE8 SDT -45,406 XDFH,DTE 0,000 Z#QFeDTE 0 1t8.563 XXXD'.D'' 440t~00 MTEMeDTE 94,200 DTL,~DT .,..,oo 1104,000 bT $ T -999.150 D~$N XTP -999_ -10 lO0 292 ~SO 6200,000 i04g ,~00 "~00 29~ 000 464! 1~6' ~26 669 ..000 ,969 ~00 600 134~ 2189 16 IMPH.DTE 7 CIDP~OTE 29 XXR#,DTE 12 MREStDTE i DTbN'SDT g~ TT3,SDT 90 bTT ,S T 440 ~ TENi,$~T 128 DT.PTE 96 R6HC:REC. RHOB bDT bD~' . ;~ TNRA Nb CNTC · 2O.. 7 0 CXMP 5~0 D~b~ :800 TT4 ,~00 ~00 bTT4 MTE# ,~04 DT 25 40~ QFCO 08 .$ HTEN 269 NPOR :.'47 CFTC ~00 MRES DTE 70480 DIE I 875 DTE 438 DTE 959~500 ~DT 66,500 SDT 638~400 ZTP 96 604 ,REC 0000 .bDT 0 011 , DT 000 1 250 35. 08 4~4 INPH,DTE · 'RES,DTE'~ HTEN..DTE DTLN,$DT* ~73':200 i !.D:.',PTE' 744..800 TT4.'~DT87, TIE'SOT DTLF,SDT · ~SHV,:bOT 1357,.000 S1RH,.LDT ~?.. MR'~SebDT 1,9.65 HTEN;:.LDT CNTC,,CNL 3B7!.,255 NPOR'CNL CFTC,CNL: 494 TEN$eCNL 2810.000 MRE$eCNb ~...395 bO 16-297 i~RE 63,781 ClNP 6Z"594 2.041 HTI~ .gE*300 DTbF ?92*400 'TT4 1237,200 LTT4 426.750 MTEM 84.319 DT DTE MPH.DTE· lOP. OTE~ IRM* DTE. M:RE$,DTE: DTLN.&DT' TT3.$DT LTT3$DT TENS 6DT DT PTE 600 40 o00 17 406 O0 45 344 .: 000 !~O0 0,.00 00~ 4 ~56 50 I0 t95 .14, 56 974,0 80,000 616,400 .'3!9 IS rape verii~¢~t$~n ~i$tinq ~lnl~bergerA1a~l<e Co~p~tin~ Center 08148 PAGEt 0?5# PTE -999.250 DT~M,ITP 171.988 RGXC. REC ~ 040 QFCO REC 0 000 OFSH REC 5,000 DPHX,GDT 13,8~4 RHOB~,GD~ 421 DRHO ~DT 0 006 PEF GDT 20186 G~oGDT 00041 OSS,,bD? -0 014 GS GDT 267 000 ~U GDT 248i875 L~eLDT 42, 5 90 938 188 875 1148.6'030~ LITX~DT SSI GDT SS~ GDT 297,350 LSHV.LDT SSHV.GDT 1357 000 SIRH GDT 2.377 GSRH GDT 2,402 GURH,GDT 2,4Z0 .CALI..GDT t2 ~69 GR GDT 47 844 TENS bDT 2740,000 #ZEM.LDT 1~6,387 #RESt,GDT I $T9 HTEN GDT 509 250 NPHI CN~ 19v743 TNPH,CN~ -20,8~5 TNRA,CNG, 2,282 NPOR CNG 20 119 RCNT CNG 4051,679 RCF~,CN~ 1600,456 'CNTC~,CNL' ]502,400 CFTC CNG 1556 614 GR CNG 47,~44 CALZ,CNL 12,469 TENS,,CNL 2740,000 MRE$ CNL i 979 HTE# CNG 126~387 XTEN.,CNL 509.250 SP DTE IDPH~D. 9.8~9 X#PX,DTE 10.0~1 IFRE.DTE ~0.000 T~N$.DTE 410,~S0 HTEM,DTE' 125~938 MRES;DTE~ ~2,05~ HT£N.DTB 938.000 DT :SDT 9T, 060 DTG:.SDT ~9~000 DTLNvSDT~ .9~,300 DTLF.SDT 76,600 800 TTSvSDT~ TT4,$DT 67 .6oo 470,000 -8860800 TT2,SDT TTI~SDT GTTI SDT 120.,600 LTT2*SD 99J,600 1428,ooo 12o3,2oo · TENStSDT~ 4i8.750 MTEM.$DT 125,938 '. DTSM,P~EMRES;;SDT -g92.,25~90 H~E~,SDT .938,0~0 DT~.PTE: 98.594 DT.'.ITP 98,594 QFSH.REC DPHX,LDT DRHO.LDT GU,GDT 300,25 G~,GDT i $SIOLDT 194~625 582,LDT 1348.!0~0 i i 81RX*LDT LSHVaL:D~ HTEN.bDT' 498.500 TENS,GDT RCNT,CN~ : 4 , 11 RCFT,CNL 1148,574 CNTCiCNL '43~,~81 1.2,281 GR ,CNG CALZ.*C:NL TENSo. CNG 2720,000 MRES.CNL 1.972 ~21,825 HTE~,CNL 49~,:500 DEP~',~ 5900*000 SFbU*DT£: 4.~.~9' 4.262 SPeDTE -42~875 XDPX,D~E 4,371 I~PH~DTEi · 4.~88 XFR~,DTE ~ 000 IDOF,DTE 0,000 IMGF,.DTE. 5.~ ClDP,.DTE .228,~50 CIMP*DTE 2~ 8 :750 14,$ ~ 22:0;.~25 2 375 I~RD,D~; ~94~000 llXOtD~E ~25~6~6.~ llRHtDTE GR.DTE T~NS;.D~ 420,000 MTEM,D~E:: · DT.'SDT Z00,200 DTL.SDT 97.05~0 DTLN*SDT, :9~. ~,40 DTLF.SDT 70. 50 ''TTZ~SDT' 664,900 TTZ,SDT 4~4,0~0 T'Ta,SDT :85 * 00 T'T4- DT 6640;00 Se*SOT 42'8'75 GR*;$DT '82:.3~5 TENS,SOT 420*000 MTEM.':&DT '25 6:56 RS.HC,REC QFCO*REC. DTS.,~T DTSH,~TP -999,2~0 999.250 ~ :00'3:000 GFSH,RE~ 10,000 DPHZ,GDT 2~,4~2. RH.OB,~DT 2'297 DRHO.LDT PEF~LDT 2~410 QLS, LDT 0,02. OS$:tLDT 0..000 LS.LDT 32~ 500 , LU bDT ' 4,000 LLtLDT 1~ ,500 ~09.063 $~Z.LDT ~TSO 134 ,0~0 .270 SSHV,LDT: I356,0'00 SlRH.LDT $82 GDT CFTC.CNG CNG 78,I~3 'CAL.! CNG .... $ :,648 TEN$,CNL~ .2~54..000 ~RE$,CNL 2,000 MTEMCNL 25-$1gP-299008=48 PAGEt 14 $1 6 453 'XMPH,OTE 6?22 IrRE.DTg 201000 DTE -124.375 ~DPH DTE 000 414 242,250 40.438 lPG] DTE 0.000 IMOF DTE _0 CIDP.DTE 154,750 CZM~.DTE 248.8?5 IIR] DT" 137.250 IlXD DTE XIRNoDTE GRiDTE TENi DT~ 404.2S0 MTEM,DTE lOl~8 2~0 MRES.DTE 2~072 HTEN.DTE .939'000 P' 'SDT 210.200 DTL SDT 400 DTLN,SDT 107,600 DTLF.$DT 52.900 TT SDT 698.400 TT2$DT 489 600 TT3.SDT 872~600 TT415DT 694.400 950 800 2246,8O0 2117.200 LTT2$DT ~TT3.SDT LTT4,SDT LTT; '6DT [123,200 $1 SD? 124,375 GR,SDT 40 438 TENSoSDT 404,250 MTEMo'SDT 125;~50 #RE; ,:SOT 2,o72 HTEN;SDT 9)9 000 95,,534 DTo~TP 95.534 DTS# ~T~M:~[T~ 945 RSHC,REC~ ~,,664 GFCO.REC 0.000 ~'"~' ~-o o,,,~T., o,,0,2 L~.~, RCFT,CN~ 2970~539 C~TCiCNL GR,iCN~. H?EN,CN~ ~ TENSoCN~. 2640.000 MRESoCN~ 2,006 .,,.~c., ,...... ,~ ooo 86~ XXRMmDTE 226.250 T $*DTE. M?E~DT.E ,12t -QO ~RZS,DTE, 2,072 HTEN.DTE O0 ' DTLNgSDT: DT~FoSDT 0 DT~SDT 65,: q DTL~:SDT :940400 o~~ ~,SDT: S]e. O00 :TT4:,'SD~ 0 · ~,~,~.,~ ' :"',,t,.'"'~',, .,tl.:~: ,~,,.~,. '"°:~'~'°' .2~o .,~,.s~,~,..,,, :l~i° PEF~'bDT Qb$i,bDT i;0002~ GS$iLDT. LS*LDT 285: 0 300,~ ;0 LSHV,~DT SBHV.,LDT i,3 :SIR ,.LDT 2570.0, iO 'M~EM ,LDT MR $,~ DT 2 2 DEPT,., , 5600,0(0 SFLU~DTE .:84 DSP'DTE ~ *0(103 IMGF,DTE 0 · OOO M~E:MvDTE TENS*DTEDT.SDT 8;2,1 2~500 TL~.$DT ~ · '~ ,- . GR~TDT :32 MR:E$.'SDT . HTEN.SDT 949 CXDP.:;DTE~ ii IIRM.DT~:: I MRE:$,DTE. iO0 SDT DT,PTE 76,~00 TI4 SDT 54~:g00 LTT4 SDT ~ 98*, O0 ~TEM,$DT -999.250 DT,~ZTP ,656 32'~0 949. 96;200 820,800 1420,800 t24~475 .126,225 TaPe veriftcation l, Lst~ng chlumbergerAlasKa-ComPutlnq Center 25-SEP-1990 0~148 PAGEI 15 PEF bDT NPHi RCNT GR NL aTE# Nb IlR: ,:SOT D · MR~*i'SDT DTSM.PTE QFSH,REC bSR:g~bOT: TENS'~bDT' NPHX*CNL GR;CNL M?EM,CNb DEPT,: $P*DTE: XDQF,DTE X~RD*DTE TEN$,DTE MR:ES*SDT QSH*REC PEr*bDT L..R bDT TENSLDT NPH!~'CNL: RCNT*CNL' GR:eCNb -999,250 DTSM,ZTP -9992~0 RSHC, REC -999.250 OFCOoREC .500000, Lb*bDT 8_8 50 LXTH,bOT ?00,000 SSI,bDT 199,375 375 1,397 LURH,LDT t 426 MRES,bDT ~2..031 HTEN.LDT S 000 2614.00064.091 TNPH.CNL#TE#'LDT 3 79 TNRA~¢NL 45.097 NPOR,CNL 3~i!410 ~ 9i9 CAL~.bDT 2~,21~ GR.bDT 323 033: CNTC,CNL I 51~301 'CFTC*CNL 657 1599,650 RCFT,CNL 33,375 CAL],CNb 219 T£N$,CNb 26 4,000 MRES,CNL 031 t23,969 HTEN,CNL 532 000 5500~000 SFLU.DTE 10 039 'Ib#.DTE !A'~'~7 XLD'DTE 13'99 -50,:8t) XDPH~iDTE 13906 XMPHe. DTE -o.o o z.or, o oooo _09~? 38~.25~ XXXD~,DTE XZRM.DTE GR.DTE 9~!00 MTEM..:DTEDTL:;~SDT t24.08! 82 ~0 X07,~00 DT~N't'S~T DTLFTSDT o 74~&00 T~,~SDT- TT ~SDT 978,400 131~*$00 1~7;~0~ bTTt,aDT 1470,400 TT4.$D~ 3.'0 LTY21iSD~ iii4 400 LTT4oSDT 9.0; O0 L06..~42 'RSHC;RE~! GFCO,REC DT&M:i~TP 000 '"999','25~ '0'000 OPH'I;LDT 19,8!0 RHOB'LD' ~2..'23 DRHO.LDT 0 017 3,~77 OL$.~bD~. '::~0.~6: OSS,LDT ~0..000 319 250 6Si,LOT LXTH,LOT 199.$75 ~9,000 MTE:M,LDT MRES,bDT 2,047 HTEN.,LDT 520,500 4.~:OIS!:a, RCFT~:CNL 567,6f:9 CNTC,CNL. :2083'944 CFTC'CNL 544,27.9 5400'000.. .0,000 0,~ 00. :. ,.04,00~ tO~O00 ~3 ~0 XXXDEDTE MTEM.DTE DTb'~SDT :TT2~DT P'HX*LDT GL$*bDT LSHV~LDT LURH~LDT MTE. M~LDT TN~H, CALX*C#L HTEN,CNL 8.438 1016.000 · $00 ~0 i 4 134 g 6 5.3: 0 ~MPH~DT: XIRM~DTE MRESaDTE bTT3~&DT' TENS¥SDT DT*PTE RSHC. RECi RHOBLDT, O$$.bDTi 85HV bT CAL~ MRE~ bDT TNR ~ NL CNT~:~NL TENSCNb .I:,273 ILD,DTE ,617 XFRE,DTE ,:000 CXM~,DTE II!;185 G...DTE · : -096 HTEN,DTE · ~04,400 i408,:800 LTT4~SD'T DRHO.LDT .0,008 77,313 SSI,LOT I355,000 $1RH,bDT HTEN'LDT 222~,27~ NPOR:,CNL 2540,000 90 500 84;, OD .0. 003~ 2?8 ~50 0 0 6512 049 I!s Tape verXf~lcetlon blstSnq chlum~erger Alas)ca Computlng Center 25-$~P-~990 08:48 PAGEI 16 DEPT SP D?E /DQF DTE ZIRD DTE TI! SDT SP~SDT MRE$'SDT D?SMPTE ,REC LU~DT b~RH'bDT NPH~, ~TEM, ~b. 5300.OO0 srbu DTE 7.648 -49,438 IDPH DTE 9 102 0'000 ZMOF DTE 0 100,938 IlXD DTE _7 5)8 352~500 MTEM DTE ~22 ~ ,800 ~$DT ~08 6~1.200 DTb 1~30.000 ..-2e104_ HTEN.SD? 913 0 ~0 ~gv2$0 DTS#~TP ~76 811 RSH~ Se,00 OPHIebDT 19 0:5 RHOB ~ 0 308,2$0 bSH¥~bDT ~34~ 0!0 :Nb i~ RCFTe:Nb .830,8 4 2.1 :.5 ~ ~,8 HTENeCNb $35~0~0 ILM,DTE ZMPHeDTE CZDP,DTE ZXRNoDTE MRES,DTE DTbN~ ~$DT TT3 ,SDT ~&DT ,SDT DT~ PTE REC bDT bDT bDT bDT bDT~ NTC Nb TENS Nb 8,336 XLD,DTE 8,500 XFR$,DTE 109,813 CIMPoDTE 113,375 'GReDTE 10~..t04 HTENoDTE 000 DTLF.6DT 912:800 TT4 $DT 1390,400 bTT4 3820500 MTEM SDT i04,25J DT XTP 1,695 OFCO 2033~ DRHO bDT SSi bDT 91,~09 kS bDT ~355,:. 09 $1RH bDT 12'695 . GR LDT 2-07~ HTEN~LDT 3v007 NPOR,CNL 2380,230 CF?CvCNb 2444,000 MRE$*CNL . ~;3~5' IDP:H~ )TE 139,000 XM!PH,OTE. 80,938 S',DTE '.*~.6,?$0 .2,* : . RCNT,CNL 30~4,491 RCFI~CNb 11!7,059 CNTC~CNL, 2747,669 C~TC,CNb N?EN;CNb ~21:..~00 H~EN,CN~ 598'500 · 7:727 ' 7.355 0.0-0 'XMPH .DTEi!i IFRE,DTE 6':0 3 XIRN DTE ~30 875 GR,DTE 104:200 DTLN SDT 465 200 ~TT3 SDT 932,000 TT40~DT ~044 800 bTT3 SDT Z459 600 GTT4,$DT 66 9}8 TENS SDT 375 000 MTEM,SDT :962 000 DT PTE ~04 68~ DT,ITP SP,DTE: 6,734' IDPH,DTE XDQF,DTE: 0'000 IMOF.,DTE: :I!RD.DTE. 113,688 IiXD,DTE' TENS,DTE: 375,000 MTE~,DTE DT,SDT ~33,600 DTb,&DT TTieSDT* 724*400 TT~'$DT LTTX,SDT 1249~600 LTT2*SDT SP'SDT 6,734 ~GR,'SDT MRESeSDT 2,t4~ HTEN,SDT 8,805 20,000 117,500 82.~88 913,000 97,100 69'7.;200 1227~600 122,731 I04~251 g:ooo .t13 0~0 200 25O · 747 7 7X9 20 000 75 13566 ~38 962 000 102 700 724 800 ~244 800 121 83. 104 68t: chlu~berge~. AlasKa Comput Center PAGE~ DTSM.PTE QrSH.REC PEFebDT bU,bDT SS2ebDT bSRH.bDT TENS;bDT NeNI.CNb RCN?.CNb GR.eCNb NTENeCNb 1 .000 DPHI,bDT RSHC,REC -999.250 Q~¢OoREC 000 .039 ~250 bSHV.bDl 134 0~0 8TENeLDT 23 ,000 MTEM.bDT 12 NRES.bDT 2,~09 520,000 .450 TNPH'CNL 5~2,?1271477 TNRA,CNb 3, 68 NPOR,CNb .42,575 · 66,~25 CAbZ,CNb 5!0* TgNSoCNb 2340.000 ~RES.¢,b .109 i20,762 HTEN.CNb DE:PT, 5000,000 SFbU'DTE: 24.043' XbM*DTE:. 39,5_94 XNPHvDTE: 31-~.~500 IFRE,DTE 20,(~,~9 XDQFeDTE :0,000 XMGFeDTE 0 0 T~ ,SDT 7 ,- 0 .BO~.,600 TT4,SDT 0 .1. n~00~ DT~M~XTP -9~9,250 RSHC R~C N~Hl.CNb 64 TNPH*CNL N'PO~,~NL 29. t70 RCNT.CNL 30 i. 702 RCrTiCNL 951,284 .C~TC CNL: 274~,0'71 CFT~, Nb 988,435 ~TE:M"GR ,CNL. CNL: ~ ,.,2540 . CALZ, CNLH~EN ,CNL 5' 12,508~ ?, 500 TENS CNL 23240000 MRE; .~NL 2,109 X ~F,DTE T..NS,DTE ,DT*$DT TTI,!$DT MRES.,$DT GFSH*'R£C bU.LDT 'SS2,LDT L~R~.LDT TENS.bDT RCNT 'GR , Nb MT£M 4900'000 'SFbU,DTZ ~t,875: ,,.,.o,.. oo .. ,.o,.' 360*000MTE~DTE I 0e988~SiDTE~: '14140800 bTT2*SDT b~Ti~:SDT '::-9~2.152'99 HTEN,SOT 1045,000 DT'.PTE ,250 D:TS~,'~TP -999,250 R8HC~REC · ,000 DPHX;bDT 50..~9 RHOB,bDT .ooo "1~818 b ~*LDT ,~ '.ClbI~':bOT" CALX,;CNL 6;~:250 19 C.NT ~ INL t1·.906 H~EN.CNb 5380,000 ~2,92~ IbD~DTE ~.82~ ZFRE~.DTE I 256.00 blllSDT,SDT 3~0 000 MTEN :SDT 123 933 DT;'~TP -999 250 GFCO*: EC 1 81~ DRHO,LDT -0 ,bDT 54.000 $IRH,LDT ~9~219 GR.bDT · 2~,~39 H?EN;bDT 4.501 NPOR*CNb 1685;~41 .¢rTC.CNb 2334..000 21'344 30,000 '34o656 '47.906 1045.,'000 ~25 8~0 817 2 0 1429 200 120988 123 933 0,000 -0~016 ?$4500 204.500 s 000 58,57 3803~4 2 i3g Xumber~er l~slc& Com~Ut:~ Cent:er 25-$EP-~990 08=48 PAGEI 18 DEPT 4800,000 8FbU DTE 908~7 XbK,DTE 4,547 ILD DTE 4,059 SP D?E 2,602 XDPH, DTE 4,159 XKPH,DTE 4,563 IFRE DTE 20,000 ' 242.125 IDGF DTE 0,000 INGF DTE _0,0~0 CIDP,DTE 206,3~ C~MP DTE 219,125 TEN& DT 364,250 MTEM DTE DT SD~ DTL:~&DT 120,300 DTLF ~DT 162.900 t34,300 DTLN,~DT $SDT 799,600 .TT2,$DT 519,200 TT3j6DT 1046.000 TT4 '$DT 794.400 I SDT 796.800 LTT2~SDT I183.600 bTT3.SDT' 1968.400 LTT4 SDT !440.800 S..6DT HTEN,SDT DT.PTE. DT;ITP 999,250 #.PTE TSM,~T .9 -999,250 -999,25~ GFCO.REC -999.250 DRHO.LDT H,REC ; RHO~ LDT GS~ bDT bS.LDT 368,000 L 'b T 190,62S ~S$2,L~T 3tt,O00 bSHV, bDT ~346,~00 ~,~ LDT t§~,000 $1RH.bDT 2.254 'LURH,LDT : 2,2~7 ~3,28t GR.bDT 44,094 T N , D? ,2224*:000 MTE~,LDT NPHt,~Nb 24o48o TNPH,CNL 24,~0 RCFT,CNL CNT( 285~,,168 CFTC,CNb 1!3~,999 RCNT.CNb $313.$~t 117t,~t~ ~2.593 NPOR.CNb 23,586 HTEN.CNL TT LTT DT8 LDT DEPT, 4700'000 Sr U*D? SP..)TE -6,254 XD~H;DT~ XDQ'r,)TE '0,000 X:MGF,DTE CIDP,DTE ~,~ ..30,953 'IIXD, DTE !~:ii! iiRM,DTE ~....~. 346,~50 MTEM,.DTE DT,SDT 128,000 DTb,SD, . ' DTLN '$DT TT3,SDT 1399,600 LTT2,'SDT ~:~00 DT~PTE MR£$,SDT . ..;~ HTEN,'SDT PE~.LDT ,2:~580 OhS bDT 22;:7~0 O~$~.LDT: RCNTeCNb RCFT CNL :GR,CNb 43 ~281 CALl CNL NTEM~CNL itT: 500 HT/N CNb 49060~0 '.2~i82 I50,30~ 1048.000 3O DEPT,: 4600 · SP,DT~ 59 lPO:r..DT£ 0 TENSoDTE DT.SDT TTZ~SDT LT .,SDT: SP.,:"$DT 59 ~R£$,':SDT '2 0 0 8FLU'DT£ 9~8 'XDPX,DTE ~ .000 'I~QF,DTE 0 :375 MTEM,DTE 1!i ~§ 'IIXD.DTE. 3 DTL,'$DT ~ 800 TT2,SDT 80 GR.:~DT ~ 207 HTENoSDT 9 4 IF E,DTE CZMP.DTE GR.DTE HTEN.DTE. TT4~$DT ~400 LTT4*6DT ~750 MTEN,SDT ,~50 DT'ZTP .250 GFCO,RECi NPOR ~NL 999 O0 000 0 400 525 i64 207 H~EN 000 DTLF ,200 T'T4 600 LTT4 000 ~TEM 250 DT ,DTE .DTE ~DTE !,SOT :"$DT 8:'609 I ?0 000 '7~4 400 ;800~ 1260 I$ ?&pc Yerl~AXCat~on LXst'"ng chlumDerqer laslca Comput~nq Center 25"SEP-1990 08~48 DTSM RCNT GR MTEM DEPT. SP IDQ~ XIRD TI DTSM OFSH PEF TENS NPH! RCN~ GR tDQ~, DTE XIRD.,DTEi TENS,DTE LTTt,SDT DTSM,PTE OFSH..REC PEF·;bDT ,bDT b~RH'bDT T·NS.bDT RCNT~NL PTE REC bDT bDT bDT bDT bDT :CNL ~CNL · 4,oo: 69 DTE 33},250 SDT SDT 8,000 'SDT .$]]06800 SDT 69,688 SDT . ~,207 :PTE '. 9 :,250 310,500 bDT 309,2~0 :CNL: 2282,229 :.CML 69,000 .CNL 31~,:'500 ~09,~50 ,2,297 :2090,000 ~26~6,563 75,6i3 $i6:.094 ~999.250 DTSM.ITP -999 999.250 DPHX,LDT 25 3.399 QLS.LDT 373,000 Lb,bDT NTE#.bDT 38,232 TNPH,CNb 2259et40 RCFTeCNL 5 ?o.68e 117,275 HTEN.CNb IDPHeDTE XMOF,DTE XXXD,DTE MTEM,DTK DTL~SDT bTT2,SDT D~SM,~TP DPHX,LDT OLS, bDT bUR T.NPH,CNL RCFT,CNL CALX:~CNb 'HTEN,:CN~ SFLU~DTE 'ZDPH*.DTE XMGF.eDTE XZXD,DTE MTEM,DTE DTL-SDT TT2,SDT DTSM,~TP DPHI,LDT LL~bDT bSHV~bDT LURH,LDT MTE.M*bDT TNPH,CNL RCFT.eCNL CAbX,¢NL HTEN,CNL !0 RSHC,REC. -999.250 OFCO,REC :01_~ RHOB,LDT '2.22~ DRHO.bDT OSS.bDT "0.006 LS.LDT ~XTH*LDT -X11,06~ $ Z,LDT [~ '5SHV,bDT 1354.000 $$~H,LDT CALI'bDT $3.039 GR.bDT 15~ ,RES~LDT 2.t88 HTEN~LOT TNRA*¢Nb 3,469 NPOR.¢Nb CNTCeCNb 1908.594 CFTC,CNb 0 TENS*CNL 2204.000 MRES.CNL CZ DP., D~E~MPH* DTE 1~ 4 C XNP, DTE 156 87 XXRM,OTE 20~ GR.D~E MRES', DTE '~ 2 HTZN. DTE DTLN~&DT ttO .200 DTLF TTS,6DT iO0l 600 TT4.SDT DT,'PTE -999.250 DT,XTP RSHC, REC -999,250 QFCO.eRE~ RHOB~LD~ t3~41.4 .2,291 DRHO, bDT QSStLDT' :0,001 LS'LDT LXTHeL~T :98,~50 SSt,bDT S..~HV,L T TGR*LDT NPOR,~NL T N R k ;, C N b CNTC;,CNL: 2037,827 CF~C,CNL TENS,CNb 2~$0,000 NRESeCNL . :E. *O E:::. 2,21.7 HTEN,DTE ' DTL.NISDT il2,000 DTLF;'~DT . ..:ooo TENS'* BDT~ MTEM,'SDT QFCO~ RE~. OSS,~DT: bS: DT ~bDT LXT"~ . ..96438 H TNRA, CNL .~ ~g NPOR: CNL. CNTC,CNL 222 ~ 26~ CFTC~ CNL TENS,.CNL 2080 .000 MRES. CNL "999,250 50O 250,000 o9° 605 500 38 835 534 906 2 188 6328 20 000 163 750 64 · 9 400 77 600 12g~ 600 '5!9;000 4~.;755 565,273 .2.~88 · ~ 086 °°° 1 186 i 0 :~00 ,200 ,344 0;02~.~. .; 7~0. .,~03 , $ 93. c~lu~erger las~e ¢oe~u~J,n~ Cen~er 25-$EP-1990 08=48 2O DEPT : 4300.000 SrbU DTE 8.4)8 ILM.DTE 8 95 lbo DTE 9.375 $P DTE 77.063 XDPH.DTE 9,477 XMPH.DTE 8 34 IFRE DTE 20,000 IDO~ DTE 0,000 I#~F DTE 0,0~0 CIDP,DTE. 105 38 CZMP DTE 1~4.375 IlRD DTE 94.500 IlXD.DTE ~.070 iIRM.DTE 108 88 GR DTE 85.t88 TENS DTE 323.750 MTE#.DTE MRES.D?E 1/~t; OO!) ,TK# DTE 923,$00 DT SDT t~T,iO0 DTLiSDT i08.800 DTLN,SDT DT~F 6DT 3300500 TT1;SD~ 80~,600 TT2~SDT 5TO,fPO TT ,SDT 1040;000 802,400 ~TTI~SDT IT4 SDT LTT4~SDT ~36e,400 LTT2iSDT ~ II~ - GFCO,REg -99g,250 RSHC~REC: Q.SH~REC 999..250 PHI.LDT RHOB~LDT o~.~ DRHO.LDT . 0,002 bSRH,~DT · 20307 ~URH,LD~ CAbX,~DT~ ..,... GR,~DT 87,438 TENS,LDT 2035,000 #TE'HeLDT MREBoLDT 2,..21) HTEN.~DT 523.500 NPHI,CNb . 35.384 TNPH,CNL i TNRA,CN~ 3,328 NPOR,CN~ 36.221 RCNT,CN~ 2370,~75 RCFTsCN~ CNTC,CNL 2t13,'348 CF~C.CNL 645.030 GR,CN~ 87,438 CAL~,CNL TEN$,CN~ 2035.~00 MRE$.CNL NTENeCN~ ~.15,75~' H~ENeCN~ .. DEPT'~ 4200'000 SF~U'DTE 17.484' X~M*.DTE 24,.28~ ZLD~DTE 32,?$0 4 *:9}~ XDPH,DTE .MPH,D. XDQ~,DTE IMGF,DTE . 9[8 GR~DTE 1,24~: XIRN,DTE. 63,063 T.'NSi.D~E 328,~50 MIEM,DTE MRES',DTE HTEN~DIE 888,000 . .,30 DTLF*$DT ~5~,200 :DT,'SD? t26*.eO0 T ,SOT TT!eSDT 808.800 TT2,SDT TT3,~DT TT4,~DT ~TTI,:SDT i362.000 ~TT2,SDT: ! ~TT3,SDT: 1647-200 ~TT41~'SDT 1366,,000 NR~S*SDT DT*PTEi ' .D~,~I~P -999..250 HTEN'eCN~ DEPI ,DTE O, ~SDT ,SDT ,SDT ooo 'Sr~U:'DTE 000 IMOF,DTE 000 IIXD~DTE 60 DT~,$D? TT. ,.430 iFRE~DTE GRDTE ~008,800 LTT4,SDT i56~,20;0 TT4,SDT '30 ,:~50 MTE~,$DT 999,250 DT,.ZTP :.20,000 134,*:'500 83'813' 999,000 104,500 772,000 ~!395,600 ',6,9 8 chlum=erger Alasl<a Comput!ng Cente; 25-$EP-1990 08148 21 D~SM.PTE PE~obDT bDT bSRH bDT TENS;bDT NPHI CNL MTEM CNL 4000*000 115,625 0.000 60,938 ~000 · . 9,200 1459~00 1043~0C0 1880 OC*O 42 1~4 0t,9 -999.250 DPHI:LDT ~T,~5 RHOBebDT .~:364 DRHO.bDT 013 29~:009 3 bDT 6 bS.bDT 750 $$HV bDT 13 :000 $1RH.LDT 82.305 .750 L?HV.LDT 1345'3 8 ~LDT 797 ~96~;342 bURH,bDT I~:4~3 CAb! GRebDT 125 ,000 NTKM.bDT MRESebDT ~:232 HTEN.bDT 561~500 I , 043 CAbI,CNL 13, 97 TEN$.CNL 1965.000 MRES.CNL 232 1t4,46] HTEN,CNL 561,500 XMPH.,.DTE XFRE. 20.000 CXDP,DTE CX~P. XXR#,DTE 45,625 HRE$i:DTE 927,500 DTbN*SDT 93,500 $rbu IDPH IMGF DTE IIXD D?E NTEM DTE DTb SDT TT2 DT DPHI.LDT ObS~bOT Lb. LOT bSHV,LDT · URHtb T TNPH,CNL RCF~,CNL H~EN,CNL ' DT,PTE 9 ,250 RHOB. LDT: 53~,O00 14 070 DTE 14 !02 DTE 61 438 DTE 67 375 GRDTE 2 236 HTEN DTE ,~)~ 500 DTbF SD? i 098~400 114 &DT 62~ :600 bTT4 SDT 3~6;250 MTEM SDT 999.250 DT 999,250 GFCO;REC 1,604 DRHO,LDT .0.008 LS,LDT 436;500 ~352,000 $1RH*LDT HT'EN,LDT CFiC,CNL 1880,000 840;000 1457.,200 .116.825 .999,250 999.250 -0 O0 1096 0~0 2~3 750 47 000 2 XDPH,DTE LTTI,SDT 1.345,600 bTT2,SDT 1 RSP,:SDT :I07,813, GRiSDT I N E$~SDT , .2t~ ~$~ HTENeSDT '$S~,LDT .299,150 LSHV. LDT bDT TE~$,bDTGR,CNL I96~:~0 · MTE~.LDTLURH'bDT ~I NPHIeCNb .2~0,898 TNPH~CNL RCNT.CNL 2 1,:340 RCFT:CNb 1i3,33§ .TEN CNL MTEM.CNL '.6 .e567 ~ALX~CNL ! P'i DTE MR.SiD:. LT,i:,SDT }~ bTT4,~DT TEN,,DT. D,,~TE. ;999 ~! DT.~TP RHO~,bDT 0 DRHO,bDT LITHibDT :?6;o~e $~1 $SHV,LDT t352,000 $1RH LOT bDT hDT TNRA',CNb ,6: CNL C~TC,CNL 200~,5~t NPOR TENS,CNL~ 1865'000 MRE$ . 60, 994,. ~ ~347, ,,999~250 2 0 55 ~ Is Tape Ver~cotlon L~st~ng chlumeerger AlasKa. Compvtlnq Center 25-$EP'1990 08=48 22 TEN,cOTE 000 MTEN~,D~E NRESeOTE HTKNoDTE 10 DT,SDT 700 DTL.,SDT DTLN,SDT 15 : · DTLF.SDT 30 TTt,'SD? 000 TT2.,$DT TT3,SDT #RES,SOT HTEN.,$DT DT,P~E -99[.~$0.. O!.~TP -999 DTS#,PTE DTS#,,~TP -9921~t~,, RSHC,REC -99~250 OFCO,REC -999 tO , : CNTC* CNL:. 9 G~,CNL 1~, CALl, N~ TENS,CNL. :~ DEP~ DTE DTE DTE BDT ,:SDT SOT DT o ,DTE IMOFeDTE '0 8TEN,SOT 9~2 IbM. D? MR. ES~D~' DTLN,SDT TT3,SDT DT~TE RS:H ~R,', CALl,LOT MRES,LDT TNRA,.CNL CNT'CjCNb TENS,CNL 6,094 X~!.DTE . ,DTE 1.064.0 ~: DTL~,SDT . NPOR CNL ~993 ~63:: CFtC '~.740 000 ,~ES b 6*6?6 8~.7 600 !43~ 000 '999 064 MRES,,OTE DTLNe3DT TT ,~ SDT DTo~IE !13' O0 ~9 50 ' E :TT4,~DT LTT4 DT.ITP :~000 4.,7~ 97~. 0 193;.~0§ 85~*000 t558,~00 chlum~erqer lask:a COmPUC 25-$EP-199008148 23 DTSM,PTE ~999.250 DTSN,ITP -999, ~50 RSHC,,REC -999,25Q oreo REC -999~:50 OFSH.REC 999,250 DPHt,bDT 36, ~$' RMOB,bDT 2,218 DRHO bDT -0 PEP,bDT 2,775 GUS,bDT O.O~ GSS,LDT -0,00~ LS bDT 365500 LU.LDTNs.bDT $42.0002 Lb,LDT '1'4' i'-25-!i LITH,bDT ~116.063 SSIGR LDTbDT i89506.8625 SSHV,LDT 15S2,000 SIRM bDT 2262 S2,LDT .t219 LURHeLDT CALZ,LDT RHvbDT 305,000 LSSV,LDT 134~, 1710.000 i~: .RES,LOT 2,285 502 250 MTEM,~DT HTEN bDT NPHI;CNb -24,315 TNPH,CNL : TNRA,CNb 2,604 NPOR CNb 25 257 '.,ooO.° '"'" !i '"'" 20,000 I!RO,DTE r, IE ClDP,O~E 58,144 CI ,Dig 71,625 l!! ~EN$,DTE MTEM,DTE MREIjOTE . '099§,~50 .DTSMeITP OTS ,'eTE 9~: 921'~80FCO,REC 999,250 CALt,LD~ i2.~1~ GR:,LDT 506~ C~C,CNb !05 M~EM,CNb o,,,.. ,, i !' o_ o, o, o S~,~ TE ' I 5 0 b' T ~ 1, 1 ? 1 ?, 600 ~REa,SD~ . 2,~14 PEF bDT TENS LOT 000 bDT ...~ .~2o,,o? b i10,91.. LTT~SDT 'GR,SDT HTEN,,DT lO~l DTSM,;XTP DPHX,LDT LL, DT LSHV,~DT !34 bURHibOT MTEM~LDT CALItCNb HTENeCNb 5 ~RES DTLN RSHC RHOB LITH TNRA CNTC TENS DTE DTE DTE ~DT CNL 2C.0 il.oo 0¢0 O{ CI~ OFCO DRHO ~iRH HTEN POR TE ,, 25~453 44, 063' 10i7~000 161'~200: ,.,,,~oo . 3~ O0 18$ 250 2 242 42 504 250 .'::20 660 : :hlumeerqer AlasJ~a Compu~inq Center 25-$EP-!990 08;48 PAGEI 24 o~, ,~oo.ooo ~r~u'~ l:~!~ ~,.o~ ~,o~ ~.o~ ~.~o I~PHeDTE 9, 97 20.000 IDGF.DTE 0,000 I*GF,DTE 0.~9~ CIDP, DTE *Oa.e75 CINP.DTE 107.500 IlRDtDTE .94.$13 ZIXD,DTE 4. 9 IZRH.DTE GR.DTE 56.094 1{3, 3l ~ ,RESsDTE ~ ' .~ 2 HTEN.DTE 944.500 TENS.DTE 269,250 NTEM,DTE D?,SOT t39.200 OTb,SPT I e 0 DTbNeSDT DTbr.SDT 14~.500 TTI.SDT 847~600 TT2eSDT i~. ~ O0 TT3,SDT 1135,600- TT4.SDT 856.000 6,400 LTT36$DT bTT4.SDT 1528.400 bTT!,$OT 1544.400 SPeSDT 159,375 GR~SDT 56.094 TENS,SOT 269,250. MTEM.SDT I!3,338 M~E&oSDT HTEN~SDT 94*t~ '1il .DT. PTE'~ :999.250' DT.ITP kS.bDT -999,250 344,250 -9 ~, . RSHC, REC. 999.250 GtCO.AEC -999.250 DTS#,PTE 0999~250 DTSM,~TP RHOB,~ '~255: DRHO,~OT -0,006 }~ 4.7S0 : -0.004 l~'~'~aO=i bITH:i~ T ,104,000 SSI,bDT 190,625 :2,~50 bSHV,LDT' ~SHV,LDT l)5g,O00 ;I~H.LDT 2.273 TENS,bDT tS20, O0 ~EM, D. CAL~',LOT .I$,000 GRv~DT 48~,750 GR,CNL '5~,344 A ~, NL O0 0.. ~000 b~T~i.SDT 12~0,~0. LTTI,~OT: .1958,800 LT~4,SDT ~,,~.sD~ ~to,o. oo .~,~o, ,o.62s~l~ 8 H..EN, ' .DT*P~E: ~ or~:ti~: '999,250 . .,. ,.,~ ,~ ~; .~ ..,~ -~,'"" - -999,250 CALl*bDT . .GA,bDT N~HI,'CNL ',20 649 TNPH:JCNL TNRA,.CNL ~ :2 36.. NPOReCNL 19,987 CNTCoCNL 3~91 {89 CFTCoCNL · SP,DT£ ~190 625 iDPHiDTE IMIH O~Z 12 336 IF E,DTE 0 l~Or DTE 0 000 lHgr D?E ' O0 Cll)P OTB 66 695 CIMP,DTE :000 TT, SOT LT!~3 SOT 2357 200 LTTiOSDT 1605 ' O0 . HTEN SDT )T,PTE DToITP MAES SOT ]::6 Tape verLtLcation b:Ltt~ng Chlumberger Alaska Compu~:lnq Center 25-6EP-1990 06=48 25 QFSH REC ~U bDT -999.250 DTSM.ITP "999,250 DPHX,~DT ~2,869 QLSeLD~ .20~ 36t,000 2~182 LURH~LD~ 1465.000 MTEM,LDT .26 758 TNPH,CNb 1035 3%34 047 RCFTmCNL 108 838 HTENoCNb RHOBtbDT ,~88 DRHO bDT O, O$6.LDT 0,002 LS LD~ 390,000 ,500 i95,125 CALX bDT 0952 GR bDT 61, NRE5 bDT .350 HTEN bDT 495.000 TNRA CNL ,786 NPOR,CNb 26.688 c. c .o 4 cv c.c. _6000 iDPH~)TE 70,000 DTb, iDT t' GRi;SO- o DTSM~ZTP 14~ ,ooo ~,~D~ 20~ ,25? RCF~ CNL l ,o 5,{ o · H~EN CNL ! Q XIRD TEN~ 0rS ,'REC PEr,bDT NPHX !Nb RCN? .NB GR Nb M?EM CNb t1'422 ILO,DTE CXNP,DTE 820875 GR;D?E .2.354 HTEN,DTE ~40,$00 ~1260400 'TT4,~DT 18~g,:200 LTT4'SDT .252.500 MTEM.SDT :999,250 999;250 OFCO,~,C '..2,237 DRHO,L~T "OiO0~ bDT 155~.000 SIR! ,bDT 6,3 7 HTi~ ''bDT cO006 3~ 000 O0 CIDPtDTE I .250 Cl~ ,DTEMP TT4,~LDT RSH~REC RHOBeLDT :2..~14 DRHOoLDI SSi bDT CALX,LOT '13 563: GR MRES,LDT 2 336 HTEN bDT CNTC',CNL CFTC,CNb TENS,CNL MRES,CNb 6 238 20 000 184 625 54 06'3 1:006 000 125 100 838 800 tS~, 200 .11~. 8!9 999 250 '0 oo~ 3t 4 75 ! 9,3 i e ? 5 26277 58'~!3 5~7, O0 .45,373 464,074 2,336 chlUmberger' &$1<a ComPut ng Center 25-$EP-1990 08=48 26 DTE iIRD~DTE TEN$.DTE DT 6DT TT1 BDT BDT DTSM PTE OFSN REC PEF bD bU LSRH,bDT TENS,bDT NPHXeCNL RCNTeCNL ,. DEPT SP DTE I~QF DTE IIRD DTE TENS DT£ .DT SDT TTt. SDT SP MRES~SDT DTSM'P~E QFSH,REC PEF~ bDT . DEPT : XDQF DTE iI~D DTE TENS DTE DTSDT TTi$DT LTT~.SDT 2800 000 SFbU,DTE ;5.703 l~lq DTE 24 734 IbDeDTE 250 26 469 0 000 ~ ~ ~NG~D~E C1~P DTE 29 5~8 CI~P~D~E MTEM.DTE : .~T MRES DTE. 357 DT~F.~DT t86 600 DTL,~DT TT3,SDT ~340 000 TT4.SDT 1806 ,800 LTT2,SDT ~$16eO00 ~TT3'SDT 2123 600 LTT4,SDT t?8~250 GR,SDT 46,03t TEN~.SDT* 245;000 HTEM,SDT .~ 57 HTEN,SDT .93~,0~0 DT,PTE' -090.250 -99~,a50 990,~50 8SHC*REC. -999,~S~ OFCO,REC 0999,~50 PHI,bDT 304,500 LSHV,LDT MTEM,LDT 190 4 ' MR 8i T HTKN,LDT ~07, 44 HTEN,CNL 2700.000 &FLU DTE 0,4 3= XLMoOTE. t2'469 XLD'DTE 255,3~ XDPH DTE 195000 0 ZHPHeDTK i2,609 XFRE,DTE -88,8t~ CZMP,DTE CXDP.DTE -??,:18~ :76,00u IIXD DTE l ZRM, DTE GR e DTE 24 ,~ 5 MTEM DTE lJl,8 9 ~RESeDTE' 2,330 HTEN,DTE 6~,~0 DTb SDT :~ :~ DT~N,SDT 724, 0 bTT2 .SDT 6 1,:2 0 bTT3,SDT 2~22.400 ' .9~l ' MTEM*SDT OFCO*AEC DTSM ~TP ?00 999 -999 -999 *:999 -999 -999 -999 0999 0999 000 ~FLU'DTE :250 IDPH,~E -99! 250 :250 IIXD,:.:TE 250 MT£M,DTE 250 DTL,~DT 250 TTi~SDT ~SDT '99i R,SDT IM~H'DTE,DTE: :CIDP'DTE 'IIRM~DTE TT3,SDT ~TT~,S'DT TENS SDT DT. PTE -999,15~ ID .999,~5o H -999;,~50 GTT4 -999.~50 DT )TE BDT 3! 156 000 75O 46 I 09 600 -999250 · 1950.000 20,000 79,~50 9!8,000 6750800 506,800 928,800 .999,250 999*250 -0.889 I~4 500 448 863 354~93 · .2 355 * 9'25~ '999 .~999~250 '99 ~.150 -99~ 150 -99~, 50 IS Tape Verif!cation Llst~nq 25-$EP-1990 08=48 PAGE= 27 chlum~erqer AlasKa Computlnq Center DTSM.PTE -999 250 DTSM,~TP -9~.'50 RSHC.REC -999~5~ QFCO.REC -999.250 QFSH.REC -999 250 DPH! bDT ~. :97 RHOB,LDT ~.838 DRHO.LDT -0~955 PEF,bDT 50 813 Gb$ bDT v .09 G$$ebD~ -0.1t~ b$.LDT 140.500 8~2.LDT 87 43e ~HV LD~ 13~. ~355,000 $1RH.~D~ 4,758 ~ CNTC~CNL RCNToCNL 490~38~~ RCFT CNL 3~ ~~ 1465,567 CFTC.CNL 380.149 XMPH~DTE XDOF.D?E -0999,250 X#OF,DTE CIDP,D'.E -999,250 CXM..DTE #RE$~DTE~ -999,25Q HTEN.D~E -999250 · 9 '~2 MTEM~DTE DT,'SDT .9E2, DTLN,SDT~ -999,2$o DTLF.SDT -999 250 TTI.SDT --999,250 TT2,'$DT LTT],SDT; -999.250"999'~50 bTT4.SDTTT4*SDT:999250999250 LTT1 ,~DT -999,250 LT.2 ,SDTDH '990' 2!0~ '-999 250 _'Sg,6DT ,.999i250 GR,SDT -999, TENS,SOT: -999,250 MRES,$DT .0999,250 HTEN.$DT -9~9. .DTGPTE -999250 -999250 RSNC,RE.C: OFCO.REC -999 250 D~SN,P~E ,999,250 .P~,2~P '999 250 -999,250 PZ~LDT RNOB,~DT 3 874 DRHO,LDT .-0 966 "SS' ,L ~ bSHViLDT SSHV,~DT ~:35( 000 ~IRH",~DT 4 6 CA~Z,[DT CNT ,, .. RCN?;CNL 1592.9~6 RCF~,CNL FILE NAME DI ~001 $~R¥ICE. '~ l ~AX R~C SiZE 1o2 FILE TYPE LAST FILE chlumeeroer Alaska Computinq Center 25-SEP-1990 08)48 PAGEI 28 DATE t 90/09/25 ORIGIN ~APE N~M~ , 7407, C_ONTINUATXON ! PREVIOUS TAPE COMMENT t MARATHON, TRADING BAY, 'TBU M-3, AP! #50-?33-2041! $~RVICE NAME t ~DIT- COM#~NT i MARATHON, TRADING BAY, TBU Me3~ APX ~50-733-204~1 AbABKA COMPU?ING CENTER ~ COMPANY NAME BOROUGH. _ AP! NUMBER REFERENCE RECEIVED OCT ~ ~ iSSO 'IdlI, CROF'LILLM E D LIS Tape Verification Listing Schlumberger Alaska Computing Center l-AUG-1990 19144 **** REEL HEADER **** SERVICE NAME ~ GEOLIS DATE : 90/0B/01 ORIGIN ~ FLIC REEL NAME : 73995 CONTINUATION # ~ 01 PREVIOUS REEL ~ COMMENT : RESULTS. MARATHON OIL CO,, TRADING BAY. TBU M-3 **** TAPE HEADER **** SERVICE NAME : GEOLIS DATE : 90/08/01 ORIGIN ~ FLIC TAPE NARE ~ ?3995 CONTINUATION # ~ 01 PREVIOUS TAPE ~ COMMENT ; ?$995 PAGEI FILE NAME ~ SHOT ,001 SERVICE ~ GEOLIS VERSION = 002E07 DATE { 90/08/0t MAX REC SIZE { 1024 FILE TYPE ~ FS LAST FILE : COMPANY NAME: MARATHON OIL COMPANY FIELD{ TRADING BAY BOROUGH: KENAI STATE{ ALASKA bOCA?ION: 103g' FNL & 602' FWL SECTION{ 33 TOWNSHIPS 9N PERMANENT DATUMi MSL ELEVATION:O' RANGE: 13W LIS Tape Verification Listing Schlumberger AlasKa Computing Center 1-AUG-1990 19:44 LOG MEASURED FRO~ KB 160' ABOVE PERMANENT DATUM ELEVATIONS KB: 160' DATE LOGGED= RUN NUMBER= TD DRILLERS 2?-dULY-90 2 7142' CASING lz 13 3/8" 9 DRILLER DEPTH OF 0' TO 2713' BlT SIZE lZ 12,25" IN HObE~. PObY PLUS G TYPE FLUID DENSITY. 9.55 'VISCOSITY~ 46 FLUID bOS8~ 6.5 MUD RE$ISTIV TYI FILTRATE RES~ V STI ITY~ MUD CAKE REGISTIVITY= 4,88 $ 69 5.144 @68 4, ~ 65 TIME LOGGER ON BOTTOMt 10~30 27-JUL-90 MAXIMUM'TEMP RECORDED~ 132 LOGGING DISTRICT= LOGGING ENGINEER= WITNESS~ KENAI T.SMITH BOEDEKER / UNDERWOOD PAGE= DATE JOB STARTED) 30-jUL-90 JOB REFERENCE NO= 73995 LDP/ANA: R, KRUWELL COMPUTING CENTER REMARKS~ 1,) FI~68 ,SHDTTo ~g~'CONTAINS 4' X 2' X 30 MSD RESU5TS OF REPEAT FILE'FROM 2,) FILE SHDT,O02 CONTAINS GAMMA RAY DATA OF REPEAT FILE FROM 6800.' TO 6400' 3 ), FILE.SHDT,O0~ CONTAINS 4' X 2' X 30 MSD RESULT~ OF LOG FILE FROM 7086' TO 27t2' ' ~) RILE SHD?~O04 CONTAINS GAMMA RAY DATA OF LOG~IL'E FROM 7086' TO 2712' 5,) AL~ PATA .AS BEEN SPBED CORRECTED AND ZNCLINONETR¥ DATA .HAS BEEN CORRECTED FOE 23,27 DEGREES MAGNETZC DECLZNATZON~ TABLE TYPE = CONS TUNI VALU DEFI CN HARATHQN OIL COMPANY COMPANY NAHE WN TBU M-3 WEbL NAME FN TRA.DIN9 BAY FIELD NA~E FL ~0,39' fNL & 602' FWL FIE~D LOCATION STAT ALASKA STATE OR PROVINCE , SLIS pe verification Listing chlTuam~erger AlasKa Computing Center I-AUG-1990 19:44 PAGE~ 3 TUN! VALU DEFI COUN KENAI COUNTY NATI USA NATION SECT 33 SECTION TOWN 9N TOWNSHIP RANG 13W RANGE CTRY USA COUNTRY TABLE TYPE = CONS TUNI VAbU DEF! ENGI T.$MITH WITN BO~DEKER/UNDERWOOD MRT DEGF 132, ~E~ DEGF 60. NT 07 YEAR RUN 2 REF 73995 DATE 27'dULY-90 ENGINEER'S NAME WITNESS' NAME MAXIMUM RECORDED TEMPERATURE SURFACE TEMPERATURE DATE MONTH DATE ' DAY DATE - YEAR RUN NUMBER bOG PARAMETERS TO BE RECORDED RUN DATE TABLE TYPE : CONS TUNI VALU DEFI MDEC DEG 0,' MAGNETIC DECLINATION MFIN DER O, MAGNETIC FIELD INTENSITY MiNC DEG O, MAGNETIC INCLINATION SHD'$ A STRATIGRAPHIC HIGH RESOLUTION FCDD i FAST CHANNEL DEPTH DEFINITION SOFF IN *~', STAND-OFF OF THE TOOL'-STRING TABLE TYPE = CURV DEFI DEPT DEPTH CHANNEL NAME R OUAF DEVI HLAZ CCRE AZI! RB C! DIP TRUE DIP AZIMUTH OUALITY FACTOR (SHDT) DEVIATION DEVIATION AZIMUTH CORRELATION CURVE RESISTIVITY AZIMUTH OF PAD 1 RELATIVE BEARING CALIPER 1 - 3 ~IS ~a e Verification Listing chi m~erger Alaska Computing Center 1-AUG-1990 19144 DEF! C2 CALIPER 2 - 4 bKMX MAXIMUM bIKENE$$ CO COMBINED OUALITY S12 SHDT DISPLACEMENT 1 - 2 823A SHDT DISPLACEMENT 2 - 3A 634A SHOT DISPLACEMENT 3A - 4A 84A! 8HDT DISPLACEMENT 4A - 1 613A SHOT DISPLACEMENT 1 - 3A SC SPEED CORRECTION RAD! RADIUS ! OF BOREHOLE RAD: RADIUS 2 OF BOREHObE RAD RADIUS, 3 OF BOREHObE RAD4 RADIUS 4 OF BOREHOLE DPL1 DIP PLANE COEFFICIENT 1 (SHDT) DPL2 DIP PLANE COEFFICIENT 2 (SHDT) DDOR · DIP DISPERSION QUALITY RATING (SHDT) PAGEI DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 o 104 4 66 ! 5 66 ? 6 8 ? FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** ------- i---------------------- NAME S RV UNiT SERVICE API PI AP1 A. PI F bE NUmB NUMB SIZE REPR PROCESS D ORDER # LOG TYPE CLASS MOD N MB SAMP'EbEM CODE CHEX) DEFT MBDO FT O0 636 21 0 [ 1 1 4 68 0100000000 DPTR "SDO DEG 94 61 Oi 0 i 1 1 4 $$ 0100000000 ', ~ ~ ~ ~ ~ o~oooooooo LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-AUG-1990 19:44 PAGE{ NAME SERV {)NIT SERVICE AP1 APl AP! API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE CHEX) DEVI MSDO D£G H~AZ MSDO DEG CCRE MSDO AZI1 MSDO DEG RB NSDO DEG MSDO IN bKMX MSDO CO MSDO $ 2 MSDO $~31 MSDO S~A MSDO ~3A MSDO MSDO RAD1 MSDO IN RAD2 MSDO IN RAD3 MSDO IN RAD4 MSDO IN PPbl MSDO PPb2 MSDO DDQR MSDO O0 000 O0 0 76 62O O! 0 O0 000 O0 0 94 935 O0 0 O0 000 O0 0 76. 63! 0 0 70 280I 0 70 280 ~4 0 O0 000 O0 0 O0 000 O0 0 O0 000 O0 0 O0 000 O0 0 O0 ~o9 oo o oo yOU O0 0 O0 000 O0 0 O0 000 O0 0 70 280 41 0 70 280 42 0 o 7O 0 OO O00 O0 0 O0 000 O0 0 O0 000 00 0 68 0100000000 68 0100000000 68 0100000000 68 0100000000 68 0100000000 68 0100000000 66 0100000000 68 0100000000 68 0100000000 68 0100000000 68 0100000000 668 0 00000000 i oOOOOOOooooo 00000000 O0 0 000 .o oooooo o 68 01000000 ~6.80100000000 ~,~ 0100000000 680100000000 680100000000 680100000000 DATA DEPT MSDO DEV! MSDO RB MSDO MSDO NSDO DEPT,MSDO 64014720 DEVI,MSDO 32,500 RB,MSDO 156,000 4CO.MSDO 1;000 .~SDO 7,800 DPb2.NSDO "8,324 6797,720 DPTR,MSDO 6~:800 29,800 HLAZ,MSDO ~0 136,000 Ct.~MSDO 11, 0 !,000 Sl2;MSDO .~,~00 6.500 Si3A,MSDO 0 5'900 -5,173 DDOR,M&DO 38,800 DPTR,MSDO HLAZ,MSDO CI'MSDO SI2,MSDO Si3A.MSDO RAD3'MSDO DDOR'~SDO DPAZ'MSDO CCRE,MSDO $23A~MSDO SC,MSDO RAD4;.MSDO 14.800 .DPAZ.MSDO 59,000 CCREeMSDO '200 C2,:~8D0 1~100 'S23A,MSDO -10,600 SC,~SDO 6.100 RAD4,.MSDO 45'400 . 85,000 QUAF MSDO 999,250 AZII MSDO ,11~800 LK~X MSDO 8,900 $34A MSDO 1,000 RADI MSDO 5~900 DPb! . 94 999 12 '999 0 6 000 QUAF.MSDO 250 AZIi.,MSDO 100 LKMXeMSDO 900 S34A.MSDO 970 RADI.MSDO lO0 DPL1.MSDO END OF DATA 20,000 92. 000 ,900 6,159 20,000 21~',000 ,~00 3, 00 , 83 bls Tape ~erification 6isLing Schlumberger Alaska Computing Center **** FILE TRAILER FILE NAME SERVICE VERSION t O02EO? DATE t 90/08/01 MAX REC SIZE ~ 1024 FIbE TYPE IF$ bAST FILE FIbE NAME I SHDT ,002 SERVICE ~ GEObIS VERSION ~, O02EO? DATE I 90/08/0i MAX REC SIZE t 1024 FIbE TYPE IF$ bAST FIbE. ~ 1-AUG-1990 i9=44 PAGEI 6 COS.GAR010,O01 GAROIO,O0! TABLE TYPE ~ CONS TUNI VAbU DEF! CN WN FN Fb STAT COUN NATI ECT OWN RANG MARATHQN OIb,:iCOMPANY TBU AbASEA KENAi USA 9N COMPANY NAME WEbL NAME rIgbP NAME. FIEbD LOCATION STATE OR PROVINCE COUNTY NATION SECTION TOWNSHIP i3W RANGE CTR¥ USA :. COUNTRY TABSE TYPE I CONS TUNI YAbU DEFI ENG! T.SMITH WlT~ BO~DEKER/UNDERWOOD MET DEGF 13", STE~ DEGF 60, MONT 07 DAy .27 YEAR 90 ,ENGINEER'S NAME WITNESS' NAME MAXIMUM RECORDED TEMPERATURE SURFACE TEMPERATURE DATE - MONTH DATE - DAY DATE - YEAR ~IS Tape Verification Listing SchlUmBerger Alaska Computing Center 1-AUG-1990 19:44 PAGE~ ? TUN! VALU DEF! RUN 7 23995 RUN NUMBER REF bOG PARAMETERS TO .BE RECORDED DATE 27-dULY-90 RUN DATE TABLE TYPE ~ CONS TUN! VALU DEF! MDEC DEG 0, MAGNETZC DECbINATZON MFZN OER O, MAGNETZC FIELD ZNTENSZTY MINC DEG 0 MAGNETIC INCbINATZON SHDS A' STRATIGRAPHIC HZGH RE$ObUTZON $OFF 'ZN STAND'OFF OF THE TOOL"STRING TABLE TYPE ~ CURV DEFI DEPT DEPTH CHANNEb NAME GR GAMMA RAY DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR.CODE .VALUE ll 66 128 12 68 i3 66 0 14 65 FT 15 66 68 ~6 66 0 66 LIS Tape Verification Listing SchlUmberger AlasKa Computing Center 1-AUG-1990 19:44 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API APl API FILE NUMB NUMB SIZE REPR PRDCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbEM CODE (HEX) DEpT SHSC FT O0 636 21 0 2 1 1 4 68 0100000000 OR SHSC GAPI 30 310 O! 0 2 I 1 4 68 0100000000 PAGEI DATA ** DEPT.$H$C 6799.550 GR,SH$C 86,313 DEPT,SH$C 6700.050 GR.SHSC 90,188 DEPT,SH$C 6600,050 GR,~HSC 103,813 DEPT,SHSC 6500,050 GR'SHSC 65,063 DEPT,$HSC 6400,050 GR,SHSC 51,063 END OF DATA **** FILE TRAILER **** FILE NAME : SHDT 002 SERVICE ~ GEOLIS' VERSION : 002E07 DATE ~ 90/08/01 MAX EEC SXZE : 1024 FILE TYPE ~ FS LAST FILE ~ **** FILE HEADER FILE NAME i $.HDT ,003 SERVICE : GEOLI$ VERSION ~ 002E07 DATE { 90/08/01 MAX REC SIZE : 102,4 FILE TYPE { FS LAST,FILE MSD.MSDOUT.O02 MSDOUT,O02 Sch! . rger Alaska Computing Center 1-AUG-1990 19=44 PAGE~ 9 TABLE TYPE = CONS TUN! VAbU DEF! CN MARATHPN OIL COMPANY COMPANY NAME WN TBU M-J WELL NAME FN TRADING BAY FIELD NAME FL 1039 FNb & 602' FWL FIELD ~OCATION STAT ALASKA STATE OR PROVINCE COUN KENA! COUNTY NATI ' SECT ~IA NATION SECTION TOWN gN TOWNSHIP RANG 13W RANGE CTRY USA COUNTRY TABLE TYPE = CONS ENG! MAT STEM MONT DAY YEAR RUN REF DATE TUN! VALU DEGF DEGF DEFX T-SMiTH ENGINEER'S NAME BO~DEKER/UNDERWOOD 'WITNESS* NAME 132, MAXIMUM RECORDED TEMPERATURE 60, SURFACE TEMPERATURE 7 DATE ' MONTH ~7 DATE - DAY 90 DATE - YEAR ~3~95 RUN NUMBER LOG PARAMETERS TO BE RECORDED 27 JULY-90 RUN DATE TABLE TYPE = CONS TUNi VALU DEFI MDEC DEG 9, MAGNETIC DECLINATION MFIN OER O~, MAGNETIC FIELD iNTENSITY MI'NC DEG A' MAGNETIC. INCLINATiON SHD$ STRATIGRAPHIC.HIGH RE$OLU?ION FCDD 'I1', FAST CHANNEL DEPTH~DEFZN/TION $OFF IN STAND-OFF OF THE ,TABLE TYPE = CURV DEFI DEPT 'DEPTH CHANNEL NAME DPTR DIP TRUE DPAZ DIP .AZIMUTH LI8 Tape Verification List! chlumberger Alaska ¢omputinn~ Center 1-AUG-1990 19544 DEF! QUAF QUALITY FACTOR (SHOT) DEVI DEVIATION HLAZ DEVIATION AZIMUTH CCRE CORRELATION CURVE RESISTIVITY AZI1 AZIMUTH OF PAD 1 RB RELATIVE.BEARING C1 CALIPER 1 - 3 C2 CALIPER 2 - 4 LKMX MAXIMUM LIKENESS CQ COMBINED QUALITY 6HDT DIS:PLACEMENT - 3A RAD3 RADIUS 3 OF BOREHOLE RAD4 RADIO8 4OF BOREHObE DPL! D!P PLANE COEFFICIENT 1 DPL2 DiP PLANE COEFFICIENT 2 (SHDT) DDQR DiP DISPERSION QUALITY RATING ($HD?) PAGE) lO DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB'** .TYPE REPR CODE VALUE 66 0 5 1 66 9 12 68 13 66 0 14 65 PT 15 66 68 6 66 66 I Tape Verification bistin~ chlumoerger Alaska Computin Center 1-AUG-!990 19:44 DPAZ MSDO DEG. GUAr MSDO DEVI MSDO DEG HLAZ MSDO DEG CCRE MSDO A~I1N$DO DEG " RB MSDO DEG C! MSDO IN C2 ~SOO ZN bKMX M$DO CQ MSDO $=~3A MSDO 834A MSDO $4A1MSDO &~3A NSDO ~D1 ~DO ~$DO iN ~AD2 M~DO IN RAD~ MSDO IN RA.D ** SET TYPE NAmE $ERV UNIT SERVICE hPI API API API Flbg NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB $AMP EbEM CODE (HEX) ~o~o 2, o~ ~ ~ , ~,o oooooooo ooooo OD o~ ~ ~ , ~,o.~oooooooo o ooo oo o~ ~ ~ , ~ o~oooooooo O1O0O0O00O ooooo OD o~ ~ . ~,o~oooooooo O0 000 O0 0 3 68 0100000000 O0000 O0 0 3 0 3 1 4 68 0100000000 oo°° OOOooo oo°° o ~ I ~ I ~I ~oooooooO~oooooooo ,o o ~ . ~ ~Ioooooooo 00000000 70 80 3 0 0 ~ 4 ~ I 68 01~0000000 ,o ,,o I ~ ,~o~oooooooo ~ ~o ~oooo ODo! I ~ , ~,o~ ooooooo ~.~ .~o ODooo ODo ~ , ,,o,oooooooo DDQR MSDO O0 000 O0 0 ~i i 4 68 0100000000 PAGEI 11 DATA DEPT DEVI RB CO S4A! RAD2 PPb2 MSDO 7083,67:0 DPTR'MSDO MSDO 27,300 HLAZ,MSDO MSDO. 235,000 C1,MSDO ~SDO 3,000 $12,MSDO ~SDO 0,600 Sl3A,~SDO MSDO 5,900 RAD3'MSDO MSDO -2,043 DDQR'MSDO DEPT,MSDO DEVI.MSDO RB MSDO CO MSDO $4A1MSDO RAD2 MSDO DPL2 MSDO 27~,670 DPTR,MSDO '300 HbAZ,~SDO 4 O0 $ ,MSDO -4 O0 S13~ ,~SDO ~:~oo END OF DATA 7,600 DPA MSDO ~o.ooo CCR~I.~sDO 11.700 · C2~$D0 '~3~go0 :::$23A.~MSDO -1'goo , SC,MSDO 5,8~0 RAD4~MSDO .000 .6.200 C2~.$D0 .31~0 :823A,MSDO e 6§ SC'~SDO RAD4e~SDO 23,000 2~8,000 OUAF MSDO -g 9,.250 AZI1MSDO 11,700 LKMX MSDO 1~700 834A MSDO 0,970 RAD MSDO 5.900 DPL MSDO 3 000 AZI1 '6, S34A 0.970 RADI 8~600 DPbt MSDO MSDO MSDO MSDO MSDO =~:ooo · "to~ 5, 2,946 2,000 2g,o00 51,000 7,800 .e',600 4'..211 bis Tape Verification Listing Schlumberger AlasKa Computing Center' **** FILE TRAILER ~ FILE NAME : SHOT ,003 SERVICE : GEOLIS VERSION = 002E07 DATE { 90/08/0! MAX REC SIZE : 1024 FILE TYPE ~ FS LAST FILE : 1-AUG-X990 19:44 PAGE~ 12 ~ FILE HEADER ~ FILE NAME I SHDT $,004 SERVICE { GEOb! VERSION I O02EO? DATE I 90/08/01 MAX EEC SiZE t ~024 FILE TYPE : FS CO$.GAR~[,O0! G~RO 11, TABLE TYPE I CONS TUNI VALU DEFI CN MARATHQN OIL ~COMPANY COMPANY NAME WN TBU M-3 WELL NAME FN TRADING. BAY FIELD NAME rb t03.~ .FNL & 602' FWL fIELD b. OCATION 'STAT ALASKA STATE OR PROVINCE COUN KENA! COUNTY NAT! USA NATION $~CT 33 SECTION TOWN 9N TOWNSHIP RANG ~3W RANGE CTR¥ USA COUNTRY TABLE TYPE : CONS TUNI VALU DEFI E~GI T.$MITH ' W WITN BOEDEKER/UNDER,.OOD MRT DEGF STEM DEGF MONT 07 7 DAY ~0 ¥~AR ENGINEER'S NAME WITNESS' NAME MAXIMUM RECORDED TEMPERATURE SURFACE TEMPERATURE DATE - MONTH DATE - DAY DATE - YEAR chi rger Alaska Computin~ Center 1-AUG-1990 19:44 PAGE{ 13 TUN! VALU DEFI RUN 2 RUN NUMBER REF 73995 bOG PARAMETERS TO .BE RECORDED DATE 27-dUb¥-90 RUN DATE TABLE TYPE { CONS TUNi VAbU DEF! MDEC DEG O, MAGNETIC DECbINATiON AGNETIC FIEbD MFIN OER O, M MAGNETIC MINC DEG INCLINATION EHD$ A STRATIGRAPHIC HIGH R~O~UTIOW FAST CHANNEb DEPTH DEFINITION $OFF IN STAND-OFF OF THE TABLE TYPE : CURV. DEFI DEPT DEPTH CHANNEL NAME OR GAMMA RAY DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VAbUE. ½ o 0 3 79 8 4 66 6 73 ? 1! 66 128 12 68 Ii 66 0 I 65 FT 15 66 68 16 66 0 66 bis Tape Verification Listing Schlumberger Alaska ComPuting Center 1-AUG-1990 19:44 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl APl API AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELEM CODE (HEX) DEPT SHSC FT O0 636 21 0 4 1 I 4 68 0100000000 GR SHSC GAP! 30 310 01 0 4 I 1 4 68 0100000000 DATA ** DEPT,SH$C 7085,838 GR,SHSC 42,031 DEPT,SH$C 6999,838 GR,SHSC 24.766 DEPToSH$C 6899,838 GR,SH$C 63,781 DEPT,SH$C 6799,838 GR,SH$C 77,188 DEPT,$HSC 6699.838 GR,SHSC 94.813 DEPT,SHSC 6599,838 GR,SHSC 98,188 DEPT,$H$C 6499t838 GReSHSC 60,531 DEPT,SHSC 6399,838 GR,SH$C 55.875 DEPT,$HSC 6299,838 GR,SHSC 85,750 DEPT,SHSC 6199,838 GR,SH$C 37.625 DEPT,SHSC 6099,838 GR,$HSC 45,625 DEPT,SHSC 5999~838 GR,SH$C 55,906 DEPT,SHSC 5899,838 GR',SHSC 77,563 DEPT'SHSC 5799,838 GR,$HSC 39.219 DEPT,SHSC 5699,838 GR,SHSC 79,625 DEPT"SHSC 5599,838 GR,SHSC 50,688 DEPT,SHSC 5499,838 GR,SH$C 88,875 DEPT,SHSC 5399,835 GR,SHSC 84,250 DEPT,$HSC 5299,838 GR,SHSC 74,063 DEPT,$HSC 5199,838 GR,SHSC 45,406 PAGEI 14 IS Tape verification Listing chlumberger AlasKa Computing DEPT,SH$C 5099,838 DEPT,SH$C 4999,838 DEPT,SH$C 4899,8]8 DEPT,$HSC 4799,838 DEPT,$HSC 4699,8]8 DEPT,$H$C 4599,838 DEPT,SHSC 4499,838 DEPT,SHSC 4]99,8]8 DEPT,SH$C 4299,8]8 DEPT-SH$C 4199,858 DEPTeSH$C 4099,8]8 DEPT,:SHSC 3999,8]8 DEPT,SH$C 3899,838 DEPT,SH$C 3799,838 DEPT,$H$C ]699,8]8 DEPT,$H$C 3599',838 DEPT,SH$C 3499,838 DEPT,$H$C 3399,838 DEPT,SH$C 3299,838 DEPT'~H$C 3199,838 DEPT,$H$C 3099,838 DEPT,SHSC 2999,838 DEPT,$HSC 2899,838 DEPT,SHSC 2799,838 DEPT,SHSC 2712,338 END OF DATA Center GR,SHSC GR,$H$C GR,SH$C GR,SH$C GR,SHSC GR,$H$C GR,SH$C GR,$HS¢ GR,$H$C GR,SH$C GR,SHSC GR,$H$C GR,SH$C GR,SH$C GR,SHSC GE,SHSC GR,SH$C GR,SHSC GR,SHSC GR,SHSC GR,SHSC GR,$HSC GR,SHSC GR,SH$C 1-AUG-1990 61,688 40,531 88,563 42,750 44,7i9 59,375 68,063 80,500 49,750 82,125 45,125 57,688 55,000 63,813 49,281 48,750 42,'375 58,344 45,438 64,625 47,531 56'406 47,813 56,656 19:44 PAGE= 15 LIS Tape Verification Listing Schlumuerger AlasKa Computin~ Center ~* FILE TRAILER ~ FILE NAME I SHDT ,004 SERVICE ~ GEOLIS VERSION I O02EO? DATE I 90/08/01 NAX REC SIZE ~ ~024 FILE TYPE t F$ LAST F[LE ~ 1-AUG-lg90 19)44 PAGE) :16 SERVICE NAME I GEOLIS DATE I 90/08/01 ORIGIN t FbIC TAeE NAME I 73995 CONTINUATION # I 01 PREVIOUS TAPE I COMMENT ~ 73995 SERVICE NAME ) GEOLIS DATE I 90/08/01 REEL NAME 73995 CONTINUATION # ~ Ot PREVIOUS REEL" l COMMENT I RESULTS, MARATHON OIL CO,~ TRADING:BAY, TBU * ASASKA COMPUTING CENTER * ****************************** COMPANY NAME ~ MAR:R~THON OIL COMPANY WEbb NAME ~ TBU~M 3' NAME I TRAOZNG BAY BoRoFIEbuGH i KENRI' REFERENCE NO : 7399~ RECEIYED O(;l 2 2. 1990 Alm~ 0it & ~s rxms. commission bis ?a~e Yerification blst~nn~ Cen er Sehlum'erger Alaska ComPut t **** REEb HEADER ***~ SERVICE NAME : FSHDT DATE I 90/07/26 ORIGIN : 'CSU REEL NAME I 572526 CONTINUATION ~ I 01 PREVIOUS REEb I COMMENT I SCHLUMBERGER WEbb SERVICES CSU TAPE PAGES **** TAPE HEADER **** SERVICE NAME I FSHDT DATE t 90/07/26 ORIGIN I CSU TAPE NAME ~ 5?2526 CONTI:NUATION # ! 01 PREVIOUS TAPE I COMMENT I SCHbUMBERGER wEbb SERVICES CSU TAPE **** rlbE HEADER **** rIbE NAME I SHDT ,010 SERVICE I PbAY VERSION : 32,2 DATE , 90/07/26 MAX REC S,ZE , 8~92 FIbE TYPE ~ PR bAST FILE ~ DATA FORMAT SPECIFICATION RECORD SET TYPE - 64'EB ** TYPE REPR CODE VAbUE 3 79 1'58 4 66 5 66 ~3.3 6 73 ' 1~ 68 1 66 15 66 16 66 0 66 0 Tape Verification Listing chlumDerger AlasKa Computing Center 1-AUG-I~90 21~41 ** SET TYPE - CHAN ~* NA~ S~V UN~ S~RVXC~ A~ APX APX ~X FX~E NU~ NUmB SXZ~ ~PR ~ROC~SS ID ORDER # LOG TYPE CLASS HOD NUMB SAMP ELEH CODE (HEX) B$ SHDT IN TOD SHDT $ TIME SHDT MS ETIH SHDT S CS SHDT F/HR DIFF SHDT F TENS SHDT bBF HARK SHDT F FNOR SHDT OER FINC SHDT DEG ANOR SHDT DEV! SHDT DEG RB SHDT DEG HAZ! SHDT IN AX SHDT H/S2 AY SHDT AZ · 8HDT RGR SHDT GAPZ R SHDT GAP! TSG $HDT HTE~ SHDT bBF RHTE SHDT bBF MRES SHDT OHHM HTE~ 8HDT DEGC A~TE SHDT,DEGC DTEN $HDT DC/K FCD $HDT IN IHV SHDT F3 ICV SHDT F3 75 75 75 75 75 75 75 75 75 75 75 75 75 75 282 01 0 10 000 O0 0 I0 636 21 0 10 636 21 0 10 636 21 0 10 636 21 0 10 635 21 0 I0 °° i 000 O0 0 _ 000 O0 0 0 20O~ 0 lO 31 O~ 0 ~0 615 02 0 10 615 03 0 10 8 1o 10 Ol 0 o 0 10 000 O0 0~ 000 O0 0 ° ! o ,0 0 0 0 10 · 0 10 ,000 .00 000 00 000 00 5 82 0 75 282 O~~ I I 2 49 8000000000 I I 4 73 ~200000000 I 1 4 68 8000000000 I 1 4 68 8000000000 I I 2 49 8200000000 I 1 4 68 8000020000 I i 4 68 8000000000 I I 2 49 8000000000 I 1 4 68 8000000000 i 4 68 8000000000 4 68 8000000000 4 68 8000000000 I 4 68 8000000000 68 80~0000000 ~ I ~ 68 80 0000000 I ,ooooooooo 8000000000 4 I 16 68 8000000000 4 1 16 68 8000000000 i 68 8000000000 i ,,oooooooo 8000000000 ! I ~ ~9 8000000000 ~ ~ ~9 8000000000 ~ ~ ~9 8000000000 9 8000000000 I~I ~ 4~ ~4oooooooo ~ ~ ~ ~, 8000000000 ~ ~ ~,8400000000 ! I 2 49 8400000000 ~ ~ ~ ~ 8400000000 PAGE: ** DATA ** DEPTH = 6831,500 FEET 250 TOO,SHDT 333453338 T!~E SHDT ~s.~.~~I: ' CS,'$HDT 6 000 DIFF,SHDT 0,350 :TENSeSHDT FNOR';SHDT ~, ~!5 FZNC:,$HDT ~,034 ANOR,SHDT RGR,SHDT 61', 3 GR,SHDT 8 8TSG~SHDT RHTE,SHDT 24.~: ~0 MRE$,SHDT 8 HTEM,SHDT DTEM,SHDT 000 FCD,$HDT ~', 5 ZHV'SHDT ~* DEPTH = 6800,000 FEET 2~93,000 ETIM SHDT 84.ooo~; SHDT HTEN 8HDT , AMTE,S~D~ 42,593 6,938 3,795 8,616 248,000 5~'250 ,oeo LIS Tape Verification bisting Schlumberger Alaska Computin~ Center I-AUG-1990 21=41 BS.SHDT 12 250 TOD.SHDT cs.s. $o :ooo r.o..s.D 0.550 r .CiS.D RB.SHDT 136"090 HAZI SHDT C2.SHDT 7.~ AX.SHDT RGR.SHDT 86e GR.$HDT RHTE.$HDT 282,500 MRES.SHDT DTE~.SHDT 0.000 FCD.$HDT ** DEPTH = 6600,000 FEET 333453429 -0 200 3 502 86 438 I 988 9:625 TINE.$HDT TENS.SHDT ANOR.SHDT AZIN.SHDT RY.SHDT STSG.SHDT MTEM.SHDT IHV,SHDT BS,SHDT 12,250 TOD,$HDT 333453823 TINE,SHOT CSeSHDT 1817,000 DIFF.SHDT ~0.050 TE'NS.SHDT RB,SHDT 137.417 HAZI.$HDT RGR,$HDT 112,563 GR.SHDT 98.~i ST&G.SHDT RHTE.SHDT 312,000 NRE$.SHDT 2. N~EN,SHDT DTEN.SHDT 0.000 FCD.SHDT 9, IHV.SHDT 6400,000 FEET DEPTH = BS.SHD, T 9½~,250 TOD,$HDT C$.SHDT 1,000 DIFFeSHDT FNOR,SHDT 0,550 FINC'SHDT RB,SHDT 156'!02 HAZI,SHDT C2,SHDT 7~686 AX,SHDT RGR,SHDT 47,344 GR,SHDT RHTE.SHDT 3'38'500 ~RE$,SHDT DTEN.SHDT 0.000 FCD.SHDT 6394.000 FEET TOD,SHDT DIFF;SHDT FINC.SHDT HAZI.SHDT AX*SHDT GR,SHDT NRE$,SHDT FCD.SHDT DEPTH = BS.SHDT C$,SHDT FNOR.SHDT RB,$HDT C2,SHDT RHTE,$HDT DTEN,SHDT 3334~.~06 0 5 3334~.4217 ,.2~;0 .73i2~'5 60~:293 4,392 .2,008 9.625 250 000 550 i 9 o00 ANOR SHOT AY SHDT . SHDT T~ME SHDT TENS SHDT AN'OR SHDT SHDT SHDT SHDT SHDT I~. END OF DATA 989.000 ETIN.$HDT 2920.000 MARK.SHDT 9.772 DEVI SHDT 60.314 C1SHDT 3,339 AZ SHDT 176 HTEN SHDT S 0 AHTESHDT 1013,000 ETIM,SHDT 2860.000 NARK.SHDT 3 7 AZ;SHDT 63,4~7 C!,$HDT 176 HTEN,SHDT 51,250 ANTEeSHDT 116,938 ICY,SHOT ~0.80~ ETIN,SHDT !! ,.SHDT 5 9½$ c 0 9 196 HTEN..'$HDT 50,813 ANTE,$HDT ,219,000 ICV;'SHDT 927.000 ETI~.SHDT 2820.000 ~ARK.SHDT '9~769 DEVI.,SHDT 60,22~ CI,~HD~ 2,822 AZ,$HDT HTEN,SHDT A~TE,$HDT 222,000 ICV,SHDT PAGEI 29,706 12,180 500 51,250 0.354 46'7 6 870,079 46,188 '3~,492 t2,458 8'321 338~500 50~8~3. 3.'936 32;462 oo LIS Tape Verification Listing Schlumberger AlasKa Computing Center **** FILE TRAZLER **** FILE NAME ~ SHDT ,OlO SERVICE I PLAY VERSION ~ 32 2 MAX AEC SIZE ~ 8192 FIL~ TYPE I PR LAST FILE ~ **** FILE HEADER **** FILE NAME { SHDT ,011 SERVICE { PLAY VERSION ~ 32,2 DATE I 90/07/26 MAX EEC SIZE I 8192 FI LALEST TYPE , PR FILE ~ 1-AUG-1990 21541 PAGE~ DATA FORMAT 'SPECIFICATION RECORD SET TYPE- 64ES ** TYPE REPR CODE VALUE 0 3 .79 158 4 66 5 66 l! 66 12 68 13 66 i 65 IN 16 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNiT SERVICE API API API APl FILE NUNS NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS NOD NUMB SA~P ELEM CODE CHEX) LIS Tape Verification Listing Schlumberger Alaska Computin~ Center 1-AUG-Iq90 21141 NAME SERV UNIT SERVICE APl AP! APl AP] FIbE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE CHEX) CS SHOT F/HR ?$ 636 21 0 11 ! ! ~ 4~ 8200000000 DiFF SHOT F 75 636 21 0 it t t 4 68 8000020000 TENS SHOT LBF 75 635 2t 0 11 1 I 4 68 8000000000 .ARK SHOT r 75 150 01 0 Ii 1 1 2 49 8000000000 FNOR S,D? O~R ?s ooo oo o ~t t t 4 s6 8000000000 FtaC S~Or oE~ vs 000 00 0 ~ ~ I 4 ~e ~000000o00 ~ao, S~O~ ~Si ?S 000 o0 o tl t ~ 4 Sa ~0o0o00000 pfv~ S,O~ o~ ?S Si0 ol o ~ 1 1 4 ~ aoo000ooo0 ~, ~.o, o~ ~ o ~, . 4 ~, ,ooooooooo c,s.o, z, ~s2 o i_{_ .ooooooooo is ~2 o 6e 8000000000 ax s~or ~/sl ?s s i se ~o~ooooooo ~. ~.~, ~,~ ~, oo~ o I'~ , 2 4, .oooo2oooo 000000000 HTEN SHOT LBF 75 000 O0 0 1i 1 1 2 49 8000000000 RHTE SHOT bBr 75 000 O0 0 1 1 I 2 49 8000000000 NRES SHOT OHMN 75 000 O0 0 11 1 ! 2 49 8000000000 ooooo !1 i' ,, ooooooooo ANTE SHOT DEGC 7$ 000 O0 1 2 49 400000000 O0 000 0 ~ ~, ~ ~ , , ~ ~ ooooooooo FCD SHOT IN ?5 28'2 0! 0 11 1' 1 2 49 400000000 IHV SHO' F3 *5 282 Ol 0 ~{ 1 ' ! 2 49 8400000000 ICV SHOT F3 75 ~82 0! 0 .. I I 2 49 8.400000000 DATA DEPTH = BS SHOT CS SHOT FNOR SHOT AB.SNOT C2 'SHOT RG~ S~DT ANTE'SNOT D'TE~ SHOT 7109.000 FEET 12,250 TOD,SHOT 74~,000 DIFF,SHDT ,552 FINC.SHDT ,,829 HAZI,SHDT 2~4.648 AX,SHOT N:RES'SHDT 000 FCD.SHDT DS,SHOT CS,SHOT FNOR, SHOT Re'SNOT 'C2,SHDT DEPTH = 7000,000 FEET 50 :TOD. SHOT 174~'0200 DIFF,SHDT 0:552 FINC,SHDT 227~08.7 HAZI'SHDT 4,840 AX,SHOT 33345538~ '3.'25 1;;98 MTEM,SHDT 9~62 'iHV,SNDT 333~55652 TI~E.SHDT 0,200 TENSaSHDT ~73,7}2 ANOR'SHDT 60,336 3,018 ::AYeSHDT 242:!,000 ETIM,$HDT 2824.000 MARK,SHOT '777 DEVi..SHDT s :~i4 cl.s,u~ 9 3 AZ,SHOT "2'1 ' SHOT A~TE.SHD~ :0:000 iCV.SHDT 1005,000 ETI~.SHDT 3154,000 NARK,SHDT 9'.777 DEVI.,SHDT 60.336 CAI.SHOT '3',353 'SHDT o{ ~ 000 Tape Verification Listing Schlumserger Alaska Computing Center 1-AUG-1990 21:41 RGR.SHDT RHTE.SHDT DTEM,SHDT BS SHOT CS SHOT FNOR SHDT RB SHDT C2 SHDT RGR SHOT RHTE SHDT DTEM SHDT B$,SHDT CS,SHOT FNOR,SHDT RB,$HDT C2,$HDT 'RGR,$HDT RHTE,'$HDT DTEM,$HDT BS SHOT C$$HDT FNOR SHOT RB SHOT C2 SHOT RGR SHDT RHTESHDT DTEN,SHDT BS,SHDT .CS,SHOT FNOR,$HDT RB'SHDT C2,SHDT RGR,SHDT RHT~eSHDT DTEM,$HDT BS,SHDT CS' SHOT "FNOR.SHDT RB,SHDT C 2:' $ H D T ~4,344 3.4,500 0,000 ** DEPTH = 12,250 1821,000 0,552 241,233 7,299 66,188 396,750 0,000 ** DEPTH = 5 406,000 0,000 ** DEPTH B '000 246,492 7,487 64'688 434~000 0,000 ** DEPTH = 1 0~;000 ,552 294,758 7,9{0 37,688 475,750 0'000 ** DEPTH = ,000 ;552 25~,383 ,440 GR.SHDT 23,~ MRE$.SHDT FCD.SHDT 9.625 6800.000 FEET TOD,SHOT 333456050 DIFF,SHDT '0,200 FINC,$HDT 73.721 HAZI;SHDT 60,607 MRES;$HDT l, !0 FCD,$HDT 9,625 6600,000 FEET $$ TOD,$HDT D!FF,SHDT FINC,SHDT HAZI,$HDT AX'SHDT GR,SHDT MRES,SHDT FCD,SHDT 3334564~4 _3 2u3 99 000 ! 984 9 625 6400,000 FEET .TOD,SHDT DIFF,SHDT FINC,SHDT HAZI,SHDT A.X'$HDT GR,SHDT MRES~SHOT FCD,'SHDT 333456831 .73,736 60,641 2.08'6 60.375. 6200,000 FEET TOD,SHOT DIFF, HAZi~SHDT AX~SHDT GR~SHDT MRES"SHDT FCD,'SHDT 3334572~9 '0,100 ~:73,~96 '2'331 40,000 2.'041 9~625 6000,000 FEET TOD SHOT DIFF SHDT FINC SHDT HAZI SHOT AX SHOT .100 6~'517 STSG,SHDT MTEM,SHDT IHV.$HDT TIME SHDT TENS SHOT ANOR SHDT AZIM SHOT AYSHDT :STSG SHOT MTEM SHDT IHV SHOT TIME,SHDT ENS,SHD AZIM.SHDT AY'SHOT :8TSG,$HDT ~TE~,SHDT IHY,SHDT TIME,SHOT TENS,SHOT ANOR,SHDT AZIM,SHDT AY~SHDT STSG,SHDT I.H;V~SHDT TIME,SHOT TEN~'SHDT ~ANOR,SHDT AZIM,$~DT AY,SHOT STSG.~SHDT MTEM'SHDT 'XHV~SHDT TI~ESHDT TENSSHDT ANOR SHOT AZIM SHOT AY SHOT 176 HTEN.SHDT 52.031 AMTE.$HDT 51.031 ICV.SHDT 987 000 ETIM.$HDT 3004 000 MARK,SHOT 9 777 DEVI,SHDT 60 607 CI.SHDT -4 230 AZ,SHDT 176 HTEN.SHDT 52,~81 AMTE.SHDT 153, 75 ICV.SHDT 967,000 ETI~ ;000 MARK 289~ ,780 DEV! ~.44~ C1. ,955 AZ , AMTE 255.$00 ICY SHOT $HDT &HDT SHDT SHDT SHOT SHOT SHOT 955,000 ETIM,SHDT 2794.000 MARK,SHDT 9.776 DEVI'SHDT 6~i,64~ C!,'$HDT - .793 AZ,SHOT 176 HTEN-S.HDT 51' 063 AMTE,'SHDT 347:250 ICV,SHDT 9~..000 ETIM,$HDT 27 ,000 ~ARK,SHDT C!,SHDT - ,902 AZ.SHOT 176 HTEN,SHDT 50,~I3 AMTE,SHDT 445, 50 ICV.$HDT 908,00~ ~0 4 ETI~ SHOT MARK SHOT DEVI SHOT Ct. SHOT AZ SHOT PAGE{ 6 4,500 281 670,058 4 3 '45,4 4 434,0~0 6, :2203,~ 9 45' ~9 35,186 12,442 7,9.37 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21=4! RGR.$HDT 61.313 GR.SHDT RHTE.SHDT 491.500 MRES.SHDT DTEM,SHDT 0,000 FCD,SHDT BS SHUT CS SHDT FNOR SHUT RB SHDT C2 SHDT RGR $HDT RHTE SHDT DTE~ SHDT B$,BHDT C$.$HPT FNOR,SHDT RB,SHDT C2,SHDT RG~,SHDT RHTE.SHDT DTEM,SHDT SS,SHUT CS,SHUT FNOR,SHDT RS,SHUT Ri~ 'SHUT ,SHUT RHTE;SHDT DTEN,SHDT BS SHUT ,FNOR ,SHUT RB SHUT C2$HDT RGR BHDT RHTE SHUT DTEM SHUT CS,SHUT FNOR,$HDT RB,SHDT C2,$HDT DEPTH 5800,000 FEET 12.250 TOD.BHDT 1988,000 DIFF.$HDT 0,552 FINC.~HDT 257.801 ,AZI.SHDT ~659 AX,SHUT 3 125 GR.$HDT 000 rCD.SHDT DEPTH = 00o 0 552 261 870 00o 0 000 DEPTH 201~000250 O, 552 265 474 o00 492 750 0 000 DEPTH = 12,250 2023'000 0,.551 24i,289 8,066. 40,750 456,500 0,'000 DEPTH 12250 2018000 0551 241 316 7 89~ 5600,000 FEET TOD.$HDT DIFF,$HDT FINC'SHDT AX,SHUT GR,,$HDT MRE~,SHDT FCD'.$HDT 65 788 ,.q',~'SG,SHD? 2!~ 4 MTE..SHDT 9 625 IHV.SHDT 333457947 -0 050 73 644 60 0~0 3~ 248 .219 ~ 100 625 333458304 _0,000 -73,69~ 59,3~3 0,789 59,5~4 .2,127 9,625 5400,000 FEET TOD,SHDT D!FF,SHDT FINC,SHDT HAZI,SHDT AX,SHD'T GR,SHDT MRES,SHDT FCD;SHDT ,041 ,435 '375 5200.000 FEET TOD $HDT DIFF FINC HAZI GR MRES FeD SHUT SHUT SHDT SHDT SHDT SHDT SHDT 5000.000 FEET TOD'SHUT DIFF,SHDT FINC~SH T HAZI;'SH~T AX,SHDT 333459004 0.0 2,2~3 9.6 5 3334593~i 0 050 73 6~6 58 323 2 65~ TXME,SHDT TENS,SHUT ANOR,$HDT AZXM,SHDT A¥.SHDT S, SHDT SHUT SHUT ~NE,SHDT TENS,$HDT ANOR,SHDT AY,SHDT STSG,SHDT M~EM;SHDT ZHV,SHDT :$HDT SHUT $HDT SHDT SHDT SHUT SHUT SHDT TIME,SHUT T£N$;SHDT AMOR,SHDT :AY,SHDT STSG,SHDT MTEN,$HDT IHV;$HDT TIME,SHUT TENS,SHUT ANOR,SHDT AZiM,SHDT AY;SHDT 176 HTEN SHUT 49,750 AMTE:SHDT 546.000 ICV.SHDT PAGEI 49,t,500 914.000 ETIM.SHDT 2566,666 259~,000 MARK.$HDT 45,781 .775 DEVX.SHDT 36.134 . ,010 CI.SHDT 12,4~2 6~.606 AZ.$HDT 7,957 176 HTEN,SHDT 486,750 49.063 ANTE.SHUT 49,063 642,000 XCV,'SHDT 9,680 886,000 ETXM,SHDT 249~.~ MARK.SHUT DEVf-$HDT "5,596 AZ.SHUT 48.116 HTEN;'SHDT 0 AMTE.SHDT 719,000 ICV'SHDT 887,000 2400.000 HARK'SHUT 'SHUT 6 HTEN,$HDT 47.~9 ANTE.'SHDT 828, 0 ZCV.'$HDT 888.000 ETIM.SHDT 229~,000 ~ARK,'SHDT .455 Cl;SHDT -4,841 AZ,'BHDT 176 HTEN'SHOT 46,688 AMTE,SHDT 925,000 fCV,SHDT 903.000 2280;000 9.777 58,323 -4,766 ETiN SHUT MARK SHUT DEV! SHUT SHDT :2923,604 3279' 05 34 lO '3624,299 45;8~3 34,462 I~,04i '0t6 456,500 46,688 3980,249 45,563 33,856 12,242 8,069 Tape Verification hist!hq $chlumoerqer Alaska Computing Center RGReSHDT 37,625 RHTE.$HDT 458.250 DTEN.SHDT 0.000 BS SHDT CS SHDT FNOR SHDT RB SHDT C2 SHOT RGR SHDT RHTE SHDT DTEM SHDT BS SHOT CS SHOT FNOR SHDT RB SHOT C2 SHDT RGR SHOT RHTE SHDT DTEN SHDT iSHOT SHOT FNO~ SHDT R SHDT C2 SHDT RGR SHOT RHTE SHOT DTEM SHOT BS SHDT CS SHDT FNOR SHDT C2 iHDT RGR SHDT RHTE SHDT DTE~ SHOT DEPTH 12,250 206~000 ,551 241'698 7,863 40~656 44~,000 ,000 DEPTH 85 375 464 250 0 000 ** DEPTH 000 0 51 256 7 017 7O 3 455 50 0 000 DEPTH = 236 8 42 451 0 25O 000 551 904 114 594 000 000 GR,SHDT NRES.SHDT FCD.$HDT 4800.000 FEET TOD'SHDT DIFF;$HDT FINC,SHDT HAZI,SHDT AX,SHDT GRtSHDT MRE$,SHDT FCD,SHDT 4600,000 FEET TOD,SHDT DIFF,SHDT FiNCeSHDT HAZi,$HDT AX,SHOT GR..SHDT MRE$,rSHDT FCD;'SHDT 4400.000 FEET TOD SHOT DIFF;SHDT FINC,SHDT HAZi,$HDT AXiSHDT GR;SHDT NRE$,SHDT FCD.SHDT 4200.000 FEET TOD SHDT DIFF SHDT FINC SHDT HAZI SHDT AX SHDT GR SHDT MRES SHDT FCD SHDT B8 SHDT CS SHDT FNOR SHDT RB SHDT C2 SHDT DEPTH 22~82'250 ,000 0.552 6.~ I 4000.000 FEET TOD 8HDT DIFF SHDT FINC SHDT HAZI SHDT AX SHDT 1-AUG-1990 21:41 38,~ STSG,$HDT 2. MTEM.SHDT 9.625 IHV,SHDT 333459714 TIME.SHDT .7~:050 TEN$.$HDT 621 ANOR;$HDT 60,34 64t AZIN,SHDT AY,SHDT NTEM~SHDT 625 IHV;SHDT 3334600~3 TIME.SHDT 0,1 0 TENS'SHOT 7.3.6~4 ANOR;SHDT 61,223 AZIM,SHDT 1.164 AY,SHDT · 88,500 STSG.,SHDT 2,320 MTEN.SHDT 9,625 IHV,SHDT 333460412 TINE,:SHDT 0,100 TENS,SHOT · -~3,6~7 ANOR,SHDT 60,8~4 AZIM.SHDT 1'2 4 A¥~SHDT 66~.813 STSG,SHDT 2,354 NTEN;SHDT 9.625 IHV~SHDT 3334607~4 TINE.SHDT .0,0 0 TENS,SHOT :73,610 ANOR,$HDT 60,714 AZIM~SHDT 3'0 0 AY,SHOT 48~.219 STSG,SHDT '2.367 NTEN,SHDT 9,625 IHV'SHDT 33346108 0.3~ TI~E.SHDT TENS,SHDT 7 AZIN.SHDT 0.930 AY.SHDT 76 HTEN.SHDT 45. 50 ANTE.SHOT I020.500 ICV.SHDT 870 000 ETIM SHDT 2154 000 MARK SHDT 9 777 DEVI SHDT 60 34~ CI SHDT -4 917 AZ SHDT 176 HTEN SHOT 44,844 ANTE SHDT 1112,000 ICV SHOT 866,000 ETI~ SHDT 2050,000 MARK SHDT 9,780 DEVi SHDT 61.223 ~i SHDT '5.444 SHOT 44.1~ HTEN SHDT ANTE SHDT 1216,000 ICV SHDT 000 ETIM,SHDT 8'7~ 000 ,SHOT · , SHOT 43,~11 HTEN.SHDT ANTE'SHDT 1302,'000 ICV,'SHDT 818,000 !925,000 9..775 0,72 4.615 1399,000 ETI~ SHDT MARK SHOT DEVI SHOT SHOT HTEN SHOT ANTE SHDT ICY SHDT 185~ O0 o:Ig "5,283 ETIN 'SHDT MARK SHDT DEVI SHDT C1 SHDT AZ 'SHDT PAGEI 458,250 45,750 12,602 4333.580 45.375 :34.853 44~844 .1~,484 4682,442 45-875 34;699 .:!! TM 44,281 16~844 503 i., 468 46;375 5373,5!5 85 46~2~6 :34, ¢0' 4~2;938 I,~828 :5700 369 46 500 Tape verification Listing chlumberger Alaska Computing Center I-AUG-1990 21~41 RGR.SHDT 44,781 GR,SHDT RHTE.SHDT 475.500 MRES~SHDT DTEM,SHDT 0,000 FCD,SHDT BS SHOT CS SHOT FNOR SHOT RB SHOT C2 SHOT RGR SHOT RHT~SHDT DTE ,SHOT BS,SHDT NCS,SHDT F OR,SHOT RB,$HDT C2,SHDT RGR,SHDT RHTE,SHDT DTEM,SHDT BS CS FNOR RB C2 RHT~ , DTEM SHDT SHOT SHOT SHOT SHOT SHOT SHDT SHOT BS,SHDT CS,SHOT FNOR,$HDT RB,SHDT C2'SHDT RGR,SHDT RHTE,$HDT DTEM,SHDT BS SHOT C8 SHOT FNOR SHOT RB SHOT C2 SHOT DEPTH = 12,250 2230,000 O3 -000 12,250 216~,000 26~ '552 ,948 ,390 45,188 471,000 0,000 DEPTH = 12,250 2146,000 0,55! 261,676 459 0 0,000 DEPTH = 12,250 2160,000 5OO 000 DEPTH = ,000 ~967 24~,$52 ,17! 4~,656 STSG.SHDT ,391 MTEM'SHDT 9,625 IHV,SHDT 3800,000 FEET TOD,SHOT DIFF,SHDT FINC,SHDT HAZI,SHDT AX,SHOT GR,SHDT MRE$,$HDT FCD,SHDT 333461403 0 150 73 636 60 536 5~ 570 281 2 3600,000 FEET TOD,SHOT O! F'HUT HAZI"SHDT AX,SHOT GR,'$HDT MRES,SHDT FCD,SHDT 3334617~4 0,~50 50,250 9,625 3400,000 FEET ** TOD,SHOT 3334~ DIFF.SHDT FINC,.SHDT 73 6!0 HAZi,SHDT 61. 1 6 AX,~:$'HDT 0.8~! GR.,SHOT 44,4 MRES~SHDT .2'4 ,~ FCD,SHDT 9,625 3200.,..000 FEET TOD,SHOT DIFF,SHDT FXNC,SHDT HAZI,SHDT AX~'SHDT GR,SHDT MRES~SHDT FCD,SHDT 3000,000 FEET TOD,SHOT DIFF, SHOT FINC,SHDT HAZI'SHDT AX,SHOT TIME,SHOT TENS,SHOT NOR,SHOT ~Z: ,SHDT ,SHOT S~ ,SHOT Mi ,SHOT ,$HDT SHOT IHDT HOT SHOT SHOT SHOT T T~ A~ SHDT SHDT SHDT SHDT SHDT SHDT SHDT SHDT 33346.2401 TIME,SHOT 0,200 TENS,SHOT .73,645 ANOR,SHDT 61.5~4 AZ~M,'SHDT 0;1 4 'AY,SHOT 48,~2~1 8TS:G,~SHDT 2,529 MTEM;SHDT · 9,625 iHV,SHDT 333462733 0,200 73,562 60,975 ~,896 TINE,SHDT TENS,SHOT ANOR,SHDT AZIN,SHDT A¥,~SHDT 176 HTEN,SHDT 42,219 AMTE,SHDT 1496.000 ICV.SHDT 8 0,000 ETIM,$HDT · 777 DEVI,$HDT ~0,536 Ci,'SHDT 5,375 AZ.SHOT 176 HTEN,$HOT O0 ZCV,SHDT 827,000 449 60 ETIM.-SHDT MARK T C. At,'SHDT ,SHOT HTEN,SHDT AMTE,SHDT ICV,$HDT 845,000 ETIM,SHDT 1610,000 MARK,SHOT 9,773 DEVi,'SHDT ~1;120 :C ,SHOT 1,76 HTEN T 40,!88 AMTE,SHPT 1766,000 XC¥,SHDT 8;!. 000 ETIM.SHDT t5 5 000 MARK SHDT 9 :775 DEV! SHDT i76 HTEN SHOT ~9.313 AMTE SHOT 1852,000 ICV SH. DT 807 000 ETI~ 1490 000 MARK 9 ~74 DE'V! 60 75 -5 171 AZ ,'SHOT ,SHOT .SHOT ,SHDT .SHOT PAGEt 5,500 6022,797 47,000 33,659 12,455 ~8 4i,688 19,063 6354,137 33, 19,063 56{ 34 660 1:2 504 8 04 459 40 1:88 19 063 4.7'27 ,5 0 0 3t -7353 058 O6 1~ 062 LIS Tape Verification Listing Schlumberger Alaska Computing Center RGR SHDT 52,844 RHTE:SHDT 488,750 DTE~.SHDT 0.000 GR,SHDT MAES,SHOT FCD,SHDT DEPTH = 2800,000 FEET BS SHOT CS SHDT FNOR SHDT RB SHOT C2 SHDT RGR SHOT RHTE 8HDT DTE~ SHDT' 122,250 215 ,000 0,555 243,141 ~ ~ 0 470,000 0,000 TOD.SHOT DIFF,SHDT FINC,SHDT HAZI,SHDT AX,SHOT GR,$HDT MRE$,SHDT FCD,SHDT DEPTH = 2640,000 FEET BS SHDT RB SHOT C2 SHOT RGR,SHDT RHTE,SHDT DTE~,SHDT 240' 5 7;346 0,000 TOD,SHDT DI~F,SHDT FI C.'SHDT HAZI,SHDT AXeSHDT GR'SHDT MRE$,SHDT FCO,SHDT END OF DATA 1-AUG-1990 21=41 53 31 STSG,SHDT 9 625 IHV HDT 333463059 0 200 73 508 59 606 2 438 47 188 ~ 5§3 625 TIME,SHDT TENS,SHOT ANOR,SHDT AZIM,SHDT A¥,SHDT 8TSG,SHDT MTEM,SHDT IHV,SHDT 333463431 TIME,SHOT *o 20 83 97~ tENS,SHDT ANOR;SHDT 15 573 AZI~SHDT ,2 954 A¥,SHDT 38 469t STSG.,SHDT 2 582 NTEM,SHDT 9 625 I. HV,SHDT 176 HTEN.$HDT 38,625 AMTE.SHDT 1929,000 ICV.SHDT 95~ 000 ETIH.SHDT 136 000 HARK.SHOT 9 771 DEVI.SHDT 59 606 CI,SHDT -4 803 AZ,SHOT 176 HTEN;SHDT 38.313 A~TE,SHDT 2009,000 ICVeSHDT 88~.000 ETIM SHOT 125 .000 HARK SHOT ,767 DEVI SHOT 15,573 -4,510 ~ $HDT$~DT 38,1~ HTEN SHOT AHTE SHOT 2042,000 ICV SHOT PAGES .10 488,750 38,625 19,063 7678,621 48,03 130 000 38,3t3 .19,063 oo $6 '~63 **** FILE TRAILER **** 'FILE NAME =SHOT ,011 SERVICE I PLAY VERSION = .32.2 DATE I 90t07/26 MAX REC SIZE I 8192 FILE TYPE = PR LAST FILE = *,1~ TAPE TRAILER 1,.~* SERVICE NA~E = FSHDT DATE = 90/07/26 SU ORIGIN = ~72526 TAPE NAME = CONTINUATION #~ 01 PREVIOUS TAPE ~ CON~ENT = SCHLUNBERGER WELL SERVICES CSU TAPE Tape Verification Listing chlumberger Alaska Computing Center 1"AUG-1990 2!:41 **** REEL TRAILER **** SERVICE NAME : FSHDT DATE : 90/07/26 ORIGIN : CSU REEL NAME : 572526 CONTINUATION ~ : Ol PREVIOUS REEL : COMMENT SCHLUMBERGER WELL SERVICES CSU TAPE PAGE~ 11 COmPANY_NAME ~ M ~Ebb NA~E I TB FIE6D NA~E ~ TR BOROUGH { KE APl NUMBER { REFERENCE NO { ?3995 Olh COMPANY BAY RECEIVED OCT 2 2 lggO AJaslca ~l & Gas Cons. Comnli~on ,qocho LES Tape Verification Listing Schlumuerger AlasKa Computing Center **** REEL HEADER **** SERVICE NAME ~ GE06IS DATE : 90/08/0! ORIGIN : FLIC REEL NA.E ~ 73995 CONTINUATION # : 01 PREVIOUS REEL : CONMENT : P$1EDT,MARATHON OIL **** TAPE HEADER **** SERVICE NAHE : GEOLI$ DATE { 90/08/01 ORIGIN I FLIC TAPE NAME : 73995 CONTINUATION # ~ 01 P~EVIOU$ TAPE { COMMENT ~ 73995 **** FILE HEADER FILE NAME ) SHOT ,001 VERSION ) 002E07 D~TE ~ ~AX. REC SIZE ~ 1024 FILE TYPE : FO LAST FILE 2-AUG-1990 16:21 CO., TRADING BAY~ TBU M-3 PAGE: COMPANY NAME: MARATHON OIL ~LL: TBU M'3 FIELD: TRADING BAY BOROUGH: KENAI STATE: ALASKA COMPANY LOCATION: 1039' FNL & 602' FW6 SECTION:3~ TOWNSHIP: 9N PERMANENT DATUM{ MSL ELEVATION~ O' RANGE: LIS Tape Verification Listing Schlumberger AlasKa Computing Center 2-AUG-1990 16~21 LOG MEASURED FRO~ KB 160' ABOVE PERMANENT DATUM ELEVATIONS KB: 160' DATE LOGGED: RUN NUMBER{ TD DRILLER: 7-JULY-90 7142' CASING 11 13 3/8" 9 DRILLER DEPTH OF O' TO 2713' BIT SIZE 1{ 12,25" TYPE FLUID IN HOLE{ POLY PLUS G DENSITY{ 9-55 VISCOSITY: 46 FLUID bOSS: HUD RESISTIVITY FILTRATE RESISTIVITY MUD CAKE RESZSTIVITY~ 4,88 9 69 , ~ 65 TIME LOGGER ON BOTTOMt 10130 27-JUL-90 MAXIMUM TEMP RECORDED{ 132 LOGGING DISTRICT{ LOGGING ENGINEER{ W I TNES$ II KENAI T.$MITH BOEDEKER/UNDERWOOD PAGEI DATE JOB STARTEDI 30-JUL-90 OOB REFERENCE NO: 73995 LDp/ANAI R, KRUNELb COMPUTING CENTER REMARKSl · 1.) rILE SHDT.OOI_CONTAINS SHDT FAST AND SLOW CHANNELS OF-bOG FILE FROM 5010' TO 2712' ],)FILE'SHDT,002'CONTAINS GAMMA RAY DATA OF LOO,,:FIbE FROM 5010' TO 2712' ,) ALL DATA .HAS BEEN SPEED CORRECTED AND INCbINOMETRY DATA HAS BEEN CORRECTED FOR 23,17 DEGREES MAGNETIC DECLINATION. ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 79 700 4 66 1 LIS Tape Verification bistSng Schlumberger Alaska Computing Center 2-AUG-1990 16:2! PAGEI TYPE REPR CODE VAbUE 5 66 8 73 9 65 lI~ 1~ 68 13 66 1 15 66 16 66 1 0 66 0 NAME SERV UN%T SERV%¢E AP! AP! AP% AP% F%L~ NUmB NUmB SIZE REPR PROCESS ID ORDER ~ GOG TYPE CbA~S MOD NUMB 8AMP EGEM CODE (HEX) .., ~.~,c oo,~o o,ox ~ ~ 64,.o~oooooooo o.=s.sc oo ~oo= o ~ ~ ~ ~ ~e o~oooo0oo0 DB2A SH~C O0 6 0 ~2 s~ s.sc ooe~ o,~ s.sc oo~o o~o x ~ x ~4~e o~oooooooo ~.~ s.sc oo6~o ~.o~ xex ~ 68 oxoooooooo ~.4 s.sc oo~o 04o x ~6~ e4es o~oooooooo ~ s.sc oo~o x~o ~ xe~ e4e~ o~oooooooo .tv s.sc v o~ooo oo o ~ 1 ~ ~ ~ o~oooooooo ~ ~.,: ~,~ ooooo oo o ~ ~ ~ ~ ~, o~oooooooo ~ ~ ~ 4 es oxoooooooo ?e 6~2 o~ o ~ ~ x 4 es 0100000000 c.o~e~z s.SCs.sc Bs~ oo ooooo o ~ i ~ ~ ee o~oooooooo ~ ~ 4 ee o~oooooooo FNOR SHS, C OER O0 000 O0 0 ~ ~ ~' 4 68 0100000000 F~.C s~sc D~G oo oo0 O0 0 ~ , ~ 4 es 0100000000 ~ o~ ~ ~ ~, o~oooooooo ~.~ ~.. o,ooo oo o ~ ~ ~ , ~, o~.oooooooo . . s o ~ ~ ~ ~ ~, o~oooooooo · ,~ s~sc ~~o~o ~ o ~ ~ ~ 4 ~ oxooo.ooooo .~ s.sc ~ ~o2.0 4~ o ~ ~ ~ 4 ~e o~oooooooo RAD4 SHS¢ IN ~0280 44 0 I ~ I 4 68 0100000000 DATA ** ** DEPTH = 5009,900 FEET ~erqer Alaska Compu'tin~ Center Verification Listin SBi.$H$C 225 044 DBI.SHSC DB2A.SHSC 224:188 SB2.SHSC DF4.SH$C 225.954 DB4A,$HSC HAZI,SH$C 58.159 RB'SHSC FNOR.SH$C 0.552 FINC SHSC EI,SHSC 0.000 RADI:SHSC RAD4.SHSC 5,949 DEPTH = 5000.033 FEET SBI.SHSC 222,617 DB2A.SHSC 226,226 DB4.SHSC 225.390 HAZI.SH$C 58,33! FNOR SH$C. 0,552 EI:SH$C 0,000 RAD4.$H$C 6.019 DBI.SH$C DB4A SHSC RB SHSC FINC $H$C RAD1SH$C DEPTH = 4800.033 FEET SBi.SHSC' 226,234 DBI,$HSC DB2A.$HSC 221 878 SB2,SHSC DB4,SH$C 222:785 DB4A,$HSC HAZI,SHSC 60,395 RB*SH$C FNOP,SHSC 0,551 FINCeSH$C EI~SHSC 0'000 RADI,SHSC RAD4,$HSC 6,033 ** DEPTH = 4600,033 FEET DB~A RAD4 $HSC 219 8HSC 2~I SHSC SHSC 0 $H$C 0 $HSC 6 ** DEP! ,s.sc 53 RB,$HSC 75 DB4A,SH$C 552 FINC,SH$¢ 000 RADI,SH$C 435 4400,033 'FEET B'Bt,SHSC 229;846 SB~ D$2A,$HSC 226,602 DB ,SH$C ,S~SC DB4,SH$C 222,447 DB4A,SH$C 'HAZI~$HSC 60~749 RB,$HSC FNOReSHSC 0,55t FINC,SHSC EI~$HSC 0.000 RADi,SHSC RAD4'SHSC 6'42! DEPTH = 4200,033 .FEET SB!.SHSC DB2A,'$H$C DB4,$HSC HAZI,$HSC FNOR,$HSC 2'0 222 60 0 105 DB 1., SHSC 783 SB2"SH$C 356 DB4A'SHSC 590 RB,SH$C 551 FINC,SH$C 2-AUG-1990 16:21 224,477 DBIA SH$C 227.167 DB3iSHSC 226.567 REV SHSC 237.141 PlAZ.SH$C 73,605 DEVI,SHSC 5,957 RAD2,SHSC 224,819 225,775 227,380 240,852 Oil 222,698 222,882 226*783 ,762 ,6~8 5,999 35,981 6,:1, 256*660 O2O ** 2~3,859 · 2 7,492 '73'60~ SHSC SHSC ~H$C iH$C 'SHSC ;SHSC ,'SHSC *SH$C ,SHSC ,8HSC DB 1 A, SH$C D'B3, SHSC REV, PIAZ, SHSC DEVi, 225.632 D82 SHSC 220.700 DB3A:$HSC v.s.sc 224 196 DB2.SHSC 224 023 DB3A,SHSC 5 199 SDEV.$H$C 303 480 GNOR'SHSC 33 854 EV.$HSC 6 019 RAD3,SHSC 224 227'~ DB2 SHSC , DB3A SHSC 2 7~5 SDEV SHMC 306:6{9 GNOR $HSC 3~,884 EV SHSC ,033 RAD3 SHSC t8,988 D2 32!, ~ SDEvDB~A 3 714 EV 435 RAD3 'SHSC 'SHSC :SHSC SHSC $H8C 26,55 DB2,'SHSC ~2,11 DB3A-SHSC 2,965 SDEV,SHSC 319~330 GNOR,'SH$C 33,856 EV-'SHSC 6~4'21 RAD3~8H$C 220'630 DB2,SHSC SDEV.:$HSC GNOR,$HSC ~EV-SHSC PAGEI 223,106 2i7 897 33i838 0 997 5.261 5,957 224.955 224,251 33,854 0+997 5,199 6,013 220 201 23! 134 34 88 0 99~ 3,856 :0,996 o.g 214'! LIS Ta~e Verification Listing $chlum'erger AlasKa Computing Center EI,$H$C 0,000 RADI.$H$C RAD4.SHSC 5.921 DEPTH = 4000,033 FEET SBI.SH$C DB2A SH$C DB4 SH$C HRZ! SH$C FNOR SH$C E! SH$C RRD4 $H$C 220,501 DB- 2 1,694 SB~'$H~C ,SHSC 2~:748 DB4A.SHSC 6 ~74 Re'S,$C 000 RRDI.$HSC 6.506 ** DEPTH = 3800,033 FEET DB2A DB4 HAZ! RAD4 SHS¢ sHSC 8HSC · ,SHSC 225 2,;9 0 0 6 457 DBI,SHSC ~44 SB2~SHSC RB~SH$C 551 FXNC~SHSC 000 RADleSHSC 358 DEPTH = 3600,033 FEET SB1 D~2A DB4 HAZ! FNOR E! RAD4 SHSC SHSC SHSC 8H$C 2 6 2 4 61. 0 0 6 6~ DB1 DB4~ 096 RB 696 SHS¢ SHSC S~SC S~S¢ DEPTH = 3400,033 FEET $B1 DB2R DB4 HAZ! fNO~ E! RAD4 SHSC SHSC SHSC SHSC SHSC SHSC SHSC 22.3 021 225 0 000 6 604 DBl. SH$C SB SHS¢ DB4~ SHSC RB SBSC FINC SHSC RADI SHSC DEPTH = 3200.033 FEET DB2A SHSC DB4 SHSC FNOR SHSC E1 RRD4 231 69.6 6 61 538 0 55~ 0 O0 6 978 DB DB4A FIN( RADi $HSC SHSC SH$C SHSC $HSC DEPTH = 3000,033 FEET 2-AUG-1990 16121 5,858 RAD2.$HSC 223 552 9 0 260 2~0 75~ 922 DBIA,SH$C DB3,GHSC REV'SHSC P1AZ,SHSC DEVI,SHSC RAD2,SH$C 224,854 DB1A,SHSC 2 ?.,9.0 _~v',SHSC 263,7~2 PIAZ,SHS~ .73,670 ~DEV!,SHS¢ 6,11! RAD2+SHSC 779 64 26 DB1A DB3 REV PtAZ DEV! RAD2 SHSC SHSC SHSC SHS¢ SHSC SHSC i,,~4 6.104 DB1A,SHSC DB3 SHSC REV SHSC SHSC D SftSC 256 2 5 6 8H8C 'DBmeD SHSC REV SHSC SHSC RRD2 SHSC 5.921 RAD3.SHSC 227 366 DB2 8HSC 219 DB3A SHSC 3 139 40 SDEV SHSC 322 I18 GNOR SHSC 33 297 EV SHSC 6 506 RAD3 ~SH$C 226,283 DB2 SHSC 221:I DB3A $H$C SDEV ~263 GNOR'SHSC 316,358 RAD3'$H$C ~676 EV '$HSC 224'078 DB2,SHSC ,22~460 DB3A SH$C SDEV.SHSC 33;,992. E :8HSC 6.696 RAD SHSC 224.163 DB2,SHSC 22~:,~9~ DB3A.SHSC 324::~6 :$DEV.SHSC GNOR,'SHSC 34,661 EV,SHSC 6~604 RAD3.$H$C 32,976 DB2,'$HSC 25,494 DB. 3A,'SHSC 083 SDEV,'SHSC 3~:97. RA~]:$HSC PAGEI 5,858 232.557 225..7{8 224.~ 'i 225,599 222, ~34, ,068 LIS Tape Verification btsting SchlumBerger Alaska Computtn~ Center SBI SHSC DB2A:SHSC DB4,SHSC HAZI,SHSC FNOR.SH$C El SHSC RAD4~SHSC SBI,SHSC DB2A,$HSC DB4,$H$C HAZI,SH$C FNOR,SHSC EI'SHSC RAD4,$HSC SB1SB DB4 SH$C HAZI SHSC FNOR $H$C E1 RAD4 SHSC 067 22 202 :oo4 DEPTH = 225,746 224,891 228,583 59~554 0,555 0,000 7,I55 226,222 236,169 235;06~ 206,417 0,501 0,000 8,643 DB SHSC SBI SHSC DB4A SHSC RB SHSC FINC SHSC RAD1SH$C 2800,033 FEET DBt,SHSC SB2,$HSC DB4A,$HS¢ RB,SHSC FINC,SHSC RADI~SH$C 2712,033 FEET DB ,SHSC SB '$HSC DB4A:SHSC .RB,SH$C FINC'SHSC RADI,SHSC END OF DATA **** FILE TRAILER **** FILE NAME : SHDT ,001 SERVICE : GEOLI$ VERSION : 002E07 DATE ~ 90/08/01 MAX REC SIZE : 1024 FILE TYPE : FS LAST FILE : **** FILE HEADER FILE NAME : SHDT 002 SERVICE = GEOLIS' VERSION : 002E07 DATE : 90/08/01 MAX REC SIZE : 1024 FILE TYPE ~ = F$' 'LAST FILE : 2-AUG-1990 16:21 349 226345 249 765 73584 6307 2 4,920 ,013 283 96 5~2 DB1A,SHSC DB3'SHSC REV,SH$C PIAZ,$HSC DEVI,SH$C RAD2,SHSC 8H8C PtAZ SHSC D~VI SHSC R~D2 SHSC : SH$C V $H8C A $ H S C RAD2 SHSC 229732 DB2 SH$C 229438 DB3AiSHSC 2540 SDEV SHSC 314059 GNOR SHSC 34253 EV,$HSC 6 795 RAD3,SH$C 2 8,716 DB2,$HSC 2~ DB3A,SHSC 5,488 6,404 SDEV,SHSC 306,602 GNOR'SH$C 33,484 EV,'SHSC ~7,155 RAD3,SHSC 536 DB~'$HsC '303 SDEV,SHSC 114 GNOR,SHSC 643 RAD3.SHSC PAGE= 236,327 30,~5396 l:sio ~07 225 77O 224468 33484 0 g96 6 4O4 6 244 303 592 LIS Tape Verification Listing Schlumberger AlasKa Computing COS.GAR011,O01 GAROII,O01 Center 2-AUG-~990 16:21 PAGES DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VAhUE 4 5 6 7 8 9 11 66 0 66 0 79 8 66 66 73 66 128 68 66 0 65 FT 66 68 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl APl API. API Fi~E NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG. TYPE CLASS MOD NUMB SAMP ELEM CODE~ CHEX) DEPT SHSC FT O0 636 21 0 2 I 1 4 68 0100000000 GR SHSC GAP! 30 310 O1 0 2 i 1 4 68 0100000000 DATA ** DEPT,SHSC 5009'838 GR,SHSC 3'7,750 DEPT,$HSC 4999,838 GR,SHSC 40,531 DEPT.SHSC 4799.838 GR.SHSC 42.750 DEPT.SHSC 4599.838 GR.SHSC 84'313 DEPT.SHSC 4399,838 GR.SHSC 68,063 LIS Tape Verification Listf Scl~lum~erqer Ala$1<a Comput ~ Center 2-AUG-1990 16~2! DEPT,SH$C 4199,838 GR,SHSC 49,750 DFPT,SHSC 3999.838 GR.SHSC 45,125 DEPT,$HSC 3799,838 GR,$H$C 55.000 DEPT,$HSC 3599,838 GR,SH$C 49e28! DEPT,$H$C 3399,838 GR,SH$C 42,375 DEPT,SHSC 3199,838 GR,SHSC 45,438 DEPT.$H$C 2999,838 GR,SH$C 47,531 DEPT.$HSC 2799.838 GR,SHSC 47,813 DEPT,$HSC 2712,338 GR,SHSC 56,656 END OF DATA ~*. FILE NAHE ~ SHDT ,002 SERVICE ~ GEOLI~ VERSION ~ O02EO DATE ~ 90/08/01 RAX REC SIZE ~ 1.024 FILE TYPE ~ FS LAST FILE ~ DATE ~ /08/01 O~iGIN : 7~5 TPE NAME ~ CONTINUATION # ~ Ol PRE¥IOU$ TAPE ~ COMMENT ~ 739.95 REEL NANE ~ 5 C~NTINUATION # ~ O1 PREVIOUS REEL COMMENT : PSlEDT,MARATHON OIL CO,:, TRADING PAGE~ A~ASKA COHPUTZN; CEN~ER COMPANY NAME I MARAT,HON OZb COMPANY WEbb NAME. I TBUi>M-3 FZEbD NAME I ?RADZNG BAY BOROUGH i KENA! AP! NUMBER l REFERENCE NO I 73995 Tape Verification histing chlumDerger AlasKa Computing Center 2-AUG-1990 00~03 **** REEL HEADER SERVICE NAME I GEOLIS DATE I 90/08/0! ORIGIN : FblC REEL NAME I 73995 CONTINUATION # I 01 PREVIOUS REEL COMMENT I PStEDT,MARATHON OIL CO,, TRADING BAY, TBU **** TAPE HEADER SERVICE NAME I GEObIS DATE I 90/08/01 ORIGIN : FbIC TAPE NAME I 73995 CONTINUATION # I 01 PREVIOUS TAPE CONHENT I 73995 **** FILE HEADER **** FILE NAME {SHDT ,001 -SERVICE I GEOLIS ,VERSION I O0 EOT DATE I 90 08/0! MAX REC SIZE I 1024 FILE TYPE ~FS PAGEI 'SPC.FSTO10.O01,INCO10,001 FST010,00! . 010 001 *********************************************************************************** ******************************************************************************* ** ** SCHLUMBERGER WELL SERVICES ** ** ********************************************************************************** COMPANY NAME{ MARATHON OIL COMPANY NEh,bl TBU FIELD{ TRADING BAY BOROUGHI KENA! STATE: ALASKA LOCATION{ 1039' FNh & 602' 'SECTION{33 TOWNSHIP~ RANGEI 13~ PERMANENT DATUMI MSL ELEVATIONI O' Tape Verification Listing ChlUmberger Alaska Computing Center 2-AUG-1990 00~03 LOG MEASURED FROM KB 160' ABOVE PERMANENT DATUM ELEVATIONS KBt 160' DATE LOGGED{ RUN NUMBER{ TD DRILLER{ 27-dULY-90 2 7142' CASING 1{ 13 3/8" ~ DRILLER DEPTH OF O' TO 2713' BIT SIZE 1{ 12.25" TYPE FLUID IN HOLE{ POLY PLUS G DENSITY= 9.55 VISCOSITY{ 46 FLUID LOSS{ 6,5 MUD RESISTIVITY{ 4,88 FILTRATE RESISTIVITY{ 45~14 MUD CAKE RESISTIVITYt 14 ~ 65 TIME LOGGER ON BOTTOM{ 10130 27-dUL-90 MAXIMUM TEMP RECORDED3 132 LOGGING DISTRICTt LOGGING ENGINEER{ WITNESS{ KENAI T.SMITH BOEDEKER/UNDERWOOD PAGE{ DATE dOB STARTED{ 30-dUb-90 dOB REFERENCE NOI 73995 LDP/ANA{ R, KRUNELL COMPUTING CENTER REMARKS{ 1',) FILE SHDT.OOi CONTAINS SHOT FAST AND SLOW CHANNELS OF REPEAT FILE FROM 6800' TO 6400' 2,) FILE SHDT,002 CONTAINS GAMMA RAY DATA OF REPEAT FILE FROM 6800' TO 6400' · ],) FILE SHDT.003 CONTAINS SHDT FAST AND SLOW CHANNELS OF LOG FILE FROM 7086' TO 5000' ' 4.) FILE SHDT.O04 CONTAINS GAMMA RAY DATA OF LOG FILE FROM 7086' TO 5000' 5,) ALL DATA ~HA$ BEEN SPEED CORRECTE~ AND ~NCLINOMETRY DATA HAS.BEEN CORRECTED FOR 23.I7 DEGREES MAGNETIC DECLINATION. LIS Tape Verification Llst_ing 8el~lumberger Alasl~a Computing (:enter 2-AUG-1990 00:03 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VAbU~ i 66 66 ] '79 4 66 5 66 6 '/3 -/ 65 tt '/3 9 65 68 66 14 65 15 66 16 66 0 66 0 0 700 1 16 1 OD U.B SA.P ELE~ CODE (HE ID ORDER # ~OG TYPE CLASS M X) SB1 SHSC O0 610 10 0 I 64 68 0 1 DB1 SHSC DBIA SHSC DB2 SH$C DB2A 8H$C ~SB2 SHSC DB3 SHSC DB3A DB4 D~4A SHSC REV $H8C V SDEV SHSC DEG RB SH$C .DEG P/AZ SHSC DEG · GNOR SHSC 'F~NC SH$C DEG DE'VI SH$C DEG EV SHSC V Ei $.HSC A~P RAD1SHSC ~IN RAD~ SU$C IN RAP SHSC IN RAD4 8H8C IN O0 0 oo OO ~ oo ° o °° 0. O0 6 O0 6O 01 0~0001'4 oO 000 O0 76 6}00l 6 6 Ol O0 000 O0 O0 000 O0 O0 000 O0 -/6 62O Ol 01 000 O0 01 000 O0 70 280 41 70 280 42 ~0 280 4~ 0 280 4 0 0 0 0 0 0 ,0 0 0 0 0 0 o o 0 ! 0 0 0 1 1 ! 1' 1 1 1 i ! 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ! 1 1 1 1 64 64 84 64 64 64 64 64 64 4 4 4 68 68 68 68 88 6ii 68 68 0100000000 010000000o glO0000000 O0 0 O0 010~0o 0 00000 ~I00000000 00000000 O1OOOOO0O0 0100000000 0100000000 OiO0000000 010000000.0 0t0-0000000 0i0o000000 0100000000 0100000000 0100000000 O1OO0OOOOO 0100000000 01~0000000 01 0000000 0100o00000 0100000000 glO00oo000 100000000 PAGEI LIS Tape Verification bisting Schlumberger AlasKa Computing Center 2-AUG-1990 00:03 PAGEI DATA SB! SH$C DB2A SHSC DB4 $H8C HAZ! 8H&C FNOR $H$C E{$H$C RAD SH$C DEPTH = 6799.983 FEET ** 235,848 DBI.SH$C 238.030 DB1A,SHSC 3 SB2-$H$¢ 233,6t4 DB3.$HSC 233'~[6 RB.$HSC I~ 240' 3 DB4A.SH$C 2+0,6~0 REV'SH$C 60'2 0.550 FINC.SH&C ' .{16 DEV/.SH&C 0'000 RADI.SHSC 5.9B5 RAD2.$H$C 6.019 'SB1 DB2A .DB4 HAZZ FNOR E! RAD4 .SHSC SHSC SH$C SHS¢. DEPTH = 6799,050 FEET DB3eSHS~ .PIAZ,SHS~ .924 DB4k'SHSC 186 RBeSHSC 550 FINCeSH$C ' ,i~3 DEVX,$HSC 0.000 RADI.SHSC 6.027 RAD2;SH$C 6; O9O SB1 DB2A DB4 HAZ! FNOR E! RAD4 SHSC SHSC SHSC SHS¢ SHSC SHSC -DEPTH = 6599,983 FEET 238,355 DBI.SH$C 2L40.7~ DB1A.SH$C 69 SB2 ~37,1_3 PlAZ,SH$~ 0.000 RAD~.SHSC '6.076 RAD2.SHSC '153 DEPTH g. RZ~ RkD 6400.117 FEET SHSC i1'8,574 DBI,SHSC SHSC 22*456 SB2;SHSC SHSC 19,620 DB4A,SH$C SHSC 59,966 RB,GHSC SHSC 0,550 FINC;SHSC SH$C 0,000 RADI,SH$C SHSC 6.097 END OF DATA DB1A,SH$C ;927 REV;SHSC ' ,,463 PIAZ,SH$C RAD2,SHSC 240.135 DB2.SHSC 244.068 DB3A.$HSC 3.175 SDEV.$HSC 192,444 GNOR.SH$C 29.714 EV.SH~C 6.029 RAD3.$HSC 237.~74 DB2 66 233,2~{ DB3A 8DEV 193,069 GNOR 090 RAP3 SHSC SHSC 4 DB2,$H$C 2~4'501 ,554 DB3A,$H$C ~!.652 SDEV;SHSC ,744 GNOR,'SH$C ' '799 EV,$HSC 6.153 RAD3~'$HSC ~224,746 DB2,$H$C 223,56{ DB3A,SH'SC 2,374 SDEV,'SBSC 212.549 GNOR*SH$C 32,504 EV,SH$C 6,097 RAD3,SH~C 231:674 245 9!0 29096 3 !75 5 985 239,405 239,999 236,408 ,~ 7199 ,995 ,6 2 ,06 24. '159 32.504 6.t18 I$ Tape Verification Listing chlumberger Alaska Computing Center **** FILE TRAILER **~* FILE NAME : SHDT ,001 SERVICE : GEOLIS VERSION : O02EO? DATE : 90/08/01 MAX REC SIZE : 1024 FILE TYP£ : Fg LAST FILE : 2-AUG-1990 00:03 PAGE: *~** FIhE HEADER FILE NAME : SHDT ,002 SERVICE I GEOLI$ VERSION i O02EO? DATE : 90/08/0! MAX REC'$IZE : 1024 riLE TYPE : FS LAST FILE CO$.GAROIO,O0! GAR010,O01 DATA FORMAT SPECIFICATION RECORD SET TYPE TYPE REPR CODE YALUE I 66 0 2 66 0 3 79 8 4 66 $ 66 6 1i 66 ~28 6~ 0 14 65 FT 15 66 68 16 66 1' 0 66 ~I$ Te~e Yerlftcatlon Llsti~~ C nter chlum eroer AlasKa ¢omput e 2-AUG-1990 00:0] ** 8ET TYPE - CHAN ** NAME SERV UNIT SERVICE APl APl APl APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SA~P ELEM CODE (HEX) DEPT SH$C FT O0 636 21 0 2 I I 4 68 0100000000 ~R SHSC GAPI 30 310 O! 0 2 1 1 4 68 0100000000 PAGE: DATA ** DEPT,$N$C 6799,550 GR.SHSC 86,313 DEPT.SH$C 6600,050 GR'SHSC 103.813 DEPT.SHSC 6400.050 GR,$HSC 51,063 END OF DATA **** FILE TRAILER **** FILE NAME : SHDT ,002 S~RVICE : GEOLIS VERSION ~ OOREO? DATE 1,90/08/0! MAX'REC SIZE ~ 1024 FILE TYPE : rs LAST FILE : **** FILE HEADER FILE NAME : SHDT ,003 SERVICE ~ GEOLXS VERSION ~ O02EO? o/o /OI FILE TYPE { LAST FILE SPC,FSTOII,0OI,'INCOII,O01 FSTO!I,OOZ INC011,O01 bis Tape Verification 5istlnO SchlumDerqer Alaska Computing Center 2-AUG-1990 00~03 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *~ TYPE REPR CODE VA~UE I 66 0 2 66 0 3 79 700 4 66 1 5 66 6' 73 ? 65 8 73 16 12 68 3 66 IIiN I6 66 1 0 66 *~ SET TYPE:- CHAN NAME SERV UNIT SERVICE APl APl lPI APl FIbE UMB NUMB SIZE R.EPR PROCESS lO ORDER # bOG TYPE CbASS MOD NUMB ~A:MP EGEM CODE (HEX) SB1. SHSC O0 6t0 I0 9 ~ · 1,<~ 1 64 68 0100000000 D~t_ SHSC O0 610 Ol 0 3 t& 1 64 68 0100000000 DBIA .$H$C 60 610 il :0 3 I~ I 64 68 0100000000 DB2 SH$C O0 610 02 0 3 16 i 64 68 0100000000 DB2A SHSC 06 610 12 ~ ~ 16 i 64 68 0i00000000 SB2 SHS~ O0 610 20 0 ~ t6 1 64 68 OlO0000000 DB3 SHSC O0 610 03 3 16 ' I 64 68 0100000000 DB3A :$HSC O0 610 13 0 3 1~ 1 64 68 0100000000 DB4 5H$C O0 610 04 0 3 ~6 1 64 68 0100000000 DB4A SHSC O0 610 14 9 } I6 1 64 68 0100000000 REV SHSC V 01 000 O0 0 3 1~~ I 4 68 .0100000000 SDEV SHSC DEG .~:~ 000 O0 0 { 1 4 .-~ .OlO00OOOO . z s.sc Ol o o ooooooo. o o oooooo.oo 0100000000 0100000000 'SH$C DEG PIAZ SHSC DEG GNO~ SH$C .FNOR 8H5C OER :FINC SHSC DEG DEVI SHSC DEG gV SHSC V El SHSC AMP RAP1 SHSC IN RAD2'SHSC IN RAD3 SHSC IN RAD4 SHSC IN 76 632 00 000 0 00 000 00 0 00 000 O0 0 000 O0 0 0 280 4 0 ~0 280 41 0 70 28~0 43 0 7O 280 44 0 1 1 4 4 4 4 4 4 4 4 .4 4 4 68 68 0100000000 68 0100000000 0100000000 ~100000000 100000000 68 6100000000 68 0100000000 68 0100000000 68 0100000000 PAGEI LIE Tape Verification bistlng Schlumberger Alaska Computing Center 2-AUG-1990 00=05 PAGEI DATA SBJ DB2A $H8C DB4 SHSC HAZ! FNOR SH$C EI,SHSC RAD4,$H$C EBI-.$H$C FNOR,SH$~ RAD4,$H$C 8B{,SH$C DB2A,SH$C ~' DB4,'SHSC HAZi-,SHSC FNOR,'6HSC RAD4-SH$C DB2R,~HSC DB4,:SH$C HAZi.$HSC FNOR"SH8¢ RAD4,$HSC SBI,SHSC DB2A,SHSC DB4;$HSC EI,'SH$C RAD4;SH$C DEPTH 218 075 22. 994 · 21~ 302 660 6~ 552 o 5 DEPTH = 212,406 4 '60,i67 0,552 0.000 ?.02? DEPTH = 66,274 73;759 :28,416 60+530 0~552 0,000 6,308 DEPTH =. i'797 5;409 4,202 ,0,598 0,551 0,.000 6.287 DEPTH 222 515 222 637 227 3:06 60 4.64 0 552 0 000 6 181 7085.900 FEET .SHSC DB4A,SHSC RB'$HSC FINC,$H$C RADI,SH$C 220 349 223 470 557 5.a31 DB1A SHSC DB3 $H8C REV SHSC P1AZ 6H$C DEV! SHSC RAD2 SHSC 7000.033 FEET DB~,,SHSC ~2,7 . DB41:;$H8¢ RB,$HSC 20 70~ PlAZ FINC.SHSC DEV! RADIeSH$C 286 RAD2 6800.033 FEET DBI..'SHSC S.B2,SHSC DB4A,SH$C F RB,$HSC INC,SHSC RADI,6~8C 6600.033 FEET DBi,SHSC SB2,SHSC, DB4A,SHSC RB.,SHSC FINC.SH$C RADI"SHSC 6400,033 FEET DBi,SHSC SB2,SHSC DB4A,SHSC RB.$H$C FINC.SH$C RADi,SHSC SHSC 8HSC SHSC 8HSC SHSC SH$C ** 237,2~I DBIA,SHSC 210,5 DB3'SH$C 73,7 DEVX.'SHS~ 6.0 RAD2.SHSC 231,058 DB A.SHSC · 2~6.0~6 DI3.SHSC :229 P1AZ.SHSC DEVI,SHSC 7~,2 7 RAD2.SHgC ** 231,212 DB1A,SHSC 221.843 DB3,SHSC 30,214 REV,SHSC ,: 6 DEVI,SHSC ,034 RAD2,SHSC 1 9.990 DB2.$HSC 2~.395 DB3A.SH$C 3 1,549 EDEVeSHSC ~!i447 GNOR.SH~C 253 EV,SHSC 794 RAD3,SH$C i 3,0 DB2.SHSC 290. SDEV.THg¢ 6~4 GNOR.SH$C 027 RAD3.6H&C 268 304 29 339 DB2.SHSC 462 DB3A.SHS 055 'SDEV.SHS~ 830 GNOR,SH$~ 689 EV,SH8 308 RAD3.SHSC 29:4 3t 6 859 DB2.SH$C 893 D.B3A'$HSC 607 SDEV.'SHSC · '82 EV,SH$C 60 GNOR,$HSC 287 RAD3,SHSC 230.499 DB2 SHSC 2'18,130 DB3A SH$C 2, 54 'SDEV SHSC 3t~,274 GNOR,SHSC .42! EVEH~C 6,~8! RAD3 .$~SC 5 831 28 893 · 0 997 265,08{ 251,466 29,689 6,048 ,860 ,997 '~,607 6,237 2. · . LISh Ta Verification Listing ISc lUm~rger AlasRa Computing Center 2-AUG-1990 00:03 PAGE= SB1.SHSC DB2A,SH$C DB4.$HSC HAZI.SHSC FNOR.$H$C E1SHSC RRD4~SHSC SBi.SH$C DB2A,$HSC DB4,$HSC HAZI,SH$C FNOR,$HS¢ EI,$H$C RAD4,-3H$C DB4,SHS¢ HR ;SHSC E~,SH$C RAD .SHS¢ '$Bt,SH$C DB2A,SHSC DB4"aHSC HAZIeSHSC FaOR,'SHSC EI,SHSC RAD4.SHSC $B1SHSC DB2A SH$C DB4'SH$C .HAZISH$C FNOR~SHSC E~ SHS¢ RAD SHSC DEPTH = 223 954 220 640 224 651 61 551 0 552 0.000 5,984 DEPTH = 221,284 ~24,315 20,614 60~483 0,552 0,000 6,210 DEPTH = 24,38 225,~i09 "59,913 :0,552 0,~000 6,139 DEPTH = 216.562 226,049 225 403 DEPTH 223 664 26 1:27 3I 59 o 0.000 6'428 6200.033 FEET DB1SHSC SB2 DB4A SH$C RB FINC SHSC RADI.SH$C 6000.033 FEET DB¸ 3B~ ,SHSc ,$HSC DB4A,SH$C RB.SH~C FINC,SHSC RADi;SH$C 5800,033 FEET .DBi,SHSC SB2,$H$C DB4A,SH$C RB*SHSC FINCeSHSC RADi.SH$¢ 5600,,033 FEET DBI,SH$C SB2;SHSC DB4A,SHSC RB,SHSC ~FIN.C,SHSC RADI'SHSC 5400,033 FEET DBI..SH$C SB2;SHSC DB4A'SHSC RB,SHSC FINC,SHSC RADi,SHSC 222.699 219.353 227,201 295,483 73.785 5.922 220,295 222'3i7 224,264 254,466 222,8~0 '6,090 ,.. 229,892 2,.,9,62 230 40 265 '~3 670 DBIA $HSC Db3 SHSC REV P!AZ SHSC DEVI SH$C RAD2.SHSC DBIA,SH$C DB3,SHSC REV,SHSC PIAZ,SHSC DEV !, $H8C RRD2eSHSC DBIA,SHSC DB3,SH$C REV,SH$C PfAZ,SHS¢ DEVI,SHSC RAD2,SH$C ,RE ,sHsc ,SH$C PiAZiSHSC D:~Vi,SHSC R~D2,SHSC 223.745 DB2.SHSC 224.125 DB3A.$HSC 1:404 SDEV.SH$C 168 GNOR.SHSC 3]~:753 EV.SHS¢ 984 RAD3.SHSC 222 988 DB2.$HSC 159 DB3A,~H~ 22~ 335 SDEV.SH · 3~ ,685 GNOR.$HSC 194 EV.$H&C 6 210 RAD3.~H$C 2~.375 DB2,$HSC .248 DB3A.$HSC EV,$HSC 6:1 ~ RAD3.~H$C 226,144 DB2.SHSC ,548 DB3A,SHSC 21~,952 SDEV';SHSC 32~..067 GNDR,SHS¢ 3 ;4o! EV.S SC ,189 RAD3.SHSC DB:!A,SH$C 231.868 DB2,SHSC D~3,SHSC 224,142 DB3Ae'$H~C REV,SH$C ' 854 640 ~3 EV,SH$C 220,859 2~1'076 0.753 .997 4,404 5,922 24.154 676 335 230 079 6 279 222,49! 230,000 1',854 5,999 DEPTH = 5200.033 FEET bis Tape Verification Listing Schlumberger AlasKa Computing Center SB1SHSC DB2A SHSC DB4 SHSC HAZ! SHSC FNOR SHSC E! SHSC RAD4 SH$C 226,?20 223,208 226,546 58,469 0,55i 0,000 5,942 DB1SH$C $B2 SHSC DB4A SHSC RBSH$C FINC SHSC RAD1SHSC DEPTH = 5000,033 FEET SBI,SHSC 222,617 DB!,$HSC DB2A,SHSC 226,226 SB2,SHSC DB4;SHSC 225,390 DB4A,SHSC HAZI,$HSC 58,331 RB'SH&C FNO~eSH$C 0,552 FXNC,SHSC EI-SH$C 0,.000 RADI,SHSC RAD4'$HSC 6,019 END OF DATA 2-AUG-1990 00)03 228,850 DB1A,SH$C 221,474 DB3,SHSC 228,66& REV,SHSC 241,398 PIAZ,SHSC '630 DEVZ, 7~ SH$C ,922 RAD2,SH$C 24,819 DB1A,SH$C 25,775 DB3,SH$C 227e380 REV,SHSC 240~852 elAZ,SHSC 013 RAD2eSH$C .. ,544 DB3A,$HSC 18,040 SDEV,$HSC 304,262 GNOR,SHSC 3~,463 EV,$HSC ,942 RAD3,$HSC 2 ,023 DB3A,SHSC $DEV,SH$C EV,SHSC *'019 RAD3,SHSC PAGEI 34 463 0 99"/ 18 040 5 922 10 F~bE NA~E ~ 'SHDT ,00~ SERVICE I GEObI$ YERSION I 002E07 DATE : 90/08/01 MAX REC SIZE : 1024 FILE F$ ' bAST ~¥PE : ILE : **** FILE HEADER FILE N~ME I SHDT ,004 SERVICE : GEOb~S 0 2EO? V~RSION : 9~/08/01 DRTE MAX REC SIZE ~ 1,024 FIbE TYPE ~ ~$ bAST FILE COS.GAR011,001 GAR011,001 LIS Tape Verification Listing Schlumberger AlasKa Computing Center 2-AUG-1990 00~03 DATA FORMAT SPECIFICATION RECORD · TYPE REPR CODE VAbUE I 66 0 2 66 0 3 79 8 4 66 1 5 66 6 73 ? 65 8 ?3 9 65 11 66 128 14 65 F! 15 66 68 16 66 0 66 ** SET TYPE.- CHAN ** NAME 8ERV UNIT SERVICE APl APl APl AP1 FILE NU NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SA EbEM CODE CHEX) DATA 1' DEPT,SH$C 7085,838 GR,SHSC DEPT,SHSC 6999,838 GR,SHSC DEPT,SH$C 6799,838 GR,SHSC DEPT,SH$C 6599,838 GR.,SHSC DEPT,SHSC 6399,838 GR,$~SC DEPT,SHSC .6199,838 GR,SH$C DEPT,$HSC 5999,838 GR,SHSC DEPT,SH$C 5799,838 GReSHSC 24,766 77,188 98,188 ~,., S5,875 )7'625 .55,906 ~9,219 PAGEI 11 ScSI~ Tape Yeriflcatton hist DEPT,&H$C 5599,838 GR,$HSC DEPTeSH&C 5399,838 GR,GH$C DEPT,&H$C 5199,838 GR,SH$C DEPT,$H$C 5000*338 GR,$H$C END OF DATA 2-A~G-1990 00:03 ~0,688 84,250 45,406 38,000 ***$ FIbENA~E :'SHDT ,004 SERYXCE I GEOLIS VERSION ' I 002E07 DATE: , 90/08/01 ,AX'AEC SIZE , 1024 rlbE<~¥Pg DATE' CONI~ TAPE ~RAIbER **** NAME · I :GEOblS I 90/08/01. TAPE i 73995 **'%~ i'REEb TRA ' SERVr~E NAME DATE I 9~ /0! C~N~'XNU'ATXON PREVIOUS REEb ¢O~ENT I P$1EOT~gARATHON OXb. CO~ TRADXNGBA¥~ :TBU ~'3