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Home My WebLink About189-133Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/19/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240119 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# HV B-15 50231200390000 212132 10/21/2023 Yellowjacket GPT-PERF TBU M-5 50733204130000 189133 10/20/2023 AK E-Line PERF TBU M-11 50733205900000 210145 10/21/2023 AK E-Line PLUG/PLT Please include current contact information if different from above. T38435 T38436 T38467 1/24/2024 TBU M-5 50733204130000 189133 10/20/2023 AK E-Line PERF Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.22 12:57:24 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops 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 5,600 feet 3,633 feet true vertical 5,275 feet N/A feet Effective Depth measured 3,630 feet See schematic feet true vertical 3,619 feet See schematic feet Perforation depth Measured depth 3,282 - 3,620 feet True Vertical depth 3,280 - 3,610 feet 7" L-80 2,565 (MD) 2,565 (TVD) Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 3,316 (MD) 3,314 (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: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Middle Kenai Gas 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: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Liner 1,276 7" 3,841 3,820 8,160psi 7,020psi 12 323-553 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 575 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A 853 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 936 N/A 32 Size 936 1,440 0 29590 0 210 13-3/8" 10-3/4" 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 189-133 50-733-20413-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018730 McArthur River / Middle Kenai Gas Trading Bay Unit M-05 Plugs Junk measured Length measured TVD Production Liner 429 5,051 1,075 Casing Conductor 511 5,245 3-1/2" 511 5,562 4,803 4,642 1,357 2,553 1,440Surface Intermediate Production 20" 16" 4,020psi 7,100psi 2,630psi 3,090psi 6,450psi 8,150psi 2,635 2,635 Burst Collapse 1,020psi 1,540psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:59 pm, Nov 20, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.11.20 11:57:24 - 09'00' Dan Marlowe (1267) ____________________________________________________________________________________________________________ Revised By JLL 11/15/23 Steelhead Well: M-05 PTD: 189-133 API: 50-733-20413-00-00SCHEMATIC PBTD = 3,630 TD = 5,600 MAX HOLE ANGLE = 38.7 @ 5,600 RKB to TBG Head = 74.4 KB to MSL = 160 20 D-6 D-2 C1 & C2 16 D-3B D-1 9-5/8 13-3/8 B-7 TOC @ 3,702 TOS @ 3,707 B-3 B5 B-3 2 Fill Tagged @ 4,880 on 12/21/02 3 4 5 6 9 1 7 8 B-6TOC 3,630 Posi-set plug 3,633 TOF - 3,617 A CASING DETAIL Size Wt Grade Conn ID Top Btm 20 133 X-56 83 936 16 75 J-55 / N-80 83 1,440 13-3/8 61/68 K-55 82 2,635 10-3/4 55.5 N-80 9.76 82 511 9-5/8" 47 S-95 BTC 8.681 511 5,562 7 Scab Liner 29 L-80 6.184 2,565 3,841 3-1/2 Scab Liner 9.2 L-80 Hyd 533 2.992 3,728 4,803 TUBING DETAIL 7 29 L-80 6.184 73.9 2,565 3-1/2 9.2 L-80 Butt 2.992 78.53 3,316 JEWELRY DETAIL NO. Depth Length ID Item 74.4 6.184 TBG Hanger FMC 1 79 0.75 2.992 Deployment Sub w/ GS Profile & SBE OD 5.82 2 407 3.8 Halliburton CP-2 TRSV #78-00-390 w/ XOs 7 29 to 7, 26# ABSTL top & btm 436 19.93 2.813 SSSV Insert Profile Nipple w/ Packing Adapters.WL SSSV installed 11/4/23 3 1,998' CTC External Casing Packer 4 2,565' BOT ZXP Pkr; HMC Hngr; 27 jts of 7. cemented w/ 225 sks. 5 3,277 1.24 2.97 HES Straight Slot LSA w/ 10 of seals 6 3,279 MD 14.14 BWD Eline set pkr w/ 10 SBE & XO to 3-1/2 Butt (3264 DIL) 7 3,304 1.51 2.813 X Profile Nipple 8 3,313 1.6 2.75 XN No-Go Nipple w/ 2.813 Profile w/ WLEG 9 Btm 3,316 1.32 2.992 WLEG PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount Condition B-3 3,282 3,302 3,280 3,300 20 Open 10/21/2023 B-3 3,306 3,336 3,304 3,334 30 Open B-3 3,347 3,382 3,344 3,379 35 Open B-5 3,518' 3,558' 3,511' 3,550' 40 Perf 10-23-12 B-5 3,558' 3,588' 3,550' 3,579' 30 Re-Perf 1-21-08 B-6 3,606' 3,616' 3,596' 3,606' 10 Perf 10-23-12 B-6 3,616' 3,620' 3,606' 3,610' 4 Re-Perf 1-21-08 B-6 3,636' 3,650' 3,625' 3,639' 14 ISOLATED B-6 3,671 3,679' 3,659' 3,667' 8 ISOLATED B-7 3,746' 3,771' 3,730' 3,754' 25 ISOLATED B-7 3,778' 3,798' 376' 3,780' 20 ISOLATED C-1 3,890' 3,910' 3,866' 3,884' 20 ISOLATED C-2 3,923' 3,936' 3,896' 3,908' 13 ISOLATED D-1 4,292' 4,412' 4,223' 4,324' 120 Behind liner D-2 4,662' 4,708' 4,528' 4,565' 46 Behind liner D-3B 4,864' 4,914' 4,691' 4,731' 50 ISOLATED D-6 5,302' 5,372' 5,040' 5,095' 70 ISOLATED GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,908 1,908 2.992 BST Slim Line 12 DOME 960 2 2,712 2,712 2.992 BST Slim Line 12 DOME 940 3 3,100 3,100 2.992 BST Slim Line 20 ORIFICE CEMENT DETAIL 9-5/8" 12-1/4" Hole: Pumped 130bbls 13.2ppg lead cement followed by 106bbls 15.6ppg class G tail cement. 3/1/90 cement log showed good cement up to 3200 MD with patchy cement up to 2900 MD. Isolated Jewelry Detail on Page 2 ____________________________________________________________________________________________________________ Revised By JLL 11/15/23 Steelhead Well: M-05 PTD: 189-133 API: 50-733-20413-00-00SCHEMATIC ISOLATED JEWELRY DETAIL NO. Depth Length ID Item A 3,680 57.19 1.61' Upper Vent Screen Assy. f/ B-7 3,728 MD 1076 2.992 BOT ZXP pkr (@ 3713 DIL) w/ 12 x 5-1/4 Tie-Back Ext; 33 jts of 3-1/2, 9.2#, L-80, tbg; 3,737 2.51 1.625' Polish Bore Receptacle w/ 1 ½ NU Pin x Box 3,740 65.17 1.5' Upper Screen Assy. f/ B-7 3,805 10.61 1.61' Upper Sump Pkr Assy. f/ B-7 3,832 DIL BOT 9-5/8 x 6 FB-1 pkr; X nipple @ 3,845; WLEG @ 3857. 3,858 2.0 CIBP 4,225 DIL BOT 9-5/8 x 6 FB-1 pkr; X nipple (4.562) @ 4,238; WLEG @ 4,250. 4,550 DIL BOT 9-5/8 x 6 FB-1 pkr; X nipple (4.562) @ 4,563; WLEG @ 4,575. 4,754 CIBP 4,761 DIL BWH Perma Pkr w/10 SBE; MO Ext; XO to 4-1/2 Butt; Tbg cut @ 4,806 on 3/21/90. Rig Start Date End Date Eline 10/20/23 11/5/23 Daily Operations: 10/21/2023 - Saturday IFO, PJSM PTW, start up and warm up equipment, rig up same, pressure test lubricator to 250 low and 1500 psi hi, RiH with 20 ft perf gun load with 6 spf at 60* phasing log gun on depth, perf the B-3 sand f/ 3282 to 3302. Initial FTP AT 11.7 # at 670 rate, 5 minute reading FTP 11.7# AT 630 rate, 10 minute reading. FTP 11.7# AT 630 rate, 15 minute reading 11.7 # at 630 k rate. Log up to 3130 pooh, at surface close swab and rig down E-line (all shots fired) ,gun was wet. Remove wireline bridge and install deck plate, move to M-11 well 10/30/2023 - Monday Finish Rig up and P/T 250 Low 1500 HIGH Shut in well RIH/w KJ /w 3" Brush/w 2.8" Gauge Ring to 403' SLM (436' RKB) start Brushing The Profile for 20 mins POOH Remove OJ's RIH/w 3" Xline /w Prong /w SSSV to 390' SLM while Purging 4 Gallons thru Control Line then Set at 403' SLM (' RKB) w/t until Setting then Pressure up on Control Line good Hold w/t shear and POOH Leave Pressured up for 15 Mins then Flow well an hour while Gas Is Migrating up Control line from Void in 7" Insert Attempt Closure Test- Start Bleeding Gas from Control Line 12 mins to close- Break off Control line and Bleed to Bucket getting Gas and Hydraulic Fluid Back slowly - purge to bucket for about an hour 15:30 to 16:30 Pressure Valve back up to Open hold with pressure 10 mins then Dump to bucket for an hour to migrate out more Gas Closure in 5 Mins 39 Seconds (needs to be under 4 Mins) Discuss with Production - Leave to Bleed until Midngiht Repressure up and hold 10 mins then Bleed for the rest of night shift to Let More Gas Migrate up line from Void at 7" Insert Lay down Lub and Secure well for the Night at Riser Turn in permit and Lay down Crew 10/20/2023 - Friday Pt 1500 PSI- pass. Rih w/ 3 1/2 Gs w/ 5' (1") prong to 403' wl, w/t pooh. Ooh w/ SSSV. Rih w/ 2.55 G-ring to 3654' kb, pooh. Rih w/ 22' of 2.5 Dummy guns to 3654' kb, pooh. Ooh w/ tools, rig down. Re-dress W/L vavles. Flight Departing for OSK. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20413-00-00 189-133 Well Name Trading Bay Unit M-05 Rig Start Date End Date Eline 10/20/23 11/5/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20413-00-00 189-133 Well Name Trading Bay Unit M-05 11/04/2023 - Saturday Meet at PWL shop, load up tools, drive to heliport. Standby for helicopter. Arrive on Steelhead, permit, JSA, TGSM. Rig up slickline. P/T to 1500 PSI, good. RIH W/ 3 1/2 GS and 6' prong to 441' KB, pull SSSV. RIH W/ 3" X-Line, 6' prong and SSSV, pump 5 gallons diesel, set SSSV at 443' KB. Pump 4 gallons diesel, pressures up to 5000 PSI, shear o , POOH. Clean up area, done for night. 11/03/2023 - Friday Verbal approval from Bryan McLellan at AOGCC to extend SSSV compliance period through 11/10/23 to allow for continued troubleshooting. 10/31/2023 - Tuesday Attend Moring Meeting- Complete Permit and JSA Discuss SSSV with Production - Overnight the Night Crew Tested twice between Long Bleed times to the Bucket the first Closure test was about 5mins 30 seconds- 2nd test about 6 mins- Discuss plans forward Open up SSSV and Bleed get Closure at 5 Mins 39 Seconds Start Rapidly Opening and Closing Valve to Surge Gas out of Insert into the Control Line Leave to Bleed for an hour Pump Up to 3300 PSI then Bleed Rapidly get 5 Mins 20 Seconds Start working pump open and Closed Rapidly about 15 to 20 Times trying to Surge Gas Pocket then Open To bleed all Closures same around 5 mins 30 Seconds Discuss Ideas with Production - Standby for an attempt to Set up a Venturi to Pull Fluid and Pull a Vac on Line Get some Fluid back - after an hour of Venturi Check for Vac on control Line - feels weak but on Vac - Isolate and Turn back to Pumping Hydraulic Fluid Pressure back up to 3300 PSI do Closure Test 5 Mins 22 Seconds Decision Made From Foreman to Rig down and Let Production Manipulate Pressures and Try to Burp Gas over next couple days until Reaching Target Closure of under 4 Mins Rig down Equipment and Remove Riser- Remove Bridge- Reset Hatchs Rig Start Date End Date Eline 10/20/23 11/5/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20413-00-00 189-133 Well Name Trading Bay Unit M-05 11/05/2023 - Sunday Switch to pannel, standby. Rig down slickline. Standby for helicopter. Arrive at PWL shop. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Ryan Rupert To:McLellan, Bryan J (OGC) Cc:Regg, James B (OGC); J.C. Waski; George Peters; Brandon Kocinski; Juanita Lovett; Ryan Rupert Subject:Steelhead M-05 SSSV testing (PTD#189-133) Date:Friday, November 3, 2023 11:53:58 AM Bryan- Per our conversation, thank you for the verbal approval to extend the days to get M-05's WL-SSSV functional as troubleshooting continues. The WLSSSV is installed, and does close and hold, it just is taking a minute or two longer than the 4 minute regulatory requirement. We will plan on remedying and state testing the SSSV no later than Friday 11/10. Thank you 10/30-31: SL installed WL-SSSV. Won’t close within 4 minutes. Left in hole to flow / warm up well. 10/23-24: SL installed WL-SSSV. Won’t close within 4 minutes. Remove WL-SSSV, take back to shop 10/21: EL perf add per sundry 323-553 10/20: WL-SSSV pulled for perfs Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address: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): 5,600 N/A Casing Collapse Conductor Surface 1,020psi Intermediate 1,540psi Production 4,020psi Production 7,100psi Liner 7,020psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 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 3,820' 8,160psi 10/20/2023 4,803'1,075' 7" & 3-1/2" 4,642' See schematic See schematic 5,562' Perforation Depth MD (ft): 511' 3,306 - 3,620 5,051' 3-1/2" 3,304 - 3,610 1,276' 7" 3,841' 5,245'9-5/8" 853' 20" 16" 13-3/8" 1,357' 10-3/4"429' 2,553' MD 6,450psi 2,630psi 3,090psi 1,440' 2,635' 511' 1,440' 2,635' Length Size Proposed Pools: 936' 936' L-80 & L-80 TVD Burst 2,565 & 3,316 8,150psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 189-133 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20413-00-00 Hilcorp Alaska, LLC CO 228A AOGCC USE ONLY 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 Trading Bay Unit M-05 McArthur River Middle Kenai Gas Same 5,275 3,630 3,619 1,264psi 3,633 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 3:11 pm, Oct 05, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.10.05 13:27:46 - 08'00' Dan Marlowe (1267) SFD 10/5/2023BJM 10/16/23 DSR-10/5/23 10-404 Perforate *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.10.16 21:29:49 -06'00'10/16/23 RBDMS JSB 101723 Perf Well: Steelhead M-05 Well Name:M-05 API Number:50-733-20413-00-00 Current Status:Online gas producer Permit to Drill Number:189-133 First Call Engineer:Ryan Rupert (907) 301-1736 (c)Leg B2 (NE corner) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:1625 psi @ 3,610’ TVD 0.45psi/ft to deepest open perf Max. Potential Surface Pressure: 1264 psi Using 0.1 psi/ft Brief Well Summary Steelhead well M-05 is an online gas producer with additional B-3 sand potential to complete. The goal of this project is to add B-3 sand perfs within the existing Grayling Gas Sands Pool. Pertinent information: - SSSV: Has a WL SSSV set at 407’ - Min ID: 2.75” at 3,313’ MD (3-1/2” XN-nipple) - Max inclination down to perf interval: 12 degrees at 3,300’ MD - Well History: o 4/21/20 SL gets WL-SSSV reset and holding after troubleshooting Note specific packing dimensions required o 4/8/20 EL tags at 3,636’ ELMD with 20’ x 2-3/8” gun EL adds B-3 perfs with multiple 2-3/8” x 20’ gun runs Perfs below tubing tail, and perfs through the tubing tail added equivalent rate o 4/7/20: SL pulls WL-SSSV in preparation for Perfs. D&T to 3,646’ SLMD with 2.5” x 20’ dummy gun o 2003: 3-1/2” tubing / velocity string run to downsize from existing 7” tubing Middle Kenai Gas Pool per CO 228A. SFD o add B-3 sand perfs within the existing Grayling Gas Sands Pool. Perf Well: Steelhead M-05 Note: WL-SSSV will need to be pulled and reset within 14 days to accommodate wellwork. E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 1500psi high 3. RIH and perforate Grayling Gas Sand per table below a. Shooting through 3-1/2” tubing tail, 7” tubing tail/cement, and 9-5/8” casing/cement. b. All perfs stay below 3-1/2” x 7” Packer (no effect on well integrity) c. Top perf has 4’ standoff from deepest possible depth of stinger / seals (assumes no-go’d on top of BWD packer) i. Top Packer: 3,269’ ELMD ii. Bottom seal / stinger: 3,278’ ELMD iii. Bottom Seal Bore receptacle: 3,282’ ELMD iv. Top Proposed perf: 3,282’ ELMD v. Top X-nipple: 3,292 ELMD vi. Top XN nipple: 3,302 ELMD 4. RDMO EL Attachments: 1. Proposed Wellbore Schematic Zone Top MD Bottom MD Top TVD Bottom TVD TOTAL B-3 3,282’ 3,302’3,280’ 3,300 20’ Perf Well: Steelhead M-05 ____________________________________________________________________________________________________________ Revised By JLL 10/05/23 Steelhead Well: M-05 PTD: 189-133 API: 50-733-20413-00-00SCHEMATIC PBTD = 3,630’ TD = 5,600’ MAX HOLE ANGLE = 38.7q @ 5,600’ RKB to TBG Head = 74.4’ KB to MSL = 160’ 20” D-6 D-2 C1 & C2 16” D-3B D-1 9-5/8” 13-3/8” B-7 TOC @ 3,702’ TOS @ 3,707’ B-3 B5 2 Fill Tagged @ 4,880’ on 12/21/02 3 4 5 6 9 1 7 8 B-6TOC – 3,630’ Posi-set plug 3,633’ TOF - 3,617’ A CASING DETAIL Size Wt Grade Conn ID Top Btm 20” 133 X-56 83’ 936’ 16” 75 J-55 / N-80 83’ 1,440’ 13-3/8” 61/68 K-55 82’ 2,635’ 10-3/4” 55.5 N-80 9.76 82’ 511’ 9-5/8" 47 S-95 BTC 8.681 511’ 5,562’ 7” Scab Liner 29 L-80 6.184 2,565’ 3,841’ 3-1/2” Scab Liner 9.2 L-80 Hyd 533 2.992 3,728 4,803 TUBING DETAIL 7” 29 L-80 6.184 73.9 2,565’ 3-1/2” 9.2 L-80 Butt 2.992 78.53’ 3,316’ JEWELRY DETAIL NO. Depth Length ID Item 74.4 6.184 TBG Hanger FMC 1 79’ 0.75’ 2.992 Deployment Sub w/ “GS” Profile & SBE OD 5.82” 2 407 3.8 5.963 / WL insert Halliburton CP-2 TRSV #78-00-390 w/ XO’s 7” 29 to 7”, 26# ABSTL top & btm (WL Insert small ID) 436’ 19.93’ 2.813 SSSV Insert Profile Nipple w/ Packing Adapters. 3 1,998' CTC External Casing Packer 4 2,565' BOT ZXP Pkr; HMC Hngr; 27 jts of 7”. cemented w/ 225 sks. 5 3,277’ 1.24 2.97 HES “Straight Slot” LSA w/ 10’ of seals 6 3,279’ MD 14.14’ “BWD” Eline set pkr w/ 10’ SBE & XO to 3-1/2” Butt (3264’ DIL) 7 3,304’ 1.51’ 2.813 “X” Profile Nipple 8 3,313’ 1.6’ 2.75 “XN” No-Go Nipple w/ 2.813 Profile w/ WLEG 9 Btm 3,316’ 1.32’ 2.992 WLEG PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount Condition B-3 3,306’ 3,336’ 3,304’ 3,334’ 30’ Open B-3 3,347’ 3,382’ 3,344’ 3,379’ 35’ Open B-5 3,518' 3,558' 3,511' 3,550' 40 Perf 10-23-12 B-5 3,558' 3,588' 3,550' 3,579' 30 Re-Perf 1-21-08 B-6 3,606' 3,616' 3,596' 3,606' 10 Perf 10-23-12 B-6 3,616' 3,620' 3,606' 3,610' 4 Re-Perf 1-21-08 B-6 3,636' 3,650' 3,625' 3,639' 14 ISOLATED B-6 3,671 3,679' 3,659' 3,667' 8 ISOLATED B-7 3,746' 3,771' 3,730' 3,754' 25 ISOLATED B-7 3,778' 3,798' 376' 3,780' 20 ISOLATED C-1 3,890' 3,910' 3,866' 3,884' 20 ISOLATED C-2 3,923' 3,936' 3,896' 3,908' 13 ISOLATED D-1 4,292' 4,412' 4,223' 4,324' 120 Behind liner D-2 4,662' 4,708' 4,528' 4,565' 46 Behind liner D-3B 4,864' 4,914' 4,691' 4,731' 50 ISOLATED D-6 5,302' 5,372' 5,040' 5,095' 70 ISOLATED GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,908’ 1,908’ 2.992 BST Slim Line 12 DOME 960 2 2,712’ 2,712’ 2.992 BST Slim Line 12 DOME 940 3 3,100’ 3,100’ 2.992 BST Slim Line 20 ORIFICE CEMENT DETAIL 9-5/8" 12-1/4" Hole: Pumped 130bbls 13.2ppg lead cement followed by 106bbls 15.6ppg class G tail cement. 3/1/90 cement log showed good cement up to 3200’ MD with patchy cement up to 2900’ MD. Isolated Jewelry Detail on Page 2 ____________________________________________________________________________________________________________ Revised By JLL 10/05/23 Steelhead Well: M-05 PTD: 189-133 API: 50-733-20413-00-00SCHEMATIC ISOLATED JEWELRY DETAIL NO. Depth Length ID Item A 3,680’ 57.19’ 1.61' Upper Vent Screen Assy. f/ B-7 3,728’ MD 1076’ 2.992 BOT ZXP pkr (@ 3713’ DIL) w/ 12’ x 5-1/4” Tie-Back Ext; 33 jts of 3-1/2”, 9.2#, L-80, tbg; 3,737’ 2.51’ 1.625' Polish Bore Receptacle w/ 1 ½” NU Pin x Box 3,740’ 65.17’ 1.5' Upper Screen Assy. f/ B-7 3,805’ 10.61’ 1.61' Upper Sump Pkr Assy. f/ B-7 3,832’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple @ 3,845’; WLEG @ 3857’. 3,858’ 2.0’ CIBP 4,225’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple (4.562”) @ 4,238’; WLEG @ 4,250’. 4,550’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple (4.562”) @ 4,563’; WLEG @ 4,575’. 4,754’ CIBP 4,761’ DIL BWH Perma Pkr w/ 10’ SBE; MO Ext; XO to 4-1/2” Butt; Tbg cut @ 4,806’ on 3/21/90. ____________________________________________________________________________________________________________ Revised By JLL 10/05/23 Steelhead Well: M-05 PTD: 189-133 API: 50-733-20413-00-00PROPOSED PBTD = 3,630’ TD = 5,600’ MAX HOLE ANGLE = 38.7q @ 5,600’ RKB to TBG Head = 74.4’ KB to MSL = 160’ 20” D-6 D-2 C1 & C2 16” D-3B D-1 9-5/8” 13-3/8” B-7 TOC @ 3,702’ TOS @ 3,707’ B-3 B5 B-3 2 Fill Tagged @ 4,880’ on 12/21/02 3 4 5 6 9 1 7 8 B-6TOC – 3,630’ Posi-set plug 3,633’ TOF - 3,617’ A CASING DETAIL Size Wt Grade Conn ID Top Btm 20” 133 X-56 83’ 936’ 16” 75 J-55 / N-80 83’ 1,440’ 13-3/8” 61/68 K-55 82’ 2,635’ 10-3/4” 55.5 N-80 9.76 82’ 511’ 9-5/8" 47 S-95 BTC 8.681 511’ 5,562’ 7” Scab Liner 29 L-80 6.184 2,565’ 3,841’ 3-1/2” Scab Liner 9.2 L-80 Hyd 533 2.992 3,728 4,803 TUBING DETAIL 7” 29 L-80 6.184 73.9 2,565’ 3-1/2” 9.2 L-80 Butt 2.992 78.53’ 3,316’ JEWELRY DETAIL NO. Depth Length ID Item 74.4 6.184 TBG Hanger FMC 1 79’ 0.75’ 2.992 Deployment Sub w/ “GS” Profile & SBE OD 5.82” 2 407 3.8 5.963 / WL insert Halliburton CP-2 TRSV #78-00-390 w/ XO’s 7” 29 to 7”, 26# ABSTL top & btm (WL Insert small ID) 436’ 19.93’ 2.813 SSSV Insert Profile Nipple w/ Packing Adapters. 3 1,998' CTC External Casing Packer 4 2,565' BOT ZXP Pkr; HMC Hngr; 27 jts of 7”. cemented w/ 225 sks. 5 3,277’ 1.24 2.97 HES “Straight Slot” LSA w/ 10’ of seals 6 3,279’ MD 14.14’ “BWD” Eline set pkr w/ 10’ SBE & XO to 3-1/2” Butt (3264’ DIL) 7 3,304’ 1.51’ 2.813 “X” Profile Nipple 8 3,313’ 1.6’ 2.75 “XN” No-Go Nipple w/ 2.813 Profile w/ WLEG 9 Btm 3,316’ 1.32’ 2.992 WLEG PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount Condition B-3 ±3,282’ ±3,302’ ±3,280’ ±3,300’ ±20’ PROPOSED B-3 3,306’ 3,336’ 3,304’ 3,334’ 30’ Open B-3 3,347’ 3,382’ 3,344’ 3,379’ 35’ Open B-5 3,518' 3,558' 3,511' 3,550' 40 Perf 10-23-12 B-5 3,558' 3,588' 3,550' 3,579' 30 Re-Perf 1-21-08 B-6 3,606' 3,616' 3,596' 3,606' 10 Perf 10-23-12 B-6 3,616' 3,620' 3,606' 3,610' 4 Re-Perf 1-21-08 B-6 3,636' 3,650' 3,625' 3,639' 14 ISOLATED B-6 3,671 3,679' 3,659' 3,667' 8 ISOLATED B-7 3,746' 3,771' 3,730' 3,754' 25 ISOLATED B-7 3,778' 3,798' 376' 3,780' 20 ISOLATED C-1 3,890' 3,910' 3,866' 3,884' 20 ISOLATED C-2 3,923' 3,936' 3,896' 3,908' 13 ISOLATED D-1 4,292' 4,412' 4,223' 4,324' 120 Behind liner D-2 4,662' 4,708' 4,528' 4,565' 46 Behind liner D-3B 4,864' 4,914' 4,691' 4,731' 50 ISOLATED D-6 5,302' 5,372' 5,040' 5,095' 70 ISOLATED GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,908’ 1,908’ 2.992 BST Slim Line 12 DOME 960 2 2,712’ 2,712’ 2.992 BST Slim Line 12 DOME 940 3 3,100’ 3,100’ 2.992 BST Slim Line 20 ORIFICE CEMENT DETAIL 9-5/8" 12-1/4" Hole: Pumped 130bbls 13.2ppg lead cement followed by 106bbls 15.6ppg class G tail cement. 3/1/90 cement log showed good cement up to 3200’ MD with patchy cement up to 2900’ MD. Isolated Jewelry Detail on Page 2 ____________________________________________________________________________________________________________ Revised By JLL 10/05/23 Steelhead Well: M-05 PTD: 189-133 API: 50-733-20413-00-00PROPOSED ISOLATED JEWELRY DETAIL NO. Depth Length ID Item A 3,680’ 57.19’ 1.61' Upper Vent Screen Assy. f/ B-7 3,728’ MD 1076’ 2.992 BOT ZXP pkr (@ 3713’ DIL) w/ 12’ x 5-1/4” Tie-Back Ext; 33 jts of 3-1/2”, 9.2#, L-80, tbg; 3,737’ 2.51’ 1.625' Polish Bore Receptacle w/ 1 ½” NU Pin x Box 3,740’ 65.17’ 1.5' Upper Screen Assy. f/ B-7 3,805’ 10.61’ 1.61' Upper Sump Pkr Assy. f/ B-7 3,832’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple @ 3,845’; WLEG @ 3857’. 3,858’ 2.0’ CIBP 4,225’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple (4.562”) @ 4,238’; WLEG @ 4,250’. 4,550’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple (4.562”) @ 4,563’; WLEG @ 4,575’. 4,754’ CIBP 4,761’ DIL BWH Perma Pkr w/10’ SBE; MO Ext; XO to 4-1/2” Butt; Tbg cut @ 4,806’ on 3/21/90. 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 5,600 feet 3,633 feet true vertical 5,275 feet N/A feet Effective Depth measured 3,630 feet See Schematic feet true vertical 3,619 feet See Schematic feet Perforation depth Measured depth 3,306 - 3,620 feet True Vertical depth 3,304 - 3,610 feet 7" 29# / L-80 2,565 (MD) 2,565 (TVD) Tubing (size, grade, measured and true vertical depth)3-1/2" V String L-80 3,316 (MD) 3,314 (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:Mark McKinley Authorized Title: Contact Email:mmckinley@hilcorp.com Contact Phone:(907) 777-8387 WINJ WAG 686 Water-Bbl MD 936 1,440 2,635 4,803 TVD 936 0 Oil-Bbl measured true vertical Packer 9-5/8: 3-1/2" 511 5,562 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 240 Casing Pressure Tubing Pressure 59 Trading Bay Unit M-05 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 189-133 50-733-20413-00-00 Liner 1,276 7" Plugs Junk measured N/A ADL0018730 N/A 3,841 3,820 8,160psi 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-129 34 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 38 Authorized Signature with date: Authorized Name: Liner 1,075 5. Permit to Drill Number: 1,124 McArthur River Field / Middle Kenai Gas PoolN/A measured 429 5,051 Surface Intermediate Production Production Casing Conductor 20" 16" 13-3/8" 10-3/4" Length 853 1,357 2,553 1,440 2,635 511 5,245 4,642 7,020psi 7,100psi Burst 3,060psi 2,630psi 3,090psi 6,450psi 8,150psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 1,500psi 1,020psi 1,540psi 4,020psi Daniel E. Marlowe Operations Manager PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Daniel Marlowe I am approving this document 2020.04.27 12:56:57 -08'00' Daniel Marlowe By Samantha Carlisle at 3:10 pm, Apr 27, 2020 gls4/28/20 DSR-4/27/2020 RBDMS HEW 4/27/2020 SFD 4/28/2020 ____________________________________________________________________________________________________________ Revised By JLL 04/24/20 Steelhead Well: M-05 PTD: 189-133 API: 50-733-20413-00-00SCHEMATIC PBTD = 5,478’ TD = 5,600’ MAX HOLE ANGLE = 38.7q @ 5,600’ RKB to TBG Head = 74.4’ KB to MSL = 160’ 20” D-6 D-2 C1 & C2 16” D-3B D-1 9-5/8” 13-3/8” B-7 TOC @ 3,702’ TOS @ 3,707’ B-3 1 Fill Tagged @ 4,880’ on 12/21/02 2 3 5 6 7 4 9 8 A C D E F G B H e) d) c) b) a) B-5 B-6TOC – 3,630’ Posi-set plug 3,633’ TOF- 3,617’ CASING DETAIL Size Wt Grade Conn ID Top Btm 20” 133 X-56 83’ 936’ 16” 75 J-55 / N-80 83’ 1,440’ 13-3/8” 61/68 K-55 82’ 2,635’ 10-3/4” 55.5 N-80 9.76 82’ 511’ 9-5/8" 47 S-95 BTC 8.681 511’ 5,562’ 7” Scab Liner 29 L-80 6.184 2,565’ 3,841’ 3-1/2” Scab Liner 9.2 L-80 Hyd 533 2.992 3,728 4,803 TUBING DETAIL 7” 29 L-80 6.184 73.9 2,565’ 3-1/2” 9.2 L-80 Butt 2.992 78.53’ 3,316’ JEWELRY DETAIL NO. Depth Length ID Item 74.4 6.184 TBG Hanger FMC 1 407 3.8 5.963 Halliburton CP-2 TRSV #78-00-390 w/ XO’s 7” 29 to 7”, 26# ABSTL top & btm 2 1,998' CTC External Casing Packer 3 2,565' BOT ZXP Pkr; HMC Hngr; 27 jts of 7”. cemented w/ 225 sks. 4 3,728’ MD 1076’ 2.992 BOT ZXP pkr (@ 3713’ DIL) w/ 12’ x 5-1/4” Tie-Back Ext; 33 jts of 3-1/2”, 9.2#, L-80, tbg; 5 3,832’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple @ 3,845’; WLEG @ 3857’. 6 4,225’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple (4.562”) @ 4,238’; WLEG @ 4,250’. 7 4,550’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple (4.562”) @ 4,563’; WLEG @ 4,575’. 8 4,754’ CIBP 9 4,761’ DIL BWH Perma Pkr w/ 10’ SBE; MO Ext; XO to 4-1/2” Butt; Tbg cut @ 4,806’ on 3/21/90. VELOCITY STRING DETAIL A 79’ 0.75’ 2.992 Deployment Sub w/ “GS” Profile & SBE OD 5.82” B 436’ 19.93’ 2.813 SSSV Insert Profile Nipple w/ Packing Adapters. C 1,908’ 6.84’ 2.992 3-1/2” BST Slim Line GLM 2,712’ 6.85’ 2.992 3-1/2” BST Slim Line GLM 3,100’ 6.38’ 2.992 3-1/2” BST Slim Line GLM D 3,277’ 1.24 2.97 HES “Straight Slot” LSA w/ 10’ of seals E 3,279’ MD 14.14’ “BWD” Eline set pkr w/ 10’ SBE & XO to 3-1/2” Butt (3264’ DIL) F 3,304’ 1.51’ 2.813 “X” Profile Nipple G 3,313’ 1.6’ 2.75 “XN” No-Go Nipple w/ 2.813 Profile w/ WLEG H Btm 3,316’ 1.32’ 2.992 WLEG PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount Condition B-3 3,306’ 3,336’ 3,304’ 3,334’ 30’ Open B-3 3,347’ 3,382’ 3,344’ 3,379’ 35’ Open B-5 3,518' 3,558' 3,511' 3,550' 40 Perf 10-23-12 B-5 3,558' 3,588' 3,550' 3,579' 30 Re-Perf 1-21-08 B-6 3,606' 3,616' 3,596' 3,606' 10 Perf 10-23-12 B-6 3,616' 3,620' 3,606' 3,610' 4 Re-Perf 1-21-08 B-6 3,636' 3,650' 3,625' 3,639' 14 ISOLATED B-6 3,671 3,679' 3,659' 3,667' 8 ISOLATED B-7 3,746' 3,771' 3,730' 3,754' 25 ISOLATED B-7 3,778' 3,798' 376' 3,780' 20 ISOLATED C-1 3,890' 3,910' 3,866' 3,884' 20 ISOLATED C-2 3,923' 3,936' 3,896' 3,908' 13 ISOLATED D-1 4,292' 4,412' 4,223' 4,324' 120 Behind liner D-2 4,662' 4,708' 4,528' 4,565' 46 Behind liner D-3B 4,864' 4,914' 4,691' 4,731' 50 ISOLATED D-6 5,302' 5,372' 5,040' 5,095' 70 ISOLATED Fish 5,376’ 5’± Cut Tbg; “X” Nipple; 7’ 4-1/2” pup jt THRU TUBING GP EQUIPMENT a 3680’ 57.19’ 1.61' Upper Vent Screen Assy. f/ B-7 b 3737’ 2.51’ 1.625' Polish Bore Receptacle w/ 1 ½” NU Pin x Box c 3740’ 65.17’ 1.5' Upper Screen Assy. f/ B-7 d 3805’ 10.61’ 1.61' Upper Sump Pkr Assy. f/ B-7 e 3858’ 2.0’ CIBP B-3 3,347’3,382’3,344’3,379’35’Open B-3 B-3 3,306’ 3,336’ 3,304’ 3,334’ 30’ Open Rig Start Date End Date WL & SL 4/7/20 4/13/20 R/U on M-05, P/T lubricator 250/1500 good. RIH w/ Brush wipe through profile @ 407', rig w/WRSV set in profile at 407’ make 3 runs to get on seat, pump open valve and pt to 4200 psi to ensure seated good. 04/07/2020 - Tuesday Mobe hands to location, orientate & PJSM. R/U w/l, spot eq. M/u lubricator & PT 250/1500 good. RIH w/3" GS w/7' prong t/456', bleed off ctl line, lock in & pull WLRSV. RIH w/2.75" GR t/ tag @ 3646' KB, POOH. RIH w/2.5" x 20' dummy gun t/ 3646'KB tag, POOH. R/D w/l unit. Spot e-line unit on M-05 & start r/u. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20413-00-00 189-133 Well Name Trading Bay Unit M-05 04/08/2020 - Wednesday PJSM, simops meetings. Continue rigging up E-line. M/U tool string Garm 2 3/8" 60 deg phasing 5 SPF gun. M/U lubricator. PT lub t/250/1500 good. RIH (well flowing 700CFD) t/3636' wlm, tag, log up t/3080'. Send logs to town for Geo & Res engineers to correlate. Advised to make 12' adjustment. Re-send adjusted log for verification, good. RIH & pull up into position placing shots @ 3382'-3362', fire guns, POOH all shots fired. M/u 15' 2 3/8" gun 5 spf, 60 deg phasing, RIH, correlate into position placing shots from 3362'-3347' fire guns, POOH all shots fired. M/u 15' 2 3/8" gun 5 spf, 60 deg phasing, RIH, correlate into position placing shots from 3336'-3316' fire guns, POOH no shots fired. Troubleshoot, (detonator fired but did not ignite prima cord) re-arm gun, RIH, correlate into position placing shots from 3336'-3316' fire guns, POOH all shots fired. M/u 10' 2 3/8" gun 5 spf, 60 deg phasing, RIH, correlate into position placing shots from 3316'-3306', fire guns, POOH all shots fired. R/D e-line, secure well. 04/13/2020- Monday 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 5,600'N/A Casing Collapse Conductor 1,500 psi Surface 1,020 psi Intermediate 1,540 psi Production 4,020 psi Production 7,100 psi Liner 7,020 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:mmckinley@hilcorp.com Contact Phone: (907) 777-8387 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Daniel E. Marlowe Operations Manager Mark McKinley See Schematic 5,275'3,630'3,619'1,125 psi 1,276'7"3,841'3,820'8,160 psi 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. Authorized Signature: 4/15/2020 4,803'1,075' 7" & 3-1/2" 4,642' See Schematic 5,562' Perforation Depth MD (ft): 511' 3,518 - 3,620 5,051' 3-1/2" 5,245'9-5/8" 853' 20" 16" 13-3/8" 1,357' 10-3/4"429' 2,553' 2,630 psi 3,090 psi 1,440' 2,635' 511' 1,440' 2,635' 936' 936' 29# / L-80 & V-String L-80 TVD Burst 2,565 & 3,316 8,150 psi MD 3,060 psi 6,450 psi 189-133 50-733-20413-00-00 Length Size Anchorage, AK 99503 Hilcorp Alaska, LLC CO 228A Trading Bay Unit M-05 3,633' Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 3,511 - 3,610 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Daniel Marlowe I am approving this document 2020.03.24 10:19:54 -08'00' Daniel Marlowe By Samantha Carlisle at 11:47 am, Mar 24, 2020 320-129 GLS-3/24/20 10-404 DSR-3/24/2020SFD 3/24/2020 dts 3/25/2020 03/24/2020 Well Work Prognosis Well Name:Trading Bay Unit M-05 API Number: 50-733-20413-00-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:4/15/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:189-133 First Call Engineer:Mark McKinley Office: 907-777-8387 Cell: 907-953-2685 Second Call Engineer:Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Current Bottom Hole Pressure:99 psi @ 3,550’ TVD SIBP Completed 10/11/2017 Maximum Expected BHP:1,463 psi @ 3,379’ TVD 0.433 psi/ft water gradient to surface Maximum Potential Surface Pressure:1,125 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) **Well to be perforated while flowing Brief Well Summary: Well M-05 is a gas well completed in the “B” Sands. This project will add additional perforations in the B- 3 Sand. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic ____________________________________________________________________________________________________________ Revised By JLL 11-08-2012 Steelhead Well: M-05 As Perfed 10-23-12SCHEMATIC PBTD = 5,478’ TD = 5,600’ MAX HOLE ANGLE = 38.7q @ 5,600’ RKB to TBG Head = 74.4’ KB to MSL = 160’ 20” D-6 D-2 C1 & C2 16” D-3B D-1 9-5/8” 13-3/8” B-7 TOC @ 3,702’ TOS @ 3,707’ 1 Fill Tagged @ 4,880’ on 12/21/02 2 3 5 6 7 4 9 8 A C D E F G B H e) d) c) b) a) B-5 B-6TOC – 3,630’ Posi-set plug 3,633’ TOF- 3,617’ CASING DETAIL Size Wt Grade Conn ID Top Btm 20” 133 X-56 83’ 936’ 16” 75 J-55 / N-80 83’ 1,440’ 13-3/8” 61/68 K-55 82’ 2,635’ 10-3/4” 55.5 N-80 9.76 82’ 511’ 9-5/8" 47 S-95 BTC 8.681 511’ 5,562’ 7” Scab Liner 29 L-80 6.184 2,565’ 3,841’ 3-1/2” Scab Liner 9.2 L-80 Hyd 533 2.992 3,728 4,803 TUBING DETAIL 7” 29 L-80 6.184 73.9 2,565’ 3-1/2” 9.2 L-80 Butt 2.992 78.53’ 3,316’ JEWELRY DETAIL NO. Depth Length ID Item 74.4 6.184 TBG Hanger FMC 1 407 3.8 5.963 Halliburton CP-2 TRSV #78-00-390 w/ XO’s 7” 29 to 7”, 26# ABSTL top & btm 2 1,998' CTC External Casing Packer 3 2,565' BOT ZXP Pkr; HMC Hngr; 27 jts of 7”. cemented w/ 225 sks. 4 3,728’ MD 1076’ 2.992 BOT ZXP pkr (@ 3713’ DIL) w/ 12’ x 5-1/4” Tie-Back Ext; 33 jts of 3-1/2”, 9.2#, L-80, tbg; 5 3,832’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple @ 3,845’; WLEG @ 3857’. 6 4,225’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple (4.562”) @ 4,238’; WLEG @ 4,250’. 7 4,550’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple (4.562”) @ 4,563’; WLEG @ 4,575’. 84,754’ CIBP 9 4,761’ DIL BWH Perma Pkr w/ 10’ SBE; MO Ext; XO to 4-1/2” Butt; Tbg cut @ 4,806’ on 3/21/90. VELOCITY STRING DETAIL A 79’ 0.75’ 2.992 Deployment Sub w/ “GS” Profile & SBE OD 5.82” B 436’ 19.93’ 2.813 SSSV Insert Profile Nipple w/ Packing Adapters. C 1,908’ 6.84’ 2.992 3-1/2” BST Slim Line GLM 2,712’ 6.85’ 2.992 3-1/2” BST Slim Line GLM 3,100’ 6.38’ 2.992 3-1/2” BST Slim Line GLM D 3,277’ 1.24 2.97 HES “Straight Slot” LSA w/ 10’ of seals E 3,279’ MD 14.14’ “BWD” Eline set pkr w/ 10’ SBE & XO to 3-1/2” Butt (3264’ DIL) F 3,304’ 1.51’ 2.813 “X” Profile Nipple G 3,313’ 1.6’ 2.75 “XN” No-Go Nipple w/ 2.813 Profile w/ WLEG H Btm 3,316’ 1.32’ 2.992 WLEG PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount Condition B-5 3,518' 3,558' 3,511' 3,550' 40 Perf 10-23-12 B-5 3,558' 3,588' 3,550' 3,579' 30 Re-Perf 1-21-08 B-6 3,606' 3,616' 3,596' 3,606' 10 Perf 10-23-12 B-6 3,616' 3,620' 3,606' 3,610' 4 Re-Perf 1-21-08 B-6 3,636' 3,650' 3,625' 3,639' 14 ISOLATED B-6 3,671 3,679' 3,659' 3,667' 8 ISOLATED B-7 3,746' 3,771' 3,730' 3,754' 25 ISOLATED B-7 3,778' 3,798' 376' 3,780' 20 ISOLATED C-1 3,890' 3,910' 3,866' 3,884' 20 ISOLATED C-2 3,923' 3,936' 3,896' 3,908' 13 ISOLATED D-1 4,292' 4,412' 4,223' 4,324' 120 Behind liner D-2 4,662' 4,708' 4,528' 4,565' 46 Behind liner D-3B 4,864' 4,914' 4,691' 4,731' 50 ISOLATED D-6 5,302' 5,372' 5,040' 5,095' 70 ISOLATED Fish 5,376’ 5’± Cut Tbg; “X” Nipple; 7’ 4-1/2” pup jt THRU TUBING GP EQUIPMENT a 3680’ 57.19’ 1.61' Upper Vent Screen Assy. f/ B-7 b 3737’ 2.51’ 1.625' Polish Bore Receptacle w/ 1 ½” NU Pin x Box c 3740’ 65.17’ 1.5' Upper Screen Assy. f/ B-7 d 3805’ 10.61’ 1.61' Upper Sump Pkr Assy. f/ B-7 e 3858’ 2.0’ CIBP ____________________________________________________________________________________________________________ Revised By JLL 03/19/20 Steelhead Well: M-05 As Perfed 10-23-12 PTD: 189-133 API: 50-733-20413-00-00 PROPOSED PBTD = 5,478’ TD = 5,600’ MAX HOLE ANGLE = 38.7q @ 5,600’ RKB to TBG Head = 74.4’ KB to MSL = 160’ 20” D-6 D-2 C1 & C2 16” D-3B D-1 9-5/8” 13-3/8” B-7 TOC @ 3,702’ TOS @ 3,707’ B-3 1 Fill Tagged @ 4,880’ on 12/21/02 2 3 5 6 7 4 9 8 A C D E F G B H e) d) c) b) a) B-5 B-6TOC – 3,630’ Posi-set plug 3,633’ TOF- 3,617’ CASING DETAIL Size Wt Grade Conn ID Top Btm 20” 133 X-56 83’ 936’ 16” 75 J-55 / N-80 83’ 1,440’ 13-3/8” 61/68 K-55 82’ 2,635’ 10-3/4” 55.5 N-80 9.76 82’ 511’ 9-5/8" 47 S-95 BTC 8.681 511’ 5,562’ 7” Scab Liner 29 L-80 6.184 2,565’ 3,841’ 3-1/2” Scab Liner 9.2 L-80 Hyd 533 2.992 3,728 4,803 TUBING DETAIL 7” 29 L-80 6.184 73.9 2,565’ 3-1/2” 9.2 L-80 Butt 2.992 78.53’ 3,316’ JEWELRY DETAIL NO. Depth Length ID Item 74.4 6.184 TBG Hanger FMC 1 407 3.8 5.963 Halliburton CP-2 TRSV #78-00-390 w/ XO’s 7” 29 to 7”, 26# ABSTL top & btm 2 1,998' CTC External Casing Packer 3 2,565' BOT ZXP Pkr; HMC Hngr; 27 jts of 7”. cemented w/ 225 sks. 4 3,728’ MD 1076’ 2.992 BOT ZXP pkr (@ 3713’ DIL) w/ 12’ x 5-1/4” Tie-Back Ext; 33 jts of 3-1/2”, 9.2#, L-80, tbg; 5 3,832’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple @ 3,845’; WLEG @ 3857’. 6 4,225’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple (4.562”) @ 4,238’; WLEG @ 4,250’. 7 4,550’ DIL BOT 9-5/8” x 6” FB-1 pkr; “X” nipple (4.562”) @ 4,563’; WLEG @ 4,575’. 84,754’ CIBP 9 4,761’ DIL BWH Perma Pkr w/ 10’ SBE; MO Ext; XO to 4-1/2” Butt; Tbg cut @ 4,806’ on 3/21/90. VELOCITY STRING DETAIL A 79’ 0.75’ 2.992 Deployment Sub w/ “GS” Profile & SBE OD 5.82” B 436’ 19.93’ 2.813 SSSV Insert Profile Nipple w/ Packing Adapters. C 1,908’ 6.84’ 2.992 3-1/2” BST Slim Line GLM 2,712’ 6.85’ 2.992 3-1/2” BST Slim Line GLM 3,100’ 6.38’ 2.992 3-1/2” BST Slim Line GLM D 3,277’ 1.24 2.97 HES “Straight Slot” LSA w/ 10’ of seals E 3,279’ MD 14.14’ “BWD” Eline set pkr w/ 10’ SBE & XO to 3-1/2” Butt (3264’ DIL) F 3,304’ 1.51’ 2.813 “X” Profile Nipple G 3,313’ 1.6’ 2.75 “XN” No-Go Nipple w/ 2.813 Profile w/ WLEG H Btm 3,316’ 1.32’ 2.992 WLEG PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount Condition B-3 ±3,290’ ±3,336’ ±3,288’ ±3,334’ ±46’ PROPOSED B-3 ±3,347’ ±3,382’ ±3,344’ ±3,379’ ±35’ PROPOSED B-5 3,518' 3,558' 3,511' 3,550' 40 Perf 10-23-12 B-5 3,558' 3,588' 3,550' 3,579' 30 Re-Perf 1-21-08 B-6 3,606' 3,616' 3,596' 3,606' 10 Perf 10-23-12 B-6 3,616' 3,620' 3,606' 3,610' 4 Re-Perf 1-21-08 B-6 3,636' 3,650' 3,625' 3,639' 14 ISOLATED B-6 3,671 3,679' 3,659' 3,667' 8 ISOLATED B-7 3,746' 3,771' 3,730' 3,754' 25 ISOLATED B-7 3,778' 3,798' 376' 3,780' 20 ISOLATED C-1 3,890' 3,910' 3,866' 3,884' 20 ISOLATED C-2 3,923' 3,936' 3,896' 3,908' 13 ISOLATED D-1 4,292' 4,412' 4,223' 4,324' 120 Behind liner D-2 4,662' 4,708' 4,528' 4,565' 46 Behind liner D-3B 4,864' 4,914' 4,691' 4,731' 50 ISOLATED D-6 5,302' 5,372' 5,040' 5,095' 70 ISOLATED Fish 5,376’ 5’± Cut Tbg; “X” Nipple; 7’ 4-1/2” pup jt THRU TUBING GP EQUIPMENT a 3680’ 57.19’ 1.61' Upper Vent Screen Assy. f/ B-7 b 3737’ 2.51’ 1.625' Polish Bore Receptacle w/ 1 ½” NU Pin x Box c 3740’ 65.17’ 1.5' Upper Screen Assy. f/ B-7 d 3805’ 10.61’ 1.61' Upper Sump Pkr Assy. f/ B-7 e 3858’ 2.0’ CIBP STATE OF ALASKA • r �r /�® A OIL AND GAS CONSERVATION COMMISSION !� REPORT OF SUNDRY WELL OPERATIONS !Cy 13 2012 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ., O '1r CC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac 1:1 Waiver CI Time Exte s 4 Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development is Exploratory ❑ 189 -133 Hilcorp Alaska, LLC 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20413 -00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 " Trading Bay Unit M -05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A McArthur River Field / Middle Kenai Gas 11. Present Well Condition Summary: Total Depth measured 5,600 feet Plugs measured 3,633 feet true vertical 5,275 feet Junk measured N/A feet ■ Effective Depth measured 3,630 feet Packer measured See Schematic feet true vertical 3,619 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Conductor 853' 20" 936' 936' 3,060 psi 1,500 psi Surface 1,357' 16" 1,440 1,440 2,630 psi 1,020 psi Intermediate 2,553' 13 -3/8" 2,635' 2,635' 3,090 psi 1,540 psi Production 429' 10 -3/4" 511' 511' 6,450 psi 4,020 psi Production 5,051' 9 -5/8" 5,562' 5,245' 8,150 psi 7,100 psi Liner 1,276' 7" 3,841' 3,820' 8,160 psi 7,020 psi Liner 1,075' 3 -1/2" 4,803' 4,642' Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet `'),:, w - 1 h.!! , .F r " Z nil Tubing (size, grade, measured and true vertical depth) 7" 29# L -80 2,565' (MD) 2,565' (TVD) 3 -1/2" V- String L -80 3,316" (MD) 3,314' (TVD) Packers and SSSV (type, measured and true vertical depth) See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,577 0 105 70 Subsequent to operation: 0 2,200 1 120 90 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development IS ' Service ❑ Stratigraphic El Daily Report of Well Operations X 16. Well Status after work: Oil ❑ .- Gasp WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Ted Kramer Email tkramert�hilcorD.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature Phone 907 - 777 -8420 Date 11/12/2012 Form ru-4u4 rcevrseo rurzu I �, F ' /J I �� / I / �,/ auumrt vrrgrnar uruy • • Trading Bay Unit .11 SCHEMATIC Well #:M -05 Mean) Alaska, LLC Completed: 3 -22 -1990 RKB to TBG Head =74.4' CASING DETAIL KB to MSL =160' Size Wt Grade Conn ID Top Btm l A r 20 133 X -56 83' 936' 16" 75 J -55 / N -80 83' 1,440 B 13-3/8" 61/68 1 55,5 47 K -55 82' 2,635' .4 ' �• 10 -3/4" N -80 9.76 82' 511' 9 - 5/8" 5 95 BTC 8.681 511' 5,562' 20„ I 7" Scab Liner 29 L -80 6.184 2,565' 3,841' 3 -1/2" Scab Liner 9.2 L -80 Hyd 533 2.992 3,728 4,803 16 "L TUBING DETAIL 7" 29 L -80 6.184 73.9 2,565' I 2 3 -1/2" 9.2 L -80 Butt 2.992 78.53' 3,316' 13 - 3/8 , =4 3 JEWELRY DETAIL NO. Depth Length ID Item �_ 0 ; E 74.4 6.184 TBG Hanger FMC 1 2 407 3.8 5.963 Halliburton CP -2 TRSV #78-00-390 w/ XO's 7" 29 to 7 ", 26# F ABSTL top & btm C; 1,998' CTC External Casing Packer H 3 2,565' BOT ZXP Pkr; HMC Hngr; 27 jts of 7 ". cemented w/ 225 sks. 1 TOF - 3,617' B 5 4 3,728' MD 1076' 2,992 ice. BOT ZXP pkr (@ 3713' DIL) w/ 12' x 5 -1/4" Tie -Back Ext; 33 jts of 3 -1/2 , 9.2 #, L -80, tbg; TOC - 3,630' B - 6 Posi - set plug j 5 3,832' DIL BOT 9 -5/8" x 6" FB -1 pkr; "X" nipple @ 3,845'; WLEG @ 3857'. 3,633' ' ` oc@ 3 ,702' BOT 9 -5/8" x 6" FB -1 pkr; "X" nipple (4.562") @ 4,238'; WLEG @ a) F=' L. �i , ' Tos @ 3,202 6 4,225' D IL 4,250'. BOT 9 -5/8" x 6" FB -1 pkr; "X" nipple (4.562 ") @ 4,563'; WLEG @ PI 4 7 4,550 DIL 4,575'. b) ®, , B.7 8 4,754' CIBP r 7 � • B c) ,, 0 9 4,761' DIL BWH Perma Pkr w/ 10' SBE; MO Ext; X0 to 4 -1/2" Butt; Tbg cut d) , - 1 ,,-.. - 4 5 @ 4,806' on 3/21/90. VELOCITY STRING DETAIL • E j A 79' 0.75' 2.992 Deployment Sub w/ "GS" Profile & SBE OD 5.82" B 436' 19.93' 2.813 SSSV Insert Profile Nipple w/ Packing Adapters. C1 a : c2 C 1,908' 6.84' 2.992 3 -1/2" BST Slim Line GLM 2,712' 6.85' 2.992 3 -1/2" BST Slim Line GLM ►'� 3,100' 6.38' 2.992 3-1/2" BST Slim Line GLM 6 D 3,277' 1.24 2.97 HES "Straight Slot" LSA w/ 10' of seals ( E 3,279' MD 14.14' "BWD" Eline set pkr w/ 10' SBE & X0 to 3 -1/2" Butt (3264' DIL) F 3,304' 1.51' 2.813 "X" Profile Nipple D -1 -- G 3,313' 1.6' 2.75 "XN" No -Go Nipple w/ 2.813 Profile w/ WLEG H Btm 3,316' 1.32' 2.992 WLEG 7 ►�� THRU TUBING GP EQUIPMENT a 3680' 57.19' 1.61' Upper Vent Screen Assy. f/ B -7 1 t b 3737' 2.51' 1.625' Polish Bore Receptacle w/ 1 A" NU Pin x Box c 3740' 65.17' 1.5' Upper Screen Assy. f/ B -7 D -2 d 3805' 10.61' 1.61' Upper Sump Pkr Assy. f/ B -7 e 3858' 2.0' CIBP 9 ►11 s PERFORATION DETAIL • � � _ y „�D _ T• B is V � ■ u • nt Cs . • ition B -5 , 3,518' • 3,558' 3,511' 3,550' _ 40 Open Fill Tagged @ B -6 3 606' ' � 3,616' - 3,5_96' 3,606' 10 Open w•► 4,880' on 12/21/02 D-313 :-6 3,• • ,621 3,606' � e- !" -21-x: B -6 3,636' 3,650' 3,625' 3,639' 14 ISOLATED D-6 B -6 3,671 3,679' 3,659' 3,667' 8 ISOLATED B -7 3,746' 3,771' 3,730' 3,754' 25 ISOLATED 9 - 5/8" . B -7 3,778' 3,798' 376' 3,780' 20 ISOLATED PBTD = 5,478 TD = 5,600' C -1 3,890' 3,910' 3,866' 3,884' 20 ISOLATED MAX HOLE ANGLE = 38.7 @ 5,600 C-2 3,923' 3,936' 3,896' 3,908' 13 ISOLATED Fish D -1 4,292' 4,412' 4,223' 4,324' 120 Behind liner 5,376' 5'± Cut Tbg; "X" Nipple; D -2 4,662' 4,708' 4,528' 4,565' 46 Behind liner 7' 4 -1/2" pup jt D -38 4,864' 4,914' 4,691' 4,731' 50 ISOLATED D -6 5,302' 5,372' 5,040' 5,095' 70 ISOLATED Revised By JLL 11 -08 -2012 • Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -05 50- 733 - 20413 -00 189 -133 10/23/2012 10/23/2012 Daily Operations: 10/23/12 - Tuesday Mobe equipment and spot equipment. Run line thru grease head and re -head cable. Pressure test to 250 psi low / 2,500 psi high. Shut well in. RIH with 1- 11/16" gamma ray /CCL, tie into RST Sigma Log dated 20- Dec -2002 and tag fill at 3,617'. POOH. RIH with 2- 1/8 "x10' HC, 4 spf, 60 deg phase and tie into RST Sigma Log dated 20- Dec -2002. Spot perfiun from 3 606' to_3 61.V' peteFinal Approved Perforation Request Form dated 10/16/2012. Tubing pressure 156 psi. Fired guns and saw 1 psi. POOH. ALL guns fired. RIH with 2 -1/8 "x20' HC, 4 spf, 60 deg phase and tie into RST Sigma Log dated 20- Dec -2002. Spot perf gun from 3,558' to 3,538'_per Final Approved Perforation Request Form dated 10/16/2012. Tubing pressure 157 psi. Fired guns and saw 0 psi. POOH. ALL guns fired. RIH with 2 -1/8 "x20' HC, 4 spf, 60 deg phase and tie into RST Sigma Log dated 20- Dec -2002. Spot perf gun from 3,538' to, 3,5 per Final Approved Perforation Request Form dated 10/16_2012. Tubing pressure 157 psi. Fired guns and saw 0 psi. POOH. All guns fired. Rig down lubricator and turn well over to production. ~hQy~'On Francisco Castro Chevron North• rica Exploration and Production Technical Assistant 909 W. 9th Avenue ~~'-' ` Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE March 7, 2008 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 NOTES- WELL LOG TYPE SCALE LOG INTERVAL RUN # 8-LINE CD ~S' DATE LOGGED PDS, DLIS PDF, ULTRA-SONIC IMAGING TOOL PDS, CORROSION EVALUATION DLIS, TBU D-47 IMAGE 5" 21-Jan-08 200-10676 1 1 1 WCL POSISET PLUG SETTING TBU M-5 RECORD 5" 13-Jan-08 3633-3633 PS 3 1 1 PDS TBU M-5 PSP - GHOST GR/CCL 5" 5-Jan-08 3480-3676 PS 2 1 1 PDS TBU M-5 PERFORATING RECORD 5" 21-Jan-08 3558-3620 PS 4 1 1 PDS 19l-0~1 l~9- ~~ ~'Ir1- Off'" ~- /~a i~ I(~d~i 1 ~ovra I~o~3 ~~ MAR ~. ~ 200 Please acknowledge receipt by signing and returning one copy of this transmittal or SAX to= 907 263 7828. Received By: 1 Date: STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS DEB ~ ~ ?.QQ~ 1. Operations Abandon Repair Well Plug Perforations Stimulate I~~~S~~'~Il ~~~ (`~n!~. (;rt~mmi5Sl Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate^ Re-enter Suspended Well ^ACI~~Of~~~ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory^ 189-133 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-733-20413-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB to TH - 74.4' M-05 ' 8. Property Designation: 10. Field/Pool(s): Steelhead Platform McArthur River Field/Middle Kenai Gas 11. Present Well Condition Summary: Total Depth measured 5600' feet Plugs (measured) 3633', 3858', 4754' true vertical y Z~~ ~ feet „~ Junk (measured) ,ti~> ~~ a Effective Depth measured 3630' feet {{~~~~~~~~~I L~ true vertical 3619' ~ feet ~ r'4 k 9~6~~ F~~ ~ ~ ~~~~ Casing Length Size MD TVD Burst Collapse Structural Conductor 853' 20" 936' 926' 3,060 psi 1,500 psi Surface 1,357 16" 1,440' 1,440' . - -• .2630psi~ 1,020 psi Intermediate 2,553' 13-3/8" 2,635' 2,635' 3,090 psi 1,540 psi Production 429' 10-3/4" 511' 511' 6,450 psi 4,020 psi Production 5,051' 9-5/8" 5,562' 5,244' 8,150 psi 1,580 psi Liner 1,276' 7" 3,841' 3,819' 8,160 psi 7,020 psi Liner 1,075 3-1/2" 4,803' 4,641' 0 0 Perforation depth: Measured depth: 3616'-3620' 3558'-3588' True Vertical depth: 3605'-3609' 3549'-3578' Tubing: (size, grade, and measured depth) 7", 29#, V-String 3-1/2" L-80 2,565', V-String @3,316' Packers and SSSV (type and measured depth) See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2.2 100 100 82 psi Subsequent to operation: 0 2.7 0 360 248 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run 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: ~E.~~.t ' ~- 3 4 Contact Steve Tyler - 263-7649 ~ ,~ ,~,-^„ ` Printed Name Tim Brandenburg Title Drilling Manager Signature ~ ~ Phone 907-276-7600 Date 1/29/2008 Form 10-404 Revised 04/2006 •~ AFE 6034 ~ a~~ ubmit Original Only Chevron Steelhead M-05 Current Completion of B-6 & B-5 Sands RKB to TBG Head = 74.4' KB to MSL = 160' CASING AND TUBING DETAIL Revised 1/29/2008 SIZE WT GRADE CONN ID "i'OP BTM. 20" 133 X-56 83' 936' 16" 75 J-55/ N-80 83' 1440' 13-3/8" 61/68 K-55 82' 2635' 10-3/4" 55.5 N-80 9.760 82' 511' 9-5/8 47 5-95 BTC 8.681 511' 5562' 7" Scab Liner 29 L-80 6.184 2565' 3841' 3-1/2" Scab Liner 9.2 L-80 H d 533 2.992 3728 4803 Tubin 7" 29 L-80 6.184 73.9 2565' 3-1/2" 9.2 L-80 Butt 2.992 78.53' 3316' JEWELRY DETAIL VO. De th Len th ID Item 74.4 6.184 TBG Han er FMC 1. 407 3.8 5.963 Halliburton CP-2 TRSV #78-00-390 w/ XO's 7" 29 to 7", 26# ABSTL to & btm 2. 1998 CTC External Casio > Packer 3. 2565 BOT ZXP Pkr; HMC Hn ; 27 'ts of 7". cemented w/ 225 sks. 4. 3832' DI BOT 9-5/8" x 6" FB-1 kr, "X" ni le 3845'; WLEG ~ 3857'. 5. 4225' DI BOT 9-5/8" x 6" FB-1 kr; "X" ni le 4.562" 4238'; WLEG 4250'. 6. 4550' DI BOT 9-5/8" x 6" FB-1 kr; "X" ni le (4.562" 4563'; WLEG , 4575'. 7. 4761' DI BWH Perma Pkr w/ 10' SBE; MO Ext; XO [0 4-1/2" Butt; Tb cut , 4806' on 3/21/90. 8. 3728' M 1076' 2.992 BOT ZXP kr , 3713' DIL w/ 12' x 5-1/4" Tie-Back Ext; 33 is of 3-1/2", 9.2#, L-8Q, tb 9. 4754' CIBP VELOCITY STRING A. 79' 0.75' 2.992 De to ment Sub w/ "GS" Profile &SBE OD 5.82" B. 436' 19.93' 2.813 SSSV Insert Profile Ni le w/ Packin Ada lets. C. 1,908' 6.84' 2.992 3-1/2" BST Slim Line GLM 2,712' 6.85' 2.992 3-1/2" BST Slim Line GLM 3,100' 6.38' 2.992 3-1/2" BST Slim Line GLM D. 3,277' 1.2 2.97 HES "Strai ht Slot" LSA w/ 10' of seals E. 3,279' 14.14' "B WD" Eline set kr w/ IO' SBE & XO to 3-1/2" Butt 3264' DIL F. 3,304' 1.51' 2.813 "X" Profile Ni ple G. 3,313' 1.6' 2.75 "XN" No-Go Ni le w/ 2.813 Profile w/ WLEG H. Btm 3316' 1.32' 2.992 WLEG hhru'hubin GP E ui ) 680' 7.19' .610 Opper Vent Screen Assy. f/ B-7 TT.S Release Nipple +v/ 1-!/I" G Fishing Neck Lsolatinn Plug with .illlllNt Re%nse 1-I/4" /IIRD Rory .Spring C'entruli:ers rv/ 1 % " Rax s Pin w/ RA Tag. TT.SVent .Screen +v/1-1/1"NU7I1RDPinxRnz Rory .Spring CentroliZers ro/ / %"Roxx Pfn R/nnk Tuhing +v/ 1 '/: " Rox x Pin Rmr.Spring C'entrali;,ers w/ / %"Ros.x Pin Anchor Latch .Seal Asaenrhlr rv/ / %"Ras Pinned it 361111# Release b 3737 2.51' 1.625 Polish Bore Rece tacle w/ 1 %" NL% Pin x Box ) 740' $,17' SU Cpper Screen Assy. f/ B-7 Rmv .Spring Cenhulizers rv/ ! '/: " N'U Pin x Rax 'lStrntrr Coi!".Screen (3) Aunts rv/ 1 '/:"NU Pln x Rax Ro+rS~ringCentralizers+v//'/:"NU Pin .r Rax "Strom Coil"Screen (1) ./Dints +v/ I /:"NU Pin x liox Rmv .Spring CentrnliZCrs u'/ / !: " Rax x Pin Anchor Latch .Sea/ Assemh/ rv/ 1 `/:"liar Pinned or 4NI1lNi re/ease. d) 3805' IO.GI' 1.610 upper Sump Pkr Assy. f/ B-7 TT.S Paragon // Pnrkrr +v/ Unircro'rtl Rottnm Pup Join, lion .Spring Ccntrali;,er Rc-E'ntn' Guide r 3858' 2.0' /// CIBP PERFORATION DATA Fish i76' S'f Cut Tbg; "X" Nipple; 7' 4-1/2" pup jt Zone To Btm Amount Condition B-5 3,558' 3,588 30 Re-Pert 1-21-08 B-6 3,616' 3,620' 4 Re-Pert 1-21-08 B-6 3,636' 3,650' 14 ISOLATED B-6 3,671 3,679' 8 ISOLATED B-7 3,746' 3,771' 25 ISOLATED B-7 3,778' 3,798' 20 ISOLATED C-1 3,890' 3,910' 20 ISOLATED C-2 3,923' 3,936' 13 ISOLATED D-1 4,292' 4,472' 120 Behind liner D-2 4,662' 4,708' 46 Behind liner D38 4,864' 4,9.1 d' S0 ISOLATED D-6 5,302' 5,372' 70 ISOLATED M-OS 1 /29/08 BCA MAX HOLE ANGLE = 38.7° @ 5600' • • 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. 7t" Ave. Ste#100 Anchorage, AK 99501 ~ ~ ~ ~ ~~ PERMIT # API NUMBER WELL LOG TYPE SCALE LCG DATE INTERVAL RUN B- FILP~1 CD NOTES - I LOGGED # LINE LAS, .PDS, DLiS 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 /~sq X33 '~ rS~~6~ iS~~ ~S~Y~ ~,~ SEC ~. 1.2007 ~~ _~ , Please acknowledge receipt by signing and returning one copy of this tr-~nsmitt~f off=-F'AX to 907. 263 7828. Received By: 1 Date: ~; ~. / ...~YIS^G., Zq, RECEIVED STATE OF ALASKA ALA.IL AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERAlPrONS ð N 1 7 2007 Plug Perforations Perforate New Pool D Perforate [], 4. Well Class Before Work: Development [] , StratigraphicD issior 1. Operations Abandon Repair Well Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. ShutdownD 2. Operator Union Oil Company of California Name: 3. Address: P.O. Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): RKB to TH - 74.4' 8. Property Designation: Steel head Platform 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural Conductor Surface Intermediate Production Production Liner Liner Perforation depth: Stimulate Waiver D Time ExtensionD Re-enter Suspended Well D 5. Permit to Drill Number: ExploratoryD ServiceD 189-133 ' 6. API Number: 50-733-20413-00 9. Well Name and Number: M-05 . 10. Field/Pool(s): McArthur River Field/Middle Kenai Gas measured 5600' feet true vertical ~' Sz. )' feet V'" .Þ'1 measured 3279' feet true vertical 3277' . feet Length Size 853' 20" 1,357' 16" 2,553' 13-3/8" 429' 10-3/4" 5,051' 9-5/8" 1,276' 7" 1 ,075 3-1/2" Measured depth: 3671'-3679 Tubing: (size, grade, and measured depth) True Vertical depth: 3658'-3666' Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Plugs (measured) 3858', 4754' Junk (measured) SCANNED JAN 2 5 2007 MD TVD Burst Collapse 936' 926' 3,060 psi 1,500 psi 1 ,440' 1,440' 2,630 psi 1,020 psi 2,635' 2,635' 3,090 psi 1,540 psi 511' 511 ' 6,450 psi 4,020 psi 5,562' 5,244' 8,150 psi 1,580 psi 3,841' 3,819' 8,160 psi 7,020 psi 4,803' 4,641' 0 0 3636'-3650' 3616'-3620' 3558'-3588' 3625'-3638' 3605'-3609' 3549'-3578' 7",29#, V-String 3-1/2" L-80 2,565', V-String @3,316' See Schematic RBOMS 8Ft 2 5 7007 Treatment descriptions including volumes used and final pressure: Gas-Mcf o 2.8 15. Well Class after work: ExploratoryD 16. Well Status after work: Oil r c\J Gas [] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge;." \ AJ' "' ")7 13. Oil-Bbl o o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact Steve Tyler - 263-7649 Printed Name Tim Brandenburg Signature "2:- Representative Daily Average Production or Injection Data Water-Bbl o o Casing Pressure 400 psi 360 Tubing Pressure 340 psi 307 Development [] Service D WAG D GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 306-374 Title Drilling Manager Date I-I D ~07- '( /' Submit Original Only ~ ~1Ø7 ,¿b {·¿3.o7 Phone 907-276-7600 AFE 6034 M-05 Primary Job Type Perforating Jobs Daily Operations 121281200600:00 ·1212912006 00:00 Operations Summary Mobe equipment and help DSM Lazenby pickle rig. 121291200600:00 -1213012006 00:00 Operations Summary . Lay down V-door and cat walk. Move pallets around so to get to hatch covers. Get stuff ready for wireline 121301200600:00 ·1213112006 00:00 Operations Summary RIH and pull SSSV at 444' RKB (slm). Ran 2.5" GR and tag at 3715' RKB (slm). Ran 2.5"x25' bailer and tag at 3715' RKB (slm). Found out later, it looked like tools went by vent and was tagging top of cement. Turn well over to production. 121311200600:00 -111/2007 00:00 Operations Summary Get Schlumberger ET out and work on computer system all day. Found the problem and fixed. Shut down for the ight. 1111200700:00 -112/2007 00:00 Operations Summary Perf 8;6 zone with 2.25" HC Power Jet, 6 spf, 60 degree: 3671' - 3679'; 3636' - 3650'; 3616' - 3620'. Saw no pre sure increase. Perf 8-.5 with same guns: 3568' - 3588' (Saw 10 psi increase in tubing pressure); 3568' - 3558' (No pressure incr ase). 1121200700:00 - 11312007 00:00 Operations Summary Attempt to set SSSV at 444' RKB (slm) several times. Would not pass pressure test Wait on orders. ~ 1131200700:00 - 11412007 00:00 Operations Summary RIH and pull SSSV at 444' RKB (slm). Will put well on test while sending valve in to town. 1171200700:00 - 11812007 00:00 Operations Summary RIH and set SSSV at 444' RKB (slm). Pressure test thru control line to 4400 psi. Shear off and POOH. Perform closure test. (ok). Secure well and turn over to production. Steelhead M-05 Current Completion of ß-6 & Sands RKB to TBG Head:: 74.4' KB to MSl:: 160' As Completed 9/28/06 963' SIZE WT GRADE CONN m TOP BTM. 20" 133 X-56 83' 936' 16" 75 J-55 I N-80 83' 1440' 13-3/8" 61/68 K-55 82' 2635' 10-3/4" 55.5 N-80 9.760 82' 511' 9-5/8 47 S-95 BTC 8.68] 511' 5562' T' Scab Liner 29 1.-80 6.]84 2565' 3841' 3-112" Scab Liner 9.2 1.-80 Hyd533 2.992 3728 4803 Tubin!!: T' 29 1.-80 6.184 73.9 2565' 3-]/2" 9.2 1.-80 Butt 2.992 78.53' 3316' m 2635' 6.184 1. 3.8 5.963 &btm 2. 3. 4. 5. 6. 7. B-5 8. 9. 8-6 A. 0.75' 2.992 OD 5.82" B. 19.93' 2.813 C. 6.84' 2.992 6.85' 2.992 6.38' 2.992 D. 1.24 2.97 E. 14.14' F. ].5] , 2.813 G. 1.6' 2.75 H. 1.32' 2.992 C1 & C2 5 D·1 6 ÓJ' 48(){ì#releilst?;. 1 25 Zone Amount 30 4 14 5562' PST MAX HOLE ANGLE = 38.7° @ 5600' B-7 C-1 C-2 D-1 D·2 D-3B D-6 20 20 13 120 46 50 70 BehindJiner Behind Hner ISOLATED ISO M-05 1/1 0/07 BCA . . FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION Tim Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 333 W. 7'H AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 \~;;. \~.r Re: McArthur River Field, Middle Kenai Gas Pool, M -05 Sundry Number: 306-374 Dear Mr. Brandenburg: f \.. 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 thisH day of November, 2006 Enc!. ,Â 1"'7JIIilb STATE OF ALASKA f/f¿...LJ!e..))e¡; Rt::Gt::IVt:.L1 vr-r ALA. Oil AND GAS CONSERVATION COM. ION fr\\.I'}. NOV 2 0 2006 APPLICATION FOR SUNDRY APPROVALS A¡<ìSk~ Oil II Gas Cons.Comnùsi.n 20 MC 25 280 . 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to~umber: Union Oil Company of California Development 0 Exploratory 0 189-133 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20413-00 ...,/ 7. If perforating, closest approach in pooJ(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 M-05 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Steelhead Platform RKB to TH 74.4' McArthur River Field/Middle Kenai Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TYD (ft): Effective Depth MD (ft): Effective Depth TYD (ft): Plugs (measured): Junk (measured): 5,600' 5,527' 3,279' 3,277' 3279'; 4754 Casing Length Size MD TVD Burst Collapse Conductor 853' 20" 936' 936' 3,060 psi 1,500 psi Surface 1,357' 16" 1,440' 1 ,440' 2,630 psi 1,020 psi Intermediate 2,553' 13-3/8" 2,635' 2,635' 3,090 psi 1,540 psi Production 429' 10-3/4" 511' 511' 6,450 psi 4,020 psi Production 5,051' 9-5/8" 5,562' 5,244' 8,150 psi 1,580 pis Liner 1,276' 7" 3,841' 3,819' 8,160 psi 7,020 psi Liner 1,075' 3-1/2" 4,803' 4,641' 0 0 Perforation Depth MD (ft): Perforation Depth TYD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3746' - 3798' 3730' - 3779' 7",29#; V-String 3-1/2" L-80 2,565'; V-String @ 3,316' Packers and SSSV Type: Packers and SSSV MD (ft): See Attached Schematic See Schematic 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: December 11, 2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Tim Brandenburg Title Drilling Manager Signature L: /) ~~ Phone 907-276-7600 Date / ( - /1- -oj&. ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30(0 -- 374 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: ~<£. \\.<:C~\~ \ <è.~'-.)\~~~~\ ~~ r- d-Ot\~<:..-d-S,d-~( RBDMS SFl 2 'j 2006 Subsequent Form Required: 4,Qm ) ~~ ').~ APPROVED BY Date: /;,/,;/,..06 Approved by: T_}" 'I CO~SIONER THE COMMISSION Form 10-403 Revised 06/2006 ~ K (J ''ffi L Su . in Duplicate It~ :;- ~ /ð¡( . Steelhead M-05 Operation Summary . MIRU Slickline. RIH w/ 2.5" sent dumm un. To TOS 3680'. POOH. RD. MI/S ot and RU Eline. Test 80PE's RIH Peforate 8-6 Zone. Note ressure before & after each RIH Peforate 8-6 Zone. Note ressure before & after each RIH Peforate 8-5 Zone. Note ressure before & after each RD Eline Unit. Packa e for Demobe RKB to TBG Head::: 74.4' KB to MSL::: 160' 963' 2635' 01 & 02 5 D·1 6 7 Steelhead M-05 Current Completion of B-7 Sands As Completed 9/28106 X-56 83' 936' J-55 I 1'1-80 83' 1440' K-55 82' 2635' 1'1-80 9.760 82' 511' S-95 BTC 8.681 51I' 5562' L-80 6.184 2565' 3841' L-80 H d 533 2.992 3728 4803 29 L-80 6.184 73.9 2565' 9.2 L·80 Butt 2.992 78.53' 3316' fWUrir'iDV 'IN.1r''Ir>>~ . ^¥W' NO. Oeoth Leul!til m Uem 74.4 6.184 TBG Haug~r FMC 1. 407 3.8 5.963 Halliburtou CP·2 TRSV #78-00-390 wI XO's 7" 29 to 7", 26# ABSTL top & btm 2. 1998 CTC Ext~rnal Casing Packer 3. 2565 BOT ZXP Pkr; HMC Hngr; 27 jts of7". cemented wI 225 sks. 4. 3832' DI BOT 9-5/8" x 6" FB-I pkr; "X" uipple (iij 3845'; WLEG (iij 3857'. 5. 4225' DI BOT 9·5/8" x 6" FB-I pkr; "X" uipple (4.562") (iij4238'; WLEG (iij4250'. 6. 4550'DI BOT 9-5/8" x 6" FB-l pkr; "X" uipple (4.562") (iij 4563'; WLEG (iij 4575'. 7. 4761' DI BWH Pe11uaPkrwI 10' SBE; MO Ext; XO to 4-1/2" Butt; Tbg cut (iij 4806' on 3/2J/90. 8. 3728' M 1076' 2.992 BOT ZXP pkr ((â! 3713' DlL) wI 12' x 5-1/4" Tie-Back Ext; 33 jts of3·1/2", 9.2#, L-80, tbg; 9. 4754' CIBP VELOCITY STRING A. 79' 0.75' 2.992 Deployment Sub wI "GS" Profil~ & SBE OD 5.82" ß. 436' 19.93' 2.813 SSSV Insert Profile Nipple wI Packing Adapt~rs. C. 1,908' 6.84' 2.992 3-1/2" BST Slim Line GLM 2,712' 6.85' 2.992 3-1/2" BST Slim Line GLM 3,100' 6.38' 2.992 3-1/2" BST Slim Line GLM D. 3,277' 1.24 2.97 HES "Straight Slot" LSA wI 10' of seals E. 3,279' Me 14.14' "BWD" Eline set pkr wI 10' SBE & XO to 3- J/2" Butt (3264' DIL) F. 3,304 ' 1.51 ' 2.813 "X" Profile Nipple G. 3,313' 1.6' 2.75 "XN" No-Go Nipple wI 2.813 Profile wI WLEG H. Btm 3316' 1.32' 2992 WLEG Tbrll Tubhil! GP Equip upper wem f18-7 I ~!1R1) .. '. .." IIW' '0 a) 3680' 7.19 1'1;~ Ú. 'Ph . u,,:v~ .. ," SoxxPìo ~llInk '~"'n!l. », '" "OX ..I. ..~.." '_A wi J b) 3737 2.51' J.625 W' NU Piu x Box Upper fl ß·7 ,¥flov 'T ;.... n u'" . D.. 3740' U7 ~, .. ,',,!I" <. , '" " m.. ... , V".. , ,; I ¡;:;'.' '" VI''' .." "1 Ç/ß·7 3805' 1O.6! PuP Joi/li' 'umn no",,.,, I.6HJ Re-Entry GUidE ,,\ 3858' 2.(!' III emp Zone To Blm Amount 8-7 3,746' 3,771' 25 8-7 3,778' 3,798' 20 C-1 3,690' 3,910' 20 C-2 3,923' 3,936' 13 5562' D-1 4,292' 4,412' 120 Behind·finer D-2 4,662' 4,708' 46 Behind liner PST D-3B 4,884' 4,914' 50 ISOLATED MAX HOLE ANGLE::: 38.7" @ 5600' 0-6 5,302' 5,372' 70 ISOLATED SL T 5/3/2006 RKB to TBG Head:::: 14.4' KB to MSl:::: 160' 963' 1440' 2635' 5 6 7 Steelhead M-05 Proposed Completion of B-5 & B-6 Sands Proposed Completion 11/17/06 .'" ¡IN£:, AND ~,,~ n SIZE WT GRADE CONN II) TOP BTM, 20" 133 X-56 8Y 936' 16" 75 J-55 I N-80 8Y 1440' 13-3/8" 61168 K-55 82' 2635' 10-3/4" 55.5 N·80 9.760 82' 511' 9-5/8 47 S·95 BTC 8.681 511' 5562' T' Scab Liner 29 L-80 6.184 2565' 3841' 3·112" Scab Liner 9.2 L-80 Hvd 533 2.992 3728 4803 Tubing; T' 29 L-80 6.184 73.9 2565' 3-112" 9.2 L-80 Butt 2.992 78.53' 3316' C1 & C2 nè\),rIHDV·'-" n NO, DeDih LemHh m Item 74.4 6.184 TBG Hanger FMC 1. 407 3.8 5.963 Halliburton CP·2 TRSV #78-00-390 wi XO's 7" 29 to T', 26# ABSTL top & btm 2. 1998 CTC External Casing Packer 3. 2565 BOT ZXP Pia; HMC Hn....; 27 its ofT' cemented wi 225 sks. 4. 3832' Dl BOT 9·5/8" x 6" FB·1 okr; "X" ninole (á! 3845" WLEG (ã) 3857'. 5. 4225'Dl BOT 9-5/8" x 6" FB-l okr; "X" nionle (4.562") (á! 4238'; WLEG (ã) 4250'. 6. 4550' DI BOT 9-5/8" x 6" FB·l okr; "X" nioole (4.562") (á! 4563'; WLEG (ã) 4575'. 7. 4761' DI BWH Penna Pkr wi 10' SBE; MO Ext; XO to 4·1/2" Butt; Tbgcut (ã)4806' on 3/21/90. 8. 3728' M 1076' 2.992 BOT ZXP Dkr ((ã) 371Y DIL)w/12' x 5-114" Tie-Back Ext; 33 its Df3·1/2", 9.2#, L·80, tbg' 9. 4754' CIBP VELOCITY STRING A. 79' 0.75' 2.992 Deúlovment Sub wi "GS" Profile & SBE OD 5.82" B. 436' 19.93' 2.8!3 SSSV Insert Profile NiDD!e wi Packing Adapters. Co 1,908' 6.84' 2.992 3·112" BST Slim Line GLM 2,712' 6.85' 2.992 3·1/2" BST Slim Line GLM 3,100' 6.38' 2.992 3-1/2" BST Slim Line GLM D. 3,277' 1.24 2.97 HES "Straight Slot" LSA wi 1 0' of seals E. 3,279' Mf 14.14' "BWD" Eline set pkr wi 10' SBE & XO to 3-1/2" Butt 13264' DlL) F. 3,304' 1.51' 2.813 "X" Profile Nipple G. 3,313' 1.6' 2.75 "XN" No·Go Nipple wi 2.813 Profile wi WLEG H- Btm 3316' 132' 2.992 WLEG 'Ihm ,U!}III!!' brF2Glliu tipper "..v II ß...7 , , ~;¡¡?1:" 'N. ... 3680 57.19' " ·fI"v "'" " DWL< "no ,,,,x x rm " ""xxrm ,,, bJ 3737 2,51' 1.625 Polish wi I 14" NU Pi" " Box '!', h.". ff ß...7 '" " m ./ ,,/1 " c) 3740' 6fU7' '" ,. 'W' .:' "mw" 'WI' .¡:;,,~ rmxmJX ^" " MM." l' I'pcr "",,,¡¡Pkr AJI,SY,,!/ B=7 Ii) 3805 10.61' Pup }¡,int' .. " ';:'~,~",..;,;= e) :;I!!;¡¡' 2.0' III emp 5562' C-1 3,890' 3,910' 20 C,2 3,923' 3,936' 13 PB D-1 4,292' 4,412' 120 Behind finer MAX HOLE ANGLE:::: 38.7° @ 5600' D-2 4,662' 4,708' 46 Behind liner D-38 4,864' 4,914' 50 D..ß 5,302' 5,372' 70 ISOLATED SL T 5/3/2006 ~ 'L..\JI-' V a....:u _ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI.)N REPORT OF SUNDRY WELL OPERA fróNS OCT 2 5 2006 L\laska " c öt o£lS COilS. Commission 1. Operations Abandon Performed: Alter Casing D Change Approved Program D 2. Operator Name: Repair Well Pull Tubing D Opera!. Shutdown D Plug Perforations ./ ' Perforate New Pool D Perforate 0 . 4. Well Class Before Work: Development 0 StratigraphicD Stimulate Other ./ Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 189-133 . 6. API Number: 50-733-20413-00 . 9. Well Name and Number: M-05 10. Field/Pool(s): McArthur River Field/Middle Kenai Gas Union Oil Company of California Exploratory D Service 0 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): RKB to TH 74.4' 8. Property Designation: Steel head Platform 11. Present Well Condition Summary: Total Depth measured 5600 ' I feet Plugs (measured) 3279'; 4754 true vertical ~ ~,.~ feet þC. Junk (measured) p ,.' ,..~. C Effective Depth measured 3279' feet true vertical 3277' feet Casing Length Size MD TVD Burst Collapse Conductor 853' 20" 936' 936' 3,060 psi 1,500 psi Surface 1,357' 16" 1 ,440' 1 ,440' 2,630 psi 1,020 psi Intermediate 2,553' 13-3/8" 2,635' 2,635' 3,090 psi 1,540 psi Production 429' 10-3/4" 511' 511' 6,450 psi 4,020 psi Production 5,051' 9-5/8" 5,562' 5,244' 8,150 psi 1 ,580 pis Liner 1,276' 7" 3,841' 3,819' 8,160 psi 7,020 psi Liner 1,075' 3-1/2" 4,803' 4,641' 10,160 10,540 Perforation depth: Measured depth: 3746' - 3798' True Vertical depth: 3730' - 3779 Tubing: (size, grade, and measured depth) 3-1/2" Velocity String L-80 7" Tbg L-80 3316' 2565' Packers and SSSV (type and measured depth) Too Numerous See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): GGS B-7 3730' - 3798' . RBDMS 8Ft 0 CT :3 1 2006 Treatment descriptions including volumes used and final pressure: Eline Convey and dumped 1475 Ibs of 20-40 Gravel. Placed 28.9 Ibs of gravel per foot of perfoations, outside pipe. . 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 000 0 o 790 . 22 700 (on gas lift) 15. Well Class after work: Exploratory D 16. Well Status after work: oilD Gas 0' WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tubing Pressure 320 148 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Development 0 Service 0 Operations Summary GINJ 0 WINJ D WDSPL Sundry Number or N/A if C.O. Exempt: 306-141 D Contact Steve Tyler 263-7649 Printed Name Tim Brandenburg Signature L- Form 10-404 Revised 04/200 Title Drilling Manager Phone 263-7657 Date 10/23/2006 ORIGINAL kt.I?,.\ À IO'Zó,O(p Submit Original Only ~ (O(.h(æ. M-05 . Primary Job Type · Sand Control Installation Jobs Primary Job Type Sand Control Installation Daily Operations 7/28/200607:00 - 7/29/200600:00 Operations Summary Mobe Equipment. RU slickline. RIH w/ Dummy CIBP. Tag fill @ 3887' SLM (Had indication of fluid level @ 3855' SLM). POOH. RU Eline. RIH w/ CIBP. Set .:: same @ 3858' ELM. RD. Suspend operation to wait on Schlum Unit for Perf work. 8/24/2006 07:00 - 8/25/2006 00:00 Operations Summary · PJSM. Prep Drill deck for work. RU Schlumb Unit. RIH w/2" PJ Omega guns loaded 6 spf 60 deg phased. Correlate GR depths to Schlumb RST SIGMA log dated 12/20/2002. RI tag CIBP @ 3831' DIL. Noted hole is "sticky". Perf B-7 sands 3778' - 3798'. POOH. Lay down guns. Found guns were covered w/ sludge. ':: Discoved 45 gals of grease had be pumped in to well to seal a leaky swab valve. 8/25/200600:00 - 8/26/2006 00:00 Operations Summary Cont perforating w/2" PJ Omega guns loaded 6 spf @ 60 deg phased. Gun #2 3758' - 3778' · Gun #3 3746' - 3758' PUMU TTS Sump pkr. RIH set down @ 3795' 20' shallow of planned set depth. POOH. RD Schlumb. RU slickline. RIH w/2.73" GR. Tag at 3758'. POOH. RIH w/2.5" bailer to 3843'. Worked bailer. POOH. recovered Perf gun debris, sand and pea gravel. Debris coated w/ sludge or grease. POOH. RD 8/26/200600:00 - 8/27/200600:00 Operations Summary ND leaky swab valve. NU replacement. Mobilized PX plug and chemicals. Ran gas lift annalysis. Arranged replacement valves in top two mandrils. Suspend operations. Work on forward plan. 8/30/2006 12:00 - 8/311200600:00 Operations Summary Mobilize equipment. RIH set GLV Catch sub in XN nipple @ 3,313'. RIH retrieve GLV #2 @ 2712'. SDFN. 8/3112006 00:00 - 9/1/2006 00:00 Operations Summary · PJSM. CO GL V # 1 &2. Retrieve Catch sub. LD clean lubricator. PUMU PX plug. RI set same in X nipple @ 3304'. Pressure test tbg to 665 psi w/ gas for (2) · hours. 9/1/200600:00 - 9/2/2006 00:00 Operations Summary Bundle test 9-5/8" annulus to 770 psi. (TP=770 psi, PC=770 psi, 13-3/8"=85 psi, 16"=415 psi, 20"=328 psi, 26"=135 psi. U-tube gas to check system. OK. PJSM. RU surface pump equipment. Mix (2) totes of Xylene w/ (2) totes of PAO-033. Total cocktail 1320 gals (31.4 bbls). Lubricate 28.5 bbls of chemical cocktail into tbg. SDFN allow tbg to soak. 9/2/2006 00:00 - 9/3/2006 00:00 Operations Summary Wait on well to soak. 9/3/2006 00:00 - 9/4/2006 00:00 Operations Summary .' PJSM. RIH w/7" Braidedline brush to 79'. Reciprocate from lubricator to 79'. PUMU 3-1/2" brush. RIH to 3295'. Reciprocate for 11 hrs. POOH. RD. Attempt to gaslift. No Joy. 9/4/2006 00:00 - 9/5/2006 00:00 Operations Summary Gaslift "Degreaser" Chemical cocktail out. Dump 5bbls of 6% KCI down tbg. Gaslift remaining chemical cocktail out. RI retrieve PX plug. RI w/2-1/2" spent Dummy gun to EOT. POOH. Found dummy gun to be clean. RIH w/ dummy gun to fill tagged depth of 3854'. POOH found dummy gun to be clean (slight clean formation sand on bottom 2'. SDFN. 9/5/2006 00:00 - 9/6/2006 00:00 Operations Summary " PJSM. Eline convey & set top of TTS sump pkr @ 3805'. Braided line convey B-7 GP screen assy (67' length) & latch into sump pkr @ 3805'. Top of screen assy @ 3737'. PUMU blank pipe & vent screen assy. RIH latch into GP screen assy. Top of vent screen @ 3681'. 9/6/200600:00 - 9171200600:00 :- Operations Summary · SIMOPS & PJSM. Spot RU Eline. Mix 50 bbls of 6% KCI. Viscosify 9 bbls of brine w/ HEC. PUMU TTS 50' Dump Bailer. Arm same. Blend 20/40 Gravel @ 6 ppg in 55 gal slurry blender. Fill bailer with 8.14 gals of slurry. RIH to 3672'. Dump bailer. PU to 3660'. Pump 3 bbls of 6% KCI. POOH. Repeat process on 2nd '. run. SDFN. ·:~..;(.*J.~". .~. Da'ily Operations 91712006 00:00 - 9/8/2006 00:00 Operations Summary PJSM & SIMOPS. Made 6 bailer runs (#3 bailer misfired) with 5 bailers of slurry placed. pumped 3 bbls of 6% KCI after each bailer run. 10 bbls pumped on last bailer run. Accumulated Total In Place: 415# of 20-40 gravel (calculated is 415#) 28 bbls of 6% KCI 9/8/200600:00 - 9/9/200600:00 Operations Summary '.: PJSM & SIMOPS. RI tag top of ZXP @ 3713'. No gravel. Made four (4) dump bailer runs. Secure operations due to high winds. Accumlative totals in place: 615# of 20-40 gravel 46 bbls of 6% KCI 9/9/2006 00:00 - 9/10/2006 00:00 . Operations Summary " PJSM & SIMOPS. RIH tag RS nipple @ 3734'. Made 5 bailer runs, only two dumped. Accumlative Total in place: ',: 740# of 20-40 gravel (13 Ibs per foot of perfs) ~~: 61 bbls of KCI '~9/10/2006 00:00 - 9/11/2006 00:00 Operations Summary PJSM & SIMOPS. RIH tag RS nipple @ 3734'. POOH RD secure equipment and well. Wait on new shipment of detonators. 9/21/2006 00:00 - 9/2212006 00:00 ":" Operations Summary Rig up riser attempt to set tree saver. Found Bridging pup to be too big of OD to go through riser and Wellhead. RD. Sent same to beach for refab work. 9/22/2006 00:00 - 9/23/2006 00:00 Operations Summary RU 7-1/16" Riser. RIH set Bridging spacer assy in hanger. Load lubricator with three batches of gravel slurry. Pressured lubricator to 450 psi, dumping each. Chase each gravel slurry batch with 3 bbls of 6% KCI. SDFN. Total 20-40 Gravel dumped is 590 Ibs. 9/23/2006 00:00 - 912412006 00:00 Operations Summary PJSM & SIMOPS meeting. RIH w/ Eline, tag top of sand @ 3720'. Mixed 220 Ibs of 20-40 gravel slurry batch. Load lubricator. Dump same. Chase with 3 bbls of 6% KCI brine. RI tag top of sand @ 3707' (planned depth). SDFN. Total gavel in place is 1475 Ibs. 28.9 Ibs per ft of perfs placed outside of casing. 912412006 00:00 - 9/25/2006 00:00 Operations Summary RIH with Eline Dump bailer. dumped 9 gals of cement on top of sand @ 3707'. TOC @ 3702'. RD demobe equipment. ,.9/28/2006 00:00 - 9/2912006 00:00 ~ Operations Summary RU Slickline. Installed SSSV. Test same. RD. . RKB to TBG Head = 74.4' KB to MSL = 160' 963' 1440' 2635' 5 6 7 5562' PBT = 5 MAX HOLE ANGLE = 38.7° @ 5600' SL T 5/3/2006 o r:'" r'\ r- ~\ ,_ '"" . . Steelhead M-05 Current Completion of B-7 Sands As Completed 9/28/06 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 133 X-56 83' 936' 16" 75 J-55 I N-80 83' 1440' 13-3/8" 61/68 K-55 82' 2635' 10-3/4" 55.5 N-80 9.760 82' 511' 9-518 47 S-95 BTC 8.681 511 ' 5562' 7" Scab Liner 29 L-80 6.184 2565' 3841' 3-1/2" Scab Liner 9.2 L-80 Hyd 533 2.992 3728 4803 Tubin!!: 7" 29 L-80 6.184 73.9 2565' 3-1/2" 9.2 L-80 Butt 2.992 78.53' 3316' JEWELRY DETAIL C1 & C2 NO. DepJh Lene:th ID tern 74.4 6.184 TBG Hanger FMC 1. 407 3.8 5.963 Halliburton CP-2 TRSV #78-00-390 wI XO's 7" 29 to 7", 26# ABSTL top & btm 2. 1998 CTC External Casing Packer 3. 2565 BOT ZXP Pkr; lIMC Hngr; 27 its ofT'. cemented wI 225 sks. 4. 3832'DI BOT 9-518" x 6" FB-I pkr; "X" nipple (å) 3845'; WLEG (å) 3851'. 5. 4225'DI BOT 9-518" x 6" FB-I pkr; "X" nipple (4.562") (å) 4238'; WLEG (å) 4250'. 6. 4550' DI BOT 9-518" x 6" FB-I pkr; "X" nipple (4.562")(å) 4563'; WLEG (å) 4575'. 7. 4761' DI BWH Penna Pkr wI 10' SBE; MO Ext; XO to 4-1/2" Butt; Tbg cut (å) 4806' on 3/21/90. 8. 3728' M 1076' 2.992 BOT ZXP pkr «(å) 3713' DIL) wI 12' x 5-1/4" Tie-Back Ext; 33its of 3-1/2", 9.2#, L-80, tbg; 9. 4754' CIBP VELOCITY STRING A. 79' 0.75' 2.992 Deplovment Sub wI "GS" Profile & SBE OD 5.82" B. 436' 19.93' 2.813 SSSV Insert Profile Nipple wI Packing Adapters. C. 1,908' 6.84' 2.992 3-1/2" BST Slim Line GLM 2,712' 6.85' 2.992 3-1/2" BST Slim Line GLM 3,100' 6.38' 2.992 3-1/2" BST Slim Line GLM D. 3,271' 1.24 2.97 HES "Straight Slot" LSA wI 10' of seals E. 3 279' MI 14.14' "BWD" Eline set Pkr wI 10' SBE & XO to 3-1/2" Butt (3264' DIU F. 3,304' 1.51 ' 2.813 "X" Profile Nipple G. 3,313' 1.6' 2.75 "){N" No-Go Nipple wI 2.813 Profile wI WLEG H. Btm 3316' 1.32' 2.992 WLEG Thru Tubine: GP EQuip Upper Vent Screen Assy. fl B-7 TrS Release Nipple wi 2-1/2" G Jïshing Neck l,olation PIng with 3000# Release /-114" /ORD a) Row Spring Centralizers wi 1 ~., Box x Pin wI RA Tag. 3680' 57.19' 1.610 77'S Vent Screen wl/-l/2" NU lORD Pin.>: Box Bow Spring Centralizers wI 1 *" Box x Pin Blank Tubing wi 1 ~"Box x Pin Bow Spring Centralizers wi 1 *" Box X Pitt Anchor Latch Seal Assemblv "ý / %" Bo.>: (Pinned for 3600# Release) b) 3737' 2.51' 1.625 Polish Bore Receptacle wI 1 W' NU Pin x Box Upper Screen Assy. fl B-7 Bow Spring Centralizers wi] ~" NU Pin x Box f'Strata Coil" Screen (3) Joints wll *" NU Pin x Box c) 3740' 65.17' 1.50 Bow Spring Centralizers wll %" NU Pin .Y Box "Strata Coil" Screen (2) Joints wi 1~" NU Pill X Box Huw Sprillg LèntraJizers wi 1 ~ "8ox x Pin Anchor Latch Seal Assel1lblv wi 1 *" BOJ< Pinned for 4800# release. Ulper Sump Pkr Assy. f/ B- 7 TTS Paragon II Packer wi Universal Bottom d) 3805' 10.61' 1.610 Pup Joint Bow Spring Centralizer Re-Entry Guide e) 3858' 2.0' /II CIBP PERFORA nON DATA Zone Top 8tm Amount Condition B-7 3,746' 3,771' 25 en "'."., Reperf 8/24106 B-7 3,778' 3,798' 20 en 4".'.' Reperf 8/24106 C-1 3,890' 3,910' 20 ISOLATED C-2 3,923' 3,936' 13 ISOLATED D-1 4,292' 4,412' 120 Behind liner D-2 4,662' 4,708' 46 Behind liner D.JB 4,864' 4,914' 50 ISOLATED D-6 5,302' 5,372' 70 ISOLATED Re: Steelhead M-05 Sundry #306-141 e e Subject: Re: Steelhead M-05 Sundry #306-141 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 08 May 2006 07:02:54 -0800 To: "Tyler, Steve L" <tylersl@chevron.com> CC: "Walsh, Chantal-Petrotechnical" <WalshC@chevron.com>, "Brandenburg, Tim C" <brandenburgt@chevron.com>, "Harness, Evan" <eharness@chevron.com> \ð-~- \~:, Steve, et al: As the operator, you all know the limits and requirements dictated by the well pressures on M-05 better than 1. There are several "tools" that can be used to accomplish the work with benefits and limitations. Your intent to change from coil to Eline and Wline conveyed tools is acknowledged. Good luck with the operations. Based on the well pressures given, it is acceptable to reduce the test pressures for the WL BOPs to 1500 psI. A copy of this message should be available at the rig. Call or message with any questions. Tom Maunder, PE AOGCC Tyler, Steve L wrote, On 5/512006 4:53 PM: :::-:'~/;,N~~¡'~~ i :...i..l:'\:.,~.....,-" "!.........., r; C\ (I <,) Tom Attached is a revised proposed schematic and operation summery to perform a Through Tubing Gravel Pack utilizing Eline and Wireline on M-05. Our current SBHP of 350 psi necessitates us to not do this project with Coil. SITP is currently at 210 psi We propose to test our Wireline BOPE to 1500 psi instead of the referenced 3000 psi noted in the approved Sundry #306-141. Please respond with your concurrence to our plan. Or call me if you have any issues. ~'·"""'¡~;>'-"""'---""''''''"~'''''''''~~1'-'''''' Union Oil Company of California (Office: (907) 263-7649 1 "f') 'i/Qj')OOfi 1 ").A7 PM e e Steelhead Platform M-05 Through Tubing Gravel Pack Wireline Operation Summary \ ~~ _ \ ~ ~ ~ MIRU Slickline. RIH w/ 2.5" bailer. Bail fill to 4000'. RD Slickline. ~ MIRU Eline. RIH perforate C-I & 2 and B- 7 intervals. POOH ~ PUMU TTS sump pkr. Assy. RI set pkr @ 3942'. POOH. RD Eline ~ RU Braided line. PUMU TTS screen assy. RIH, latch anchor into sump pkr. Shear release from same. POOH. ~ PUMU TTS Vent screenlblank pipe assy. RIH, latch anchor into PBR @ 3887'. Shear release. POOH. RD Braided line unit. ~ Batch mix Sand Slurry @ 40 ppa. (300# of20/40 sand with HEC & Breaker). ~ RU Eline. PUMU TTS 50' x 2-3/8" Dump Bailer. Top fill dump bailer with sand slurry. ~ RIH with bailer & dump sand slurry 10' above removable vent plug @ 3830' .Pump 2 bbls ofFIW @ ~ BPM while POOH. Repeat dump bailing slurry (4) more times. RD Eline. ~ RU Slickline. RlH w/ 2.5" LIB. Tag removable vent plug @ 3830'. Bail excess gravel as necessary to gain access to removable plug. ~ RIH with 2-1/2" JDC & pull/retrieve removable vent plug. RD slickline. ~ RU Eline. PUMU Isolation pkr assy. RIH, latch Overshot onto vent screen external fishing neck. Set pkr. POOH. ~ PUMU B-7 Sump Pkr assy. RIH set pkr @ 3805' . POOH. RD Eline. ~ RU braided line. PUMU Screen assy. RIH, latch anchor into sump pkr. Shear release from same. POOH. ~ PUMU TTS Vent screenlblank pipe assy. RlH, latch anchor into PBR @ 3738'. Shear release. POOH. RD Braided line unit. ~ Batch mix Sand Slurry @ 40 ppa. (300# of 20/40 sand with HEC & Breaker). ~ RU Eline. PUMU TTS 50' x 2-3/8" Dump Bailer. Top fill dump bailer with sand slurry. ~ RIH with bailer & dump sand slurry 10' above removable vent plug @ 3682' .Pump 2 bbls ofFIW @ ~ BPM while POOH. Repeat dump bailing slurry (5) more times. RD Eline. ~ RU Slickline. RlH w/ 2.5" LIB. RIH w/ 2.5" LIB. Tag removable vent plug @ 3682'. POOH. ~ Bail excess gravel as necessary to 15' past vent screen. RD slickline. ~ RU Eline. PUMU TTS 40' x 2-3/8" Dump Bailer. Top fill dump bailer with 7 gals ofTTS supplied cmt. ~ RIH with bailer. Dump 5' cmt plug on top of gravel pack, below vent screen. POOH. RD Eline. wac for 24 hrs. ~ Turn well over to production. 2635' I) 6 ¡;} 31105' 963' 1 5562' P MAX HOLE ANGLE:::: 38.7° "'f T ,/~/?lìlìh e e ¡-:;::! IÞ , ,I b FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, AK 99519 ., "'0,. A. ~u>Jpn ~\;rìel'; .~~.~"... ÎÀ ;' \ "? -:3 \~~\ Re: McArthur River Field, Middle Kenai Gas, Trading Bay Unit M-05 , Sundry Number: 306-141 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisl1 day of April, 2006 Encl. .. STATE OF ALASKA It ALA~ OIL AND GAS CONSERVATION COMMI ION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 t( 0 ¿?'J <;z / ~hc:.. / /~ 1. Type of Request: Abandon U Suspend D Operational shutdown U Perforate L::J Waiver U Other L::J Alter casing 0 Repair well 0 Plug Perforations D Stimulate 0 Time Extension 0 Through tubing Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 gravel pack 2. Operator Name: 4. Current Well Class: 5. Permit ~rill Number: :Þ Union Oil Company of California Development 0" Exploratory 0 189-133 ã) C/O :;rt::' 3. Address: Stratigraphic 0 Service 0 6. API Number: - ~ PO Box 196247, Anchorage, AK 99519 50-733-20413-00 J ~ )::.~ 2-" -\:..' 7. KB Elevation (ft): 9. Well Name and Number: ~ Cõ) A..' ~ r,,-' 0.' RKB to TH 74.4' ;::''- <:n ¡.....o, M-05 ~ ~ t"\n 8. Property Designation: 10. Field/Pools(s): å5 :::J < ,0 ~ ~) C) m Steelhead Platform McArthur River Field/Middle Kenai Gas ~J = en 0 11. PRESENT WELL CONDITION SUMMARY 3 Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (mea~~ed): 5,600 5,527 5,478 5,179 n/a Slickline tagge~ÊiII @ 4918' MD, 4 734' TVD Casing Length Size MD TVD Burst Collapse Conductor 853' 20" 936' 936' 3,060 psi 1 ,500 psi Surface 1,357' 16" 1 ,440' 1 ,440' 2,630 psi 1 ,020 psi Intermediate 2,553' 13-3/8" 2,635' 2,635' 3,090 psi 1 ,540 psi Production 429' 10-3/4" 511' 511' 6,450 psi 4,020 psi Production 5,051' 9-5/8" 5,562' 5,244' 8,150 psi 1 ,580 pis Liner 1,276' 7" 3,841' 3,819' 8,160 psi 7,020 psi Liner 1,075' 3-1/2" 4,803' 4,641' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3,746 to 5,372' 3,730 to 5,095' 7",29#; V-String 3-1/2" L-80 2,565'; V-String @ 3,316' Packers and SSSV Type: see schematic attached Packers and SSSV MD (ft): see schematic attached 12. Attachments: Description Summary of Proposal L::J 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/1/2006 Oil 0 Gas 0 J Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Branden~urg Title Drilling Manager -".. Signature ~/ ~~// _/~.-Phone 907-276-7600 Date L¡ í9- Of- .~~ f/"~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3Dú- /41 Plug Integrity 0 BOP Test œ:. Mechanical Integrity Test 0 Location Clearance 0 Other: 3ðOO ~\ "'" ......', t"\.~ ~ \S'G'Y ~<=:"?~ ((;r~ RBDMS 8Ft APR 2 0 2006 Subsequent Form Required: APPROVED BY 4-11-0~ M ~.J ~.1\r.. I ^ qOMMISSIONER Approved by: THE COMMISSION Date: Form 10-403 Revised 07/20~ '-'~ .... NJ"\ L..þFE 165042 Submit in Duplicate - .A);fiÒ if /f'-.oG. KI\I:I to 11:11.> Heaa = 14.4' KB to MSL = 160' 963' 1440' 2635' 5 6 7 5562' PBTD MAX HOLE ANGLE = 38.7° @ 5600' CRW 11/30/04 SteelheadM-05 As Completed on 10/19/04 9. 4754' A, B. C. 79' 436' 1,908' 2,712' 3,100' 3,277' 3,279' (3264'OIL 3,294 3,304 3,305 3,3 13 D. E, F, G. H. I. J. Btm 3316 83' 83' 82' 9.760 82' BTC 8,681 511' 6.184 2565' Hyd 533 2.992 3728 29 L-80 6.184 73.9 2565' TBG Hanger FMC HaHìburton CP-2 TRSV #78-00-390 wi XO's 7" 29 to 7", 26# AI3STL top & btm CTC External Casing Packer Baker ZXP Liner Pkr wi 6' Tie-l3ack Ext; HMC LincrHngr; 27 jts of 7", csg; Float CoHar@ 3807'; 15' Perf 7", 29# pup; 15' 7",29# cmt fiHed pup (driHed out); 15' 7",29# pup jt; 7" x 5-1/2" XO; EBH-22 anehorassy @ 3841'. Liner cemented w/225 sks. Baker 9-5/8" x 6" FE-l pkr; 10' 5-1/2" pup; "X" nipple@ 3845'; 10' 5-1/2" 1) ; WLEG @ 3857'. Baker 9-5/8" x 6" FB-l pkr; 10' 5-1/2" pup; "X" nipple (4.562") 1/2" pup; WLEG@4250'. Baker 9-5/8" x 6" FE-I pkr; 10' 5-1/2" pup; "X"nìpple(4.562") @4563'; 10' 1/2" pup; WLEO@4575'. OTIS BWH PC1111a-Drill Pkr wi 10' SBE; MO Ext; XO taU cut @ 4806' on 3/21/90. 1076' 2,992 Baker ZXP Liner top pkr wi 12' x 5-1/4" Tie-Back Ext; 33 jts on-1/2", 9.2#, L-80, Hydrìl533 tbg; 4-1/4" locator; 20' pupjt; Landing CoHar; XO; MS Float CoHar CIBP 0.75' 19.93' 6.84' 6.85' 6.38' 1.2 14,14' VELOCITY STRING Deployment Sub wi "GS" Profile & SBE 005.82" SSSV Insert Profile Nipple wi Packing Adapters. 3-1/2" BST Slim Line GLM 2.992 2.813 2.992 2.992 2,992 2,97 HES "Straight Slot" LSA wi 10' of seals "BWD" Eline set pkr w/]o' SBE & XO to 3-1/2" Butt 2.992 2,813 2.992 2.75 2.992 Pup JI. ]0' x 3-1/2" "X" Profile Nipple Pup J1. 8' x 3-1/2" "XN" No-Go Nipple wi 2.813 Profile wi WLEG WLEG e Steelhead Platform McArthur River Field Well # M-05 e ~ MIRU Slickline. RIH wI 2.5" bailer. Bail fill to 4000'. RD Slickline. ~ MIRU Eline. RIH perforate C-l & B-7 intervals. POOH "" ~ PUMU ITS pkr. RI set pkr @ 3915'. POOH. RD Eline ~ MIRU CT. (Tumkeyed Mobe) Pull test CTC. Test BOPE & CT. ~ Accept CT unit. PUMU TTS Completion Equipment. RIH latch into sump pkr. Set GP pkr. ~ Gravel pack C-1 sand. POOH. Stand-back injector head. ~ RU slickline. RIH gauge C-1 gravel pack completion assy. Bail fill if required. ~ RU Eline. PUMU TTS sump pkr. RIH set same @ 3800' DIL (2' below lwr B-7). POOH. RD Eline. ~ PU CT injector head. PUMU ITS Vent Screen GP Equipment. RIH latch into sump pkr. ~ PU above vent screen. Gravel pack B-7. POOH. Stand-back injector head. ~ RU slickline. RIH Bail fill as required. ~ PU CT injector head. PUMU Venturi bailer wI TTS wash shoe. RIH wash over vent screen. POOH. (make two runs if necessary). ~ RU Eline. RIH wI cmt dump bailer. Dump cement around vent screen. POOH. RD Eline. ~ Tumkeyed Demobe CT equipment. SteelbeadM-05 Proposed Through Tbg GP of C-l & B-7 Sands RKB to TBG Head = 74.4' KB to MSL = 160' 963' 1440' 9, 4754' 5 A. 79 B. 436 C. 1.908 2,712 3,100 D. 3,277 E. 3,279' (3264' DIL 3,294' G. 3,304' H, 3,305' L 3,313' J. Btm 3316' 6 7 5562' PB MAX HOLE ANGLE = 38.7° @ 5600' CRW 11/30/04 X-56 83' J-55 I N-80 83' K-55 82' N-80 9.760 82' S-95 BTC 8.681 511' L-80 6,184 2565' L-80 Hyd 533 2,992 3728 29 6,184 73.9 2565' Hanger FMC Halliburton CP-2 TRSV #78-00-390 wi XO's 7" 29 to 7", 26# ABSTL top &b CTC External Casing Packer Baker ZXP Liner Pkr wi 6' Tie-Back esg; Float Collar @ 3807'; 15' Perf7", 29# pup; (drilled out); 15' 7",29# pupjt; 7" x 5-1/2" XO; Liner cemented wi 225 sks. Baker 9-5/8" x 6" FH-l pkr; 10' 5 1/2" pup; "X" pup; WLEG @ 3857', Baker 9-5/8" x 6" FH-l pkr; 10' 5 1/2" pup; "X" 1/2" pup; WLEG @ 4250', Baker 9-5/8" x 6" FH-l pkr; 10' 5-1/2" pup; "X" nipple (4.562") @ 1/2" pup; WLEG@4575'. OTIS BWH Perma-Drill Pkr wi 10' SBE; MO Ext; XO to tail cut (i) 4806' on 3/21/90. 1076' 2.992 Baker ZXP Liner top pkr wi 12' x 5-1/4" TiecBaek Ext; 33 jts of3-1/2", 9.2#, L-80, Hydril 533 tbg; 4-1/4" locator; Collar; XO; MSFloat Collar ClBP 0,75' 2.992 19.93' 2.813 6.84' 2.992 6.85' 2.992 6.38' 2.992 1.2 2.97 14.14' VELOCITY STRING Deployment Sub wi "GS" Profile & SBE SSSV Insert Profile Nipple w/Paeking Adapters. 3-1/2" BST Slim Line GLM HES "Straight Slot" LSA wi JO' of seals "BWD" Eline setpkr wi 10' SBE & XO to 3-1/2" Butt 9.64' 2.992 1.51' 2.813 7.98' 2,992 1.6' 2.75 1.32' 2,992 Pup Jt 10' x 3-1/2" "X" Pr()lìle Nipple Pup Jt 8' x 3-1/2" "XN" No.Go Nipple wi 2.813 Prome wi WLEG WLEG Fish I 5376' 5'± Cut Tbg; "X" Nipple;?' 4-1/2" pup jt To 3,746' 3,778' 3,890' 3,923' 4,292' Btm 3,771' 3,791.1' 3,910' Amount 25 20 20 13 120 46 50 70 4,412' 4,701.1' 4,914' 5,372' e e Chevron Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com March 16, 2006 Steve McMains AOGCC 333 W. ¡th Avenue, Ste. 100 Anchorage, Alaska 99501 Re: Outstanding Sundries Dear Mr. McMains, We have conducted an internal audit of regulatory filings for 2003 and 2004. As a result, several projects were found to have outstanding sundries. We have researched the work and have prepared the sundries to close out the projects left uncompleted. The list of projects includes the following: 2003 Grayling, G-12RD3, Reperforate Grayling, G-24, Reperforate \~ ~ Monopod, A-15RD2, Perforate \ Qq ~ Steel head , M-01, Repair Casing Patch \to Steel head , M-05, Perforate V Swanson River, SCU 32-04, Reperforate (3 Sundries) Swanson River, SRU 12-15, Recomplete Swanson River, SRU 32A-33, Reperforate 2004 Happy Valley, HV-A02, Coil Tubing Clean Out In order to assure that we do not have any such gaps in the future, we have implemented a database to track all drilling related AOGCC filling requirements. Please contact me directly at 263-7657 if you have any questions about these filings. Sincerely, c¿ -""" ~ Timothy C. Brandenburg Drilling Manager Attachments Cc: Well Files TB:sk Union Oil Company of California I A Chevron Company http://www.chevron.com A STATE OF ALASKA _ ALA~OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 StratigraphicO Stimulate Other Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 189-133 ServiceD 6. API Number: 50-733-20413-00 9. Well Name and Number: 1. Operations Abandon Repair Well Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: 7. KB Elevation (ft): 160' above MSL 8. Property Designation: Steel head Platform/Cook Inlet 11. Present Well Condition Summary: M-05 10. Field/Pool(s): McArthur River Field, Grayling Gas Sands Total Depth measured 5,600 feet true vertical 5,274 feet Effective Depth measured 5,478 feet true vertical 5,179 feet Casing Length Size MD Structural Conductor 936' 20" 936' Surface 1 ,440' 16" 1 ,440' Intermediate 2,635' 13-3/8" 2,635' Production 511' 10-3/4" 511' Production 5,051' 9-5/8" 5,562' Liner 1,276' 7" 3,841' Liner 1,075' 3-1 /2" 4,803' Plugs (measured) Junk (measured) Slickline tagged fill @ 4,918' TVD Burst Collapse 936' 1 ,440' 2,635' 511' 5,244' 3,819' 4,641' 2,630 3,090 6,450 8,150 8,160 1,020 1,540 4,020 1,580 7,020 Perforation depth: Measured depth: 4,864 - 5,372' True Vertical depth: 4,691 - 5,095' Tubing: (size, grade, and measured depth) 7", 29#, L-80 tubing @ 2,565' Packers and SSSV (type and measured depth) Otis 9-5/8" packer @ 4,761', BOT 9-5/8" pkrs @ 4,550'; 4,225',3,832'. ZXP @ 3,728' and 7" HES CP-2 TRSSV @ 407' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: n/a Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 6,980 0 220 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Tubing Pressure o 350 Service 0 x GINJ 0 WINJ 0 WDSPL 0 SUfldry Number or N/A if C.O. Exempt: 302·387 Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager AFE 160 " Date '2- 22-~ Signature Phone 907-276-7600 Form 10-404 Revised 04/2004 . MAR 1 1 2006 / Submit Original Only e e 3/8/03 PJSM. RU. Pressure tested to 2400 # with leak-off thru swab. RIH with Wt bars, CCl, CIBP. Tied in with 7" scab liner, 3" liner, and counted collars to 4,745'. Packer 9 feet below CCL. Spotted packer 9' below collar at 4,754'. Fired gun and set packer at 4,754'. Saw wt drop from 260# to 235#, and amp meter discharge. PU 15 feet and went back down. Tagged packer as expected. POOH and checked tools. Bled well from 577 psi to 100 psi and monitored buildup. leaking. Changed valving. Bled well to 98# and pressure held steady for 50 minutes. Pressured well to 1,180# and shut-in for high pressure test. Well at 1,180# for 50 minutes (ok). Bled lubricator and made up gun. RIH with wt bars, CCl, magnets, and 6' gun. Tied in with 7" scab liner, 3-1/2" liner packer assembly. Dropped down approximately 62 feet into second joint of 3-1/2" liner. Fired gun and perforated 3,795- 3,801 per Schlumberger RST log 12/20/02. (3809-3815 per APRS tie in with tubing tally). Saw amp meter discharge. logged up/down and CCl indicated perf hole present. Tubing pressure instantly fell from 1,162 psi to 1,147 psi, then held for 35 minutes while POOH. 3/22/03 PJSM. RU. Pressure tested to 2,500. Swab leaking but no lubricator leaks. RIH with CCI and 25' gun. Tied in with Schlumberger RST log 12/20/02 and with top of ZXP packer. Positioned top of gun 6' below packer assembly in 3 1/2 scab liner. Fired gun. Perforated 3,746-3,771' (25 feet) through 3 casing strings. Saw weight loss. logged up. POOH. TP before firing 810 psi. Fell to 580 psi in 20 minutes. Casing pressure steady at 190 psi. RD. Production monitoring tubing pressure. 4/16/03 PJSM, Spot and RU eline. PT lubricator to 2,500 psig. WHP flowing 320 psig. RIH with guns SIP of 390 psig indidcated. On depth and logging well to correlate. Tied into Schlumberger RST log dated 12/20/02. Fire guns from 3,778 to 3,798'. Confirmed. POOH. lD tools. Secure well. RD SWS. SWS off location. M-05 Perforate, 160083 morning report summary, CONFIDENTIAL: last revised 2/22/2006, Page 1. RKS to TSG Head :: 963' 1440' 2635' 5 6 7 5562' PST MAX HOLE ANGLE:: 38,7° @ 5600' Steelhead M-05 Final Completion 20" 133 X-56 83' 936' 16" 75 J-55 / N-80 83' 1440' 13-3/8" 6li68 K-55 82' 2635' 10-3/4" 55.5 N-80 9.760 82' 5Il' 9-5/8 47 S-95 BTC 8.681 511 ' 5562' 7" Scab Liner 29 L-80 6.184 2565' 3841' 3-1/2" Scab Liner 9.2 L-80 H d 533 2.992 3728 4803 Tubin : T' 29 L-80 6.184 73.9 2565' NO, 1. TBG Hanger FMC Halliburton CP-2 TRSV #78-00-390 w/ XO's 1" 29 to 7", 26# ABSTL to & btm CTC External Casing Packer Baker ZXP Liner Pkr w/ 6' Tie-Back Ext; HMC Liner Hngr; 27.its ofT, 29# csg; Float Collar @ 3807"; 15' Perf 1",29# pup; IS' 7", 29# cmt tilled pup (drilled out); IS" 1",29# pup .it; 1" x 5-112" XO; EBH-22 anchor assy @ 3841'. Liner cemented w/ 225 sks. Baker 9-5/8" x 6" FB-I pkr; 10' 5-1/2" pup; "X" nipple @ 3845'; 10' 5-1/2" up; WLEG 3857". Baker 9-5/8" x 6" FB-! pkr; lQ' pup; "X" nipple (4.562") âJ. 4238'; 10' 5-112" pu ; WLEG àJ 4250', Baker 9-5/8" x 6" FB-I pkr; 10' 5-l/2" pup; "X" nippJe (4.562") (@ 4563'; 10' 5-1/2" pup; WLEG àJ 4575'. OTIS BWH Penl1a-DriH Pkr wi 10' SBE; MO Ext; XO to 4-112" Butt tb ; Tb tail cut (@ 4806' on 3!2l/90. Baker ZXP Liner top pkr w/ 12' Tie-Back Ext; 33 .its of 3- 112", 9.2#, L-80, Hydril 533 tbg; $- J /4" locator; 20' pup .it; Landin Collar; XO; MS Float Collar CIBP 2. 3. 1998 2565 4. 3832' OIL 5. 4225' OIL 6. 4550' OIL 7. 4761 ' OIL 8. 3728' 1076' 9. 4754' 2.992 Fish I 5376' I 5'± Cut Tbg; ax" Nipple; 7' 4-1/2" pup jt I Amount 25 6 20 27 120 46 50 70 Condition 3/22J031íed into RST log 3/8103 tied into RST log 4/16/2003 Behind liner Behind liner Behind liner Isolated Isolated DED 02122/06 Steelhead M-5 SSSV e '-1) +t:. 1<b<1_ì33 Subject: Steelhead M-5 SSSV From: "Chivers, Mike W" <chivemw@unocal.com> Date:. \yed, 14 I)ec2005.~7:tl}6 -O~OO. '''5R'l~ l z,ltsiùÇ;", To: JlmRegg A?GCC ~lm-le; ¡: adrnm.state.~,:~~,r~ Ro1:)~J:Í Fleckenstem <bob.::..fleckenstem@adrnm.st~e. "s>//# >: CC: "Paÿ111,' "Glen A" <payif¡tega ,unocal.com>, liT Stðve L" <ta ' s~tiag9j ,,' " ",a1.com ~:~'::, Mr. Regg and Mr. Fleckenstein We have removed the SSSV on M-5 gas well to do some wire line work (12-13-05). I will let you know when we re-install it. I expect to re-install it tomorrow (12-15-05). I will send you the results of the test when we get it back in. Sincerely Mike Chivers Unocal Steelhead Platform Trading Bay Unit 907 -776-6834 'I:.::(f"tJ¡".' 1f¡;"ÄiI("', i ""\#fM¡~ ~~~.t.t:.. ' tJ C 1 of 1 12/15/2005 8:43 AM ') Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unoca1.com ) UNOCALG> Debra Oudean G & G Technician Date: March 16, 2005 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 SCANNEC JUN 1 [I' 2005 <;[~~lli; [n;~~~~~tÊ~;º~~i~S~~:lX~~tiGLt~:.tL~L~~,'¿~~' !~~~@i_i~j.,~ fE I ('¡ '7 ", Schlumberger TBU M-1 COMPLETION RECORD 2.5 HSD POWERJET 6SPF i 5 INCH 1 0/16/200f 5050-5735 1. 1 1 () t.{.(o GAMMA RAY /CCL 'If () Schlumberger TBU M-1 COMPLETION RECORD 2.5 HSD POWERJET 6SPF ,5 INCH 12/17/2004 4600-4985 '-----;- 1 1 GAMMA RAY /CCL ~1' c41 ~S¿¡;¡~;;;'¡;';g;;;- TŠU-M-:¡3'---~~~~~Ë~%~~CõÃÕ2:5-HSÕ¡;OWERJ-ËT6-s¡;F"-- sïÑCH"1õi14i2òö4r35õ:2ããõ-----------j---;-1 t 1~~~~~~~~~ü~~~~l~~-~r~n ICr?; i ~~~~~~~:;:~~~:~-~~1~~~~*~i~~~:~~~~~~~~~-~~~~~:~~~~~:-~:;~::¡~~:~~~~;~~-~~::~;¡~ ¡C[o 'D 1 1:~~~:::~:;i~:~-~:;----~~::J~:~~~~~~~:.:=:~:::ËT6sPF-l:~~T~:::~~::::~~~:---T----:r----r:1 J ~ 1.... (") ~ .. . ........ ......, ............... .-."... ......_. ..-...,-,-........-...-....-,. . ".. ..."..., .. .."".. --".. ".. .. .". - .............. "'''' '.. .."" . -".. . .....,,,....._~,,....,,.. ...". ........ ......, .."...._1___......_....."........... _...... .-..-- ..... ...... --~... ... ....... -.-- ~.".._. j :~:~y~;llZ: on:~:py of thiS;;;ZA~ to (907) 263-7828. ". STATE OF ALASKA ) ALAS \ blL AND GAS CONSERVATION COMMk '. ON REPORT OF SUNDRY WELL OPERATIONS '1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 Stimulate U Other U Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 89-133 Service 0 6. API Number: 50-733-20413 9. Well Name and Number: M-05 10. Field/Pool(s): MacArthur River Field/GGS 7. KB Elevation (ft): 160' KB to MSL 8. Property Designation: Steel head Platform 11. Present Well Condition Summary: Total Depth measured 5600' feet true vertical 5247' feet Effective Depth measured 3,937' feet true vertical 5179' feet Casing Length Size MD Conductor 853' 20" 936' Surface 1,357' 16" 1 ,440' Intermediate 2,553' 13-3/8" 2,635' Production 429' 10-3/4" 511' Production 5,015' 9-5/8" 5,562' Liner 1,276' 7" 3,841' Liner 1,075' 3-1/2" 4,803' Plugs (measured) CIBP @ 4,754' Junk (measured) Fill tagged @ 3,937' Perforation depth: Measured depth: 3,746 to 5,372 TVD 936' 1 ,440' 2,635' 511' 5,244' 3,819' 4,641' SCANNED DEC 2 7{ 2DD4 Burst 3,060 psi 2,630 psi 3,090 psi 6,450 psi 8,150 psi 8,160 psi Collapse 1,500 psi 1,020 psi 1,540 psi 4,020 psi 5080 psi 7,020 psi True Vertical depth: 3,730 to 5,095 Tubing: (size, grade, and measured depth) 7", 29#, L-80 @ 2,565' RECE'\fED DEe 2 2 2004 Alaska Oil 81 Gas Cona. Commission Anchorage Packers and SSSV (type and measured depth) detail on schematic attached. 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: RBDMS BFL DEC 2 3 2004 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 2690 1 220 3790 0 200 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 0 0 Tubing Pressure 234 225 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service 0 x GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: 304-374 Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Signature?"- Q C8 Form 1 U-4U4 Ke~/UU4 /~ "--;g//' Ó Title Drilling Manager Phone 907-276-7600 Date SUDmlt unÇllnal unLY nR1h1f\IA1 10/19/04 ') ) PJSM. Rigged up. Pressure tested 2250 #. WIH with CCL and 131 gun. Tagged bottom at 3937 KB. Did second tie-in with RST log of 12/20/02. TP@ 380 #. Perforated 3923-3936 (13 feet) with 2.5" HC, 6 spf. Logged up to confirm tie-in and POOH. WIH with CCL and 20' gun. Tied in with RST log of 12/20/02. TP@ 380 psi. Perforated 3890-3910' (20 feet) with 2.5" HC, 6 spf. Logged up to confirm tie-in and POOH. TP@ 383 psi. RD M-05 morning report summary, CONFIDENTIAL: last revised 12/16/2004 Page 1 ) ) Steelhead M-05 As Completed on 10/19/04 K.KtS to ItS\:i Heao = 14.4' CASING AND TUBING DETAIL KB to MSL = 160' L~~ SIZE WT GRADE CONN ID TOP BTM. ; ~/ 20" 133 X-56 83' 936' ,¡, B... ......," 1 16" 75 J-55 I N-80 83' 1440' 'I~< / .' 13-3/8" 61168 K-55 82' 2635' " = ~ 10-3/4" 55.5 N-80 9.760 82' 511' 963' 9-5/8 47 S-95 BTC 8.681 511' 5562' L C( ~ ~ 7" Scab Liner 29 L-80 6.184 2565' 3841' 3-1/2" Scab Liner 9.2 L-80 Hyd 533 2.992 3728 4803 Tubing: 1440'¿ ~ 7" 29 L-80 6.184 73.9 2565' 2635' NO. Depth Lene:th 74.4 407 1998 2565 1. 2. - 3. 4. 3832' DIL 5. 4225' DIL 6. 4550' DIL 7. 4761' DIL 8. 3728' (3713' DlL) 5 9. 4754' 6 7 Fill Tagged @ 4880' on 12/21/02 5562' CRW 11/30/04 79' 436' 1,908' 2,712' 3,100' 3,277' 3,279' (3264' DlL) F. 3,294' G. 3,304' H. 3,305' I. 3,313' J. Btm 3316' D.1 A. B. C. D. E. JEWELRY DETAIL ID Item 6.184 TBG Hanger FMC 3.8 5.963 Halliburton CP-2 TRSV #78-00-390 wi XO's 7" 29 to 7", 26# ABSTL top & btm CTC External Casing Packer Baker ZXP Liner Pkr wi 6' Tie-Back Ext; HMC Liner Hngr; 27 jts ofT', 29# csg; Float Collar @ 3807'; 15' Perf7", 29# pup; 15' 7",29# cmt filled pup (drilled out); 15' 7",29# pup jt; 7" x 5-1/2" XO; EBH-22 anchor assy@ 3841'. Liner cemented wi 225 sks. Baker 9-5/8" x 6" FB-1 pkr; 10' 5-1/2" pup; "X" nipple @ 3845'; 10' 5-1/2" pup; WLEG @ 3857'. Baker 9-5/8" x 6" FB-1 pkr; 10' 5-1/2" pup; "X" nipple (4.562") @ 4238'; 10' 5- 1/2" pup; WLEG @ 4250'. Baker 9-5/8" x 6" FB-1 pkr; 10' 5-1/2" pup; "X" nipple (4.562") @ 4563'; 10' 5- 1/2" pup; WLEG @ 4575'. OTIS BWH Perma-Drill Pkr wi 10' SBE; MO Ext; XO to 4-1/2" Butt tbg; 10g tail cut @ 4806' on 3/21/90. 1076' 2.992 Baker ZXP Liner.top pkr wi 12' x 5-1/4" Tie-Back Ext; 33 jts of 3-1/2", 9.2#, L-80, Hydri1533 tbg; 4-1/4" locator; 20' pup jt; Landing Collar; XO; MS Float Collar CIBP 0.75' 2.992 19.93' 2.813 6.84' 2.992 6.85' 2.992 6.38' 2.992 1.24 2.97 14.14' 9.64' 2.992 1.51' 2.813 7.98' 2.992 1.6' 2.75 1.32' 2.992 VELOCITY STRING Deployment Sub wi "GS" Profile & SBE 005.82" SSSV Insert Profile Nipple wi Packing Adapters. 3-1/2" BST Slim Line GLM HES "Straight Slot" LSA wi 10' of seals "BWD" Eline set pkr wi 10' SBE & XO to 3-1/2" Butt Pup Jt. 10' x 3-1/2" "X" Profile Nipple Pup Jt. 8' x 3-1/2" "XN" No-Go Nipple wi 2.813 Profile wi WLEG WLEG Fish I 5376' I 5':!: Cut 1Og; "X" Nipple; 7' 4-1/2" pup jt I Zae B-7 B-7 G1 G2 D1 D2 Dæ D6 PERFORA nON DATA Tcp 3l4> ~778 ~æJ ~9B 4~ 4,ffi2 4;ffif ~:m Anut 25 LD LD 13 12) 43 !i) iD 0:rdtia1 RJf32VCB RJf 4'16Œ RJf 10'19rn RJf 10'19rn ßtirdlira- ßtirdlira- Patialy <.r>.eW Cb.ea:iw RII am ~711 ~i9J ~91a ~9E 4;412 4;ïœ 4;914 ~372 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 \1-141\- IO(tt{2-0ot RECEIVED OCT I 2 2004 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate ~ A/ask O:'1fiv.er f::c: Annular Dispos. U Alter casing D Repair well D Plug Perforations D a ¡¡ lis. pns Commi- Stimulate D Time Exten~on):o1 . D Change approved program D Pull Tubing D Perforate New Pool D nc age Re-enter Suspended Well L-.J 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 / Exploratory D 89-133 / 3. Address: Stratigraphic D Service D 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20413 /" 7. KB Elevation (ft): 9. Well Name and Number: 160' KB to MSL M-05 / . 8. Property Designation: 10. Field/Pools(s): Steelhead Platform MacArthur River Field/Grayling Gas Sands .---- 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5,600' 5,247' 5,478' 5,179' 3,860' Casing Length Size MD TVD Burst Collapse Conductor 936' 20" 936' 936' 3,060 psi 1,500 psi Surface 1,440' 16" 1,440' 1,440' 2,630 psi 1,020 psi Intermediate 2,635' 13-3/8" 2,635' 2,635' 3,090 psi 1,540 psi Production 511' 10-3/4" 511' 511' 6,450 psi 4,020 psi Production 5,015' 9-5/8" 5,562' 5,244' 8,150 psi 5080 psi Liner 1,276' 7" 3,841' 3,819' 8,160 psi 7,020 psi Liner 1,075' 3-1/2" 4,803' 4,641' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3,746 - 5,372' 3,730 - 5,095' 7" L-80 2,565' Packers and SSSV Type: See schematic attached Packers and SSSV MD (ft): see schematic attached 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: ",' Detailed Operations Program D BOP Sketch D Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/17/2004 Oil D Gas 0 Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh 263-7627 Printed Name Tim Brandenburg Title Drilling Manager Signature "z. '/S. ~/ Phone 907-276-7600 Date 10/11/2004 ""'./" ¿::? COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30'1:.. 37'1 Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: Subsequent Form Required: - 04. C?:~ ~ Lh Q ß l ~l~ A ~Y ORDER OF Io/Í.~ .f) Approved~~L 1L.J ... c..~~?, M INC:::TI5P~ I S -ñt-T HE COMMISSION Date: 7<.ß fJn ~ -- ~ -1 ,""'" ~-".. 963' 1440' 2635' Steelhead M-O5 As Completed on 11/24/03 KI\I:J to 11:J\:õ Heaa = f4.4' KB to MSL = 160' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 133 X-56 83' 936' 16" 75 J-55 I N-80 83' 1440' 13-3/8" 61168 K-55 82' 2635' 10-3/4" 55.5 N-80 9.760 82' 511' 9-5/8 47 S-95 BTC 8.681 511' 5562' 7" Scab Liner 29 L-80 6.184 2565' 3841' 3-1/2" Scab Liner 9.2 L-80 Hvd 533 2.992 3728 4803 Tobin!!: 7" 29 L-80 6.184 73.9 2565' 5 9. 4754' D-1 A. B. C. 6 79' 436' 1,908' 2,712' 3,100' 3,277' 3,279' 3264' DIL F. 3,294' G. 3,304' H. 3,305' I. 3,313 J. BIm 3316' D. E. 7 5562' PBT = MAX HOLE ANGLE = 38.7° @ 5600' JEWELRY DETAIL ID tern 6.184 TBGHangerFMC 3. 5.963 Halliburton CP-2 TRSV #78-00-390 wI XC's 7" 29 to 7", 26# ABSTL top & b CTC External Casing Packer Baker ZXP Liner Pkr wI 6' Tie-Back Ext; HMC Liner Hngr; 27 jts ofT', 29# csg; Float Collar@ 3807'; IS' Perf7", 29# pup; IS' 7",29# crnt filled pup (drilled out); IS' 7",29# pup jt; 7" x 5-1/2" XC; EBH-22 anchor assy @ 3841'. Liner cemented w/225 sks. Baker 9-5/8" x 6" FB-I pkr; 10' 5-1/2" pup; "X" nipple @ 3845'; 10' 5-1/2" u ; WLEG 3857'. Baker 9-5/8" x 6" FB-I pkr; 10' 5-1/2" pup; "X" nipple (4.562") @ 4238'; 10' 5- 1/2" 0 ; WLEG 4250'. Baker 9-5/8" x 6" FB-I pkr; 10' 5-112" pop; "X" nipple (4.562")@4563'; 10' 5- 1/2" u ; WLEG 4575'. OTIS BWH Perma-Drill Pkr w/lO' SBE; MO Ext; XO to 4-1/2" Butt tbg; Tbg tail cut 4806' on 3/21/90. 1076' 2.992 Baker ZXP Liner top pkrwl 12' x 5-1/4" Tie-Back Ext; 33 jts of3-1/2", 9.2#, L-80, Hydril533 tbg; 4-1/4" locator; 20' pup jt; Landing Collar; XC; MS Float Collar CIBP 0.75' 2.992 19.93' 2.813 6.84' 2.992 6.85' 2.992 6.38' 2.992 1.2 2.97 14.14' 9.64' 2.992 1.51' 2.813 7.98' 2.992 1.6' 2.75 1.32' 2.992 VELOCITY STRING Deployment Sob w/"GS" Profile & SBE OD 5.82" SSSV Insert Profile Nipple w/ Packing Adapters. 3-1/2" BST Slim Line GLM HES "Straight Slot" LSA wI 10' of seals "BWD" Eline set pkr wI 10' SBE & XO to 3-1/2" Butt Pup Jt. 10' x 3-1/2" "X" Profile Nipple Pup Jt. 8' x 3-1/2" "XN" No-Go Nipple wI 2.813 Profile wI WLEG WLEG Fish I 5376' I 5':1: Cut Tbg; "X" Nipple; 7' 4-1/2" pop it I PERFORATION DATA Zone Top Btm Amount Condition B-7 3,746' 3,771' 25 Perf 3/21/03 B-7 3,778 3,798' 20 Perf 4/16103 0-1 4,29Z 4,412' 120 Behind liner 0-2 4,662' 4,708' 46 Behind liner D-3B 4,864' 4,914' 50 Partially covered D-Q 5,302' 5,372' 70 Covered wi Fill M -5W ork Summary Perforate sands . MIRV Slickline. Tag fill. RIH wi gauges. Obtain flowing pressure survey. . Bail fill. / . RIH wi dummy gun. RD Slickline. . MIRV Eline. RIH wi 2-1I2"guns (HSD, 6spf, 60° phasing). . Perfthe following sand (GR log will detennine DIL depth for perf): C-2 sand 3929' to 3942' /'" C-1 sand 3890' to 3910' . RD Eline. . Turn well over to production. Contingency Plan: . If no flow, MIRV Eline. RIH wi 2-1I2"guns (HSD, 6spf, 60° phasing). . Perf the following sand (GR log will detennine DIL depth for perf): B-3 sand 3314' to 3332' B-4 sand 3347' to 3379' /' B-5 sand 3546' to 3585' B-6 sand 3615' to 3620' 3669' to 3683' . RD Eline. . Turn well over to production. ~V~VŒ (ill~ ~~~~æ~ AI.ASIiA OIL AND GAS CONSERVATI ON COMMISSION / I / ¡ í FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager Union Oil Company of California P.o. Box 196247 Anchorage, Alaska 99519 Re: McPufhurFUverM-05 Sundry Number: 304-374 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. 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 requeste . BY ORDER OF THE COMMISSION DATED thisLt'day of October, 2004 Enc!. Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 Tete: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com UNOCALi) He-Alaska Debra A Oudean G & G Technician 19tP1. January 29, --- DATA TRANSMITTAL To: From: Lisa Weepie Debra Oudean 333 W 7m Ave, Suite 100 909 W. 9th Avenue Anchorage, AK 99501-3539 Anchorage, AK 99519-6247 AOGCC Unocal Alaska Transmitting as follows: )æ!~!~~ ~9!A!~.'Q~~~VI~ ~11~' . ~~~ ~~~ ~,~,:.~~. J Cfij-C1..P L( TB~ G-21 RD C()MPL~TIO~ RECORD. . ; 5 INCH; 9380-9900 .1 1; 0 , BU M-1 .. COMPLETION RECORD OWEN X-SPAN PATCH . ¡ 5 INCH' 12/12/2003 4100-4296. ;.1. 1 . O. . 1719-Œ7 TBUM:14RSTSIGMALOG. .... .. ~1~INc~_j...:!l11I2()()3195o-~~1112mJC~~ ) 259<f/q TBU M-13 : COMPLETION RECORD 2.5 HSD POWERJETS ¡15 INCH r 11/19/2003 2789-2798 ßlf~$f1 F"lo -~..I ) ?59"ÚL 11Tsü M-1:;-lPERi'ÕÃÄÏ1NG RECORD 2.5 HSD POWERJETS --[5INCH[111212003 253B-27~!!./x~L3~2Jl-T1-;io ~I ) q'I-)t.P T.B~M-16 JCOMPLETIO~.RECORDEZSVDRILLPAqKER. ... j51.NCH.111/3/200311560-1606 '~~H TBU M-16RD :ICEMENT BOND LOG ~5INCH 111/13/200313859-3958 11 . rv 0 ~-J~ mU~~6~D.~MP~O~~ORD~H~~~~~~~-~c~r~~~~~-~~~- :IMODEL FA SUMP PACKER 'I, I I :1 j;¡ q' ; =' TB0- M-5 " ICOMPLETiÓN RECORD VELOCITY STRlÑG PACKER ~,r5INCH~ 1Ù25/200315O:33SO-I-li¡itJ~1--l1-<.I()--- J (5 ., -1r.Î3 ,TUBING PUNCHER II "I: RECEIVED FED 2 6 2004 t f.\jaska on & Gas Cons. Commission Aoooorage of this transmittal or FAX to 907 263-7828. Date: ~CA¡~r~E[} MAr~ 152004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of request Abandon D Suspend D Operation Shutdown D Perforate D Variance D Annular Disposal D Alter Casing D Repair Well D Plug Perforations D Stimulate D Time Extension D Other [J Change Approved Program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D Install Velocity String 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: Union Oil Company of California 89-133 3. Address: Development 0 Exploratory D 6. API Number: PO Box 19-0247, Anchorage, AK 99516 Statigraphic D Service D 50-733-20413 7. KB Elevation (ft): 9. Well Name and Number 160' KB above MSL M-05 8. Property Designation: 10. Field/Pool(s): MRF-GGS 11. Present well condition summary Total depth: measured 5,600' Feet Plugs (measured) true vertical 5,274' Feet Effective depth: measured 5,478' Feet Junk (measured) Slickline tagged fill at 4,918' MD true vertical 5,179' Feet Casing Length Size MD TVD Burst Collapse Conductor 936' 20" 936' 936' 2,125 psi 1,500 psi Surface 1,440' 16" 1,440' 1,440' 1,178 psi 1,020 psi Intermediate 2,635' 13-3/8" 2,635' 2,635' 962 psi 1,540 psi Production 511' 10-3/4" 511' 511' 1 ,276 psi 4,020 psi Production 5,015' 9-5/8" 5,562' 5,244' 1289 psi 5080 psi Liner 1 ,276" 7" 3,841' 3,819' 676 psi 7,020 psi """",,-,.- """". "."",.". " """ """ ""'""' """".-.- """.,,- Liner 1,075' 3-1/2" 4,803' 4,641' Perforation depth: measured D-3 4,864-4,934' and D-6 5,302-5,372' true vertical D-3 4,691-4,747' an~ D-6 5.040-5.095' ":"'" Tubing (size, grade, and measured depth) 7",29#, L-80 tubing, surface to 2,565', 1\/::-c~/I/€ Packers and SSSV (type and measured depth) ) OTIS 9-5/8" pkr @ 4,761', BOT 9-5/8" pkr(s) @ 4,550'; 4,225', 3,832', ZXP @ 3,728' and 7" HES CP-2 TRSSSV @ 407' JAN n n - .~ 12. Stimulation or cement squeeze summary Ii/Isk, Oil & v ¿:UO4 Intervals treated (measured) n/a Gas Cons Treatment description including volumes used and final pressure Anchor8hð" COll1rni~ ri 13 Representative Daily Averaoe Production or Injection Data Oil-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 1,900 1 235 217 Subsequent to operation 0 2,110 1 260 274 14. Attachments 15. Well Class after proposed work: Daily Report of Well Operations: D Exploratory 0 Development []service 16. Well Status after proposed work: DOil 0 Gas D WAG D GINJ D WINJ D WDSLP 17. I hearby certify that the foregoing is true to the best of my knowledge. Sundry Number: Contact: Steve Tyler 907-263-7649 Printed Name: Philip Krueger Title: Drilling Manager V~-/Ä,. Phone: 263- 7628 Date: 12/05/03 Signature: ~ J' / e 'J'ì ') on [inN¡ "'" .'IJ,\n, J \èj.ûfj- .~ tJnO'l ¿U ejl¡f ORIGINAL JAM 1 .1,20\)\ Form 10-404 Revised 2/2003 RKB to TBG Head = 74.4' 963' 1440', 2635' " 5 , , "'" ". ",' " ',~'" ,,' ' ,:,":". , ,,' . 6 , , ' , : " 7 5562' D Steelhead M-O5 As Completed on 11/24/03 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 133 X-56 83' 936' 16" 75 J-55 I N-80 83' 1440' 13-318" 61/68 K-55 82' 2635' 10-3/4" 55.5 N-80 9,,760 82' 511' 9-5/8 47 S-95 BTC 8.681 511' 5562' 7" Scab Liner 29 L-80 6.184 2565' 3841' 3-1/2" Scab Liner 9.2 L-80 Hyd 533 2.992 3728 4803 Tubing: 7" 29 L-80 6.184 73.9 2565' 1. 2. 3. ~ 6.184 3.81 5.963 4. 3832' DI . ,"I 5. 4225' DIL 6. 4550' DIL 7. 1 4761' OIL C-1 I 8. 3728' 1076'1 2.992 (3713' DIL) 9. 4754' "§ò C')UI 0«1 õ'C':I ,,~@ "..-,- co!! oëii "ØI Go go J!. : =~ u.."": Fill Tagged @ 4880' on 12/21/02 d_r1 /;G~"~~ Q:;¿ PBTD = 5478' TD = 5600' MAX HOLE ANGLE = 38.7° @ 5600' 0-1 I A. B. C. 0-2 79'1 436' 1,908' 2,712' 3,]00'1 3,277' 3,279' (3264' DIL) F. 3,294'1 G. 3,304' H. 3,305' I. 3,313' J. Blm 33]6' D. E. D-3B D-G 0.75' 2.992 19.93' 2.813 6.84' 2.992 6.85' 2.992 6.38' 2.992 1.24 2.97 14.14' 9.64' 2.992 1.51' 2.813 7.98' 2,992 1.6' 2.75 1.32' 2.992 JEWELRY DETAIL Item TBG Hanger FMC Halliburton CP-2 TRSV #78-00-390 wI XO's 7" 29 to 7", 26# ABSTL top & btm CTC External Casing Packer Baker ZXP Liner Pkr wI 6' Tie-Back Ext; HMC Liner Hngr; 27 jts ofT', 29# csg; F]oat Collar@ 3807'; 15' Perf7", 29# pup; 15' 7",29# cmt filled pup (drilled out); 15' 7", 29# pup jt; 7" x 5-1/2" XO; EBH-22 anchor assy @ 3841'. Liner cemented wI 225 sks. Baker 9-5/8" x 6" FB-1 pkr; 10' 5-1/2" pup; "X" nipple @ 3845'; 10' 5-1/2" pup; WLEG @ 3857'. Baker 9-5/8" x 6" FB-1 pkr; 10' 5-1/2" pup; "X" nipple (4.562") @ 4238'; 10' 5- 1/2" pup; WLEG @ 4250'. Baker 9-5/8" x 6" FB-1 pkr; 10' 5-1/2" pup; "X" nipple (4.562") @ 4563'; 10' 5- 1/2" pup; WLEG @4575'. OTIS BWH Perma-Drill Pkr wI 10' SBE; MO Ext; XO to 4-1/2" Butt tbg; Tbg tail cut @ 4806' on 3/21/90. Baker ZXP Liner top pkr wI 12' x 5-1/4" Tie-Back Ext; 33 jts of3-l/2", 9.2#, L-80, Hydril 533 tbg; 4-1/4" locator; 20' pup jt; Landing Collar; XO; MS Float Collar CIBP VELOCITY STRING Deployment Sub wI "GS" Profile & SBE OD 5.82" SSSV Insert Profile Nipple wI Packing Adapters. 3-1/2" BST Slim Line GLM HES "Straight Slot" LSA wI 10' of seals "BWD" Eline set pkr wI 10' SBE & XO to 3-l/2" Butt Pup Jt. 10' x 3-1/2" "X" Profile Nipple Pup Jt. 8' x 3-]/2" "XN" No-Go Nipple wI 2.813 Profile wI WLEG WLEG Fish I 5376' I 5':1: Cut Tbg; "X" Nipple; 7' 4-]/2" pup it I PERFORATION DATA Zone Top Btm Amount Condition B-7 3,746' 3,771' 25 Perf 3/21/03 B-7 3,778' 3,798' 20 Perf 4/16/03 0-1 4,292' 4,412' 120 Behind liner 0-2 4,662' 4,708' 46 Behind liner 0-3B 4,864' 4,914' 50 Partially covered D-6 5,302' 5,372' 70 Covered wI Fill 11/20/2003 No work preformed. Safety meeting permit - stage equipment & prepare for rig up. Standby for crane - Shut in well. Rlup wire line. Pressure test lubricator t/2500 psi (ok) & place methonal cap on same. Rih wI hes lock out tool t/437' WLM RKB & set tool in TRSV & jar dn wI no movement - have production pump water dn tbg wI tbg @ 267 psi - Sleeve shifted @ 520 psi on tbg & continued to pressure up t/1 000 psi to assure full shift of flow tube across flapper - Equalizer tbg psi & pooh wI lock out tool. Release lubricator from crane & standby while drilling uses crane. Rlup crane to lubricator. Rih wI 1.75" drive dn bailer & tag fill @ 3806' Wlm Rkb work bailer dn 25' & fell thru t/ 3847' - work bailer t/ 3860' Wlm Rkb unable to pass same - pooh bailer coated & full of sand. Rih wI 1.75" drive dn bailer & tag fill @ 3860' Wlm Rkb work bailer 20 min & unable to pass same pooh. Wait in lubricator for crane operator 11/21/2003 Accpet rig @ 00:00 hrs fl AFE #161498 M-16 t/ AFE # 161376 M-05 - Place rams for 16-3/4" stack in south west upper well bay - Clear decks of dunnage- make room on "C" deck to stage Equipment. Finish skid Rig to leg B-1. Move jacks from north -south skid to east - west. Stage equipment from the top of northeast well bay t. "C" deck. Clear equipment off north side and stage for south crane. Rldn & move Slick line equipment & work landing off M-1. Install service lines in B-2 upper well bay - Remove valve from old M-16rd tree & put in B-2 upper well bay - start removing swab valve From M-05. Crane Hydraulic hose blew on north crane - repair same & clean up mess. Unload boat. Finish removing swab valve from M-05 & replace wI old M-16rd's. Stack 11/22/2003 Moving equipment off of "C" deck to allow diverter line passage - removing hand rails - preping to skid f/leg B-1 TI leg B-2. Start to skid - Blew seal on pancake on grippers - repair same. Skid rig off leg B-1 t/leg B-2 & spot over M-05. Install hand rails - spot catwalk & beaver slide - start working on hooking up services lines. Prep loads for boat - remove mud products from dry sack room - continue work on service lines. Load boat & continue work on services lines. Continue work on services lines - start up tioga heater thaw rig - transfere glyco back in to system - work on rlup of choke & kill lines & 11/23/2003 Continue tightening bolts on bops & install choke & kill lines - turn heat on to rig & bleed lines & remove hyd line from derrick for repair, hook up Koorney lines to BOP. Clean up NE Upper Well bay room, Dry sack room, open Koomey isolation valves, grease up flanges on 163/4" risers from storage. Clean Rig floor and SW upper well bay, start insulating sub-base. Install test pump in Dry sack room and rig it up for BOP test, rig up tubing tongs, install repaired hydraulic line in derrick, continue insulating sub-base. Unload boat. Layout tubing and strap same, make up buttress riser ( test choke manifold 250 low 11/24/2003 Build test jt - Test BOP and related equipment to 250-3000 psi - Rldn test jt & blow dn equipment. Make up buttress pup to riser and install XO to 7" Otis connection for wireline. ( Helicopters not flying) weathered out? Install drain plugs in trip tank centrifugals, run water into flow ditch and check out return system to pits. Clean decks, S.W, wellhead room, Dry sack room, move tioga heater off of C-Deck and and on to Southside pipe rack. Finish tubing tong rig up, continue cleaning up. wireline crews on board at 15:45 hrs, Rig up slickline, test lubricator to 2000 psi. RIH with brush and dress SSSV profile, wash with 15 bbls KCL water. 250 psi tubing pressure. RIH with SSSV dummy and land out in SSSV profile, pump 7 gallons hydraulic fluid into void with 11/25/2003 Rig up Schlumberger, make up 5.94" gauge ring RIH to 3350'. 250 psi on well. Pressure testing 7" lubricator, had to change out ring on Schlumberger 7" union and retest same. RIH with 5.94" gauge ring junk basket to 3350'. Pick up packer and tailpipe assembly, load prong in plug in upper X nipple in tail pipe assembly, and comer up with 8' of SafeCarb 40, 5 ' of the Carb above the top of the prong. Review perforating checklist and have pre-job safety meeting. Arm setting tool make up E-line to packer assembly and RIH, tie into Schlumberger log, RST SIGMA dated 12/20102. Noted 15' difference between our strip and SIGMA log on collars and GR, set packer at 3263' top of packer depth, 3300 tailpipe depth, good indication of packer setting. POH LD setting tool. Fill and bleed well, took 120 bbls to fill hole, calculated dry all the way to packer. Pressure test 7" tubing to 500 psi for 30 minutes (OK). Review perforating checklist and have pre-job safety meeting. Arm tubing punch and RIH, log 450' to 550', hook up 0 3/4" X 7" annulus to choke manifold Rig up to run tubing, pick up seal assembly and one joint of tubing. Secure well work operations for night. Finish De-mob on #2 Mud pump, P/U trash in pits, repair throttle linkage on HYD tubing tog unit. Working two man crew from 18:00 hrs to 6:00 hrs. 11/26/2003 Two man crew working on De-Mobe issues. Pre-tour safety and operations meeting. Prep to pick up tubing. Pick up tubing to 3174'. Secure well, shut down for lunch. Pick up tubing to 3263'. Make up head pin and circulate down to top of PKR at 3278' tubing measurement, Pressure increase noted when stabbing into top of packer, locate out on packer. Test seals to 500 psi ( Test Good ). Spot corrision inhibitor in annulus. POH and pick up insert assembly and space out pups, space out and land completion. Production pressure up on SSSV control line and test insert assembly to 4000 psi ( OK ). Pump down tubing at 2 BPM and release GS from deployment sub, POH with landing joint, shut blinds test seal assembly to 500 psi (OK). Blow down lines. two nabors 11/27/2003 Run #4 RIH with 2 114" pump bailer with flapper, recovered one cup perf debris an tow cuo Safecarb, at 1: 15 hrs RIH with ball type bailer. recover two cups Safecarb, at 2:45 RIH with latching tool, latch prong and POH with prong. Pollard crew houred out, shut down for crew rest. 11/28/2003 RIH run # 17 1.75" Hydrostatic bailer, POH little recovery, end of bailer mushroomed, indicates being on top of plug. At :30 hrs RIH with 3.5" GR latch up on plug, shear off trying to pull free, POH. Rih wI 3 1/2" GS. Latch plug body Work free, POOH recovered plug body, bottom of plug still packed with safe carbo Run & Latch in place 3 1/2" SSSV. POOH, Production pressure up on control line to 4200 psi, bleed dn & close valve for differential test of 280 psi gas, good test open valve, tbg pressure now 194 psi, release pollard wire line. RIG Down pollard wire line. 11/29/2003 RIH run # 17 1.75" Hydrostatic bailer, POH little recovery, end of bailer mushroomed, indicates being on top of plug, At :30 hrs RIH with 3.5" GR latch up on plug, shear off trying to pull free, POH. Rih wI 3 1/2" GS. Latch plug body Work free, POOH recovered plug body, bottom of plug still packed with safe carbo Run & Latch in place 3 1/2" SSSV. POOH, Production pressure up on control line to 4200 psi, bleed dn & close valve for differential test of 280 psi gas, good test open valve, tbg pressure now 194 psi, release pollard wire line. RIG Down pollard wire line. Well released to Production. Re: Steelhead M-05 Velocity String Sundry # 303-294 Date: Wed, 08 Oct 2003 14:09:42 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Nienhaus, Doug R" <nienhausd@unocal.com> CC: "Tyler, Steve L" <tylersl@unocal.com>, "Hauck, Shane R" <haucks@unocal.com>, "Harness, Evan" <eharness@unocal.com>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us>, Jim Regg <jim_regg@admin.state.ak.us> Doug, et al, Chuck Scheve and myself have reviewed the drawing you have provided for the 7-1/16" stack and 2" x 3" choke and kill lines. It is our determination that what you propose is acceptable given the required pressure rating. Please stay in touch with the Inspector's office (659-2714 or pager 659-3607) so arrangements may be made to witness the BOP test. A copy of this message should be on board Steelhead for the Inspector's reference. Tom Maunder, PE AOGCC "Nienhaus, Doug R" wrote: Tom This is a drawing of the stack and two inch choke & kill lines we would like to use on The M-5 Velosity string install. The stack is 7 1/16" 5M. We plan to be nipple it up dirrectly on the 7 1/16" 5m Tree. ..... Original Message ..... From-' Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent; Monday, October 06, 2003 4.:06 PM To; Tyler, Steve L Cc-' Nienhaus, Doug R; Hauck, Shane R; Harness, Evan Subject; Re: Steelhead H-05 Velocity String Sundry # 303-294 Hello All at Unocal, I need a picture to understand how all this is planned to be set up. Thanks in advance. Tom "Tyler, Steve L" wrote: Tom Unocal is proposing to reduce down to 2" choke hoses, from 3" 5m HCR valve, then back to 3" 5 m choke hoses on rig ( the hoses will have flanged hoses threaded and Baker locked) Workover Foreman / Engineering Tech Unocal Alaska ~Office: (907) 263-7649 ~Cell: (907) 350-6295 ~Home: (907) 696-1837 1 of 2 10/8/2003 2:10 PM M-5 Top of Rotary Table 6.75' Need to Build plate with 7" Buttress pin to cross back over to Steel head Scoping Flow nipple. 3" 5M Kill line hose I ::.::'&,?,, :'"' 3" 5M X 2" 5M DSA 7" 29# Casing Joint 7 1/16" BOP Stack up KB= 74.4' 36.25' 3" 5M Choke hose I.': '~'1 RIG CHOKE 3" 5M X 2" 5M DSA Rig Sub Grating Flanged 2" 5M Hose Flanges threaded & Baker locked on. · :. 7 1116"5M .'--:-. ~.::~ Annular " ,~, ? -:~ .-'?,' . .,,:;.'.~ 2.54' .. .'.. :<.. . Flanged 2" 5M Hose Flanges threaded & Baker locked on. TChoke line Upper well Bay Floor Both Kill line valves 2" 5M Gate 3" 5M X 2" 5M DSA 3" 5M X 2" 5M DSA Both manual choke & HCR are 3" 5M Gate Top of 7 1/16" 5M Tree " {. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~SSION APPLICATION FOR SUNDRY APPROVAL 20 ACC 25.280 1. Type of request Abandon n Suspend ~1 Operation Shutdown n Perforate [] Variance D Annular Disposal Alter Casing n RepairWell [] Plug Perforations [] Time Extension n OtherX: Velocity String Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-enter S. uspended Well [] Stimulate ri 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: Union Oil Company of California/Unocal 89-133 3. Address: Development X Exploratory [] 6. APl Number: PO Box 19-0247, Anchorage, AK 99519 Statigraphic r3 Service [] 50-733-20413 7. KB (Elevation) 160' 9. Well name and number: M-05 8. Property designation: Steelhead Platform 10. Field/Pools: MRF-GGS 11 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Eft Depth TVD (ft): Plugs (measured): Junk (measured): 5,600 5,527 5,478 5,179 n/a Slickline tagged fill @ 4918' MD, 4,734' TVD Casing Length Size MD TVD Burst Collapse ., Conductor 936' 20" 936 936 2125 1500 Surface 1,440' 16" 1440 1440 1178 1020 Intermediate 2,635' 13-3/8" 2635 2635 962 1540 Production 511' 10-3/4" 511 511 1276 4020 Production 5,051' 9-5/8" 511 - 5562' 511-5244' Liner 1,276' 7" 2565' - 3841' 2564' - 3819' Liner 1,075' 3-1/2" 3728' - 4803' 3713' - 4641' Perf Depth MD (ft): Perf Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD(fi): 3746-5372' 3730-5095' 7", 29# L-80 2565' Packers and SSSV Type: Packers and SSSV MD (ft): See attached schematic See attached schematic 12. Attachments: Detailed Operations Summary X 13. Well Class after proposed work: Description Summary of Proposal [] BOP Sketch [] Exploratory [] Development X Service [] 14. Estimated date for commencing operations: 15. Well Status after proposed work: 10/27/2003 16. Verbal Approval: Date: Oil [] Gas X Plugged [] Abandoned [] Commission Representative: WAG Q GINJ [] WINJ [] WDSLP [] 17. I hearby certify that the foregoing is true to the best of my knowledge. Contact: Printed Name: Steve Tyler _ j Title: Engineering Technician !Signature: "~ ~~ Phone: 907-263-7649 Date: 9/22/03 ~' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Sundry Number: .-~'~ ~ - ~ Plug integrity BOP Test Mechanical Integrity Test LocatiO~ ~bll~a,,~,¢b~,,- ~ ~,~¢ ~.~ L~~ '?. ,~ ,~ , ~.~ Subsequent form required 10- L,~)t,..~ ;.,~{~$k,~ 0if & G85 Cor~& Approved by: CommJssJoner COMISSION Date "'~. Submit in triplicate ORiGInAL / Form 10-403 Revised 2/2003 963' 2635' RKB to TBG Head = 80' Fill Tagged (~ 4880' on 12/21/02 ~ D-6 ? PBTD -'.' 5478' ' TD 5 MAX HOLE ANGLE = 38.7° @ 5600' i0, '/ Steelhead M-05 Actual Completion CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 133 X-56 83' 936' .. 16" 75 J-55/N-80 83' 1440' 13-3/8" 61/68 K-55 82' 2635' 10-3/4" 55.5 N-80 9.760 82' 511' 9-5/8 47 S-95 BTC 8.681 511' 5562' 7" Scab Liner 29 L-80 6.184 2565' 3841' 3-1/2" Scab Liner 9.2 L-80 Hyd 533 2.992 3728 4803 Tubing: 7" 29 L-80 6.184 73.9" 2565' JEWELRY DETAIL NO. Depth Length ID Item 80 6.184 TBG Hanger FMC 1. 407 3.8 5.963 Halliburton CP-2 TRSV #78-00-390 w/XO's 7" 29 to 7", 26# ABSTL top & btm 2. 1998 CTC External Casing Packer 3. 2565 Baker ZXP Liner Pkr w/6' Tie-Back Ext; I~iMC Liner Hngr; 27its ofT', 29# csg; Float Collar ~ 3807'; 1.5' Perf 7", 29# pup; 15' 7", 29# cmt filled pup (drilled out); 15' 7", 29# pup jt; 7" x 5-1/2" XO; EBH-22 anchor assy ~ 3841 '. Liner cemented w/225 sks. 4. 3832' Baker 9-5/8" x 6" FB-1 pkr; 10' 5-1/2" pup; "X" nipple ~ DIL 3845'; 10' 5-1/2" pup; WLEG ~ 3857'. 5. 4225' Baker 9-5/8" x 6" FB-1 pkr; 10' 5-1/2" pup; "X" nipple DIL (4.562") ~ 4238'; 10' 5-1/2" pup; WLEG~ 4250'. 6. 4550' Baker 9-5/8" x 6" FB-1 pkr; 10' 5-1/2" pup; "X" nipple DIL (4.562") ~ 4563'; 10' 5-1/2" pup; WLEG~ 4575'. 7. 4761' OTIS BWH Perma-Drill Pkr w/10' SBE; MO Ext; XO to DIL 4-1/2" Butt tbg; Tbg tail. cut ~ 4806' on 3/21/90. 8. 3728' 1076' 2.992 Baker ZXP Liner top pkr w/12' Tie-Back Ext; 33 jts of 3- 1/2", 9.2#, L-80, Hydril 533 tbg; 4-1/4" locator; 20' pup jt; Landing Collar; XO; MS Float Collar 9. 4754' CIBP Fish 5376' 5'4- Cut Tbg; "X" Nipple; 7' 4-1/2" pupjt I PERFORATION DATA Zone Top Btm Amount Condition B-7 3746 3771 25 Perf 3/21/03 B-7 3778 3798 20 PROPOSED C-1 3,893' 3,920' 27 Behind liner D-1 4,292' 4,412' 120 Behind liner D-2 4,662' 4,708' 46 Behind liner D-3B 4,864' 4,914' 50 Partially covered D-6 5,302' 5,372' 70 Covered w/Fill JWS 9/22/2003 963' RKB to TBG Head = 80' 2635' 5562' Fill Tagged @ 4880' on 12/21/02 ............................................... ~D-3B ' ,. . . . . ... · ... PBTD -' 5478' TD = 5 ;00' MAX HOLE ANGLE = 38.7° @ 5600' Steelhead M-05 Proposed Velocity String Completion CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 133 X-56 83' 936' 16" 75 J-55/N-80 83' 1440' 13-3/8" 61/68 K-55 82' 2635' 10-3/4" 55.5 N-80 9.760 82' 511' 9-5/8 47 S-95 BTC 8.681 511' 5562' 7" Scab Liner 29 L-80 6.184 2565' 3841' 3-1/2" Scab Liner 9.2 L-80 Hyd 533 2.992 3728 4803 Tubing: 7" 29 L-80 6.184 73.9 2565' 80 407 1998 2565 3832' DIL 4225' DIE 4550' DIL JEWELRY DETAIL Item TBG Hanger FMC Halliburton CP-2 TRSV #78-00-390 w/XO's 7" 29 to 7", 26# ABSTL top & btm CTC External Casing Packer 4754' PROPOSED VELOCITY STRING A. ! ~81' 3.25 SBE · i 407' 2.813 SSSV Insert Profile C. I I 3-1/2" GEM(S) i. -2,580' 2.813 Profile Nipple I I LSA ~3,150' I Eline set pkr w/10' SBE 10.0 2.992 Pup Jt. 10' x 3-1/2" H_ 2.813 Profile Nipple 10.0 2.992 Pup Jt. 10' x 3-1/2" I I 2.666 No-Go Nipple w/2.813 Profile __ I 560' I 1.75 I 2-3/8" FJWPw/Lock Mandrel w/WLEG ~}; -~ I 1.71 "R" Nipple [ Btm -.N Fish ] 5376' Baker ZXP Liner Pkr w/6' Tie-Back Ext; HMC Liner Hngr; 27 its ofT', 29# csg; Float Collar ~ 3807'; 15' Perf 7", 29# pup; 15' 7", 29# cmt filled pup (drilled out); 15' 7", 29# pupjt; 7" x 5-1/2" XO; EBH-22 anchor assy ~ 3841 '. Liner cemented w/225 sks. Baker 9-5/8" x 6" FB-1 pkr; 10' 5-1/2" pup; "X" nipple ~ 3845'; 10' 5-1/2" pup; WLEG ~ 3857'. Baker 9-5/8" x 6" FB-1 pkr; 10' 5-I/2" pup; "X" nipple (4.562") 4238'; 10' 5-1/2" pup; WLEG ~ 4250'. Baker 9-5/8" x 6" FB-1 pkr; 10' 5-1/2" pup; "X" nipple (4.562") 4563'; 10' 5-1/2" pup; WLEG~ 4575'. OTIS BWH Perma-Drill Pkr w/10' SBE; MO Ext; XO to 4-I/2" :4806' on 3/21/90. Baker ZXP Liner top pkr w/12' x 5-1/4" Tie-Back Ext; 33 its of 3-1/2", 9.2#, L-80, Hydril 533 tbg; 4-1/4" locator; 20' pup Collar; XO; MS Float Collar CIBP Zone Top Btm Amount ~ondition B-7 3746 3771 25 Perf 3/21/03 C-1 3,893' 3,920' 27 Behind liner D-1 4,292' 4,412' 120 Behind liner D-2 4,662' 4,708' 46 Behind liner D-3B 4,864' 4,914' 50 Partially covered D-6 5,302' 5,372' 70 Covered w/Fill SLT 9/1. 8/03 M-5 Velocity String Workover Summary: 1. Prep-Work- Have wellhead technician qualify wellhead. 2. Prep-Work- Conduct a pre-job assessment of facilities. 3. Prep-Work- Lock open HES CP-2 TRSSSV w/slickline. RI/Work brush in SSSV area @ 407'. RI w/SSSV Dummy. Pressure test hydraulics and seals. RD slickline. 4. Prep-Work- At BOT shop, set Thru-Tbg BP in in tail between profile nipples. Pressure test, on each side to 2500 psi. 5. EL - RU Eline. PU/MU Pkr and tail assy onto setting tool. RIH set pkr/tail assy @ 3150'_+. POOH. 6. Fill wellbore w/FIW w/inhibitor. Jug test tubing to 500 psi. 7. EL- PU/MU 6' tbg punch gun. RIH punch tbg @ 500'_+. POOH. RD Eline. 8. Re-Fill wellbore wi FIW wi inhibitor. Jug test tubing to 500 psi. 9. RIG - Move/Spot rig over M-05. NU 7-1/16" BOPE stack on swab valve. 10. RIG - Pressure test BOPE and riser. 11. RIG - PU/MU BHA and GLM(s). RIH w/18 its of 3-1/2" tbg. MU HES Profile Nipple. 12. RIG - PU/MU 18 jts of 2-3/8", 4.6# Hydril 511 tbg. Run concentrically inside 3-1/2" tbg. Latch Lock Mandrel into 3-1/2" profile. 13. RIG - Continue PU/RIH w/3-1/2" tbg w/GLM(s) spaced out. Stab into pkr @ 3150'_+. Pressure test down tbg to confirm seal assy placement. 14. RIG - PU space-out HES Insert SSSV Profile Nipple so profile lands, sequentially, in 7" SSSV when seal assy is in packer. 15. RIG - RIH space out SBE to land 2' to 5' below 7" tbg hanger. Run velocity string on SBE running tool. Land tbg string in SSSV nipple. Release from SBE. POOH. 16. RIG - Pressure test to 500 psi w/7" x 10-3/4" annulus open. Pressure test SSSV hydraulics. 17. RIG - Close Master/Swab valve(s). ND BOPE. Release Rig. 18. RU 1" Temporary Gas Line. Gaslift FIW out of well. 19. SL - RU slickline. RIH w/retrieving tool. Latch, release, retrieve BOT Thru-Tbg BP. RD slickline. 20. BL - RU braided line. RIH w/3-1/2" GS. Latch/release 2-3/8" tail pipe lock mandrel. RI w/2-3/8" tail pipe. Land tail pipe lock mandrel in "XN" profile nipple. Release GS PT. POOH. RD Braided line. 21. SL- RU Slickline. PU/MU 2.813" SSSBV. RIH set in SSSV Profile Nipple. POOH. Test SSSV. RD Slickline. 22. Turn well over to Production Steelhead M-05 , Table Btm of Trolly beam ~ of Swab Valve Unocal Alaska 909 W. 9th Avenue Anchorage, AK 9950 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unocal.com UNOCAL Beverly Harrison Business Ventures Assistant 6/17/2003 To: AOGCC Lisa Weepie 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL - ~Wi~;~: ~~[OG~.TYPE~~:~i!~ ?!!~i¢~[g;i ;~:":,;!"DATE~{~' ';~':.,"(INTER~fAL~?~ '~iB'"UNE~! 'FILM?;'CD.;' ' COMPLETION RECORD- 2.5" HSD A-15RD POWERJET 2506HMX 5INCH 5/1/2003 11750-12550 2 1 1 AN-13RD2 RST SIGMA MODE 5INCH 5/22/2003 3400-4650 2 1 1 AN-19 RST SIGMA MODE 5INCH 5/22/2003 3400-4650 2 1 1 AN~37 RST SIGMA MODE 5 INCH 5/22/2003 3100-4250 2 1 1 COMPLETION RECORD- 2.5" HSD G-12RD3 POWERJETGSPF 5INCH 5/10/2003 12400-13610 2 1 1 2 1/2" HSD PWER JET 2506, HMX 3 1/2" '"GRINER-1 HALLIBURTON PLUG 5 INCH 4/19/2003 250-1780 1 1 1 ,., ' GRINER-1 CEMENT MAP 418/2002 0 0 1 TEMPERATURE SURVEY- CEMENT TOP KGSF-3 IDENTIFICATION PBMS 2INCH 6/4/2003 3500-7020 1 1 1 COMPLETION REPORT- 2.5" HSD M-5 POWER JET, 6 SPF 5 INCH 4/16/2003 3600-3900 2 l,,- \ 1 1.56" 1606 HMX, TUBING PUNCHER ~ 7.X /SRU223-28 COMPJETION RECORD 5INCH 5/25/2003 1580-5606 1~,~) 1\ ,, 3.5 HALLIBURTON CAST IRON PLUG / SRU223-28 CEMENT DUMP BAILER 5INCH 5/24/2003 1662-5665 1 1 1 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. ""',~' .... ,'"""~ ~i ....... ~'%,//~i ...... ~r"~ ',, .v,.-,:, '": ~' ',?~ ' ' ........ ~:~. ~,,.i ," ~.,'~'U Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-765 I Fax: (907) 263-7828 E-mail: harrisonb(C, unocal.com UNOCAL Beverly Harrison Business Ventures Assistant April 15, 2003 To: AOGCC Lisa Weepie 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL - ,, 10000- D-01 TCP CORRELATION HALLIBURTON 4 5/8" CARRIER 5, INCH 3/20/2003 10569 2 1 1 --- -- M-05 COMPLETION RECORD 2.5" HSD POWERJET 5 INCH 3/22/2003 3570-3870 2 1 1 Please acknowledge receipt by signing and returning one., copy of this transmittal[,,,~, ~ c°r Received BY"~, ,~- ';~- ~-~"¢"~ ~(~ ~~Date: ^nchom§e. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: X 160' KB above MSL feet 3 Address Exploratory: i 7. Unit or Property name P.O. Box 19-0247 Anchorage, AK. 99519-0247 Stratigraphic: Trading Bay Unit Service: 4. Location of well at surface Leg B2 Slot # 11 Steelhead Platform 8. Well number 1,037' FNL, 598 FWL, Sec. 33, 9N-13W-SM M-05 At top of productive interval ~" '~/ ~ 9. Permit nu,m~r 1,383' FNL, 1,181' FEL, Sec. 33, 9N-13W-SM 89-133 ~ At effective depth 10. APl number 50- 733-20413 At total depth 11. Field/Pool 1,634 FNL, 2,479' FEL, Sec. 33, 9N-13W-SM MRF - GGS 12. Present well condition summary V" Totaldepth: measured 5,600' feet~. Plugs (measured) true vertical 5,274' feet ~ Effective depth: measured 5,478' feet Junk (measured) Slickline Tagged fill @ 4918' MD true vertical 5,179' feet 4734' TVD Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 936' 20" 3655sx 936 936 Surface 1,440' 16" 1300sx 1440 1440 Intermediate 2,635' 13-3/8" 1900sx 2635 2635 Production 511' 10-3/4" 1220sx 511 511 Production 5,051' 9-5~8" 1050 sx 511 - 5562' 511-5244' Liner 1,276' 7" 205 sx 2565'- 3841' 2564'- 3819' Liner 1,075' 3-1/2" 102 sx Lite Create 3728' - 4803' 3713' - 4641' Perforation depth: measured D-3 4864' - 4934' & D-6 5302' - 5372' true vertical D-3 4691'-4747' & D-6 5040'- 5095' Tubing (size, grade, and measured depth) 7", 29#, L-80 Tubing. Surface to 2565'. Packers and SSSV (type and measured depth) OTIS 9-5~8" pkr @ 4761', BeT 9-5~8" pkr(s) @ 4550', 4225', 3832', ZXP @ 2565', 7" ZXP @ 3728' & 7" HES CP-2 TRSSSV @ 407' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 12/20/2002 16. If proposal well verbally approved: Oil: Gas: X Suspended: Name of approver Date approved Service: 17. I hereby certify that th.e foregoirj.g is true and correct to the best of my knowledge. Steve Tyler vf FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity BOP Test Location clearance~ ,t~ ,, , ~:?~'~- --.~'-~ Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner M L Bill Commissioner Date Form 10-403 Rev 06/15/88 ( ¢,' -' --: i -~. L ~FI" SUBMIT IN TRIPLICATE Steelhead M-1 Procedure Summary 1RI and set Composite BP @ 4740' on E/line. 2 Dump bail 25' of cemment on top of plug. 3 RI & perforate the C-1 sand 3889' to 3918' 4 RD E/line. 5 Put well on test. RKB to TBG Head = Tree nnection: Fill Tagged ~ 49t8' on 9~22~02 Steelhead M-05 Current Completion CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 133 X-56 83' 936' 16" 75 J-55 / N-80 83' 1440' 13-3/8" 61/68 K-55 82' 2635' 10-3/4" 55.5 N-80 9.760 82' 511' 9-5/8 47 S-95 BTC 8.681 511' 5562' 7" Scab Liner 29 L-80 6.184 2565' 3841' 3-1/2" Scab Liner 9.2 L-80 Hyd 533 2.992 3728 4803 Tubing: 7" 29 L-80 6.184 73.9 2565' JEWELRY DETAIL NO. Depth Length ID Item 80 6.184 TBG Hanger FMC 1. 407 3.8 5.963 Halliburton CP-2 TRSV #78-00-390 w/XO's 7" 29 to 7", 26//ABSTL top & bun 2. 1998 CTC ExtemaI Casing Packer 3. 2565 Baker ZXP Liner Pkr w/6' Tie-Back Ext; HMC Liner ltngr; 27its ofT', 29//csg; Float Collar ~ 3807'; 15' Peff 7", 29//pup; 15' T', 29//cmt filled pup (drilled out); 15' 7", 29//pup jr; 7" x 5-1/2" XO; EBH-22 anchor assy @ 3841 '. Liner cemented w/225 sks. 4. 3832' Baker 9-5/8" x 6" FB-I p~; 10' 5-1/2" pup; "X" nipple DIL 3845'; 10' 5-1/2' pup; WLEG ~ 3857'. 5. 4225' Baker 9-5/8' x 6" FB-I pkr; t0' 5-1/2" pup; "X' nipple DIL (4.562") ~ 4238'; 10' 5-1/2" pup; WLEG ~ 4250'. 6. 4550' Baker 9-5/8" x 6" FB-1 p'kr; 10' 5-l/2" pup; "X" nipple DIL (4.562") ~ 4563'; 10' 5-1/2" pup; WLEG .~/4575'. 7. 4761' OTIS BWH Pem~a-Drill Pkr w/10' SBE; MO Ext; XO to DIL 4-1/2" Burl tbg; Tbg tail cut ~ 4806' on 3/21/90. 8. 3728' 1076' 2.992 Baker ZXP Liner top pkr w/12' Tie-Back Ext; 33 jts of 3- I/2", 9.2//, L-80, Hydril 533 tbg; $-t/4" locator; 20' pup jr; Landing Collar; XO; MS Float Collar 4740 NA Baker 3~ /2 ! Compos tc Bridge Plug Fish 5376' t 5'± Cut Tbg; "X" Nipple; 7' 4-1/2" pupjt ] 5562' 5478' MAX HOLE ANGLE = 38.7 @ 5600 PERFORATION DATA Zone Top Btm Amount Condition C-1 3,893' 3,920' 27 Cmt Isolated D-1 4,292' 4,412' 120 Cmt Isolated D-2 4,662' 4,708' 46 Cmt Isolated D-3B 4~864' 4,9~4' 50 Open D-6 5,302' 5,372' 70 Covered w/Fill SLT 12/18/2002 Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOCAL ) Dale Haines Drilling Manager Monday, November, 24, 1997 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: Steelhead Platform Well M-5 The Steelhead Platform Well M-5 "Well Completion Or Recompletion Report And Log" Form 10-407 was completed, but apparently was not submitted to the state. The Engineer working on this well was transferred and the report inadvertently filed without being signed and sent to the State. UNOCAL completed the workover on M-5 on 9/19/96, in the C-1, D-l, and D-2 series Grayling Gas Sands. We apologize for the delay in sending in the completion report. If you have any questions, please contact the undersigned at 263-7660 or Dan Williamson at 263-7677. Sincerely~, Dale Haines Drilling Manager DH/leg STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CC,,VlMISSION '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 ~umb~:~ ~ 3. Address 8. APl Number v- PO Box 190247 Anchorage Ak, 99519-0247 50- 733-20413-00 4. LocalJon of well at surface Steelhead Pltf. Leg B-2 Conductor # 11 - ' 9. Unit or Lease Name 1,037' FNL, 598' FEL, Sec- 33, 9N'13W'SM i! ~~l~t~ Trading Bay Unit At Top Producing Interval . 10. Well Number 1,383' FNL, 1,181' FEL, Sec 33, 9N-13W-SM M-5 At Total Depth 11. Field and Pool 1,634 FNL, 2,479' FEL, Sec. 33, 9N-13W-SM McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Grayling Gas Sands Pool 160 KB Above MSLI ADL 18730 12. Date Spudded 13. Date T.D. Reached J 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions W/O Began 9/7/96I 9/19/96] 187' feet MSL 1 17. Total Depth (MD+TVD)5,600 & 5,247' 18. Plug Back Depth (MD+TVD)5,478, & 5,179' I 19' Directi°nal Survey I20' Depth where SSSV setYes: X No: 437' feet MD I21' Thickness °f Permafr°stN/A 22. Type Electric or Other Logs Run DIL-GR, LDT-CNL-GR, SHDT, GR-CBT-CET-GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FI-OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# X-56 O' 936' 26" 3,655 SX CMT N/A 16" 75# J-55, N-80 O' 1,440' 22" 1,300 SX CMT N/A 13-3/8" 61/68# K-55 O' 2,635' 17.5" 1,900 SX SMT N/A 10-3/4" 55# N-80 O' 511' 12.25" 1,220 SX CMT N/A 9-5/8" 47# S-95 511' 5,562' 12.25" (Same) N/A 7" 29# L-80 2,565' 3,857' 8.681" 205 SX CMT N/A 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7" 78' - 3,840' 2,565' & 3,832' See Attached Perforations. 5-1/2" 3,840' - 3,857' 5-1/2" 4,225' - 4,250' 4,225' 5-1/2" 4,550' - 4,575' 4,550' 4-1/2" 4,765' - 4,806' 4,779' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 9/19/96I Flowing Gas Well Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MMCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 9/25/96 24 TEST PERIOD => 54,842 3.2 N/AI N/A Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 935 20 24-HOUR RATE => 54,842 3.2 N/A 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE: RECEIVED Form 10-407 NOV 2 5 199 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate Alaska 011 & gat Cons. Commlasion 29. 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. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed(~~~'/~t ~r¢2~f'' J~H Title_ Drilling Manager Date 11/24/97 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 injecfion, steam injection, air injection, salt water disposal, water supply for injeclion, 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 addi§onal 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. Form 10-407 Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. RECEIVED Item 28: If no cores taken, indicate "none". NOV 25 199/' Ala6ka 011 & Gas Cons. Commission Anchorage STEELHEAD PLATFORM WELL M-5 PERFORATED INTERVAL SUMMARY= c-1 3,893' - 3,920' 27' 3.67" HC D-1 4,292' - 4,412' 120' 3.67" HC D-2 4,662' - 4,708' 46' 3.67" HC 5 SPF, 72 PHASE, 9/96 5 SPF, 72 PHASE, 9/96 5 SPF, 72 PHASE, 9/96 The below noted D-3B and D-6 sands are isolated with a Baker nominal NPR (WLR) plug. Sand was dump bailed on top. D-3B 4,864' - 4,914' 50' D6 5,302' - 5,372' 70' 3-3/8" HC 3-3/8" HC 6 SPF, 60 PHASE, 3/90 6 SPF, 60 PHASE, 3/90 · UNOCAL ~ Unocal Corporation ~ Detailed Activity Report UNOCALe AND HOSES 11 P6 35B 5.50 15:00 20:30 11 P6 28 3.00 20:30 23:30 11 P6 45 0.50 23:30 00:00 5478.0 9/8/96 11 PlO 35K 2.00 00:00 02:00 5478.0 11 PlO 35C 5.00 02:00 07:00 5478.0 11 PlO 5 1.00 07:00 08:00 5478.0 11 PlO 35K 2.00 08:00 10:00 5478.0 11 PlO 35E 2.00 10:00 12:00 5478.0 11 PlO 5 1.50 12:00 13:30 5478.0 11 PlO 14C 2.50 13:30 16:00 5478.0 11 PlO 14A 8.00 16:00 00:00 5478.0 11 PlO 15A 8.50 00:00 08:30 5478.0 9/9/96 11 PlO 23 9.00 08:30 17:30 5478.0 5478.0 SECURE WELL FROM PRODUCTION - RIG UP 4 1/2" BUTT TUBING FROM TREE TOP TO RIG FLOOR - RIG UP LUBRICATIOR AND HALABURTION SLICK LINE - INSTALL HAND PUMP ON SSSV & FUSEABLE LINK ON SSV - MAKE 3.78 GUAGE RING - PRESSURE TEST LUBRACATIOR TO 250 & 3000psi RUN TO 4806slm - POH SET SLICK LINE TO THE SIDE 5478.0 RIG UP SCHLUMBERGER - HOLD PRE ARMING SAFETY MEETING - ESTABLISH RADIO SILENCE MAKE UP PACKER AND RUNNING TOOL - PRESSURE TEST LUBRACATIOR TO 250 & 3000psi - RIH WITH BAKER ISOLATION PACKER MAKE UP BAKRER ISOLATION PACKER - RIH WITH SAME - ESTABLISH TIE IN TO TUBING TALLY WITH ATLAS CALIPER LOG DATEED 03/21/90 - SET PKR WITH TAIL AT 4818 , CENT RUBBERS 4808 & PKR TOP ART 4806 - TRIP OUT WITH WIRE WHILE BLEEDING DOWN WELL TO lOOpsi PLUG HOLDING OK RIG UP HES SLICK LINE - MAKE UP 2" DUMP BAILER WITH 20/40 CARBOLITE - PRESSURE TEST TO 250 & 3000psi -RIH TAG AT 4803 - AND DROP SAND - TRIP FOR #2 RUN - TAG AT 4799 - DUMP BAILER - TRIP FOR #3 RUN FOUND THAT SAND HAD NOT FALLEN OUT - MAKE #3 RUN WITH SAME RESULTS - ONE OF THE SPRINGS ON DUMP BAILER NOT CORRECT - QUIT DUMP BAILER RUNS - WILL SAND OUT WITH CIR FILL TUBING WITH INLET WATER - PRESSURE TEST TO 2500psi (OK) RIG UP SCHLUMBERGER - RSTABLISH RADIOS SHUT OFF , HOLD PREARM SAFETY MEETING - ARM TUBING PUNCHER - PRESSURE TEST LUBRACATIOR TO 250 & 3000psi RIH WITH 5' OF TUBING PUNCHER WITH 4$hpf - TIE IN TO TUBING TALLY USEING ATLAS CALIPER LOG 03/21/90 - SPACE GUNS OUT FOR PERFS 4712 TO 4707 THIS WAS THE BEST SPOT IN RELATION TO TUBING COLLAR FOR GUN PERFORMANCE - HAD GOOD INDICATION OF COMMUNICATION DISPLACE ANNULUS WITH INLET WATER - POOR ENOUGH SAND DOWN TUBING TO FILL TO 4798 WHICH SHOULD BE MIDDLE OF MILL OUT EXT DISPLACE WITH 35Bb[ SET CAMRON TYPE "H" BPV - NIPPLE DOWN TREE NU/ND BOP's PULL BPV - FUNCTION RAMS & ANN IN A ATTEMPT TO KEEP TRASH OFF CK - SET TWO WAY CK - MAKE UP TEST STRING - PRESSURE ALL BOP EQUIPMENT - PULL DBL CK CK 10 3/4 9 5/8 ANN FOR PRESS (0) - BACK OUT HOLD DOWN PINS ' PULL TUBING OUT OF SEALS DID NOT SEE MUCH OVER PULL (STRING WT = 130K) - PULL HANGER TO RIG FLOOR - CLOSE TIW - PUNP OPEN SSSV - CK FOR PRESSURE AT TIW (VENTED SOME GAS NOT MUCH) - ALLOW SSSV TO CLOSE - POH TO SAME - PUMP OPED ONE MORE TIME TO CK PRESSURE - CONT POH STAND BACK 4028' - LAY DOWN BALANCE - ' UNOCAL Unocal Corporation .~ UNOCALe Oetailed Activity Report I_ I 11 P9 13B 6.50 17:30 00:00 5478.0 9/10/96 11 P9 13B 5.00 00:00 05:00 5478.0 9/11/96 11 P9 13A 9.00 05:00 14:00 5478.0 11 P9 45 2.00 14:00 16:00 5478.0 11 P9 6F 2.50 16:00 18:30 5478.0 11 P6 31A 3.00 18:30 21:30 5478.0 11 P6 31A 1.00 21:30 22:30 5478.0 11 P6 31A 1.50 22:30 00:00 5478.0 11 P6 31A 7.50 00:00 07:30 5478.0 11 P6 31A 2.50 07:30 10:00 5478.0 11 P6 6F 4.00 10:00 14:00 5478.0 11 P6 6F 4.50 14:00 18:30 5478.0 RIG UP SCHLUMBERGER - MAKE 8.25" JUNK BASKET RUN - TAG AT 4760wtm CBT 01/03/90 - RUN CORRALATION LOG FROM 4750 TO 3250 - DID NOT SEE ANYTHING GOOD TO TIE INTO - TRIP WIRE FOR ISOLATION PACKER #1 - RIH WITH SAME TIE INTO CBT LOG 01/03/90 - SET PKR TOP AT 4550 - TRIP WIRE FOR PACKER ASSEMBLY #2 AT 2400hr$ WIRE LINE SET TREATING/ISOLATION PACKERS ON "E" LINE - DEPTH CONTROLL TIED INTO CBT LOG 03/01/90 - PACKER TOPS 4550 , 4225 & 3832 - TAIL ASSEMBLY ON EACH PKR = X0,9.25 5 1/2" 17# PUP , HES 4.562 "X" NIPPLE , 9.25 5 1/2" 17# PUP , WIRE LINE RE-ENTRY GUIDE - PACKER & TAIL LENGTH OVER ALL = 25'+- PICK UP CEMENT HEAD AND LINER HANGER ~ STAND BACK BOTH ITEMS - PICK UP LINER RUNNING TOOLS - HOLD PRE JOB SAFETY MEETING - RUN 7" LINER - LATCH INTO BAKER FB-1 PACKER ASSEMBLY SET AT 3832 (CBT 03/01/90) 3841rrm - WITH LINER ANCORED IN FBI PKR AT 3841rtm (3832 CBT) , CEMENT FILLED COLLAR AT 3824rtm , PERFORATED PUP FROM 3824 TO 3808 , BAKER LANDING INSERT AT 3805rtm AND TOP OF LINER TOP PACKER AT 2565rtm - CEMENT WITH 225sk$ (265cf) CLASS "G" MIXED TO 15.Bppg , BUMP PLUG - SET LINER HANGER ~ SET LINER TOP PACKER , RELEASE LINER , REVERSE CLEAN 8Bbt CLEAN CMNT TO SURFACE POH WITH 5" D.P. , BREAK DOWN TOOLS MAKE UP BAKER TIE BACK EXTENSION CLEAN OUT MILL - RIH AND POLISH TIE BACK EXTENSION - TAGGED TOP OF LINER AT 2565rtm - CIR CLEAN - TRIP FOR 6" CLEAN OUT ASSEMBLY MOVE 4 1/2" TUBING TO ALLOW ACESS TO 3 1/2" D.P. MAKE UP 6" CLEAN OUT ASSEMBLY - RIH WITH SAME CONT RIH WITH 6" CLEAN OUT ASSEMBLY - TAG SOFT CEMENT AT 3689 - WASH DOWN FROM 3689 TO 3785rrm - WAIT ON CEMENT 1hr - CONT CLEANING OUT SOFT CEMENT TO INSERT AT 3805 - DRILL INSERT DRILL F/C CLEAN OUT PERF JNT (HAD GOOD CEMENT IN PERF JNT) - PUMP 200 TO 300 VIS SWEEP AROUND WHILE DRILLING CEMENT FILLED COLLAR AT 3824 - HAD GOOD INDICATION OF ALL THESE ITEMS - KICKED OUT ROTARY AFTER DRILLING CEMENT FILLED COLLAR - RIH 15' AND TAG AT 3840rtm - CIR WELL CLEAN PULL 12stnd$ - WE WERE SHORT 2Bbt ON FILL UP - RUN BACK TO BTM - CIR BTMS DID NOT SEE ANYTHING - POH DID NOT HAVE TROUBLE WITH FILL - PICK UP 2 7/8 10.4# "E" PAC D.P. 1100' - RIH WITH SAME TO 4762 - GETTING SOME LIGHT GAS TO SURFACE ON 9 5/8 ANN - CIR AROUND FIW WHILE CKING OUT PROBLEM - BLED 13 3/8 BY 9 5/8 FROM 200psi TO 0 (SOME FLUID TO SURFACE) - QUIT GETTING GAS ON 9 5/8" ANN - PRESSURE TEST AGANST ANN TO lO00p$i NO LEAK OFF NO PRESSURE ON 13 3/8 BY 9 5/8 - RIH TAG AT 4794rrm - PULL TO 4779 - FILTER FLUID -UNOCAL ~ Unocal Corporation Detailed Activity Report UNOCAL ) ........................... ...`..~.~.....~...~.............~......~..~.................~.~........~.........~........+:........../.~/..../...........~.........~...........~..~...~../~......~.........~....~.:.:.:.:.:~:.:.:.:~:.:.:.:.:.:.:.:.:.:.:.:°:.:.:.:+:.:.:.:<.>:+:<.:.:.~.:.:.:°>:.:.:.:.:.~.:.:+:.:+:.:+:+:.:.:.:.:+:.:.......~....~...........~.....~....~......~...........~:.:.:.:.:~.:~:.:~:.:.~.:.:.:.~.:..~.....~.~...~.:...:~. ... ::::::::::::::::::::::::::::::::::::::::::::::: 9/12/96 9/13/96 11 P6 5 5.50 18:30 00:00 5478.0 11 P6 5 1.00 00:00 01:00 5478.0 11 P6 6F 2.50 01:00 03:30 5478.0 11 P9 15A 1.00 03:30 04:30 5478.0 11 P9 13A 8.50 04:30 13:00 5478.0 11 P9 13A 2.50 13:00 15:30 5478.0 11 P9 13A 1.00 15:30 16:30 5478.0 11 P9 13A 4.00 16:30 20:30 5478.0 11 P9 45 3.50 20:30 00:00 5478.0 11 P6 31A 1.00 00:00 01:00 5478.0 11 P6 31A 4.00 01:00 05:00 5478.0 11 P6 23 8.00 05:00 13:00 5478.0 11 P6 35B 6.00 13:00 19:00 5478.0 11 P6 6F 1.50 19:00 20:30 5478.0 FILTER FLUID TO 20NTU AT FLOW LINE - CONT WATCHING 13 3/8 BY 9 5/8 NO PRESSURE BUILD UP CONT CIR AND FILTER FLUID LESS THAN 20NTU AT FLOW LINE - TRIP FOR 7" TUBING TIE BACK CHANGE BTM RAMS TO 7" ' PRESSURE TEST DOOR SEALS RIG UP EQUIPMENT TO RUN 7" CSNG ' HOLD PRE JOB SAFETY MEETING - RUN & DRIFT 7" 29# L'80 ABSTL TUBING STRING - INSTALLED HES CP'2 TRSV AT 446 TO 438 ' CONT RIH STAB INTO LINER TOP AND TAG WITH LOCATIOR AT 2565rtm - PRESSURE TEST TO lO00psi TO CONFIRM SEALS HOLDING - POH TO SPACE OUT HANGER SPACE OUT FOR LANDING TUBING - THREAD CONTROLL LINE THREW HANGER AND PRESSURE TEST PACKOFF - SPLICE LINE AND RE-OPEN SSSV - CLOSE SSSV WHILE REVERSING & TEST SSSV FOR FUNCTION AND SEAL TO lOOpsi - REVERSE IN NALCO 3900 AT lga[/lOBb[ AS PACKER FLUID - RIH AND STAB INTO LINER TOP - LAND TUBING (P.U. WT= 130K S.0.=125K) - TIGHTEN HOLD DOWN PINS - PRESSURE TEST SEALS , TUBING & HANGER TO 2500psi FOR 15min - BACK OUT LANDING JNTS RIG UP HES SLICK LINE AND LUBRACATIOR - RIH TO 4571slick Line mesurements - HAD TO WORK TOOL ONCE TO GET INTO PKR AT 4225 (CBT 03/01/90) - HAD TO WORK TOOLS TO GET BY SPOT AT 4568 SETTING DOWN AT 4569 TO 4571 - ATTEMPT TO DRIVE THREW N/G - HAD TO JAR UP TO GET FREE - TRIP TO CK TOOLS RIG TO RIH WITH 4.5" MILL ON 2 7/8 10.4# PAC D.P. - CHANGE TOP RAMS TO 3 1/2" - OFF LOAD BOAT - CHANGE RAMS FOR CLEAN OUT RUN - PRESSURE TEST DOOR SEALS - MAKE 4.5" O.D. TAPER MILL - PICK UP 1100' 2 7.8" 10.4# "E" PAC D.P. - CONT TO RIH WITH 3 1/" 15.5 "S" IF D.P. - WORK THREW ISOLATION PACKERS AT 3832 & 4225 (CBT 03/01/90) - WORK DOWN TO BTM ISOLATION PACKER AT 4550 (CBT 03/01/90) - DID NOT SEE ANY RESTRICTION - ROTATE SLOWLY THREW PACKER & TAIL ASSEMBLY 3times - CONT RIH AND TAG AT 4793 POH LAYING DOWN 3 1/2" & 2 7/8" D.P. - CLEAR FLOOR - CHANGE TOP PIPE RAMS TO 4 1/2" ' RIG UP HES .125 SLICK LINE UNIT AND LUBRACATIOR ' MAKE UP PLUG FOR THE "X" PROFILES IN THE ISOLATION PACKERS , LEFT THE PACKING AND BACK UP RINGS OFF OF THE TOOL MAX OD = 4.53 - COULD NOT GET PAST 4573wLm - TRIP OUT DROP KNUKLE JNT & DOGS - RIH TO 4765w[m - TRIP AND RE-INSTALL DOGS - RIH TO 4765 THIS IS BELOW BTM ISOLATION PACKER - TIRP OUT WITH SLICK LINE AND RIG DOWN SAME RIH WITH 4 1/2" TUBING TO DISPLACE COMPLETION FLUID FOR UNDERBALANCE - 70Bb[ MESURED OUT AT THIS TIME - RIG TO BLOW DOWN STACK FOR ADDTIONAL DISPLACEMENT - DISPLACE A TOTAL OF 80Bb[ FROM WELL BORE ' UNOCAL ~,, Unocal Corporation Detailed Activity Report UNOEAL 11 P6 23 3.50 20:30 00:00 5478.0 POH LAYING DOWN 4 1/2" TUBING AT 2400hrs 9/14/96 11 P6 15F 1.50 00:00 01:30 5478.0 CONT LAYING DOWN 4 1/2" TUBING - CLEAR 11 P9 14A 4.50 01:30 06:00 5478.0 11 P9 14C 8.00 06:00 14:00 5478.0 11 P6 6F 5.00 14:00 19:00 5478.0 11 P13 30 5.00 19:00 00:00 5478.0 FLOOR - SET BPV NIPPLE DOWN BOP - 4.5" RAMS IN TOP - 5" RAMS IN BTM - GREASE ALL SEALING SURFACES BEFOR STUMPING BOP INSTALL SEAL FLANGE AND MASTER VALVE - PRESSURE TEST SAME TO 5000p$~ - PULL BPV - SET IN ACUATED VALVE , FLOW TEE , SWAB VALVE & TREE CAP - PRESSURE TEST SAME TO 250 PSI LOW & 5000ps~ HIGH LAY DOWN 5" D.P. INSTALL RISER AND PRESSURE TEST SAME - RIG UP SCHLUMBERGER - RIG FOR PERFORATING WORK - ASSIST PRODUCTION WITH FLOW LINE - CLEAN UP RIG Steel" '~d Platform Well M-5. 1996 workover 20 133# x-56 driven to 936' 10-3/4 55#, N-80 X/O @ 511' 16 75# J-55 / N-80 1440' 437' Completion: 74' FMC 6 ID Hanger 76' X/O 7 29# crossover 79' 3' 7 29# space out pup jnt 83' 8 jnts 7 29# L-80 ABSTL 426' X/O 729# TO 726# ABSTL HALL[BURTON TOP SUB HAL. CP-2 TRSV #78~00-390 HALLIBURTON BTM SUB X/O 7 26# TO 7 29# ABSTL 456' 49 jnts 7 29# L-80 ABSTL 2563' BAKER SEAL ASSEMBLY #297-55- 0075 WITH 4.73' OF 6' SEALS STABBED CTC External Casing Packer @ 1,998' 13-3/8 61/68# K-55 2635' RECEIVED t,,lOV 2 5 9'f ,qa~ka 011 & 6~ 8onm Cmmmi~0n An0h0rage 4,856' Cmt Sqz Perf 4,858' 5,308' Cmt Sqz Perf 5,310' 9-5/8 47# S-95 BTC 511'-5,562' C-1 Sand D-1 Sand D-2 Sand 2,565' 3,832' 4,225' I4,550 Baker ZXP [nr Pkr w/ 6' ext, HMC [nr Hngr, 27 jnts ? 29 # casing, FLoat coLLar (38073, 15' perforated 7 29# pup (38093, 15' 7 29# cmt filled pup (drilled out), 15' 7 29# pup joint, 7 to 5-1/2 crossover (38403, EBH-22 anchor assembly @ 3841' Liner cemented w/ 225 sx. Baker 9-5/8 x 6 FB-1Pkr, 10' 5.5 pup, X- nipple (4.562), 10' 5.5 pup, WLEG. Nipple @ 3,845' & WLEG @ 3,857'. Baker 9-5/8 x 6 FB-1Pkr, 10' 5.5 pup, X- nipple (4.562), 10' 5.5 pup, WLEG. Nipple @ 4,238' & WLEG @ 4,250' Baker 9-5/8 x 6 FB-1Pkr, 10' 5.5 pup, X- nipple (4.562), 10' 5.5 pup, WLEG. Nipple @ 4,563' & WLEG @ 4,575'. D-3B Sand 4,779' C-1 D-1 2 OTIS BWH Perma-Drit[ Pkr w/lO' SBE, MO Ext, X/O to 4.5 Butt Tbg; 10' 4.5 tub pup, Otis X nipple (3.813), 7' 4.5 pup. TBG Tail was cut off @ 4,822' using a jet cutter on 3/21/90. D'3B D'6 Perforations: DIL 3,893' - 3,920' 27' 3.67HC 5 spf 72° 9/96 4,292' - 4,412' 120' 3.67HC 5 spf 72° 9/96 D- 4,662' - 4,708' 46' 3.67HC 5 spf 72° 9/96 <D-3b and D6 sands Isolated with Baker NPR Plug> 4,864' - 4,914' 50' 3.37HC 6 spf 60° 3/90 5,302' - 5,372' 70' 3.37HC 6 spf 60° 3/90 Top of Fish @ 5,376' DIL Top of Fit[ @ 5,381' 3/90 PBTD @ s,478, I\TD @ 5,600' DRAWN BY: SSL- 11/96 Unocal Energy Resources Division Unocal Corporation ~ 909 West 9th Avenue, P.£ ,x 196247 Anchorage, Alaska 99519-~.~47 Telephone (907) 263-7813 UNOCAL Gary A. Orr Senior Petroleum Engineer October 7, 1996 Mr. Jack Hart; Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hart: Unocal has finished drilling Well M-9 and recompleting Well M-5 on the Steelhead Platform in the McArthur River Field, Grayling Gas Sands Pool. Please find attached Gas Well Open Flow Potential Test Reports for Well M-9 (A2, A3, and A5 sands commingled) and for Well M-5 (D2 sand and D2, D1, C1 sand commingled). Please note that a large portion of the data requested on Form 10-421 is not provided. Due to the automation that exists on the Steelhead Platform, the recording of this information was not needed to get accurate flow measurements· The computerized system is programmed and calibrated to provide accurate flow measurements. Pressures for the buildup and step-rate test are recorded tubing pressures for Well M-9. For the test of the D2 sand in Well M-5 the buildup pressure was recorded using downhole pressure gauges· Pressures for the four flow periods for the D2 sand are surface recorded tubing pressures. For the buildup and step-rate test in Well M-5 for the D2, D1, C1 commingled test, all pressures were recorded using downhole pressure gauges. If you have any questions concerning this work, please feel free to call me at (907) 263- 7813. Sincerely, · Orr , rCr-IVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL [~ D1, D2,C1 SANDS ANNUAL D SPECIAL D lb. STABIUZED ~ NON STABILIZED MULTIPOINT ~ CONSTANT TIME OTHER ISOCHRONAL D D D 2. Name of Operator 3. Address 4. Location of Well UNOCAL PO Box 190247, Anchorage, AK 99519-0247 1037' FNL, 598 FWL, SEC 33, T9N-R13W-SM 5. Elevation in Feet (indicate KB, DF etc. 16.Lease Designation and Serial Number 160 I ADL 18730 12. Completion Date 113. Total Depth 114. Plugback T.D. RECOMPLETION 9/15-22/96 I 5600 I 5478 16. Casing Size Weight per foot, lb. I.D. in inches Set at ft. 9-5/8 47 8.681 5562 17. Tubing Size Weight per foot, lb. I.D. in inches Set at ft. 7" 29 6.189 3832 18. Packer set at ff. !19. I 3832' GOR cf/bbl 20. APl Liquid Hydrocarbons 22. Producing thru: Reservoir Temp. °F Tbg. [~ Csg. D 99.6 23. Length of flow channel (L) I Verticle Depth (H) 4240' I 4183.57 24. Flow Data I Prover Choke I Line X Orifice Pressure Diff. i°' !size(in') size(in') psig hw· 7. Permit No. 89-133 8. APl Number 50- 733-20413 9. Unit or Lease Name TRADING BAY UNIT 10. Well Number M-5 11. Field and Pool MRF-GGS 15. Type Completion (Describe) PERFORATION Perorations: From To 21. 4662 4708 4292 4412 3892 3920 Specific Gravity Rowing fluid (G) Mean Annual Temp.*F % CO2 .12 %H~S 0 Barometric Prasaue (Pa), pela Prover I Casing Data Meter run ITap8 Duration of Flow Hr. 2 2 NO. Basic Coefficient (24-Hour) Fb or Fp hwPm Pressure Pm Flow Temp. Factor Ft Gravity Factor F9 Super Comp. Factor Fpv Rate of Flow Q, Mcfd 29154 45500 57100 63000 Form 10-421 Rev. 7-1-80 Temperature T 559.6 559.6 559.6 559.6 CONTINUED ON REVERSESIDE ;ritical Pressure Critical Temperature for Separator Gas 69 IV I) for Flowing Fluid G OCT O 8 Submit in dupllcale A!ask,?. Oil & {~as Cons. Cgmm[3o~ol~ Pc Pc~ w 1152.85 P¢ 1329063 NO. Pt Pt~ Pcb-Pt~ PW Pw; PcZ-P~ Ps Ps~ Pf~-Pe~ 1. 914.65 1133.45 1284709 44354 2. 864.65 1126.05 1267989 61074 3. 814.65 1122.85 1260792 68271 , 4. 764.65 1120.55 1255632 73431 ,, , 25. AOF (mCFD) 1,140,000 n 1.545 Remarks: Assumed N= 1 for calculating AOF All pressures were recorded with downhole guages. I hereby certify tha~the foregoing is true and correct to the beet of my knowledge. Signed ,j~. '~1~ _/~.~.~, , Title Senior Petroleum Engineer__ Date 9/26/96 AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd "-~' hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = -V/ 1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ration, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back- pressure equation, dimensionless Field barometric, pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dirnensionless Flowing pressure at vertical depth H, psia Static column wellhead pressure corresponding to Pt, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT ,a. TEST= ,.,~AL E! tb. STAS,.ZEO E! .O. ST~B,UZED E! o-2 ~..u~L D MULT, PO,.T El CO.ST~.,T,.E D SPECIA~ E! OT.ER ..... ISOC.RON~L ,,, 2. Name of O~rator 7. Permit No. UNOCAL 89-133 3. Address 8. APl Numar PO Box 190247, Anchorage, AK 995] 9-0247 50- 733-2~13 4. Loc~ion of Well 9. Unit or Lease N~e TRADING BAY UNIT . 10. Well Numar 1037' FNL, 598 ~L, SEC 33, T9N-R13W-SM M-5 11. Field and P~I MRF-GGS 5. Elevation in F~t (indi~te KB, DF etc. 16. Lease ~signation a~'rial Numar 160 ....i ADL 18730 ,I , RECOMPLETION 9/15/96 5600 5478 PERFORATION 16. Casing size ' ' ' Weight ~r foot, lb. ' I.D. in inches Set at ff. Pedorati~s: From To ' ' 9-5/8 47 8.681 5562 4662 4708 ~'7. Tu~ing Size Weight ~r foot, lb. I.D. in inches Set at ff. 7' 29 6.189 3832 ' 18~ Packer set at ff. ~9. GOR ~bl ~20. APl Liquid Hydr~rbons 21. S~cific G~av~ Fl~ing fluid (G) I I 3832' 22.' Pr~ucing thru: Resewoir T~mp. OF M~n Annual Tamp. OF ' ' Baro~rlc P~s~ (Pa), psis ' ' 4~50 , , 4518.205 , , A2 :92 0 , ,~,~., . .. F~ow ~,t, . ,,~,g ~,t, ~'~"g ~'~ Prover Choke Duration ~ ,~ne X Orifice Pr~sure Diff. Tamp Pressure Tamp Pr~sum T~p Flow No. ~Size (in,) Size (in,) psig hw "F psig "F psig "F Hr. , , 1. 900 .5 , , , , ,,, 2. 850 .5 3. 800 .5 , , , 4. 750 ,5 , ' , , , , , , , ,, , ,,, , , I Basic C~.icient I Flow Temp. ! G~ I Suer Co~. -----~~pm' Pressure Factor FaVor FaVor Rate of Flow (2~Hour) No. , ,Fb or Fp Pm Ft F~ Fpv Q, Mcfd 1. 7 ..... 2. , ,, , 3. 11.7 4. , ..... ,, , , ~4.5 5. , , , , .., f~ ~pa~or for Fl~wing Pr Tem~ture Tr Z Gas Fluid No. , , T ..... , , , , G~ G 567 .908 .56 1. , . , ,,,, , . , , 2. 567 ..... .91 ~5 .... , . , ~. 567 .917 Critical Pre.urn 4. ' ' 567 .9215' :~riacal +em~ratUre ,, Form 10-421 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Or'¥:_,T 0 8 '189S Submit in duplicate Alao~ka Oil & C~a,s Cons. Commission PC:' Pf Pf~ NO. Pt ~;~ Pt2 pcS'Pta ~ ~..r ~ pca-pw2 ~S Paa Pf;-Paa 1. 914.65 82:9'3 ' ' ' 997.58 995166 352871 2. 864.65 ................ 77'.'94 ' ' ' 942.'59 888476 459561 3. 814.65 ..... 72.99 ..... 887.64 787904 ' ' '5601~2 ..... 4. ' 764.~' 68.10 ' ' 832.75 693473 654564 5. ,, , , , ,, , 25. AOF (mCFD) 33,276 n 1.157 Remarks: Shut-in reservoir pressure was measured with downhold gauges, Pw= hydrostatic pressure of gas column at flowing tubing pressure. I hereby certify that t. he foregoing is true and correct to the best of my knowledge. Signed ~.~,~_ '~v~ ~v,'~_ ~ Title Senior Petroleum Engineer Date 9/26/96 AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd --V/ hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = -V/ 1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ration, cu. ft. of gas (14.65 psis and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back- pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psis Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Static column wellhead pressure corresponding to Pt, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil COmpact Commission, Oklahoma City, Oklahoma. Form 10-421 iVIEMORANDUI , TO: David Johns~, Chairmar~~ of Alaska Alaska Oil and Gas Conservation Commission DATE: September 9, 1996 THRU: Blair Wondzeil, ~,~ FILE NO: au7kiidd.doc P. I. Supervisor Chuck Scheve, Petroleum Inspector FROM: SUBJECT: BOPE Test Steelhead Platform Well M-5 PTD# 96-180 89"t ~3 Monday, September 9, 1996: I traveled to UNOCAL's Steelhead Platform and witnessed a BOPE test on Well M-5. The BOPE test report is attached for reference. I arrived on the platform at 7 PM on the previous day and rig up was underway. A walk-through was completed with drilling Forman Evan Harness and I found the rig and platform to be in excellent condition. The BOPE test began at 1:00 AM and lasted for 5 hours. There were no failures although the accumulator system is marginal. The 1200 PSI After Closure barely meets our requirements and the 4 minute 15 second recharge time, though excessive, is an improvement over previous tests. The problem appears to be the excess volume required to fill and pressurize the lines to the other three legs of the platform. I discussed the accumulator system with Mr. Harness and found he had already begun investigating possible solutions for the systems deficiency. Summary: I witnessed a BOPE test on UNOCAL's Steelhead Platform. The test lasted 5 hours and there were no failures. Attachment: au7kiidd.xIs X Unclassified STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg:___._. Workover: X ..... DATE: g/9/96 Drlg Contractor: Pool Rig No. SHP PTD # 96-180 Rig Ph.# 776-6833 , . , Operator: UNOCAL Rep.: , Evan Ham, ess Well Name: M-5 Rig Rep.: Tom Covington Casing Size: g 5/8 Set @ 5,478 Location: Sec. 33 T. gN R. 13W Meridian Test: Initial X Weekly ..... Other___._ Seward Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F LocafionGen.: OK WellSign Yes UpperKelly/IBOP ~ I 250/3,000 i~. PI l Housekeeping: OK' (Gen) Drl. Rig oK ' Lower Kelly / IBOP ...... 1 '250/3,000 P PTD On Location ' ~ Hazard Sec. Yes Ball Type ~ ~ 2~0/3,000" P Standing Order Post~i ' '...yes .. ' .... Inside BOP .' ~. 250/3,000 ~ 'P BOP STACK: Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams 1 Blind Rams Choke Ln. Valves HCR Valves 1 Kill Line Valves 2 Check Valve N/A , , Quan. Test Press. ....... 250/3,,000. 25o/3,ooo 2, ox3,o,oo , 25,0/3,o0o 250/3,000 2,50/3,000 250/3,000 250/3,o00, P/F P CHOKE MANIFOLD: P No. Valves 12 ~ P . No. Flanges P Manual Chokes ~ P . Hydraulic Chokes .. 1 .I P Test Pressure 250/3,000 P 250/3,000 Functioned Functioned P/F ACCUMULATOR SYSTEM: System Pressure 3,000 ~ Pressure After Closure .... '1..~ 200. . .1 ' MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 40 'sec. Trip Tank OK OK System Pressure Attained ' 4" minutes ~ 15 ' sec. Pit Level Indicators OK "OK' Blind Switch Covers: Master: OK Rem0:te: ' OK Flow Indicator OK OK" Nitgn. Btrs: 8 Bottles ~, ' Meth Gas Detector OK OK 2050 Averaf;~e Psig. H2S Gas Detector OK "'O/~ ' , , , ,,, Number of Failures: 0 ,Test Time: 5.0 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within ~days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office ac: 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 I I I I . I I I [ I II 11 [ II. I III I I I I I I II I I II I II I r III REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector FI-021L (Rev. 12/94) STATE WITNESS REQUIRED7 YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: I I AU7KIIDD.XLS Chuck Scheve - ~ STATE OF ALASKA ALAS~ C,,.. AND GAS CONSERVATION ,.,OMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: , Alter casing: Repair well: Plugging: Time extension: Stimulate: ~ Change approved program: Pull tubing: Variance: Perforate: Other: Workover 2. Name of Operator UNOCAL 3. Address PO Box 190247 Anchorage, AK 9.~519-0247 5. Type of wal: Development: X Exploratory: Stratigraphic: Service: 4. Location of well at surface 1,037' FNL, 598 FWI_, Sec. 33, 9N-13W-SM At top of productive interval 1,383' FNL, 1,181' FEL Sec. 33, 9N-13W-SM At total depth 1,634 FNL, 2,479' FEL Sec. 33, 9N-13W-SM 6. Datum elevation (DF or KB) 160' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number M-5 9. Permit number 89-133 10. APl number 50- 733-20413 11. Field/Pool MRF- GGS 12. Present well condition summary Total depth: measured true vertical 5,600' feet 5,274' feet Effective depth: measured 6,478' feet true vertical 5,179' feet Plugs (meas4zed) Junk (measured) Casing Length Size Cemented Structural Conductor 936' 20" 3666sx Surface 1,440' 16" 1300sx Intermediate 2,636' 13.3/8" 1900sx Production 611' 10-3/4" 1220sx Production 5,051' 9-5/8" Perforation depth: measured D-3 4864' - 4934' & D-6 5302' - 5372' true vertical D-3 4691' - 4747' & D-6 5040' - $095' Tubing (size, grade, and measured depth) 4-1/2" 12.6#, 4,780' Packers and SSSV (type and measured depth) OTIS Permanent packer ~} 4766' & OTIS SCSSV (~ 418' ORIGINAL Measured depth True vertical depth 936 936 1440 1440 2636 2636 511 611 511-5662' RECEIVE'D""' AUG 5 0 1996 Naska 0il & Gas Cons. commission Anchorage 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: X ,, 14. 15. Status of well classification as: Estimated date for commencing operation 9/711996 16. If proposal well verbally approved: Name of approver Date approved Oil: Gas: X Suspended: ,, ,,, Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ~ ~-~ ~k Ov~.. Title: Drilling Manager Date: 8/2711996 FOR COMMISSION USE ONLY Conditions of approval: NolJfy Commission so representative may witness Plug integrity ~(- BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- ~//:C) 7 ,, . . lc>- ~ IApproval No~/~ _, , Approved by order of the Commissioner Original Signed By David W. Johnston Form 10-403 Rev 06/15/88 Approved Copy Returned Commissioner Date SUBMIT IN TRIPLICATE M-5 Workover Procedure. 8/27/96 - 2:02 PM Page- 1 PROPOSED WORKOVER AND RECOMPLETION STEELHEAD M-5 It is proposed to workover and recomplete Steelhead well M-5. The well is presently a single completion with perforations in the D-3B and D-6. It is intended that the existing completion interval will be preserved by placing a plug in the tailpipe. Successively shallower intervals will be completed. The 3 proposed intervals are not planned with any sand control methods. PREP WELL FOR WORKOVER: Check and bleed pressure from 30" x 20", 20" x 16", and 16" x 10-3/4" casing annuli. Record pressures and build up information on mormng report. Bleed any pressure off 10-3/4" x 4-1/2" annulus. Fill and bleed casing annulus with 3% KCI. RU strip chart_ Pressure test annulus to 2,000 psi with water. Monitor pressure for 30 minutes. Bleed pressure to atmosphere. NOTE: SCSSV should be isolated with an auxiliary pressure source prior to commencing downhole operations to prevent wire cutting in the event of a Platform ESD. Take SCSSV off platform system and isolate with hand pump with control line pressure set at 3,800 psi. Fusible cap to be installed on master manumatic valve. 3. ~ RU slickline. Measure up 3.78" gauge ring. RIH gauging tubing to 4,806'. The tubing tail was cut offMarch 21, 1990 and no WLEG is present. POOH and RD slickline. NOTE: TRSV is out of round from initial completion. Maximum OD through SCSSV profile is 3.78". The setting of a standard X-lock isolation plug in the lower profile is not an option. Due to rig interference, additional prep work will be done with the rig. 4. j..~ Skid rig over ax:Il. RU hardlines to casing annulus and line out to choke manifold. Pressure test to 80% of working line pressure. RU electric line, lubricator, and BOPs. Pressure test to 2500 psi. Measure up isolation packer assembly on an E-4 setting tool. E-4 runmng tool to be pinned with Brass shear screws and Blue Loktite. l}O NOT USE BRASS SHEAR STOCK. RIH and set assembly in tailpipe assembly at 4,810' between X-nipple and MO extension. Do not nm packer or setting tool out tubing tail. POOH. Bleed tubing pressure to 100 psi to ensure plug is holding. 6. Monitor for pressure build up. Fill short string with FIW. Pressure short string to 2500 psi. · l/ Bleed pressure back to 750 psi. . RU E-Line unit, lubricator, and BOPs. Pressure test to 2500 psi. MU 5' of 1-9/16" 4 spf tubing puncher. Record pressure and RIH Perforate_the~tub~ t~r70~. Monitor tubin§ pressure for communication. POOH with tubing punch anc~,.,a~ Reshoot interml ff the tubing is not communicating to the annulus. RD E-line. AUG Anchorage M-~ Workover Procedure 8/27/96 - 2:02 PM Page - 2 Circulate down 10-3/4" x 4-1/2" annulus taking returns to production to clear any residual gas from tubing. Circulate down tubing to clear residual gas from casing. Monitor well for 20 minutes. 10. RU BPV lubricator. Set a 4-1/2" nominal Cameron Type "IF' BPV in profile. RD Lubricator. 12. ND production tree and towlines. Blind flange towlines per UNOCAL lock out tag procedure. Pull BPV and set two way check valve. Pressure test BOP high low to 2500 psi/250 psi. Pull two way check valx;e-. 13. Measure up 4-1/2 "EUE 8 md landing joint and engage hanger. Back out hanger hold down screws. PU hanger and unseat from seal assembly. Circulate bottoms up. Displace hole with 3% KC1 in filtered fluid. 14. POOH laying down 4-1/2" 12.6# buttress AB modified tubing. Stand back 40 stands for later use. Thread protectors to be installed and the pipe send to Tuboscope for inspection. Being a gas well completed in the GGS, a NORM survey will not be required. SCSSV and pups to be sent to Halliburton for inspection ofb~d-~'~§fii~te for refurbishment. 15. RU E-line umt with .39" cable. Measure up GR, CCL, and 8.25" gauge ring. RIH gauging casing. Pull a correlation log from 4,750' up to 3,250'. POOH with gauge ring. 16. Measure lower up isolation packer assembly noted below on an E-4 setting tool. RIH and set the top of the packer assembly at 4.550'. POOH with setting tool. Redress setting tool on second packer. 9-5/8" 47# Baker FB-1 permanent packer B-Guide crossover 10' of 5-1/2", 17# tubing pup joint 5-1/2" nominal (4.562" ID) X- nipple 10' of 5-1/2", 17# tubing pup joint Wire line Re-entry Guide 17. 18. Measure middle up isolation packer assembly noted below on redresses E-4 setting tool. RIH and set the top of the isolation packer at 4,225'. POOH with setting tool. Redress setting tool on third packer. 9-5/8" 47# Baker FB-1 permanent packer B-Guide crossover 10' of 5-1/2", 17# tubing pup joint 5-1/2" nominal (4.562" ID) X- nipple 10' of 5-1/2", 17# tubing pup joint Wire line Re-entry Guide Measure up upper isolation packer assembly noted below on redresses E-4 setting tool. RIH and set the top of the isolation packer at 3,832'. POOH with setting tool. RD E-Line. 9-5/8" 47# Baker FB-1 permanent packer B-Guide crossover 10' of 5-1/2", 17# tubing pup joint 5-1/2" nominal (4.562' ID) X- nipple 10' of 5-1/2", 17# tubing pup joint M-~ Workover Procedur.e 8/27/96 - 2:02 PM Page - 3 19. ? PU liner Wire line Re-entry Guide hanger assembly as noted below: Baker EBH-22 Anchor assembly dressed for 9-5/8" FB-1 packer 15' 7" 29# tubing pup joint Glass shear disk assembly set for 3,000 psi differential pressure 15' 7" 29# tubing pup joint filled with 20/40 sand 15' 7" 29# tubing pup joint punched with 6 ~ 3/4" holes per foot Baker Type I landing collar 27 joints of 7" 29# tubing with buttress connections Baker HMC liner hanger Baker ZXP liner top packer with RS nipple Baker HR setting w/Hydraulic Pusher Sleeve w/liner wiper plug installed 5-1/2" Drill pipe as required 20. Measure up Baker "TD" / Cementing head for top drive to 1 joint of DP and stand back in V door for use as necessary. 21. RIH with assembly on 5-1/2" drill pipe to 3,810'. Verify circulation after PU assembly. PU "TD" cementing head with 1 joint drill pipe. Verify circulation and latch into top packer set at 3,832'. CirCulate a mimmum of one hole volume (300 bbls) down tubing taking returns from annulus not exceeding 1800 psi at liner hanger. NOTE: "HR" Hydraulic Release Liner Setting Tool Specification Guide: Tensile Yield Strength: Right Hand Torsional Yield Strength Rating: Internal Pressure Rating: External Pressure Rating" Pressure required to actuate Hydraulic Cylinder: LH Torque Required to start emergency Release Proc: 597,000 lbs 30,000 ft-lbs 10,000 psi 9,000 psi 1,200 psi / screw 2,200 ft-lbs / shear 22. Mix and pump 200 sx 15.8 ppg, Class "G" cement with additives for a 4 hour set and compressive strength of 2,000 psi in 14 hours. Pump cement at 5 BPM not exceeding 1,800 psi at the liner hanger. 23. Drop D.P. pump down plug and displace with FIW. Check indicator on cementing head to verify plug releases. Displace cement. Should see slight pressure increase as PDP picks up liner wiper plug from running tool. 24. Bump plugs in landing collar and pressure up to 2,000 psi to set liner hanger. Slack off 20,000 lbs + weight of liner assembly while holding pressure the 2,000 psi on the DP. 25. 26. Pressure DP up to 3,000 psi to set ZXP liner top packer. Pressure up to 3,800 psi (+/-) to release "HR" Liner Setting Tool. Bleed pressure to -0- psi. 27. ~-Pick up until seals of nmmng tool release from liner. Circulate residual cement OOH. POOH. 28. PU 6" junk mill. TIH and tag TOC. Drill out cement, Type I landing collar, and cement down to the sand on the glass disk. Circulate HI-VIS sweeps as required to clean hole. Break up glass disk by setting weight down. TIH additional 15' and tag reduced ID at Tubing anchor. POOH. M-5 Workover Procedure. 8/27/96 - 2:02 PM Page ~ 4 29. PU Baker Tie Back Extension Cleanout Mill and TIH to top of liner at 2,635'. Rotate between ~60 to 70 RPM while circulating 6 to 8 BPM. Make 3 to 5 passes and set down 4,000 to 6,000 #'s on top of sleeve to dress off. POOH. 30. PU 2-7/8" mule shoe, 1250' 2-7/8" PAC DP, X/O to 3-1/2" IF drill pipe, 3-1/2" DP. RIH to lower most ~Solation packer assembly at 4,765'. Circulate down casing taking returns from DP. Filter all fluids being pump to 10 microns. Continue circulating until return fluid has no visible sohds setting after 30 minutes. Work DP down to top of isolation packer assembly at 4,810' while circulating. POH to 2,800'. 31. With DP at 2,800', pump 200 bbls filter water with Tretolite's CRW-132 corrosion inhibitor ~ mixed at 2% per volume ( 165 gallons). POH with DP. 32. PU completion assembly consisting of Baker Bullet seal assembly with 15 pup joint, 51 joints of 7" 29# tubing, HES 7" SCSSV TRFV w/15' pup joints w/continuos 3/16" stainless steel control line, and 7" tubing as required (8 Joints). RIH with assembly torqueing connections to 5,000 fl- lbs. Control line to be banded 2 X's on pup joint on SCSSV and 1 per joint to surface. Maintain 5,000 psi on control line while RIH with SCSSV. 33. Land bullet seal assembly in tie back extension sleeve. PU and space out for neutral string weight with seals fully engaged. Make up hanger assembly. Make 3 wraps around 7" tubing with control line prior to making up control line to the hanger. 34. _.Make up landing joint in top of hanger and tie in control line to the top of the hanger. Pressure control line to 5,000 psi to open valve. RIH and land completion. Engage hold down screws. 35. Pres~e t~.tU_ bing, Hanger body seals, and bullet seal assembly to 2,500 psi for 10 minutes. Monitor control line pressure and bleed off as required to not exceed 5,800 psi while pressure testing tubing. Monitor casing wing valve for commumcation. 36. ~- RU slickline. Measure up 4.5" Gauge ring. RIH and drift completion assembly to 4,765'. POH and RD slickline. 37. Back off landing joint. PU and RIH with 4-1/2" completion string previously laid down with a bull plug installed to displace fluid. Monitor pit gain and RIH displacing a total of 70 bbls completion fluid. POH with 4-1/2" tubing laying down singles. 38. Bleed off control line pressure and allow SCSSV to close. Set back pressure valve. Cut the ' control line. 39. ND BOP's and riser. Cover the riser to prevent debris from falling in the well while ND BOP's. NLI adapter flange and bottom master valve (Previously pressure tested in Cameron shop). Leave lower master valve slightly open to communicate pressure. 40. ~ Pressure test adapter flange ring gasket, body seal, and lower neck seals to 5,000 psi and hold for 10 minutes. Pressure upper neck seals by pressuring SCSSV control line to 5,000 psi. Close master valve. NU and test reminder of tree. Pull BPV. 41. ,- Release Drilling rig. 42. NIJ towlines and pressure test to 3,000 psi. M-5 Workover Procedure 8/27/96 - 2:02 PM Page ~ 5 43. 44. RU E-Line umt, lubricator, and BOPs. Pressure test to 2500 psi. Establish underbalance and perforate the following interval with a 3.67" Hollow carrier, 5 SPF, 72 degree phase, loaded with 34J UJ HMX charges. D-2 ) 4,663' - 4,710' 47' Estimated SBHP - 1,200 psi ? Flow well to flare tg~_~_o~_d?a~_[~er.~ .an.~.!ine out to low pres. sgre tr~i9,. Limit draw down to 20% at -'" s.agd face. Minimum unloading rate for 7" tubing is 8.0 MMSCFD. RU two pen recorder on well to monitor pressures while unloading. 45. Rig aside E-Line. RU slickline on E-Line lubricator. Pressure test to 2,500 psi. Measure up ..... · ~E.~DAT extended memory electronic gauges on the bottom of HES's slickline. Program gauges per Onsite PE's recommendation to capture data. RIH and hang pressure bombs at 4,650' ELM. Perform the following flow test: ' -4 hr flow with 100 psi Ap at sand face ~ -2 hour surface shut-in --2 hour flow with 150 psi Ap at sand face --2 hour flow with 200 psi Ap at sand face --2 hour flow with 250 psi Ap at sand face 46. SI well and POOH with data. Download and verify data's quality. Rerun test if required. Else, Measure up PX type plug and prong. RIH and set 5.5" lock mandrell in X-nipple at. 4,565'. Set extended neck prong in lock mandrell. Bleed tubing pressure to 200 psi and monitor for pressure build up. Ensure plug is holding. Rig aside slickline. 47. ~/Remove check valve from one towline and backflow gas into tubing charge tubing to 950 psi. 48. RU E-Line umt. Pressure test to 2500 psi. Establish underbalance and perforate the following ...... interval with a 3.67" Hollow carrier, 5 SPF, 72 degree phase, loaded with 34J UJ HMX charges. D-i') 4,293' - 4,455' 163' Estimated SBHP --- 1,200 psi 49. //Flow well to low pressure tram. Limit draw down to 10 % at sand face. 50. Rig aside E-Line. RU slickline on E-Line lubricator. Pressure test to 2,500 psi. Measure up PETREDAT extended memory electronic gauges on the bottom of HES's slickline. Program gauges per Onsite PE's recommendation to capture data. RIH and hang pressure bombs at 4,270' ELM. Perform the following flow test: -4 hr flow with 100 psi Ap at sand face --2 hour surface shut-in --2 hour flow with 150 psi Ap at sand face --2 hour flow with 200 psi Ap at sand face --2 hour flow with 250 psi Ap at sand face 51. SI well and POOH with data. Download and verify data's quality. Rerun test if required. Else, Measure up pulling tool dressed to recover PX prong set at 4,565'. Pull prong and POOH. RIH with GS pulling tool and recover lock mandrell. Redress plug and prong assembly. 52. .~Measure up PX type plug and prong. RIH and set 5.5" lock mandrell in X-nipple at 4,240'. Set extended neck prong in lock mandrell. Bleed tubing pressure to 200 psi and monitor for pressure build up. Ensure plug is holding. Rig aside slicldine. M-5 Workover Procedure 8/27/96 - 2:02 PM Page - 6 53. Remove check valve from one flowline and backflow gas into tubing charge tubing to 950 psi. 54. 55. RU E-Line unit, lubricator, and BOPs. Pressure test to 2500 psi. Establish underbalance and perforate the following imerval with a 3.67" Hollow career, 5 SPF, 72 degree phase, loaded with 34J US HMX charges. C-1 3,890' - 3,920' C-1/J~ 3,890' - 3,920' 30' Estimated SBHP - 1,200 psi Flow well to low pressure train. Limit draw down to 10 % at sand face. 56. Rig aside E-Line. RU slickline on E-Line lubricator. Pressure test to 2,500 psi. Measure up PETREDAT extended memo~ electronic gauges on the bottom of HES's slickline. Program gauges per Onsite PE's recommendation to capture data. RIH and hang pressure bombs at 3,875' ELM. Perform the following flow test: -4 hr flow with 100 psi Ap at sand face --2 hour surface shut-in --2 hour flow with 150 psi Ap at sand face --2 hour flow with 200 psi Ap at sand face --2 hour flow with 250 psi Ap at sand face 57. SI well and POOH with data. Download and verify dam's quality. Rerun test if required. Else, Measure up pulling tool dressed to recover PX prong set at 4,240'. Pull prong and POOH. RIH with GS pulling tool and recover lock mandrell. 58 .......Rig down E-line and Slickline. Return well to production group for additional step rate testing. 59. ~Ijesign any treatments as required for stimulation based on recovered data. Sheet1 !~ Connection I OD Req# QTYiRig[ Item Top I Bottom OD ID I Length From To floor to Hanger top ~ I 77 0 77 AD-1474 1 ! 16" x 7" OD tubing hanger, 17" butt AB mod (B) 17" butt AB mod (B) 16 6.2 1.5 77 78.5 AD-1514 1 i 7" 29//pup joint, pin x pin butt AB mod (P) 17" 29/I AB STL Pin 7 6.184: 4 78.5 82.5i AD-1514I 1 ! 7" 29~ Space out pup joints 29# AB STL Box [ 7" 29# AB STL Pin 7 6.184 30 82.5 112.5 AD-1514 8 ! 7" 29# tubing Avg length 42' 7" 29~ AB STL Box 7" 29# AB STL Pin 7 6.1841 336 112.5 448.5 AD-1514 1 i 7" Crossover Pup 7" 29~ AB STL Box 7" 26# AB STL Pin 7 6.1841 10 448.5 458.5 AD-1511 1 i HES 7" SCSSV TRFV 7" 26~ AB STL Box 7" 26~ AB STL Pin . 9.4 5.9631 11.66 458.5 470.16 AD-1514 1 ! 7" Crossover Pup 7" 26# AB STL Box 7" 29# AB STL Pin 7 6.184 10 470.16 480.16 AD-1514 51 ! 7" 29# tubing Avg length 42' 7" 29# AB STL Box i T" 29# AB STL Pin 7 6.184 2142 480.16 2622.16 AD-1514 1 7" 29# Pup Joint 7" 29//AB STL Box 7" 29~ AB STL Pin 7 6.184 51 2622.16 2627.16 AD-1480 1 Baker Bullet Seal Assembly 7" 29~ AB STL Box i 7.5 6.184 7.5 2627.16 2634.66 1 2634.66 2635.66 AD-1480 j Tie back Extension sleeve i 6 2635.66 2641.66 AD-1480 ! Baker "ZXP' liner top packer AD-1480 Baker "RS' nipple *~ 3 2641.66 2644.66 AD-1480 Baker "HMC" liner hanger i 3 2644.66 2647.66 AD-1513 27 7" 29# tubing Avg length 42' 7"29# Buttress Box 7"29# Buttress Pin i 7 6.164 1134 2647.66 3781.66 AD-1480 i Baker Type I Landing Collar 7" 29/l Buttress Box 7" 29// Buttress Pin i 7 6.184 2 3781.66 3783.66 AD-1513 1 !7"29/1 Perforated PuP Joint 7"291l Buttress Box 7"29# Buttress Pin i 7 6.184 15 3783.66 3798.66 AD-1513 I 7" 29// Pup Joint filled wi sand 7" 29~ Buttress Box 7" 29~ Buttress Pin , 7 6.184 15 3798.66 3813.66 AD-1515 Glass Shear Disk 7" 29~ Buttress Box 7" 29/I Buttress Pin i 8 6.184 1 3813.66 3814.66 AD-1513 i7" 29~ Pup Joint 7" 29~ Buttress Box ,7" 29/I Buttress Pin,i 7 6.184 15 3814.66 3829.66 AD-1515 i Baker Anchor w/check valve 7" 29/I Buttress Box ~ 4.875 2 3829.66 3831.66 AD-1515 !9-5/8" 47//Baker FB-1 PPKR NA Baker PKR THRD 3.4 3831.66 3835.06 AD-1515 B-guide Crossover Baker PKR THRD 5.5" 17# AB STL Box i 4.778 1.6 3835.06 3836.66 AD-1515 i 5-1/2"17# pup joint 5.5"17# AB STL Pin 5,5"17# AB STL Pini 5.5 4.778 10 3836.661 3846.66 AD-1515 15-1/2" nora "X" Profile nipple 5.5" 17# AB STL Box 5,5" 17# AB STL Pin I 6.11 4.562 1.7 3846.66! 3848.36 AD-1515 5-1/2"17# pup joint 5.5"17# AB STL BOx 5,5"17# AB STL Pin i 5.5 4.778 10 3848.36 3858.36 AD-1515 '5-1/2" WLEG ' 5.5" 17# AB STL BOxI 6.052 4.778 1 3858.36 3859.36 C-1 Perforations I 3890 3920 408267 ~ i 9-5/8" 47# Baker FB-1 PPKR NA Baker PKR THRD 3.4 4225 4228.4 4082671 i B-guide Crossover Baker PKR THRD AB STL BOx , 4.7781 1.6 4228.4 4230 4082671 j 5-1/2" 17# pup joint AB STL Pin AB STL Pin I 5.5 4.778 10 4230 4240 408267 5-1/2" nora "X- Profile nipple AB STL Box AB STL Pin 408267,, 5-1/2" 17# pup joint AB STL Box AB STL Pin I 6.11 4.562 1.7 4240 4241.7 ~ 5.5 4.778 10 4241.7 4251.71 408267 15-1/2" WLEG AB STL Box ' 6.0521 4.778 1 4251.7 4252.7 D-1 Perforations i 4293 4465 , 408267 9-5/8" 47# Baker FB-1 PPKR NA Baker PKR THRD ~ 3.4 4550 4553.4 408267 lB-guide Crossover Baker PKR THRD AB STL Box i 4.778 1.6 4553.4 4555 408267 5-1/2" 17# pup joint AB STL Pin AB STL Pin [ 5.5 4.778 10 4555 4565 408267 5-1/2" nora "X" Profile nipple AB STL Box AB STL Pin t 6.11 4.562 1.7 4565 4566.7 408267 5-1/2" 17# pup joint AB STL Box AB STL Pin~ 5.5 4.778 10 4566.7 4576.7 408267 15-1/2" WLEG AB STL Box I 6.052 4.778 1 4576.7 4577.7 D-2 Perforations I 4663 4710 i Top of existing Jewelry . 4765; Page1 RECEIVED Kill Line 16-314 0,000 " 1 PIl3e Rame Flow Line I ii L f Hydrtl 16-$/4° 5000 Dat Type GK Annuler Blir~l Reme C~c~ Vllve G&te Velve Gete Velve Gate Velve HCR Valve Ch;)ke Un( 16-8/4' 10,000 Slngiegate 16-314' 5000 Del Ricer STEELHEAD PLATFORM Preventer Schematic Ball Valve Wellhea~l STEELHEAD PLATFORM CHOKE MANIFOLD TO GAS B'I, JSTER TO DERRICK VENT TO SHALE SHAKERS CHOKE LINE SECTION AA ALL VALVE8 IN FLOW PATH ~.RE 3-1/16' 5000 PSI CAMERON GATE TYPE -, .. MUD --] DESANDER J ~ PIT : I PIT P~ P~1 - ~ ' ** 113 gbll Cep 10S Obl~ ~ep 100 I ~ 1H I~ C~ 113 Bb~ Cop ' I 11 gbh/~ 0.99 0-"-~ . ""-",.o,._, ,.,,.,.,, .... ,,,,v, ,,,..o. ,,,. ~., ~~lq' ' ~0''°''''''~ ~QL o~ o~ o ,.,,,,~ .: . ~ 320 Bblo - 'MIX PIT PILL PIT 0 0 0 0 , MUD RETURN DITCH , , J EQUALIZER AGITATOR MUD GUN STEELHEAD PL.~.TFORM MUD PIT LAYOUT Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOCAL ) Dale Haines Drilling Manager Tuesday, August 27, 1996 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzeil' Steelhead Platform Well M-5 UNOCAL is proposing to workover Steelhead Platform Well M-5 and complete the C-1, D-l, and D-2 series Grayling Gas Sands. Existing production from the D-3 and D-6 series sands will be temporarily isolated with a wireline retrievable isolation plug until the reservoir pressures near equilibrium. The attached procedure details the workover and completion of the zones to allow for future through tubing recompletions in the monobore well. If you have any questions, please contact the undersigned at 263-7660 or Dan Williamson at 263-7677. Sincerely, ' Dale Haines Drilling Manager DH/leg Unocal Energy Resources Di .n ~ ' 909 West 9th, P.O. BOX 1962,7 ................................. .......... Anchorage, AK 9951§-6247 . Teleohone (909) 276-7600 ~ .:.: . --,. _; , Fax (907) 263-7828 UNOCAL Debra Childers Clerk DATA TRANSMITTAL 96-13 June 8, 1996 -- u To: Howard Oakland 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchoraoe, AK 99519-6247 Unocal Transmitting the following items. ,-.0'4'I Granite Point / Anna-21 fil~ blackline"' Completion Record 4/01/96 --07? Granite Point / Anna-26 f'flm / blackline ~ Tubing Packer Setting Record 4/20/96 -~.t~ Granite Point / Anna-36 ~ blackline-' Completion'Record 5/20/96 - l,f¢ Granite Point / 42-23 RDftl'm / blackline? Perforating Depth Control 2/17/96 ' 0~.~3- Trading Bay Unit K-26 RD film,-/'blackline~-' Main Pass (Collar Locator) 3/23/96 i.~._.~.~ Trading Bay Unit M-5 ~ / blackline-..'Completion Record 2/14/96 Trading Bay Unit M-25 ~ t blackline,..----~ompletion Record 4/24/96 -0~____Trading Bay Unit M-25 ~l~fi"/blackline~-."Completion Record 4~30~96 Trading Bay Unit G-21 ¢ib'r~..blackline,.--- CCL)Gamma Ray 4/03/96 Trading Bay Unit. G-21 f~-¢ blackline.." Cement Retainer 4/08/96 Trading Bay Unit G-21 4frm / blackline.-"Completion Record 4/13/96 /4~ Trading Bay Unit G-21 ..~ / blacklineu-- Completion Record 4/18/96 Trading Bay Unit G-21 ~ / blackline--' Completion Record 4/22/96 Trading Bay Unit G-21 d"ilm / blackline~..-. Completion Record t 4/25/96 Trading Bay Unit G-21 ,,, .... ~- ......... ~. ...... , ~. _, ,~.:ge..--o~F4/I 5196 Trading Sa:/Unit G-21 ~rnrn~ r~ay/, ,:~, ,r,=, ~ur~ 4/10/96 Tradin.g Bay Unit G-21 ~.if"r~ / blackline.-' Tubing Cutter 4/08/96 . -,.,,,,_, .,-,I-~ ~c u.., ~ffl --H d, rl'm / blackline,.- Completion Record 5/17/96 , ,RECEIVED Please ackn°wle,~ pPt bylcigning a~returning one copy of this transmittal or FAX to (907) 263-7828 Receh:~.d hy: ~~ t Date: , , ~ ~1 & ~ ~. ~~n Unocal Corporation Oil Ex Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL March 4, 1996 Alaska Mr. David Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Commissioner Johnston: Re: Steelhead Platform -Well M-5 APl Number 50-733-20413-00 This is to inform you that on February 15, 1996, Unocal perforated the following intervals in Well M-5, Trading Bay Unit. BENCH TOP (MD) BOTTOM (MD) FEET D-3B 4864 4934 70 D-6 5252 5302 50 Total 120 Attachment Very truly yours~, G. Russell Schmidt Drilling Manager ~PR 0 5 19~I~ AI;~ska {)il & Gas OOns. commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELl_ OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: x Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: x 160' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Trading Bay Unit 4. Location of well at surface 8. Well number top productive ORIGINAL M-5 At of interval 9. Permit number/approval number 89-133 At effective depth 10. APl number 50- 733-20413-00 At total depth 11. Field/Pool McArthur River Field/Grayling Gas 12. Present well condition summary Total depth: measured 5600' feet Plugs (measured) true vertical 5274' feet Effective depth: measured 5478' feet Junk (measured) true vertical 5179' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 20" 936' 936' Surface 16" 1440 1440' Intermediate 13-3/8" 2635' 2635' Production 9-5/8" 511 511 Liner Perforation depth: measured 4864'-4934'; 5252'-5372' true vertical 4691 '-4747'; 4974'-5095' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 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 OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2/11/96 8945 0.2 20 745 Subsequent to operation 2/17/96 7656 ' 2.3 20 749 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: G. Russell Schmidt Title: Drilling Manager Form 10-404 Rev 06/15/88 '~ SUBMIT IN DUPLICATE ' ' STATE OF ALASKA --' 0 ~ i 6 IN A~ ' ~ . ALASK. DIL AND GAS CONSERVATION ~OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS~ SUSPENDED [] ABANDONED [] SERVICE [] "- ........ 7. Permit Number 2. Name of Op_erato, r . UNOCAL (Marathon Oil Co. Sub-operator) ~ 89-133 · ~',~;l.T_.~ 8. APl Number 3. Address P. 0. Box 190247 Anchorage, AK 99519 s0- 733-20413 4. Location of well at surface Leg BZ, Cond. Stee]head P]atfoFt~~· - 2 9. Unit or Lease Name 1,037' FNL, 598 FWL, Sec. 33 9N-13W-SM _~ ~_ Trading Bay Unit ~ 10. Well Number At Top Producing Interval 1,383' FNL, 1,181' FEL, Sec. 33 9N-13W-SM ~~ M-5 1,634' FNL, ' F , Sec. 33 9N-13W-SM McArthur River Field 5. Elevation in feet (indicate KB~DF, etc.) I 6. Lease Designation and Serial No. Gray] ing Gas Sands Pool 160' KB above MSLI ADL 18730 12. Da~e/~?¢~I 13. Date T.D. Reachedz/25/90 14. Date C~,mo., Susp. or Aband.3/22/90 115' Water Depth' if °ffsh°rel87' feet MS L I16' N°' °f C°mplet'°nsl 17. Total Depth (MD+TVD)18.PlugBackDepth(MD+TVD)19. DirectionalSurveYE,600. & 5,274' 5,478' & 5,179' YES~( NO[-1 I 20'DepthwhereSSSVset I 21';hickness°fPermafr°st427' feetMD N A 22. Type Electric or Other Logs Run DIL-GR, LDT-CNL-GR, SHDT, GR-CBT-CET-GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SlZEiWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" t33~ X-b~ O' 936' 26" 3655 sx cat N/A 16" 75#J-55/N-80 O' 1,440' 22" 1300 sx cmt N/A 3-3/8" 51/68# K-55 O' 2,635' 17.5" 1900 sx cmt N/A 0-3/4" 55# N-80 O' 511' 12.25" 1220 sx cmt N/A 9-5/8" 47# S-95 5TI' 5,562' N/A 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACi(ER SET (MD) D-3B 4864'-4934' MD 4691'-4747' TVD 4.5" 4,780-' 4,764 D-6 5302'-5372' MD 50.40'-§095' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. A11 perforations were 6 SPH 60 phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 3/21/90 IFlowing Gas Well I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MrG~F WATER-BBL CHOKE SIZE IGAS-OIL RATIO 3/22/90 24 TESTPERIOD ~ NA 20.967.. ,~ NA] NA . Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS,AAC-¢-¢4~ '~V~,TER-BBL OIL GRAVITY-APl (corr) Press. 1789 60 24-HOUR RATE I~ NA 20. 967 0 NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. REEEIVED None JUN - 6 1990 Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME Tyonek FM A-Zone B-Zone C-Zone D-Zone IVI EAS. DEPTH 2,594' 3,139I 3,843I 4,286' TRUE VERT. DEPTH 2,594' 3,138' 3,822' 4,183 ' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS ~ttach #!, Summary of Daily Operations; Attach #2, Current Wellbore Diagram; Attach #3, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Directional Survey Signed 0 I[~i,~,..~ ~ . ~) ~.,~:,~ L Title 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-5 Daily Wel 1 Summary Report 01/25/90 ACCEPTED RIG from reconstruction 0 00:00 hrs. on 1/25/90. NU diverter riser. 01/26/90 NU diverter. Hook up cuttings chute. 01/27/90 Fin NU diverter and functioning all equipment. BHA. PU 17-1/2" drlg assembly. 01/28/90 RIH w/ drlg assembly. Tag 0 451'. Drill 451'-755'. Lost returns. Spot LCM pill and regain same. Drld to 904'. Lost returns. Spot LCM pill and regain same. 01/29/90 Drill 904'-972'. CBU. Ran gyro single shot survey. POOH. RU electric line. Ran induction log and caliper 960'-480'. RD. RIH w/ UR and open hole from 17.5" to 26" from 451'-733'. 01/30/90 Fin UR 17.5" hole to 26" from 733' to 966' Made ST. Circ and cond mud. POOH. RU and ran 20" csg to 795'. Hit bridge. Started RU to circ. 01/31/90 Attempted to wash csg down past 795' w/o success. POOH w/ csg. Left two joints plus shoe in hole. RIH w/ spear and pulled fish free. POOH. Recovered 1004 of fish. RIH w/ bit and UR to 972'. Started CBU. 02/01/90 CBU. Made ST. Circ and cond mud. POOH. Ran 20" csg to 936'. RIH w/ tag in string and CBU. 02/02/90 Cmt'd 20" csg w/ 1950 sx cmt. Lost returns. No cmt to surface. Waited on cmt. Attempted to run top job string and could not get past wellhead. RU and pump into annulus. Offloaded cmt. Attempted to mix cmt w/o success. Trouble shoot surge can. RECEIVED JUN - 6 1990 Oil & Gas Cons. Commission Anchorage Daily Wel 1 Summary Steelhead Well M-5 Page 2 port 02/03/90 Placed 100 sx cmt in 20" x 30" annulus. RIH w/ bit. Attempted to test 20" csg w/o success. POOH. Retrieved wear bushing. Started PU 20" landing joints. 20" Casing Detail KB to top casing I jt 20", 133#, BTC, X-56 pup & csg hanger 1 jt 20", 133#, RL4S x BTC X-56 20 jt 20", 133#, RL4S X-56 Shoe 20", BTC weld-on From: 0.0' To: 80.1' 80.1' 82.65' 82.65' 120.27' 120.27' 933.49' 933.49' 935.74' 02/04/90 Made up 20" landing joints. Tested 20" csg to 500 psi. LD landing joints. Drld out 20" csg. Ran gyro survey. Drld from 972' to 1372'. 02/05/90 Drld 1372'-1450' Ran GR/DIL from 1442'-926'. UR 17.5" hole to 20" from 966'-1444'. Started running 16" auxiliary csg. 02/06/90 RIH w/ 16" csg. CO backup tongs. Cont RIH tag @ 1002'. Could not work deeper. POOH w/ 16" csg for cond trip. 02/07/90 RD csg tools. Found 20" UR had blown seals and sleeve. UR 936'-1296' to 22". 02/08/90 UR hole to 22" 1296'-1450'. ST. Circ and cond mud. RIH w/ 16" csg to 1440'. RU to cmt. 02/09/90 RIH w/ 5" stab-in string. Unable to sting in. POOH and modify stab-in sub. RIH stab in. Circ and cond. Mix and pump 850 sxs TLW lead w/ additives and 450 sxs class "G" tail w/ additives. Displace w/ mud. Contaminated cmt to surface after 283 bbls. CIP La 2200 hrs 2/8/90. POOH. WOC. RECEIVED JUN - 6 1990 Alaska Oil & Gas Col~s. ~,ummission Anchorage Daily Wel 1 Summary Steelhead Well M-5 Page 3 port 16" Casing Detail 1 jt 16", 75#, BTC pup & FMC Fluted UHA csg hanger i jt 16", 75#, BTC, K-55 i jt 16", 75#, STC x BTC X/O 20 jt 16", 75#, STC J-55 1 jt 16" 75#, 521 x 8rd STC X/O 14 jt 16'~, 75#, 521 N-80 1 jt 16" 75# BTC x Hydril 521 X/O Float Coilar ~TC i jt 16", 75#, BTC, K-55 Shoe 16", BTC From: 80.1' 82.37 123.49 129.79 766.11 770.34 1351.51 1391.55 1393.70 1437.84 To: 82.37' 123.49 129.79' 766.11 770.34 1351.51 1391.55 1393.70 1437.84 1439.84 02/10/90 WOC. ND diverter. RU to do 20" top job. 02/11/90 Pump 105 sx top job on 20" by 34" annulus. NU csg head and BOPs. 02/12/90 NU and test BOPs. 02/13/90 Fin testing 8OPE. RIH w/ drlg assembly. Tested csg to 1850 psi. CO cmt and drld 10' new formation to 1460'. Tested shoe to 14.0 ppg EMW. Drld to 1775'. 02/14/90 Drld 1775' to 2650'. Made ST to csg shoe. 02/15/90 CBU. POOH. Logged w/ GR-DIL 2638'-1433'. RIH w/ UR. UR to 17-1/2" 1440'-2245'. 02/16/90 UR 2245'-2397' to 17-1/2". Tripped for new UR. UR to 2248'. RU to run csg. 02/17/90 Running surface casing. Tagged @ 1395'. Unable to work past. POOH w/ casing. RIH w/underreammer and Ream 1350'- 2650'. CBU. RECEIVED JUN - 6 1990 Alaska Oil & Gas Cons. uommission Anchorage Daily Well Summa. Report Steel head Wel 1 M-5 Page 4 02/18/90 CBU. POOH. R/U and run casing. Tagged @ 1395'. POOH w/ casing. RIH w/ bit and ream and clean out 16" casing. POOH. R/U and run casing. 02/19/90 Ran 13 3/8" surface casing to 2635' and cement same w/ 1500 sx lead and 400 sx tail. L/D landing joint and installed wellhead packoff. Change top rams to 5". Test BOPE 250/3000 psi. R/D floor for handling. 13-3/8" Casing Detail Elevation i Hanger - FMC Hanger Mandrel 1 jt 13-3/8", 61#, Butt., K-55, BTC pup 15 jt 13-3/8", 61#, Butt., K-55, BTC i jt 13-3/8", 68#, 521 x BTC X/O 32 jt 13-3/8", 68#, Hydril 521, K-55 1 jt 13-3/8", 68#, K-55, BTC x Hydril 521 X/O 12 jt 13-3/8", 68#, Butt., K-55, BTC Collar 2 jt 13-3/8", 68#, Butt., K-55, BTC Shoe From 0.0' 77.90 78.75 81.38 698.83 702.93 2029.79 2051.19 2548.44 2549.94 2633.33 To: 77.90 78.75 81.38 698.83 702.93 2029.79 2051.19 2548.44 2549.94 2633.33 2635.14 02/20/90 P/U steerable BHA. RIH wash to 2544' test csg to 2150 psi. Drill float equipment and 10' formation to 2660'. CBU. Perform L.O.T. = 13.8 ppg emw. Drill 2660'-3001'. 02/21/90 Drill 3001' - 3590' CBU. Short trip to shoe. Drill 3590' - 3757'. 02/22/90 Drld 3,757'-4,217'. CBU. 10 STD S.T. Drld 4,217' - 4,290'. 02/23/90 Drld 4290'-4405'. Tripped for new BHA. Drld 4474'-4638'. 02/24/90 Drld 4638'-5285'. CBU. ST. Drlg La 5286'. RECEIVED JUN - 6 1990 Alaska Oil & Gas Cons. commission Anchorage Daily Well Summary Steelhead Well M-5 Page 5 port 02/25/90 Drld 5286'-5321'. Circ off bottom. Platform power ¢ minimum due to volcanic ash fallout from Mt. Redoubt. Drld 5321'-5600'. ST to shoe. POOH. RU loggers. 02/26/90 Ran open hole logs. #1-DIL/SDT/GR. #2-LDT/CNL. #3-SHDT/GR. TIH to 5600'. CBU. 02/27/90 ST to csg shoe. CBU. POOH. RU and run 9-5/8" and 10-3/4" production csg to 5560'. Circ and cond mud. RU and prepare to cmt. 02/28/90 Cmt csg w/ 1050 sxs. Set packoff in wellhead and test same. Test BOPE to 250/3000 psi. Had to change leaking cmt jumper hose and upper top drive safety valve. 9-5/8" Casing Detail Elevation Hanger 10 jt 10-3/4", 55.5#, Butt., m-80, BIO i 10-3/4" x 9-5/8" X/O 37 jt 9-5/8", 47#, Butt., S-95, BT6 i pup 1 CTC External Packer 1 pup 88 jt 9-5/8", 47#, Butt S-95, BTC Collar- Flt- BT6 2 jt 9-5/8", 47#, Butt., S-95, BTC Shoe- Fl t - BTC From: 0.0' 77.27 79.42 509.33 511.48 1989.93 1998.04 2008.53 2009.73 5478.50 5480.02 5559.96 To: 77.27' 79.42' 509.33' 511.48' 1989.93' 1998.04 2008.53 2009.73 5478.50 5480.02 5559.96 5561.76 03/01/90 LD BHA from derrick. SD for volcanic ash. RIH w/ bit and CO cmt from 5411 '-5478'. Test shoe to 1500 psi. Displace hole w/ inlet water. POOH. RIH to 2066' open ended. Spot inflation slurry and squeeze csg pkr 0 1998'. RO. RU E-line and lubricator and test to 1000 psi. RIH w/ cmt evaluation. 03/02/90 Ran cmt evaluation logs 5478'-2300'. Ran gyro survey. RU bell nipple and RIH w/ bit and Scraper. Circ. Test csg to 3000 psi. POOH. R.E EIVED JUN - 6 1990 Oil & Gas Cons. commission ~chorage Daily Well Summary Steelhead Well M-5 Page 6 03/03/90 port REi EIVED JUN - 6 1990 Alas~.Oil & Gas Cons. Commission Anchorage Perf for squeeze @ 5308'-5310' DIL. RIH and set retainer @ 5233'. Squeezed perfs w/ 100 sx to final 1/4 BPM @ 2250 psi.~ RO and tested csg to 3000 psi. POOH. RU and perf 4856'-4858' DIL. RIH w/ retainer #2. 03/04/90 RIH w/ retainer. Spotted KCl across squeeze perfs. Set retainer 0 4783' Squeezed perfs #2 w/ 70 sx and left 25 sx below retainer. Rev circ and P~OH. WOC. RIH. Drill retainer and CO csg. Test perfs to 1500 psi. 03/05/90 CO retainer and cmt to 5398'. Attempt to test csg to 1500 psi. Lost 160 psi in 20 min. POOH. RIH w/ retainer. Test csg before setting and lost 80 psi in 30 min. POOH w/ retainer. RU and run GR-CBT-CET 5378'-4700'. RD. RIH w/ bit and scraper. 03/06/90 RIH wash 5350'-5390'. Rev circ hole clean w/ filtered 3% KC1. POOH mixed and pumped 600 sxs class "G" w/ 2% CaC12 for a top job on the 20" x 30" annulus. RU E-line and ran 8-1/2" gauge ring and junk basket to 4830'. PU tailpipe assembly and prod pkr. Pkr struck V-door and broke setting slips. Waiting on repair parts. 03/07/90 While waiting on replacement pkr slips. PU 4-1/2" tbg and stand in derrick. Received pkr slips and repaired pkr. RIH w/ pkr set same Ca 4770' w/ tailpipe Ca 4816'. POOH w/ d.p. 03/08/90 Fin POOH. Change rams to 4-1/2". Test doors to 2000 psi. RU to RIH w/ 4-1/2" tbg. Tested each connection to 5000 psi. Displaced pkr fluid to backside and displaced tbg w/ nitrogen. Landed tbg and tested annulus to 2000 psi and SCSSV to 1750 psi. Bleeding nitrogen from tbg. 03/09/90 Set 2-way check. ND BOPE and NU tree. Test tree and void area to 5000 psi. Test flowline segment to 3500 psi. RU slickline RIH and shift "XXO" sliding sleeve. RU electric-line. Test lubricator to 2500 psi. RIH w/ gun #1. 03/10/90 Perf th~ D-6 and D-3B sands w 3-3~" Hollow Carrier guns at 5372'-5302' DIL, 6 SPt,60 phasing and 4914'-4864' ~DIL. Initial SITP = 1840 psi. Test //1 Ca 7 MMSCFD w/ FTP = 1838 psi. Test #2 ca 13.4 MMSCFD w/ FTP = 1814 psi. Test #3 ca Daily Wel 1 Summary Steelhead Well M-5 Page 7 port 21 MMSCFD w/ FTP = 1779 psi. Test #4 0 26.8 MMSCFD w/ FTP = 1740 psi. RD perfs. PU d.p. prior to skidding rig to northwest leg. 03/11/90 Prepare rig for skid. Disconnect service lines. Hookup hydraulic jacking system. RELEASE RIG to Well M-28 La 13:00 hrs 3/10/90. Well M-5 presently flowing 0 18.2 MMSCFD and FTP = 1804 psi. 03/12/90 RU power and service lines on Well M-28. NU lower wellhead flange. Found leak in tbg on Well M-5. RD service lines and power for Well M-28. Skidded rig back to NE well room. RU power and service on Well M-5. 03/13/90 RU wireline. Opened SCSSV. RIH w/ wireline, shifted injector sleeve closed. Tested injection line to 3000 psi. RIH w/ X-plug to 450'. Set in XXO profile. Bled tbg pressure to 0 psi. Monitored csg pressure, increased 100 psi in 30 min. POOH w/ plug. Set XN plug 0 4825'. Set X-plug @ 4814'. Tested plugs. RIH w/ F-stop. 03/14/90 Fin RIH w/ F-stop. RIH w/ perf gun. Perf tbg w/ orifice 0 4713'. POOH. RIH w/ second perf gun. Perf tbg w/ orifice La 4709'. RIH and pulled tbg stop. Reverse circulated w/ 8.5 ppg KC1 water. Observed well. Closed SCSSV and set BPV. ND tree. NU BOP. 03/15/90 Fin NU and testing BOP. Pulled tbg and hgr to rig floor. CBU. POOH w/ tbg. Inspected seal assembly and changed out SCSSV. Pressure tested SCSSV. 03/16/90 Fin pressure testing SCSSV. RIH w/ 4-1/2" tbg, testing to 5000 psi. Made up hanger. Circ. Pumped inhibited fluid. Displaced tbg w/ nitrogen. Closed SCSSV. Bled down tbg. Set BPV. Landed tbg. Tested annulus to 2000 psi. ND BOP. 03/17/90 Fin ND BOP. Found injection line loose. ND tree. NU BOP. Tested BOP. Pulled hanger to rig floor. Reversed out nitrogen from tbg. Circ. Stung into seals. Tested annulus to 3000 psi. Tested tbg to 1500 psi. Pulled hanger to rig floor. Circ. Daily Wel 1 Summary Steelhead Well M-5 Page 8 port 03/18/90 POOH w/ 4-1/2" tbg to SCSSV. Changed control line. RIH w/ 4-1/2" tbg. Displaced tbg w/ nitrogen. Landed hanger. Tested annulus to 3000 psi. ND BOP. NU tree. Tested void and tree to 5000 psi. RIH w/ wireline to retrieve X-plug @ 4812'. Unable to latch after two attempts. RIH w/ impression block. 03/19/90 RIH w/ GR tool to 4808' WLM twice. No recovery. RIH w/ 3.8" gauge. Tagged SCSSV. RIH 3.75" gauge to 4808' WLM. RIH w/ impression block to 4808' WLM. RIH w/ GR tool 4808' WLM. Worked to 4814'. Jarred. POOH. RIH w/ impression block to 4814' WLM. RIH w/ bailer 4817' WLM 3 times. Made 3 tries w/ GR tool 0 4817'. Jarred. RIH w/ hydraulic bailer. 03/20/90 Ran 2 centralized impression block runs to verify outside and inside of fishing neck was clear. Made a total of 6 runs w/ 2 types of pulling tools. Jarred plug up from 4819' to 4801'. 03/21/90 Jarred plug free @ 4801'. Tools stopped @ SCSSV 439'. Jarred by hand w/o success. Jarred down and worked tools back to 4818' Shifted XXO sleeve. RD slickline and RU E-line. Ran CAL/CCL log and verified tbg tail to be clear below X-nipple @ 4812' MU 3-5/8" cutter and RIH to top of plug @ 4824'. Pressuring up M-5 tbg ~rom Well M-2L. 03/22/90 Pressured tbg to 1860 psi. Fired jet cutter 0 4824' POOH. RIH stem and bull plug to 4838' and verified tbg plugs had been d~opped. RD E-line. Prepare rig for skid. Production brought well on @ 1330 hrs 0 7 MMSCFD and FTP = 1830 psi. Well presently flowing 0 20 MMSCFD and FTP = 1793 psi. RELEASED RIG to Well M-28 0 1400 hrs on 3/21/90. \docs\shp\m5.doc Attachment #2 MARATHON OIL COMPANY TRADING BAY UNIT STEELHEAD PLATFORM WELL M-5 CompLeted 3/28/90 CompLetion Strlnq: 0'-4780' 4.55 12.6#, N-80 AB Mod Butt Tbg. .S..C SS V AssembLy: 418' FltJs P-110 Ir{ow CoupLing. Otis XXD SSI) Landing Nlpp[e (3,813' X profile), Otis P-110 Ftow Couptln9, ntis FMX SCSSV (3,813' X profile), Otis P-110 FLow CoupLing, 511' 10-3/4', 55.5~f, N-80 3TC 511'-5562' 9-5/8', 47~, S-95 OTC 936' 80', 133~, X-56 BTC 1998' 1440' 8635' 9-5/8' External Pkr. 16' 75~, J-55/N-80, OTC. 13-3/8' 61/68~, K-55, OTC. Csg Cmt Sqz PerF 4856'-4858' OIL Csg Cmt Sqz PerF 5308'-5310' OIL 4765' 4765' Otis strelght slot Locator ~/SA Otis BWH Perm~-drlU Pkr w/lO' SBE, MO Ext, X-over to 4.5' Butt Tbg~ 10' 4.5' AB Mod Th§ Pup~ D¢ls 'X' NippLe <3.813' Pkg Bore)j 7' 4.5' AB Hod But% Tb9 Pup-Tbg Tall was cu-t of'? ~ 4806' usln9 a jet cu%%er on 3/~1/90, D-3B PERFORATIONS D-3~B 4864'-4934' 6 SPF O' Phasing D-6 5302'-5378' 6 SPF O' Phasing Avg devlcxtlon through per-Fs = 37,1'" 3/90 3/90 D-6 Top oF Fish 8 5376' OIL Top oF FItt 8 5381' 3/90 'P3TD 8 5478' TD @ 5600' Revision Date, 4/90 Revised 3y, PMD/neF Reasom New WeLt Previous Rev;s;om None Attachment'#3 $ UB-$ URFA CE DIRECTIONAL SURVEY ~-]UIDANCE F~ONTINUOUS I-flooL RE(~EIVED JUN - 6 1990 ~Oil & Gas Cons. Commissi0.a ~, ~nchorage Company , MARATHON,., OILj COMPANY Well Name M.-5(1037' FNL~598~ ,,FWL~SEC i u 33jTgN~R13W) Field/Location TRAD I NG BAY ~ K[NA,I z ALASKA 73739 -MAR-90 Lo~ed By; J~tl~--]i~)'J,~"lJ~D,. Computed SMITH KOHRING GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR · MARATHON OIL COMPANY M-5 TRADING BAY KENA!· ALASKA SURVEY DATE: OI-MAR-90 ENGINEER: SMITH METHQOS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORZZ. DIST. PROJECTED ONTO A TARGET AZINUTH'OF'SOUTH S8 DEG' 0 MIN EAST DATA FROM SURFACE TO S~5Z.2' ACQUIRED WITH TANGENTIAL METHO0 FROM SCHLU#BERGER GCT TOOL. DATA FROM 5~77' TO 5549' ACQUIRED FROM MEASURED WHILE DRILLING SURVEY. MWO DATA T~ED TO GCT DATA AT DEPTH 545Z.2e. COMPUTATION DATE: 1Z-MAR-90 MARATHON OIL CONPANY TRADING BAI' KENAIt ALASKA PAGE DATE OF.SURVET: ' OZ-MAR-90' , KELL'f BUSHING ELEVATION.' 160.O0'FT_ - 0.00 -160.00 100.00 -60.00 ZO0.O0 40.00 300.00 ':140.00 400.00 240.00 500.00 340.00 599.99 439.99 699.99 539.99 799.98 639.98 899.97 739.97 0 0 0 0 0 2 0 0 0 9 0 29 0 26 0 42 0 41 0 41 1000.00 999.96 839.96 1100.00 1099.96 939.96 1200.00 1199'95 1039.95 1300.00 1299.95 1139'95 1400o00 1399.94 1239.94 1500.00 1~99.92' 1339.92 1600.00 1599.90 14,39.90 1700.00 1699.88 1539.88 1800.00 1799.86 1639.86 1900.00 1899.85 1739.85 0 43 0 32 0 36 0 44 0 45 ! 12 I 5 0 55 0 55 ZO00oO0 1999.84 1839.84 2100.00 2099.83 1939.83 2200.00 ~99.83 20;9.83 2:300.00 99.82 21 ').82 2,00.00 2399.82 2239.82 2500.00 2499.81 2339.81 2600.00 2599.81 2439.81 2700.00 2699.81 2539.81 2800.00 2799.80 2639.80 2900.00 2899.80 2739.80 0 46 0 33 0 33 0 40 0 34 0 27 0 26 0 26 0 26 0 26 3000.00 2999.80 2839.80 0 31 3100.00 3099.74 2939.74. 3 49 3200°00 3199.25 3039.25 7 6 3300.00 3298.19 3138.19 9 36 3400.00 3396.30 3236.30 12 3500.00 3493.63 3333.63 13 54 3600.00 3590.51 3430.51 14 43 3700.00 3686.83 3526.83 16 52 3800.00. 3781.69 3621.69 19 57 3900.00' 3874.89 371¢.89 22 13 0o00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 NO 0 E N 39 36 E N 43 41 E S 83 51 E S 44 10 W S 85 Z W S 82 31 W S 89 17 W N 87 31 N N 86 36 N N 47 11 W N 35 34 W N 14 7 W N 18 27 W N 10 21 W N 10 30 W N 7 14 W N 6 3 w N 8 6 W N '3 54 W N 135 W N 8395 N 19 6 E N 26 13 E N lO 27 E N 3O 31 E N 21 6 E N 34 33 E N 14 21 E N 37 10 E N. 37 57 E -17.42 S 71 33 E -14,99 S 65 32 E -5.42 S'62 47 E 8.98 S 59 32 E 28.26 S 59 34 E 51.20 S 57 53 E 75.97 S 56 58 E 102.81 S.58 11 E 134.42 S 59 13 E 170.64 0.00 0.00 -0.37 0.00 -0.36 0.00 -0.37 0.00 -0.35 0.42 -0.77. 0.00 -1.41 ' 0.00 -2.21 0.00 -3.28 0.00 " -4.41 0.00 -5-53 -6.58 -7.34 -8.28 -9.20 -10.41 -11.83 -13.05 -14.17 -15.09 -16.02 -16.53 -16.85 -16.98 -17.15 -17.27 -17.36 -17.40 -17.43 -17.45 0.05 0.62 N 0.03 1.44 N 0.16 2.31 N 0.00 3.51 N 0.86 4.70 N 0.1¢ 6.51 N 0.00 8.67 N 0.19 10.67 N 0.14 12.40 N 0.10 13.94 N 0.52 0.00 0.00 0.00 0.3Z 0.15 0.00 0.29 O.ZO 0.09 0.85 5.28 2.90 3.26 2.01 1.08 1.05 3.44 2.70 1.13 0.00 N 0.25 N 0.27 N 0.31 N 0.24 N 0.11 N 0.03 S 0.04 S 0.09 S 0.20 M O. O0 E 0.28 W 0.25 W, 0.24 W O. 26 W 0.85 W 1.68 W 0.00 'N O' 0 E 0.38 N 47 55 W 0.37 N 43 18 W 0.39 N 37 13 W 0.35 N 47 13 W 0.85 N 82 49 W 1.68 S 89 8 W 2.64 W 2.64 S 89 I W 3.92 W '* 3.92 S 89 45 W 5.07 W 5.08 N 87 48 W 6.14 W 6.17 N 84 13 W 6.85 W ;~ 7.00 N 78 6 W 7.22 W 7.58' N 72 16 W 7.56 W 8.34 N 65 5 W 7.91 W .~i 9.20 N 59 18 W 8.21'W 10.48 N 51 37 W 8.54 W 12.17 N 44 33 W 8.72 W 13.78 N 39 16 W 8°96 W 15.30 N 35 51. W 9.09 N 16.64 N 33 6 W 15.49 N 16.57 N · 17.50 N 18.41 N 19.44 N 20.26 N 21.03 N 21.58 N 22.27 N 22.91 N 9.22 W 18,02 N 30 45'W 9.13 W 18.92 N 28 51 W 8.93 W 19.65 N 27 3 W 8.52 W 20.28 N 24 50 W 8.08 W 21.05 N 22 34 W 7.70 W : 21.67 N 20 49 W 7.33 W 22.27 N 19.,13 W 7.04 W 22.70 N 18 4W 6.63 W 23.24 N 16 35 W 6.26 W 23.75 N 15'18 W 23.60 N 5.80 W Z4.30 N 13 48 W 23.33 N 3.10 W 23.53' N 7 35 W 19.66 N 5.89 E 20.52 N 16,41 E 13.34 N :18.93 E 23.16 N 54 49 E 3.80 N 35.70 E 35.90 N 83 55 E 7.82 S 55.49 E 56.04 S 81 59 E 20.55 S 76.74 E 79.45 S 75 I E 35.13 S :99.28 E 105.31 S 70 31. E 52.11 S 125.94 E -136.30 S 67 31 E 70.81 S 156.97 E '172.20 S 65 43 E TRUE SUB-SEA. COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH' SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH · DEPTH DEPTH DEPTH DEG'MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG HIM ENGINEER:~ SMITH INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH COMPUTATION DATE: 1Z-MAR-90 PAGE MARATHDN:OZL COHPANY TRADZNG BAY KENAZp ALASKA TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MZN DEG 'KELLY BUSHING ELEVATION: .160,00 FT : ENGINEER: .SMITH INTERPOLATED VALUES FOR EVEN IO0'FEET'OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HOR~Z. OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 4000.00 3966.93 3806.93 24 11 S 59 10 E 4100.00 4~56.65 3896.65 28 17 S 59 21 E 4200.00 ~143.57 3983.57 30 25 S 58 23 E 4300.00 4Z29.62 4069.62 31 18 *S 56 53 E 4400.00 4313.58 4153.58' 34 18 S 57 2 E 4500.00 4395°86 4235.86 34 51 ;.S '56 35 E 4600.00 4~77.64 4317.64 35 28 S 56 11 E 4700.00 4558.77 4398.77 35 57 S 55 56 E 4800°00 4639.64 4479.64 36 7 S 55 56 E 4900.00 &720.05 4560.05 36 48' S 55 57 E DATE OF*SURVEY: 01-MAR-90 FEET OEG/IO0 FEET FEET FEET OEG 209.73 3.52 253.80 3.79 303.23 1.12 354.17 3.10 403.46 1.50 465.27 0.53 522.80 0.99 581.23 0.25 640.00 0.46 699.41 0.50 0.30 0.06 0.18 0.46 0.75 90.86 S 190.53 E 211.09 S 64 30;E 113.40 S '228.4Z E 255-0Z S 63:36 E 138.88 S 270.78 E 304o3Z S 6Z 51 E 166.27 S:' 313.74 E 355.07 S 62 S E 195.85 S 359.26 E"' 409.18 S 61'.24 E 226.96 S :406.82 E 465.85 S 60,51E 25.8.84 S 454.74 E 523'Z4 S 60 21 E ' 291.49 S 503.Z3 E : 581.55 S 59 55 E ,~ 324.45 S 551.94 E 640'24 S 59 33 E ~357°71 S '601.21 E 699.58 S 59 15:E 391.57 S 651.14 E759.81 S 58 59 E 425.68 S 701'39 E. 820.46 S 58 45 E 459.77 S 751a65 E 881.11 S 58 33 E 493.8Z S 802.00 E 941,83 S 58 23 E 528.07 S 852.62 E 1002.90' S 58 14 E 5000.00 4799.81 4639.81 37'20 S' 55 50 E 759.70 5100.00 4879.25 4719.25 37 29 S 55 53 E 820.39 5200.00 4958.70 4798..70 37 16 S 55 53 E 881.07- 5300.00 5038.11 4878.11 37 35 S 55 58 E 941.81 5400.00 5117.26 4957.26 37 51 : S 55 52 E 1002.89 5451.20 ~ TIE-IN POINT GOING FROM GCT TO M~D DATA (SEE ZNTERPOLATEO VALUES FOR CHOSEN HORIZONS).'f~ 5500.00 5195.97 5035.97 38 13 S 56 8 E 1064.52 0.68 562.61S 903,70 E 1064.52 S 58 6 E 5600.00 5274.20 5114.20 38 42 S 56;36 E 11Z6.79 0.00 : 597.05 S .955.60 E 1126-79 S 58 0 E COMPUTATION DATE: 1Z-MAR-90 PAGE MARATHON 'OIL COMPANY TRADING BAY* KENAZt ALASKA DATE OF SURVEY: OZ-MAR-90- ~ KELLY BUSHING ELEVATION:' 160.00 FT- ~ ENGINEER:- SMITH INTERPOLATED VALUES' FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE 9EASURED VERTICAL' VERTICAL DEVIATION AZIMUTH' SECTION SEVERITY NORTH/SOUTH EAST/~EST ~OIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN OEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0.00 0o00 -160o00 0 0 N 0 0 E 1000o00 999.96 939.96' 0 43 N 47 1! g 2000o00 199g.84 1839o84 0 46 N ! 35 W 3000°00 2999.80 2839.80 0 31 ~' N 37 57 E 4000.00 3966.93 3806.93 24 11 S 59 10 E 5000.00 4799.8! 4639o81 37 20 S 55 50 E 0o00 0.00 -5.53. 0.05 -16.02 0.52 -17-42 0.85 209.73 3.52 759°70 0.30 0.00 N 0.00 E 0.00 "N O: 0 E 0.62 N 6.14 W 6.17 N 84 13 W 15.49 N 9.ZZ W 18.01 N 30 45 W 23°60 N 5.80 kl 24~.30 N 13 ~48 N 90-86 S 190.53 E. 211.09 S 6~* 30 E 391.57 S .651.14 E 759.81 S 58 59 E 5451.20 ~ TZE-IN.POINT'GOING FROH GCT TO M~D'DATA (SEE INTERPOLATED VALUES FOR'CHOSEN HORIZONS)' 5600.00 5274.20 5114-20 38 aZ S 56 36 E 1126.79 0.00 597.05 S 955.60 E 1126.79 S 58"i COHPUTATZON DATE: 1Z-HAR-90 PAGE HARATHON OIL CONPANY M-5 TRADING BAY KENAIm ALASKA TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZZMUTH DEPTH DEPTH DEPTH DEG MZN DEG MIN 0.00 160.00 260.00 360.00 460.00 560.01 660.01 760.02 860.03 960.03 OATE'OF SURVEY::: 01-HAR~90 .-. KELLY BUSHING'ELEVATION: 160.00 FT'*'. ENGXNEER: SMITH · INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR'COORDZNATES HORIZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/14EST OIST. AZIMUTH · FEET DEG/IO0 FEET FEET FEET: DEG MIN 0.00 -160.00 0.00 100.00 200.00 300.00 400.00 500.00 600.00 7O0.00 800.00 0 0 0 2 0 Z 0 2 0 24 0 28 0 35 0 45 0 4O 0 40 N 0 0 E N 53 56 E N 8 53 E S 6 17 E S 8O Z 14 S 79 17 14 N 89 33 W S 86 29 14 N'84 25 W 0.00 0.'00 -0.37 0.00 -0.36 0.00 -0.35 0.08 -0.52 0.41 -1.17 0.00 -1.83 0.37 -2.86 0.20 -3.98 0.00 0.57 N 61 40 W : -5.05 160.00 260.00 360.00 460.00 560.00 660.00 760.00 860.00 960.00 0 36 N 39 26 W 0 32 N 20 614 0 46 N'16 55 14 0 42 N 16 22 14 I 7 N 9 I il I 17 ':N 7 37 W I 9 N 4 21W 059 N 8 53 W 052 N, 3 2 W 054 N 6 6 il -6.20 0.00 -7.05 0.23 -7.88 0.11 -8.85 0.13 -9.86 0.47 -11.28 0.00 -12.57 0.00 -13.74 0.19 -14.74 0.00 - -15.67 0.19 1060.04 1060.00 900.00 1160.04 1160.00 1000.00 1260.05 1260.00 llO0.O0 1360.06 1360.00 1200.00 1460.07 "1460. O0 1300'00 1560.09 ~ 1560.00 1400.00 1660.11 1660.00 1500.00 1760.13 1760.00 1600.00 1 360.14 1860.00 1700.00 1960.16 1960.00 1800.00 0 36 0 33 0 34 0 38 0 34 0 3O 0 18 0 28 0 25 0 29 N 7 36 E N 13 32 E N 26 22 E N Z2 54 E N 24 33 E N Z4 35 E N 32 7 E N 28 54 E N 31 20 E N 33 4 E -16.37 0.18 -16.74 0.03 -16.94 0.00 -17.07' 0.04 -17.24 0.0Z -17.31 0.08 -17.41 0.11 -17.40 0.13 -17.46 0.00 -17.42 O.Z1 2060.17 2060.00 1900.00 2160.17 2160.00 2000.00 2260.17 2260.00 2100.00 2360.18 2360.00 2200.00 2460.19 2460.00 2300.00 2560.19 2560.00 2400.00 2660.19 2660.00 2500.00 Z760.20 2760.00 2600.00 2860.20 2860.00 2700.00 2960.20 2960.00 2800.00 S 83 19 E -16.78 4.61 S 67 11 E -9.86 3.00 S 63 56 E 2.92 2.25 S 59 37 E 20.53 2.75 S 59 35 E 43.01 1.03 S 58 59 E 68.01 1.11 S 56 52 E 94.91 2.65 S 57 45 E 126.70 3.20 S 59 14 E 16¢.57 1.73 S 59 9 E 206.60 3.34 3060.21 3060.00 2900.00 1 42 3160.~9 3160.00' 3000.00 5 56 3261.32 3260.00 3100.00 8 33 3362.88 3360.00 3200.00 11 35 3465.39 3460.00 3300.00 13 31 3568.q~7 3560.00 3400.00 14 30 3672.03 3660.00 3500.00 16 1 3776.98 3760.00 3600.00 19 17 3883.92 3860.00 3700.00 22 1 3992.40 3960.00 3800.00 23 55 O. O0 N O. O0 E 0.26 N 0.27 W 0.31 N 0.24 14 0.29 N 0.24 0.14 N ' 0.52 14 0.03 N ..' 1.37 W 0.04~ S 2.18 W 0.08 S :~ 3.42 0.15 N 4.60 W 0.33 N 5.75 W 1.13 N 1.94 N 3.02 N 4.22 N 5.69 N: 7.82 N 9.89 N 11.75 N 13.32 N 14.90 N 6.60 W 7.11 W 7.41 W 7.79 14 8.07 It 8.42 W 8.65 Id 8.86 14 9.06 W 9.17 14 O. O0 N 0 0 E 0.37 N 46 46 14 0.39 0.38 N 38 58 W 0.54 N 74 38 1.37 N 88 54 2.18 S 88 50 W 3.~2 S 88 42 W 4.60 N 88 5 14 5.76 N 86 44 6.70. N 80 16 M 7.37. N 7~ 46 Id 8.00' N 67 47 W 8.86 N 61 32 9.88 N 54 49 W 11.49 N 47 8 W 13.14 N 41 10 W 14.72 N 37 1 W 16.10 N 34 13 14 17.50 N 31 37 W 16.18 N 17.13 N 9.04 W 18.03 N 8.71 W 19.04 N 8.24 W 19.95 N .. 7.87 W Z0.73 N 7.46 W 21.37 N 7.18 W 21.98 N 6.78 W ZZ.67 N 6.43 W 23.30 N 5.99 W 9.19 W 18.61 N 29 35 W 19.37 N 27 49 W 20.03 N 25 46 W 20.75 N 23 23 W 21.44 N 21 31 W 22.03 N 19 47 W 22.54 N 18 34 W 23.00 N 17 8 W 23.56 N 15 50 W Z4.05 N 14 15 W 23.78 N 4.93 W 24.29 N 11 43 W 21.46 N 1.79 E 21.54 N 4, 46 E 16.07 N 13.49'E 20.98 N 40 I E 7.73 N 29.04 E 30.05 N 75 6 E 3.67 S 48.42 E 48.56 S 85 40 E 16.38 S 69.96 E 71.86 S 76 49 E 30.81 S 92.66 E 97.65 S 71 36 E 48-02 S :119.40 E 128.69 S 68 6 E 67.70 S 151.76 E ::166.17 'S 65 57 E 89.26 S 187.85 E 207.98 S 64 35 E MARATHON OIL COMPANT M-5 TRADING BAY KENAZm ALASKA COMPUTATION DATE: 1Z-MAR-90 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH PAG~ ~ DATE OF SURVEY:, OZ'MAR-90 KELLY BUSHING ELEVATXON:: 160.00 FT ' ENGINEER:' SMITH · TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE IEASURED VERTICAL VERTICAL DEVZATIDN AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/NEST DISTo AZIMUTH ~ DEPTH DEPTH DEPTH DEG MZN DEG M]N FEET DEG/ZO0 FEET FEET. FEET DEG H[N 4103.82 ~060.00 3900.00 28 24 S 59 20 E 4219.05 4160.00 4000.00 30 26 : S 58 ! E 4335.79 4260.00 4100.00 32 30 S'56 57 E 4456.35 4360.00 4100.00 34 41 4578.36 4460°00 4300.00 35 17 4701.,52 4560.00 4400.00 35 57 4825.23 4660.00 4500.00 36 1_7 ~,949.99 &760.00 4600.00 ,37 7 5075.75 4860.00 4700.00 37 26 5201.63 4960.00 4800.00 37 16 5327.63 5060.00 4900.00 37 39 5454.23 5160.00 5000°00 38 5581o80 5260.00 5100.00 38 42 5600.00 5274.20 5114.20 38 42 S. 56 48 E S 56 15 E S 55 56 E S 55 59 E S 55 51 E S 55 51E S 55'53 E 255.64' 312.87 373°08 440.40 510.27 582.12 654.91 729.45 805.66 88Z.06 S 55 56 E 958°67 S 55 5! E 103~.25 S 56 36 E 1115.41 S 56 36 E 1126.79 3o71 114°34 S 230°00 E ~256o85 S 63 34 E 1.07 ' 143.97 S Z78.97 E 3]3.93 S 62 42 E 3.75 176o59 S 319.58'E 373.9! S 61_ 49 E 0.42 213.29 S 386.03 E 441.03 S 61 5 E 0.66 251.86 S 444.32 E '510.73 S 60 27 E 0°25 291.99 S 503.97 E 582.44 S 59.55 E 0.78 332°80 S 564°29 E "~655°12 · S 59 18 E 0o81 374.56 S 6Z6°10 E 729.58 S 59 7 E ~ 0°23" 417.41 S 689.19 E 805.74 S 58 48 E 0.16 460°32 S 752.47 E' 882.10 S 58 33 E 0.18 503.26 S 815.97 E 958°68 S 58 ZO E 0.62 546.81 S 880°23 E 1036o25 . S 58 9 E 0.41 590°79 S '946o10 E '1115.41' S 58 I E 0.00 597.05 S 955.60 E 1126.79 S 58 0 E COMPUTATION DATE: 1Z-MAR-g0 PAGE MARATHON OIL COMPANY TRAOZNG BAY KENAIe ALASKA MARKER GCT LAST READING FZRST MWD STAT[ON'USEO SECOND MWD STATION USED DR[LLERt5 OEPTH DATE OF SURVEY:. O1-MAR~90 KELLY'BUSHING~'ELEVATION:' 160000 ENGINEER:. SMITH INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1037t FNL & 598e FWLt SEC33'TgN R13W MEASURED DEPTH BELON KB TVD FROM KB SUB-SEA RECTANGULAR. COORD1'NATES NORTH/SOUTH 'EAST/NEST 5451o20 5157.61 ~997o61 5a5o77"S 878°69 E 5477°00 5177o9~ 5017.9a 55a.68 S 891o8~ E ' 5549°00 5234°~0 5074.40 579°50 S 928°98 E 5600°00 : 5274.20' 5114o20 597o05'S 955°60 E COMPUTATION DATE: ZZ-MAR-90 MARATHON TRADING BAY KENAIp ALASKA COMPANY KELLY MARKER DRILLEReS DEPTH ************ STRATZGRAPHIC SURFACE MEASURED DEPTH BELON KB 5600,00 SUMMARY LOCATION = 1037 TVD FROM KB' SUB-SEA 5274.20 511¢.Z0 598e FINAL MEASURED DEPTH NELL LOCATION AT.TD: TRUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH 5600.00 5Z74~.20 5114.20 HORIZONTAL DISTANCE FEET DEPARTURE AZIMUTH DEG HIN ZIZ6o79 S 58 0 E DATE OF'SURVEY: BUSHING.ELEVATZON: ENGZNEER: PAG~ , :~, · 01-MAR-90,' 160.00 FT; SMITH FWLt SEC33 TgN R13W RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST.'' 597.05 S 955.60 E SCHLUMBER©ER O I RECT I ONAL SURVEY COMPANY MARATHON OIL COMPANY WELL. 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'-t ...... .'-?-t'-;'---+.+.'-'f-~-~..-~.-4.--~.-4--...-4....-J.-~.-J.....4-j....j...~ ..... :.. :. i_~ ! [ ; ~ ~ ! i t ~-F'T-F'T...-r/,'T,-:-r'T~ ~-~ ~-t''7-,-r-'7-r**'-f-'-~.'.'-+--.+*~-+~--+-f:-*+.4--...4..4-::.-p*,-',..4-.~--; ..... L-4..4-~-.....L~ ~ ~ ~ ~ ~ ~ ~ ~-T :'?*T ~--T'" "' ! ! ! ;'.7".7-..'T'--?"t' ..-t/'/'/'/"~t.. --r.-??-'-t ..... .'i..~-+--~..--4--~.-~.-:,-,..4--4 4-~.-.,4-.k.4. '_ , , : ~ ~ ~ ~ ! ~ ~ ~ ~ ~ =-'r.~'"t"l'-t..-'T'*'?'**?"' '"-t."..'!--'t.-'7--,-.'-t-.'-t-.t.-~- ' , ' ', ' ' : ; i' I i: · .... ~ ~ ~ ~ ~ ~ ~ ~-T 7-T-..' ?'T ...... ~"'T"-r-~ ...... r'-r"1--t-',-*-:,----r-t--:-...~-~ i -.l--+-*+.+-+--$.+.4..+ i.4..4._~.. - 0 200 400 600 800 1000 1200 ERST NasV Oit & Co s. comm t.qt / WI~bL' M-5 1037' 'FNL, "~598' FWL, S~ 33, T9N, R13W) VERTICAL PROJECTION -~00 0 0 ~00 400 600 800 !000 1~00 ~~- ~'~"+~T~ ''~'~'- ''~''t~'~'+l'i''*~''''' ' ' ' ......... ..... rT'T',~ ~'TT~" "T'?~'~"~,T','" '~"T'--~-"~'~"+T- '~'~'?'+'- '~'+'+'+-"~"i"+,-' ............... ' ..... 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'u~ ~ ~~ ~5~~ ~+~.-u-~-,..+~-"+'4"++'}"4"+'~"+ .... -+.+++-N-H"' ..~_..+~_--+'-N-4'--.-+~.~-"'+'-~Hb'-~-~--~-~- '-H =~ ~ ~:---~+-- ~ !"5~5 .... +++4'-'-H~-F¢- .-4-+4.+-.-444-4.--...4-4..+.-b-.~-~4-~.- ilft i-~ff-'~ffe-~-~--+++~.+-~- iii i , ! ~ i ~ ~ ! i ~ i ~ i i ~ i ~ i i iii t, i , i i i i . , · , '1'~t!m I~ 'I' I-I'~111'~ 't~-1~- '!'~!~- ~ i ~ ~ i-+'~--'~'~"~-- '~"~-'~ff'- -~ ~.~..- ~4~4~- -~..~-i-4- 4..~4q...'4-~.4..4- ' ............ ~ ................... H--++e4.~..++H .-~-++ ..+..H-+- H-+~-+- .-¥-+.~..e- --++-++-.+-b~.-4- ..4-.+.4~.-- ..+:+++- I ,, , , .4~&.. 4_~44_.i H-4: ¢ .¢: 4-~4-.-,-+~....4~+~ -4.+++ ~-+++4 .~,..+~-++++~-+.4~-4..4..4-4-, H..4~ 4...~4.._ 1400 122. m II z PROJECTION ON VERTICAL PLANE 122. - 502. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/200 IN/FT =,la,-[ February 5, 1990 Mr. Guy Whitlock Marathon Oil Company P.O. Box 190168 Anchorage, AK 99519-0168 Mr. Whitlock: Re: Level Rotor Survey Job No. ~A~.~LB-00014 Trading-~y Unit Survey Date: 02-03-90 Operator: D. Harger Please find enclosed the "Original" and four (4) copies of our Survey on the above well. Thank you for giving us this opportunity t° be of service. Enclosures Sincerely, Ken Broussard District Manager Directional Services Sperry-Sun Drlg. Svcs. ICROFILMED 8537Corbin Drive(99507) · P.O. Box231649 · Anchorage, Alaska99523 (907) 267-0200 · Fax (907) 522-3432 ~ A Baroid Company SPERRY-SUN DRILLING SERVIC~:~ ANCHORAGE ALASKA PAGE 1 MARATHON OIL COMPANY M-5 TRADING BAY UNIT ALASKA COMPUTATION DATE: ~/ 5/90 DATE OF SURVEY: 02-03-90 LEVEL ROTOR GYROSCOPIC SURVEY JOB NUMBER: AK-LB-00014 KELLY BUSHING ELEV. = 160.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 0 .00 -160.00 0 0 N .00 E .00 .00 .00 .00 141 141.00 -19.00 0 40 S 43.80 E .48 .60S .57E .2~ 231 230.99 70.99 0 45 S 39.80 E .10 1.43S 1.31E .51 321 320.98 160.98 0 35 S 18.20 E .33 2.32S 1.83E .98 412 411.98 251.98 0 40 S 52.00 W .80 3.09S 1.56E 1.78 503 502.97 342.97 0 30 S 62.30 W .22 3.60S .79E 2.63 ~94 593.97 433.97 0 35 S 29.50 W .35 4.20S .21E 3.44 685 684.96 524.96 0 35 S 42.60 W .15 4.95S .34W 4.37 776 775.96 615.96 0 45 S 86.80 W .58 5.33S 1.25W 5.17 S71 870.95 710.95 0 35 S 78.60 W .20 5.46S 2.35W 5.87 954 953.94 793.94 1 5 N 19.20 W 1.41 4.80S 3.03W 5.68 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5.68 FEET AT SOUTH 32 DEG. 16 MIN. WEST AT MD = 954 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 212.28 DEG. SPERRY-SUN DRILLING SERVICE. ANCHORAGE ALASKA PAGE 2 MARATHON OIL COMPANY M-5 TRADING BAY UNIT ALASKA COMPUTATION DATE: 2/ 5/90 DATE OF SURVEY: 02-03-90 JOB NUMBER: AK-LB-00014 KELLY BUSHING ELEV. = 160.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH' TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -160.00 .00 .00 954 953.94 793.94 4.80 S 3.03 W .06 .06 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. BPERRY-SUN DRILLING SERVICE~ ANCHORAGE ALASKA PAGE 3 MARATHON OIL COMPANY M-5 TRADING BAY UNIT ALASKA COMPUTATION DATE: 2/ 5/90 DATE OF SURVEY: 02-03-90 JOB NUMBER: AK-LB-00014 KELLY BUSHING ELEV. = 160.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF' SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -160.00 60 60.00 -100.00 160 160.00 .00 260 260.00 100.00 360 360.00 200.00 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 .00 .00 .00 .00 .00 .76 S .72 E .01 .01 1.72 S 1.56 E .01 .01 2.70 S 1.96 E .02 .01 460 460.00 300.00 3.43 S 1.12 E .03 .01 560 560.00 400.00 3.89 S .38 E .03 .00 660 660.00 500.00 4.76 S .17 W .04 .01 760 760.00 600.00 5.32 S 1.04 W .04 .01 860 860.00 700.00 5.44 S 2.24 W .05 .01 954 953.94 793.94 4.80 S 3.03 W .06 .01 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PERMIT # ,,~ - ,/.,~-~ WELL NAME COMPLETION DATE _~ ! '~'~! ~ o CO. CONTACT & NO. fo~m received received date comments 401 no completion report ,, ~ 403 yes no sundry application 404 yes no report of sundry applicauon Open required received Cased required received ~roducti°rrequired received hole Ioo.. hole Ioa,, ~. .~ log.. MUD GCT / / TEMP ~ CNL PnOD DLL CBT v-~ ~,~v,,,,/' PRESS '" El"C/AC EPI '" OTHER DATA LSS PERF Survey nEC ,, SSS PACKER Digital Data Tegts i-uC RWD required received SAMPLES required received MWD LDT!CNL ML core 'CYBER core LOOK Analysis EMS , , RI- I NGT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANT I TY ,~J~ oc~f L DESCRIPTION RECE I VED: ~ Copy sent to sender Memorandum UNOCAL ) DOCUMENT TRANSMITTAL April 2, 1990 FIRST CLASS MAlL TO: John Boyle FROM: R.C. Warthen K. D. Kiloh LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows' Trading Bay Unit, Steelhead - M-5 1 sepia and 1 blueline as follows: Run #1 Continuous Gyro (GCT) Cement Evaluation Log (CET) Cement Bond Log (CBT) Run #2 Cement Quicklock Cement 8ond Log (CBT) Cement Evaluation Log (CET) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY' DATED: ~F~R - 4 1990 Alaska Oil & Gas Cons. CommiSsio~ Anchorage FORM 1-0C03 (REV. 8-85) PRINTED IN U.S.A. Memorandum UNOCAL DOCUMENT TRANSMITTAL March 23, 1990 HAND DELIVERED TO: Oohn Boyle FROM: R.C. Warthen K. D. Kiloh LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: T. ra.ding Bay unit - Steelhead 1 magnetic tape w/listing , 1 directional survey 1 blueline and 1 sepia of logs as follows: Stratigraphic High-Resolution Dipmeter Phasor Induction-SFL Lithodensity/Compensated Neutron/GR Borehole Caliper Log Stratigraphic Dipmeter/GR/AMS Array Sonic w/STC Processing Mudlog .., PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF T T TRANSMITTAL. THANK YOU. ~ RECEIVED BY: RECEIVED FORM 1-0C03 (REV. 8-85) PRINTED IN U.S.A. MAR 2. ? ]990 :.~ OJ~ & Gas Cons. Commissio[~ Anchorage 344-3323 FROM ADDRESS CITY STATE ZIP SHIPPER I DATE / / TIME TO ADDRESS CITY , STATE ZIP ATTENTION -~ PHONE INSTRUCTIONS "SAME DAY [] 24 HOUR 1~ P/U BY 3PM [] ONE HOUR CASE NO. COURT DOCUMENTS ONE HOUR $ SAME DAY $ 24 HOUR $ X JRECE~VEDBY JDATE / / JTIME j December 28, 1989 Telecopy No. (907) 276-7542 Roy D Roberts Envirov~ental Engineer UNOCAL P O Box 190247 Anchorage, AK 99519-0247 Re: Trading Bay Unit M-5 'UNOCAL Permit # 89-133 Surf Loc 1037'FNL, 598'FWL, Sec 33, T9N, R13W, SM Btmhole Loc 1749'FNL, 1910'FEL, Sec 33, TgN, R13W, SM Dear Mr Roberts: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting 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 chat a representative of the Comm_~ission 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. ~r%~ truly yours, Alaska Oil and Gas Conaervation BY O~ER OF THE CO~ISSION jo Enclosure Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl ~IAI 1- UP ALA~ItA ALASKA ~. AND GAS GONSERVATION CC-~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[2]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) 1037' FNL-,~ 598' FWL, Sec 33, T9N, R13W, S.M. Trading Bay Unit At top of productive interval 8. Well nurpber Number 5194234 1485' FNL, 1427' FEL, Sec 33, T9N, R13W, S.M. ~-5 . At total depth . 9. Appro.xima~.e spud date Am6dnt $200,000 U.S. 1749' FNL, 1910' FEL, Sec 33, T9N, R13W, S.M. 12. Distance to nearest. 131 Distance to nearest well 14. Number of acres in prOperty 15. Proposed depth (MD and TVD) property line 8100' from 6139' MD .A_DL 18730 unlt bound] 5,83 feet 3840.00 acres 5652' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAIS 25.035 (e)(2)) Kickoff depth 3200 feet Maximum hole angle40. ~_~, Maximum surface 2189 psig At total depth C'VD) 2704 ps~g 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 2...6" 20" 133# X-56 RL-4C 877' 73 73 950 950! 1500 sx 20" 16" 75# K-55 ~BTC 1377' 73 73 1450 1450 1100 sx 17-1/2" 13-3/8" 61# K-55 !BTC 2627' 73 73 2650 2650 1433 sx 12-1/4" ~10-3/4" 55.5# N-80 BTC 427' 73 73 500~ 500 1280 sx 9-5/8" 43.5# N-80 BTC 5300' 500 500 6139 5652 DEC201989 Highest known gas bearing zone at 1467' TVD (AC-1 Sand) Anchorage Cement volumes calculated assuming gauge hole, with top of cement on production casin 200' inside surface casing. 20. Attachments Filing fee ~ Property plat [] BOP Sketch ~ Diverter Sketch I]: Drilling program .,~illing fluid program :(D Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] · I hereby certify that the foregoing is true and cor~.t_,[,o the best of my knowledge , Signed /~-)O~z~/',./-'~Z~.~.~¢' rOTitle ENVIRONMENTAL ENGINEER Date 12/19/8 Commission Use Only Permit Number I API number I App~o:~12dg~89 I See cover letter Cor~diti'on~ of approval Samples required [] Yes '~C:R/No Mud log required [] Yes "~ No Hydrogen sulfide measures [] Yes ~No Di.rectional survey required ,~ Yes [] No Requiree working gr, e~sure[or BOPE ~j[2M; ,~ 3M.; [] SM; [] 10M; [] 15M Approved by Commissioner [ / the commission Date Form 10-401 Rev. 12-1-85 / Subm~ plicate Kill Line Fillup Line 16-3/4" 10,000 psi Doublegate Check Valve Gate Valve Gate Valve Pipe Rams Flow Line Hydril 16-3/4' 5000 psi Type GK Annular Blind Rams Gate Valve HCR Valve Choke Line .-----am,- Pipe Rams 16-3/4' 10,000 p8i Singlegate STEELHEAD PLATFORM Preventer Schematic 16-3/4' 5000 psi Riser RECEIVED ~, D~c 2 ot9B9 ~ Alaska Oil & Gas Cons. Commissia,: · Anchorage Ball Valve Wellhead DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: M-5 LEG: B-2 SLOT: 11 FIELD: AFE No.: TYPe: Trading Bay Unit, Steelhead Platform 8345-O Single gas producer REVISION NO.: DATE: 12/13/89 SURFACE LOCATION: TARGET LOCATION: BOTTOM HOLE LOCATION: 1037'FNL, 598'FWL, Sec.33, T9N, R13W, S.M. 1485'FNL, 1427'FWL, Sec.33, T9N, R13W, S.M. @ 5002' TVD 1749'FNL, 1910'FWL, Sec. 33, T9N, R13W, S.M. @ 5652' TVD KB ELEVATION: 152 ft. GL ELEVATION: FORMATION ESTIMATED FORMATION TOPS: DEPTH(MD) DEPTH(TVD) AC-1 1462 1462 A-1 2762 2762 B-1 3202 32O2 C-1 3898 3882 D-1 4255 4202 D-6 5287 5002 D-8(TOTAL DEPTH) 6139 5652 TYPE SIZE 2O 16 13.375 CASING PROGRAM CONDUCTOR: AUXILIARY: SURFACE: PRODUCTION: WT. GRADE THREAD POTENTIAL CONTENT gas gas gas gas RECEIVED gas c 2 o 19 9 Aiast(a 0il & Gas Con~ Anchorage SET SET HOLE FROM TO SIZE 133 X-56 RL-4C Surf 950' 950'TVD 75 K-55 BTC Surf 1450' 1450'TVD 61 K-55 BTC Surf 2650' 2650'TVD 26" 17-1/2" U/R to 20" 10.75 55.5 N-80 BTC Surf 500' 9.625 43.5 N-80 BTC 500' 6139' 12-1/4" U/R to 17-1/2" 12-1/4" CASING DESIGN SETTING FRAC GR FORM PRSS SIZE WEIGHT GRADE ..DE. PTH,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' 2139 4.56 14.4 3.01 9.625" 43.5# N-80 5145' >14.0 2704 2189 4.37 1.29 2.34 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 4-1/16" 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,~~~ ~ pressure tested to 250 psi and to 3000 psi with the exception of the' which will be tested to 250 psi and to 2500 psi. A~s~,~ 0it & Gas Cons. Anchorage MUD PROGRAM DEPTH WEIGHT VISCOSITY WATER MUD TO pp.q sec/qt LOSS TYPE 950' 8.8-9.0 60-80 <30cc's Spud 1450' 9.0-9.2 60-80 <30cc's Spud 2650' 9.2-9.4 40-50 <20cc's Gel/Benex 6139' 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 a 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 wi 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 RECE /ED DEC 2 01989 Oil & Gas Cons. Gomm~'~'(g:~ Anchorage CEMENTING PROGRAM CONDUCTOR: 20" @ 950' MD LEAD SLU RRY TYPE: Premium cement wi 15 Ib/sk Thix Lite 373 TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (O/o): SURFACE 12.8 ppg. 2.17 cu. ft,/sk 11.9 gal/sk 6:00+ hrs:min 100 O/o ESTIMATED VOLUME (Gauge hole): TAIL SLURRY TYPE: Premium cement wi 3% TOP OF CEMENT: 750 WEIGHT: 15.8 YIELD: 1.15 WATER REQ.: 5 PUMPING TIME: 6:00+ EXCESS (%): 100 CaCI2 ft. PPg. cu. ft./sk gal/sk hrs:min % ESTIMATED VOLUME (Gauge hole): 1100 sx 400 sx AUXILIARY: 16" @ 1450' MD LEAD SLURRY TYPE: Trinity Lightweight cement w/.75% Halad 344 and 1% Calcium Chloride TOP OF CEMENT: SURFACE WEIGHT: 13.6 ppg. YIELD: 1.21 cu. ft./sk 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 O/o ESTIMATED VOLUME (Gauge hole): 400 sx RECEIVED DEC ? o1989 Alaska 0il & Gas Cons. Corn~ssi~': Anchorage SURFACE: 13-3/8" @ 2650' LEAD SLURRY TYPE: Trinity Lightweight w/1% CaCI2 + 1.5% Gas Ban and .40/0 Halad 344 TOP OF CEMENT: SURFACE WEIGHT: 13.6 ppg. YIELD: 1.21 cu. ft./sk WATER REQ.: 5.83 gal/sk PUMPING TIME: 3:50 hrs:min EXCESS (%): 50 % ESTIMATED VOLUME (Gauge hole): 1033 sx TAIL SLURRY TYPE: Premium cement wi 1.5% Gas Ban & 1% CaCl2 TOP OF CEMENT: 2170 ft. WEIGHT: 15.5 ppg. YIELD: 1.19 cu. ft./sk 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" @ 6139' LEAD SLURRY TYPE: Trinity Lightweight w/1.5% Gas Ban, .14% LWL TOP OF CEMENT: 2200 ft. WEIGHT: 13.6 ppg. YIELD: 1.22 cu. ft./sk WATER REQ.: 5.95 gal/sk PUMPING TIME: 4:00 hrs:min EXCESS (%): 30 % ESTIMATED VOLUME (Gauge hole): 600 sx TAIL SLURRY TYPE: Premium cement wi .75% Gas Ban, .12% LWL 4O60 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): 680 sx Note: External casing packer at 2600'+- to be inflated with tail slurry. RECEIVED D c2 o t989 Alaska 0il & Gas Cons. Commission: Anchorage DIRECTIONAL PLAN DESC MD TVD INCL AZIM RKB 0 0 KICK OFF 3200 3200 BUILD @ 3.0 deg/100ft. END OF BUILD 4543 4435 TARGET 5287 5002 TOTAL DEPTH 6139 5652 0 HOLD 0 40.28 HOLD 40.28 HOLD 40.28 0 S61.28E S61.28E S61.28E S61.28E NORTH COORD 0.00N 0.00N 217.61S 448.68S 713.38S EAST COORD SECTION 0.00E 0 0.00E 0 397.23E 553 819.02E 934 1302.20 E 1485 POTENTIAL INTERFERENCE: WELL DISTANCE M-1 WITHIN 100' M-2 WITHIN 100' RLF-1 71' G-12RD2 WITHIN 200' LOGGING PROGRAM CONDUCTOR: Possible GRISPICalIDIL from 480' to 950'. DEPTH 0-1350' 0-1320' 1500' 5939'-6070' M.D. on M-5 AUXILIARY: Possible GRISPICalIDIL from 950' to 1450'. SURFACE: Possible GRISPICal/DIL from 1450' to 2700'. PRODUCTION: GR/SP/CaI/DIL/LSS from 6083' to 2700'. FDC/CNL/CaI/GR from 6139' to 2700'. Dipmeter from 6139' to 2700'. COMPLETION: A Cement Bond Log (CBL/GR) and a directional gyro- survey will be run prior to perforating. RECEIVED D c 2 01989 Aiaska 0il & Gas Cons. Commission' Anchorage DRILLING PROGRAM CONDUCTOR: Nipple up diverter and function test same. Drill a 17-1/2" hole to 975' RKB. Run DIL/GR log 950' to 480'. Open hole to 26". Run and cement 20" conductor with 1300 sx. WOC. Backout and lay down landing joint. Perform top job if necessary. Set wear bushing and bit guide. Test diverter and 20" conductor to 500 psi. AUXILIARY: Drill a 17-1/2" hole to 1450' RKB. Run a DIL/GR log 1450' to 950'. Underream the hole to 20" from 950' to 1450'. Pull wear bushing. Run and cement 16" auxiliary casing w/900 sx. 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 2650' per the directional program. Log if necessary. Underream the 12-1/4" hole to 17-1/2" from 1450' to 2650'. 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 12-1/4" hole from 2650' to 6139' 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-3B and D-6 sands with TCP guns. Kill well, POOH. Retrieve wear bushing. Run 4-1/2" tubing and packer. Land tubing and set packer. Nipple down BOPE. Nipple up and test tree to 5000 psi. Turn well over to production. CORING PROGRAM No cores are planned for this well. TESTING PROGRAM No open hole tests are planned for this well. DEC 2 01989 Alasl',a Oil & Gas Cons. Co~'r~missi°~ Anchorage Fillup Line 16-3/4' 10,000 psi Doublegate Flow Line Type GK Annular · Check Valve I ~ Kill Li?e~.. _. 1~~~~~' I C_~_hoke Line Gate Valve Gate Valve ~J II Gate Valve HCR Valve ~ l PipeRams ~ 16-3/4' 10,000 psi , , i' Singlegate STEELHEAD PLATFORM Preventer Schematic 16-3/4' 5000 psi Riser Ball Valve Anchorage Wellhead STEELHEAD PLATFORM CHOKE MANIFOLD. TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS CHOKE LINE I I I I '" SWACO ALL VALVES IN FLOW PATH ARE 3-1/16" 5000 PSI CAMERON GATE TYPE SECTION AA Plan View STEELHEAD PLATFORM . DiVERTER SYSTEM Rig Substructure N~ · ~ 16' Diverter 16; Diverter Line Section View ..~---- ~ 16' Remote Operated Ball Valve Conductor. Line Riser RECEIVED' DE C 2 0 t989 Oil & Gas Cons. Corr~gt~ss~O; Anchorage 29-112' 500 psi Flange 5O ~ 50 _ 100 _ 150 _ 200 _ 250 _ 300 _ 350 _ 5O 0 50 1200 1 O0 1 50 200 250 I ~ I ,,,I , ~ ,, ,, , : 1, , , .- "' ~'200 "3~OOxx ~00 ~ 400 '"44~00 I I , ! SO 0 1400 1600 100 RECEIVED DEC2 0 Oil & Gas Cons. Anchorage I I I 1 50 200 250 5O 5O 100 150 _ 2OO _ 250 _ 300 _ 350 HOR"ONT AL PROJECT I ON SCALE 1 IN. = 1000 FEET PIARATHON OIL COHPANY Leo~ B2. Sloi:~ 11 Well No~ STEELHEAD PIstro.;, Cook Inlet:, Proposal 1000 SURFACE LOCAT ! ON, 1037' FNL. $98' FIlL SEC, 33. TSN, R13~/ z c) , 1000 2000 3000 1000 0 I SURFACE WEST-EAST 1000 I 2O0O I 3000 I TAROET / D-6 SNDS TVD-$O02 THD-528? DEP-934 SOUTH 449 EAST 819 TAROET LOCAT[ON~ 1485' FNL. 1417' FWL SEC. 33. TSN. RI3W RECEIVED TD TVD=54~$2 THD-6139 DEP-1485 SOUTH 713 EAST 1302 S 61 DEl::; 934' (TO TD LOCATION, 1750' FNL. 1900' Fk'I. SEC. 33. TSN. RI3W 17 MINE TARGET) HARATHON OIL COHPANY Leer B2, SIo~t 11, Nell Not H-5 STEELHEAD Pla~:f'orm, Cool~ Rev I sed Alasl~a 0 ~ RKB ELEVAT[ON~ 152.3 m 1000_ 2000 _ 3000 _ 4000 _ 5000 _ 6OOO 34' CONDUCTOR TVD=475 20' CSG PT TVD--950 16' CSG PT TVD=1450 13 3/8' CSG PT TVD--2650 KOP TVD=3200 TFID=3200 DEP=O 3 AVERAGE ANGLE 40 DEG 17 H!N ' 9 15 BUILD 3 DEG PER I00 Fl' 21 27 39 EOB TVD=4435 THO=4543 OEP=453 X~ TARGET / D-6 SNDS TVD--5002 THD--5287 DEP=934 x. TD / 9 5/8' CSG PT TVD=5652 THO--61 39 DEP--1 485 I I 1000 2000 RECEIVED DFC 2 o i989 Anchorage VERTICAL SECTION EN UGE ~ CLEANER f ; '~' O'~ O [' · i : DE DER 2 CLEANER PIT i PIT ; 113 Bbls Cap , ' ~ ~ ~ RESERVE PIT ,-- ~.Oa.b~./i. '' l"03.Bbls/inO' ' ,~ ~ ' ~ -- 0 509 BblsCap ' " ~ ~ 0 SUCTION PIT ~2 :, 320 Bbls Cap ~ ~ 320 Bbls Cap 3.05 Bbls/in 3.05 Bbls/in 0 - ~ , ~ -,- ..... A ~ A A "' J .... MIX PIT PILL PIT I 82 Bbls Csp 80 Bbls C~p 0.77 Bbls/in 0.75 Bbls/in From ~bs~cture '~-~ 1 EQUALIZER STEELHEAD PLATFORM ' \ A ! AGITATOR MUD PIT LAYOUT I ~ [ /~ Mud Pump Mud Pump O MUD GUN: 300 I 400 I 5OO I 500 980O 9900 %0000 I~"_~500 1 0300 '"4~00 I 300 I 400 I 5OO 6OO I 700 I 5900 6000 6100 '~ 4,~oo 4800 620O 6300 ~00 I 6O0 8OO I '-5~oo 6400 90O 1 000 11 O0 I I I '"5.]00 6500 ~00 O0 ! ! ! 700 800 900 62OO '"'~'6300 1 1000 ~oo 1 1100 1200 I 1300 I ,00 5500 *'5,~00 "' E600 1 1200 1 1 300 1 400 1 500 I I - _ I - i i I I ! - I I I I - I I 1 400 1 500 100 200 300 400 500 6OO 700 8OO m i i ii ii iii I ii iii i i iiiiiiiiiiiiiiiiiiiiiiiiiiiiii iiiiii II iiiiii iiiiIIllllllllll lull, ,,,, I,,, ,,hhl, , ,, , , ,,, , I1,,,,,, , ,,,,,,,,,,,lllllllUll,· ~.~ MARATHON OIL COMPANY ~ ~ STEELHEAD Platform ~ ~ McArthur River. Field, Cook Inlet, AK ~ Clearance RePort (SPherical Method) ElliPse dimensions NOT included in cmlculations Casin~ dimensions NOT included in calculations Proximity radius is 200. feet All depths are in feet and are referenced to the REFERENCE WELL RKB Reference File Name :- DD1:[300,003]P00451.3MA StePwise vertical depth stations run from 5000. to ._~._~. at intervals of ~ feet Reference Slot Name :- B2-11 Reference Well Name :- M-5 Requested bY :- G WHITLOCK AccePted bY :- Object Slot Names Date :- 06-DEC-8~ Revision No :- 4 PrePared bY :- T dONES Checked bY :- Ob.Ject Well Names ERSTMRN CHRISTENSEN G-2-37 G-12RD2 CALCULATION OF LEAST DISTANCE BETWEEN WELLS Re~: : S06700.7MA Position on well M-5 MD TVD Closest Position on well G-12RD2 NS EW MD TVD NS EW Distance Directio Between Between Wells Wells 5918.08 5484.00 5946.92 5506.00 5975.76 5528.00 S004.60 5550.00 644.84 S 1177.09 E 7614.70 5519.01 510.12 S 653.80 S 1193.45 E 7641.87 5538.22 526.23 S 662.76 S 1209.80 E 7664.20 5554.11 539.23 S 671.72 S 1226.16 E 7691.62 5573.75 554.91S 1320.26 E, 199.68 N46 44E 1330.73 E 190.15 ( N47 6E 1339.49 E 180.99 < N46 24E 1350.46 E 172.23 < N46 47E S033.44 5572.00 S062.28 5594.00 S091.12 5616.00 Sl19.96 5638.00 680.68 S 1242.51E 7719.05 5593.40 689.64 S 1258.86 E 7746.48 5613.04 698.60 S 1275.22 E 7772.82 5632.03 707.56 S 1291.57 E 7800.33 5651.90 570.59 S 1361.44 E 163.4.7 < N47 13E 586.26 S 1372.42 E 154.74 ~ N47 41E 601.15 S 1382.99 E 146.17 < N47 53E 616.64 $ 1394.0~ E 137.69 ( N48 25E .~:, 138.31. 5652.00 626.49 S 1401.06 E 132.30 ERSTMRN CHRISTENSEN ~'~ MARATHON OIL COMPANY ~ ~ STEELHEAD Platfor. m ~ ~ McAr. thur. River. Field, Cook Inlet, AK ~ Clemrmnce RePort (SPherical Method) ElliPse dimensions NOT included ir, cmlculmtions Cmsir,~ dimensions NOT ir, cluded ir, cmlculmtions Proximit'-,' r. mdius is 200. .Feet All depths mr.e in feet and are referenced to the REFERENCE WELL RKB Referenr~e File Nmme :- DD1:[300,003]PO0451.3MA 'StePwise ver-ticml depth static, ns run from 0. to 5600. at inter-vmls of 100. feet Reference Slot Nmme :- B2-11 Reference Well Nmme :- M-5 Requested b'r :- G WHITLOCK Accepted by :- Object Slot Names Date :- 06-DEC-89 Revision No :- 4 PrePmred b'.,- :- T CLONES Checked b",-' :- Ob.Ject Well Names CHRISTENSEN B2-1 A1-1 A1-11 B1-1 B1-2 B1-3 B1-4 B1-6 B1-7 B1-8 B1 -S.~ B1-10 B1-11 B1-12 B2-3 B2-8 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-'FY G-3-10 G-3-11 G-3-12 G-4-13 G-4-14 G-4-15 G-4-16 G-4-17 G-4-17~ G-4-20 G-4-21 G-4-22 G-4-23 G-4-24 G-2-37 G-2-38 G-2-37~ G-2-40 G-2-41 G-2-42 G-2-43 G-2-44 G-2-45 G-2-46 G-2-47 M-3 M-13 M-14 M-.26 M-28 M-27 ~M-30 · ~M-31 M-25 ~.M-32 M-2 M-1 ST ~1 G-22 G-21 G-26 G-25 G-24 G-20 G-27 G-36 DPN G-34RB G-23RD G-33 G-28 G-14A G-19 G-13 G-15 O-5 G-3 RD2 G-2RB G-11 G-10 G-17RD G-7 G-12RD2 G-31 G-4RD G-1 G-'."} G-18RD G-14 G-30 G-SRD G-6RD G-32 · . Not in Proximity r'mdius. Not in Proximity rmdius,, Not in Proximity r~dius. Not in Proximity r.~dius. Not zn ProxzmztY r~dzus. Not zn Proximity rsdzus. Not zn Pr. oxiBitY r.~dzus. Not zn ProxzmztY rAdzus. Not ih ppoximztY r'.~dzus. Not in ProximztY r.~dzu$. Not zn ProxzmztY r~dzus. Not in ProxzmztY r-~dius. Not in ProxzmztY r.~dius. Not in PPoxzmltY r.~dzus. Not in Proximity r.~dius. Not in Proximity radius. Not in ProximztY r~dzus. Not in Proximity rAdzus. Not in Proximity r~dius. Not zn Proximity r-~dius. Not in Proximity r&dius. Not in Proximity r~diu$. Not zn Proximity r~diu$. Not in Proximity rmdius. Not in Proximity rmdius. Not in Proximity rmdius. Not in Proximity radius. Not in Proximity rmdius. Not in Proximity rmdius. · t i · · ! t · D-Al-1 D-A1-2 D-A 1 D-A 1-4 D-A1 D-A 1-6 D-A 1-7 I1 -A 1 D-A 1 -~ D-A 1 - 10 D-Al-11 D-A 1-1'-"~ D-A2-1 £ -A~-~ D-A~-.~'~ D-A~-4 D-A~-.J D-Az-6 D-A2-7 I---I d~ J '~ [ --~- ~ 0 '1 '-~ '~' D-B ~ -5 D-B 1-6 D-B1-7 D-Bl-O D-BI-~ B-B1-10 D-B1-11 D-B 1-12 · ..~=.-~- 10 KS-l-1 126 127 D-27 D-28 ~'PRD 'Fl_.],.-., ], D-4~. RD D-41 D-26 D-25RD D-43 o4/24 -.=~ 1 R B -~4A D-1 D- 17RD D-11 D-7 RD D-?~ RD .~RD D- I '= ' D-44 / '-' D-._, RD D- 1.JRD~ D-3RD2 ! -4.J D-8 RD D-6 RD D- 14RD D-20 D-16RB D-22 D-2A RD D-4 RD D-10 D-12RD B-18 D-30RD K-20 K-21RD K-24 RLF-1 OB ~2 (D-13) N,:, t i r, P r. o x irr, i t'-,- r..s,---i i u s. N c, t i r, P r- ,::,x i m i t",.' r' ~ d i u s. Not ~n Pr. ox~mit'.,.' r-radius. Not in Pr. oximit'.,.' r'.mdius. Not in Pr-oximitY pmdius. Not in Proximit'-,-' r'.mdius. Not in Pr-oximitY r. mdius. Not in Pr. oximit'.~' r. mdius. Not in Pr.c, ximit'-,.' r. mdius. Not in Pr.o::.::imitY r.~ldius. Not in Pr'oxirnit"," r'.mdius. Not in Pr. oximit'.,' r. mdius. Nc, t in Pr'c, ximit"," r. mdius. Not in Pr. oximit'.,' r'mdius. Not in Pr-oximit'.,' r. mdius. Not in Pr. oximit'-,' r. mdius. Not in er. oximit'.,' r-radius. Not in Pr. oximlt'.,.' r. mdius. N o t i n P r-,:, x i m i t'.,.' r.m d i u s. Not in Pr. oximit'.,- r-radius. Not in Pr. oximitY r. mdius. Not in Pr. oximit'.,' r.~dius. Not in Pr. oximit'.,- r-~dius. N o t i n P r. o ::.:: i m i t'.,' r. m d i u s. Not in ~r. oximitY r. mdius. Not in Pr. oximit'.,- r. mdius. Not in Pr. oximit'~.' r. mdius. Not in Pr. oximit'-,.' r. mdius. Not in Proximit'.,- r. mdius. Not in Pr. oximit-,.' r. mdius. Not in Pr. oximit'.~' r-radius. Nc, t in er. oximit'.,' r'.mdius. Not in Pr. oxlmitY rmdius. Not in Proximity rmdius. Not in ~roxlmit'.,' radius. Not in Proximity r-radius. Not in Proximity rmdius. Not in Proximity rmdius. Not in Pr. oximit'-,- r-radius. Not in Proximit'-,- rmdius. Not in ~roximitY r-mdius. Not in Proximity r-~dius. ERSTMRN CHRISTENSEN Position on welt MD TVD NS 0. O0 0.00 100. O0 100.00 200. O0 200. O0 300. O0 :300. O0 400.00 400.00 500. O0 500.00 600. O0 600 ,, O0 700.00 700. O0 800.00 800.00 900.00 900.00 1000.00 1000.00 1100.00 1100.00 1200.00 1200.00 1300.00 1300.00 1400.00 1400.00 1500.00 1500.00 1600.00 1600.00 1700.00 1700.00 1800.00 1800.00 1900.00 1900.00 2000.00 2000.00 2100.00 2100.00 2200.00 2200.00 2300.00 2300.00 2400.00 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 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 N 0.00 N 0.00 N CALCULATION OF LEAST DISTANCE BETWEEN WELLS Closest Position on well M-3 EW MD TVD PIS EW 0.00 E 0.00 0.00 0.00 E 100.00 100.00 0.00 E 200.00 200.00 0.00 E 300.00 300.00 0.80 N 0.80 N 0.80 N 0.80 N Ref : POO448.2MA 0.00 E 400.00 400.00 0.00 E 500.00 500.00 0.00 E 600.00 600.00 0.00 E 700.00 700.00 Distance Directio Betmeen Between Wells Wells 0.00 E 800.00 800.00 0.00 E 900. O0 'PO0. O0 0.00 E 1000.00 1000.00 0.00 E 1100.00 1100.00 10.14 E 10.17 N85 29E N~ .~.1 10. 14 E 10 .17 ,-, = .~o,~.. ~,._ 10.14 E 10.1'7 N85 29E 10.1'4 E 10.17 N85 29E 0.00 E 1200.00 1200.00 0.00 E 1300.00 1300.00 0.00 E 1400.00 1400.00 0.00 E 1500.00 1500.00 0.80 N 10.14 E 10.17 N85 29E 0.80 N 10.14 E 10.17 N85 29E 0.80 N 10.14 E 10.17 N85 29E 0.80 N 10.14 E 10.1'7 N85 29E 0.00 E 1599.77 15~9.74 0.00 E 1699.04 1698.79 0.00 E 1797.64 1796.80 0.00 E 1895.21 1893.24 E 0.80 N 10.14 E 10.17 N85 ~.~E 0.80 N 10.14 E 10.17 N85 29E 0.80 N 10.14 E 10.17 N85 29E 0.80 N 10.14 E 10.1'7 N85 29E 0.80 N i0.14 E 10.17 N85 29E 0.80 N 10.14 E 10.17 N85 29E 0.80 N 10.14 E 10.17 N85 291E 0.00 E 1991.36 1987.57 0.00 E 2085.73 2079.31 0.00 E 2177.~6 2168.01 0.00 E 2267.70 2253.26 1.51N 3.61N 7.09 N 11.88 N 12.20 E 12.29 N82 57E 18.3~ E 18.72 N78 51E 28.44 E 29.48 N76 OE 42.38 E 44.53 N74 20E 0 00 E '-"-': .... ~._',.=,4.73 17.91N 25.09 N 33.28 N 42.36 N 59.92 E 63.76 N73 21E :30.78 E 87.']'~,.,~ N72,'~E 104.62 E 114.35 N72 131.03 E 145.42 N72 5E 52.17 N 159.56 E 180.11 N71 54E ERSTMRN CHRISTENSEN Position on walt M-.5 MD TVD NS 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 CALCULATION OF LEAST DISTANCE BETWEEN WELLS 800.00 900.00 1000.00 1100.00 Closest Position on wall M-13 EW MD TVD NS EW . 100. 200. 300. 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 0.00 0.00 11.48 S 99.93 99.93 11.50 S 199.99 199.99 11.58 S 300.05 300.05 11.72 S Re.F 400. 500. 600. 700. O0 0.00 N 0.00 E O0 0.00 N 0.00 E 00 0.00 N 0.00 E 00 0.00 N 0.00 E 400.00 400.00 12.08 S 499.59 499.59 12.63 S 597.99 59'7.97 13.38 S 694.71 694.63 14.41S : S08034.8MA 800. 900. 1000. 1100. O0 0.00 N 0.00 E 00 0.00 N 0.00 E O0 0.00 N 0.00 E 00 0.00 N 0.00 E 791.04 790.78 16.66 S 887.02 886.41 20.22 S 979.34 978.12 24.64 S 1072.28 1069.92 30.12 S Dist,"mnce Directio Between Bet~een We 11 s Wa 11 s 144.80 W 145.25 S85 28W 144.85 W 145.30 S85 28W 144.84 W 145.31 S85 26W 144.69 W 145.16 < S85 22W 144.63 W 145.13 < S85 13W 144.86 W 145.42 S85 OW ].46.16 W 146.78 S84 46W 149.49 W ].50.28 S84 30W :1. 54 '-'=' = ':"=":' ~:-:::~ . ,:.._, W 1....,6 01 162 c, ~1 W 164 02 '-"-"-' 171.66 W 174.80 S81 50W 185.00 W 189.83 S80 45W ERSTMRN CHRISTENSEN Position on TVO bis CALCUi_ATION OF LEAST DISTANCE BETWEEN WELLS Closest Position on well M-14 EW MD TVD NS EW Ref : S08090.4MA Distmnce Dir. ectio Between Between Wells Wells 0.00 0.00 100. O0 100. O0 20(}. 00 200.00 300.00 300.00 0.00 N 0.00 i',1 0.00 N 0.00 N 0.00 E 0.06 0.06 0.00 E 100.00 100.00 0.00 E 199.96 199.96 0.00 E 300.00 300.00 12.42 S 135.03 W 135.6(} S84 45W 12.54 S 134.99 W 135.57 < S84 42W 12.85 S 135.02 W 135.63 S84 34W 13.22 S 135.02 W 135.66 S84 25W 400.00 400.00 500.00 500.00 6(}0.00 60(}.00 7(}(}.00 700.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 0.00 E 0.00 E 0.00 E 4'29.91 49'.'.-.~. 91 599.81 599.81 699.60 699.59 13.69 S 135.00 W 135.69 S84 13W 14.32 S 134.98 W 135.73 S83 57W 15.12 S 135.01W 135.85 S83 37W 15.~7 S 135.17 W 136.11 S83 16W 800.00 800.00 900.00 900.00 1000.00 1000.00 11(}0.00 1100.00 0.0(} N 0.00 N 0.00 N 0.00 N 0.00 E 0.00 E 0.(}0 E 0.00 E 799.39 799.37 898.73 898.71 ~99.07 999.02 1099.09 1099.03 16.96 S 18.27 S 20.03 S 21.54 S 135.47 W 136.53 S82 136.10 W 137.32 S82 W 136.71W 138.17 S81 40W 137.21 W 138.89 S81 5W 1200.00 1200.00 1300.00 1300.00 14(}0.00 1400.00 1500.00 1500.00 0.00 N 0.00 ixi 0.00 N 0.00 N 0.00 E 0.00 E 0.00 E 0.00 E 1199.22 1199.15 1299.52 1299.44 1400.29 1400.21 1500.19 1500.11 22.92 S 137.61W 139.50 S80 33W 24.01S 137.89 W 139.97 S80 7W 24.82 S 137.88 W 140.09 S79 48W 25.22 S 137.66 W 139.95 < S79 37W 160(}.(}0 1600.00 1700.00 1700.00 1800.00 1800.00 1900.00 1900.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 0.00 E 0.00 E 0.00 E 1600.12 1600.04 1700.00 1699.92 1799.99 1799.91 1900.00 1899.92 25.36 S 137.57 W 139.89 { S79 33W 25.44 S 137.56 W 139.89 S79 31W 25.47 S 137.68 W 140.01 S79 31W 25.39 S 137.64 W 139.97 ( S79 33W 2000. O0 20(}0.00 ~100.00 2100.00 220(}. 00 2200.00 2300.00 2300.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 0.00 E 0.00 E 0.00 E 199~.63 1999.55 2099.70 2099.62 2199.81 2199.73 2299.87 2299.79 25.41 S 137.86 W 140.19 S79 33W '-' ~ .~'" ,., ~ ~W --'u,. 60 :S 1 ._ .:~. 13 W 140.4'z' 879 ~._ ~:I S 138.:~:3 W 140.72 S79 25.84 S 138.48 W 140.87 S79 26W 2400.00 2400.00 2500.00 2500.00 2600.00 2600.00 2700.00 2700.00 0.00 N 0.00 N 0.00 N 0.00 N (}.00 E 0.00 E 0.00 E 0.00 E 2400.27 24c)0.19 2500.64 2500.56 2600.63 2600.54 2700.59 2700.50 25.92 S 25.96 S 26.04 S 25.97 S 138.41 W 140.82 { S79 24W 138.17 W 140.59 < S79 22W 137.76 W 140.20 < S79 18W 137.40 W 139.83 ~ S79 18W 2800.00 2800.00 2900.00 2900.00 3000.00 3000.00 3100.00 3100.00 0.00 N 0.00 N 0.00 N 0.00 N 0.0(} E 0.00 E 0.00 E 0.00 E 2800.21 2800.13 2900.27 2900.17 2999.45 2999.36 3099.31 3099.21 25.31S 24.28 S 23.96 S 23.~8 S 137.34 W 139.65 <] S79 33W 137.41 W 139.54 -':.' S80 OW i37.81 W 139.88 S80 8W CHRISTENSEN -Position on well M-5 CALCULATION OF LEAST DISTANCE BETWEEN WELLS Closest Position on well M-14 MD TVD N.?; EW MIl TVD NS EW 3200.00 3200.00 3300.05 3300.00 3400.37 3400.00 3501.25 3500.00 3602.98 3600.00 3705.90 3700.00 0.00 N 1.26 S 5.05 S 11.39 S 20,, 35 S ":'":' 0C) ':'"' %.; .::. n '.#: 0.00 E 2.30 E 9.21 E 20.79 E 37.15 E 58.42 E 3197.86 3179.76 3298.92 3298.82 3400.49 3400.38 3501.37 3501.25 3601.47 3601.35 3700.23 3700.11 Ref : S08090.4MA Distance Dipectio Between Between Wells Wells 1 .... :, 67 W 140 63 '-'-"-'("' ~= .... o . . .~,,_-,., 24 W >22.85 S 139.24 W 14:3.18 S81 2. OW 21.98 S 140.10 W 150.27 S83 32W 20.89 S 139.8'7 W 160. 'T~5 S86 37W 2(]:,./--,8 S 1 :'=_:9.11 ~J 176.2/-, o,-,,- .. ...... :, ..:.~' 54W 20.64 S 138.56 W 197.3:L N86 42W ERSTMRN CHRISTENSEN CALCULATION OF LEAST DISTANCE BETWEEN WELLS Ref : S07078.1MA Position on well M-5 MD TVD NS EW Closest Position on well M-26 MB TVD NS EW Distance Directic Between Between Wells Wells 0.00 0. 100.00 100. 200.00 200. 300.00 300. 00 0.00 N 00 0.00 N 00 0.00 N 00 0.00 N 0.00 E 0.00 0.00 0.00 E 100.00 100.00 0.00 E 200.00 2()0.00 0.00 E 300.00 :300.00 72.14 N 72.14 N 72.14 N 72.14 N 7:3 ~3 W 1¢'-' . "'- .b~. 79 N45 26W 7:3. ""'"" '"" ~..:. W 102. ,"::~ t',145 26W 73.23 W 102.79 N45 26W 73.23 W 102.79 N45 26W 400.00 400. 500.00 500. 600.00 600. 700.00 700. O0 O. O0 N 00 O. 00 N O0 0.00 N 00 O. 00 N 800.00 800.00 900.00 900.00 1000.00 1000.00 1100.00 1100.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 4£)0.00 400.00 0.00 E 500.00 500.00 0.00 E 600.00 600.00 0.00 E 700.00 700.00 .0.00 E 799.59 799.59 0.00 E 900.99 900.98 0.00 E 999.07 999.05 0.00 E 1097.34 1097.29 72.14 N 72.14 N 72.14 N 72.14 N 72.19 N 71.87 N 71.10 N 73.38 N 73.23 W 102.79 N45 26W 73.23 W 102.79 N45 26W 73.23 W · 102.79 N45 26W 73.23 W 102.79 N45 26W 7:3. :36 W 102. ':'~':'..._. N45 ~ 74.1 '7 W 103. '-' ~,::, N4.5 .: 74.19 W 102.77 '::: N46 13W 74.56 W 104.65 N45 27W 1200.00 12¢)0.00 1300.00 1300.00 1400.00 1400.00 1500.00 1500.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 1193.97 1193.73 0.00 E 1290.38 1289.67 0.00 E 1386.24 1384.42 0.00 E 1481.93 1478.23 79.19 N 88.46 N 102.67 N 121.03 N 74.84 W 109.14 N43 23W 73.87 W 115.71 N39 52W 71.34 W 125.99 N34 48W 67.52 W 140.29 N29 9W 1600.00 1600.00 1700.00 1700.00 1800.00 1800.00 0.00 N 0.00 N 0.00 N 0.00 E 1579.80 1574.00 0.00 E 1672.55 1664.39 0.00 E 1769.48 1758.33 140.68 N 160.80 N 183.84 N 63.16 W 156.39 N24 11W 58.26 W 174.69 N19 55W 52.09 W 195.57 N15 49W ERSTMRN CHRISTENSEN Position on well M-5 MD TVD NS 0.00 0.00 0.()0 N 100.00 100.00 0.00 N 200.00 200.00 0.00 N 300.00 300.00 0.00 N CALCULATION OF LEAST DISTANCE BETWEEN WELLS Closest Position on ~ell EW MD TVD NS EW 0.00 E 0.22 0.22 70.82 N 0.00 E 99.91 99.91 70.78 N 0.00 E 200.25 200.25 70.56 N 0.00 E 300.40 300.39 '70.10 N 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 700.00 700.00 0.00 N 0.00 E 800.00 800.00 0.00 N 0.00 E 900.00 900.0C) 0.00 N 0.00 E 1000.00 1000.00 0.00 N 0.00 E 399.37 399.37 70.48 N 502.15 502.13 71.4'7 N 603.86 603.73 70.56 N 702.02 701.74 71.21N 800.91 800.54 73.14 N 901.75 901.33 73.52 N 919.30 918.87 73.63 N Re~ : S07885.8MA Distance Di r. ect i,:, Between Between We1 ~ $ We11 s 68.86 W 98.78 N44 12W 68.98 W 98.8:3 N44 16W 69.01 W 98.70 ..':.' N44 22W 68.95 W 98.:'_-'::;." '.:: N44 32W 68.45 W 98.25 ~ N44 lOW 67.84 W 98.56 N43 31W 63.42 W 94.95 ~ N41 57W 58.16 W 91.96 E N3'~ 15W 54 :~ W 91 1') ..... ~ <: N.z,z, 51.22 W 89.6:2 C N34 52W 50.61W 120.69 N34 30W ERSTMRN CHRISTENSEN Position on well M-5 CALCULATION OF LEAST DISTANCE BETWEEN WELLS Closest ~osition or', well M-28 MD TVD NS EW MD TVB NS EW 0.00 0.00 100.00 100. O0 200.00 200. O0 300.00 300.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 0.28 0.28 0.00 E 99.73 99.73 0.00 E 200.22 200.22 0.00 E 300.32 300.32 66.91 N 66.78 N 66.61 N 66.25 N 400.00 400.00 500.00 500.00 600,,00 600.00 700.00 700.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 400.95 400.94 0.00 E 501.82 501.80 0.00 E 602.50 602.45 0.00 E 702.48 702.36 66.14 N 65.43 N 64.27 N 6:3.74 N 800.00 800.00 900.00 900. O0 1000.00 1000.00 1100.00 1100.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 801.87 801.69 0.00 E 901.58 901.35 0.00 E 950.00 949.'74 0.00 E 950.0() 949.74 63.81 N 63.89 N 64.10 N' 64.10 N Re~ : S07841.8MA Distmnce Directio Between Between Wells Wells 66.14 W 94.08 N44 40W '66.0'7 W 93.93 ~ N44 42W 66.26 W 93.95 N44 51W 66.28 W 93.71 <] N45 OW 65.48 W 93.07 <: N44 43W 64.20 W 91.69 <] N44 27W 62.19 W 89.47 < N44 3W 58.68 W 86.67 ~ N42 38W ~:= 00 W 5:4 9~ e N4},;:( i:~W 51.86 W 82.30 ~ N39 4W 50.34 W 95.75 N38 9W 50.34 W 170.94 N38 ~W ERSTMRN CHRISTENSEN Position or~ we11 M-5 MD TVD NS 0.00 100.00 200.00 300.00 400. O0 500.00 600.00 700.00 CALCULATION OF LEAST DISTANCE BETWEEN WELLS 800.00 900.00 1000.00 1100.00 Closest Position on we1] M-27 EW MD TVD NS EW . 100. 200. 300. 00 0.00 N O0 O. O0 N 00 0.00 N O0 O. O0 N 62.14 N 61.47 N 61.11N 60.62 N Re~ : S07837.8MA 400. 500. 600. 700. O0 0.00 N O0 0.00 N O0 0.00 N 00 0.00 N 0.00 E 400.94 400.93 0.00 E 502.22 502.20 0.00 E 602.83 602.76 0.00 E 702.12 702.00 60.47 N 59.41N 57.65 N 56.76 N Distmnce Dir'.ectic Between Between Wells Wells 800. '.-700. 1000. 1100. O0 0.00 N 00 0.00 N 00 0.00 N O0 0.00 N 0.'00 E 801.83 801.64 0.00 E 902.07 901.82 0.00 E 975.00 974.68 0.00 E 975.00 974.68 57.03 N 57.55 N 57.96 N 57.96 N 66.60 W 91.09 N47 OW 66.5'7 W 90.62 < N47 17W 66.37 W 90.22 < N47 22W 66.23 W 89.79 ~ N47 32W 65.53 W 89. I8 < N47 18W 64.61W 87.80 4 N47 24W 62.38 W 84.98 < N47 16W 59.08 W 81.95 <: N46 ~W .~-:... ~..,. 69 W 79 .7 :.?,. -{ N 44 ._~.~'-'. 01 W 77. ._~'::~...-':: N 42'~-/..-..:, W 48.96 W 79.98 N40 llW 48.96 W 146.49 N40 ilW ERSTMRN CHRISTENSEN Position on well M-5 . MD TVD NS 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 CALCULATION OF LEAST DISTANCE BETWEEN WELLS 800.00 900.00 Closest Position on well EW MD TVD NS EW . 100. 200. 300. 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 0.13 0.13 100.04 100.04 200.13 200.13 300.13 300.12 58.38 N 58.01 N 57.70 N 57.24 N 400. 500. 600. 700. 00 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 400.22 400.22 498.65 498.64 598.87 598.85 698.79 698.76 56.88 N 56.39 N 56.41N 56.44 N 800.00 'F~()O. 00 0.00 N 0.00 N 0.00 E 0.00 E 776.30 776.26 776.30 776.26 56.76 N 56.'76 N Rmf : S07815.8MA Distance Dir. ectio Between Between We'! 1 s Wel 1 s 74.79 W 94.88 N52 2W 74.90 W 94.74 < N52 14W 75.07 W 94.69 < N52 27W '75.21W 94.51 < N52 43W 75.32 W 94.38 < N52 56W 75.90 W 94.56 N53 24W 77.53 W 95.89 N53 58W 7?.07 W 97.16 N54 2~W ERSTMRN CHRISTENSEN Position on welt M-5 MD TVD NS 0.00 0.00 0.00 N 100.00 100.00 0.0() N 200.00 '~''. ,~)~.~ 00 0.00 N 300.00 300.00 0.00 N 400.00 400.00 0.00 N 500.00 500.00 0.00 N 600.00 600.00 0.00 N 700.00 700.00 0.00 N CALCULATION OF LEAST DISTANCE BETWEEN WELLS 800.00 800.00 0.00 N 900.00 900.00 0.00 N LO00.O0 1000.00 0.00 N L100.00 1100.00 0.00 N Closest Position on well .*M-2'? EW MB TVD NS EW 0.00 E 0.11 0.11 61.18 N 0.00 E 99,97 99.97 61.19 N 0.00 E 200.00 200.00 61.17 N 0.00 E 300.27 300.27 61.03 N Ref : S07836.8MA 0.00 E 401.00 400.99 60.49 N 0.00 E 500.57 500.54 58.31N 0.00 E 599.28 599.23 57.10 N 0.00 E 699.27 699.21 56.10 N Distance Directio Between Between Wells Wells 0.00 E 799.52 799.43 54.75 N 0.00 E 900.37 900.26 53.14 N 0.00 E 'F...~75.00 974.88 51.82 N 0.00 E 975.00 974.88 51.82 N 78.69 W 99.67 N52 8W 78.66 W 99.66 'C N52 7W 78.47 W 99.49 < N52 4W 78.43 W 99.38 < N52 7W 78.32 W 98.96 < N52 19W 78.23 W 97.57 < N53 18W 79.34 W 97.75 N54 15W 81.10 W 98.62 N55 20W 82 74W. '--~'-~..... '-."--'~ ~ N5/_-. ~]~W 84.03 W 99.4:2 N57 ~w 84.48 W 102.24 N58 28W 84.48 W 159.62 N58 28W ERSTMRN CHRISTENSEN CALCULATION OF LEAST DISTANCE BETWEEN WELLS Position on welt M-5 MD ]'VD PIS EW MD Closest Position on well TVD NS EW 0.00 0.00 0.00 N 0.00 E -0. 100.00 100.00 0.00 N 0.00 E 100. 200.00 200.00 0.00 N 0.00 E 200. 300.00 300.00 0.00 N 0.00 E 300. 24 -0.24 65.87 N 1 () 100. ('z .... 9 A ~. '-;~..., ~= N 15 200.15 6..5.76 N 41 300.40 65.26 N Ref : S07842.8MA 400.00 400.00 0.00 N 0.00 E 3~. 500.00 500.00 0.00 N 0.00 E 4?7. 600.00 600.00 0.00 N 0.00 E 5~W. 700.00 700.00 0.00 N 0.00 E 67'~. 27 3~W.26 65.54 N' 75 4W7.72 66.32 N 08 5~8.?~ 65.W2 N 10 6~8.~4 63.37 N Distmnce Directio Between Bmt~een Wells Wells 800.00 800.00 0.00 N 0.00 E 7'~.)'.-:-'. ':.~00.00 '.-7~00.00 0.00 N 0.00 E 8'~'.--.~. 000.00 1000.00 0.00 N 0.00 E '.-:~'.:~'.-:~. 100.00 1100.00 0.00' N 0.00 E 1011. 77 77W.52 60.54 N ~0 87~.55 57.04 N 42 W~8.W5 53.1~ N 30 1010.81 52.73 N 77.87 W 103.53 N50 27W 77,,74 W 103.63 N50 27W 77.~4 W 103.51 < N50 33W 7W.~5 W 103.20 <5 N50 46W 7~.88 W 103.33 N50 38W 81.19 W 104.86 N50 45W 83.?5 W 106.74 N51 5iW 87.11W 107.73 N53 58W ERSTMRN CHRISTENSEN Position on well .M-5 MD TVD NS 0.00 0.00 100.00 100.00 200.00 200.00 300.00 300.00 400.00 400.00 500.00 500.00 600.00 600.00 700.00 700.00 800.00 800.00 900.00 900.00 1000.00 1000.00 1100.00 1100.00 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 CALCULATION OF LEAST DISTANCE BETWEEN WELLS Closest Position on well *M-30 EW MO TVD NS EW 0.00 E 0.13 0.13 69.97 N 0.00 E 99.96 99.96 69.91N 0.00 E 200.43 200.43 69.86 N 0.00 E 300.38 500.38 69.43 N Ref : S07988.8MA 0.00 E 399.67 399.67 69.80 N 0.00 E 500.00 499.97 71.52 N 0.00 E 599.38 599.34 72.41N 0.00 E 697.56 697.51 73.99 N Dist,snce Directio Between Between Wel 1 s Wel 1 s 0.00 E 795.23 795.10 76.70 N 0.00 E 895.76 895.54 79.30 N 0.00 E 992.00 991.73 81.21N 0.00 E 992.00 991.73 81.21N 78.00 W 104.78 N48 6W 77.85 W 104.63 < N48 4W 77.68 W 104.47 < N48 2W 77.63 W 104.15 <] N48 11W 77.13 W 104.02 < N47 51W 75.89 W 104.28 N46 42W 75.62 W 104.70 N46 15W 76.37 W 106.37 N45 54W 79.24 W 110.39 N45 82.47 W 114.49 N46 84.67 W 117.61 N46 12W 84.67 W 159.64 N46 12W ERSTMRN CHRISTENSEN Position on ~ell M-5 MD TVD NS 0.00 O. 100.00 100. 200.00 200. 300.00 300. O0 O. 00 N O0 O. O0 N 00 O. O0 N O0 O. O0 N CALCULATION OF LEAST DISTANCE BETWEEN WELLS 400.00 400.00 500.00 500.00 600.00 600.00 700.00 700.00 Closest Position on ~etl ~M-31 EW MD TVD NS EW 800.00 800.00 900.00 900.00 1000.00 1000.00 1100.00 1100.00 0.00 E 0.13 0.13 0.00 E 100.26 100.26 0.00 E 200.28 200.28 0.00 E 300.40 300.4(} 67.17 N 67.07 N 66.80 N 66,50 N Ref : S07936.8MA 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 402.14 402.12 0.00 E 500.91 500.86 0.00 E 600.70 600.65 0.00 E 701.53 701.48 65.16 N 62.82 N 61.89 N 60.89 N Distmnce Dir. ectio Between Between Wel 1 s Wel 1 s 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 801.55 801.48 0.00 E 901.03 900.95 0.00 E 927.00 926.91 0.00 E 927.00 926.91 59.34 N 57.98 N 57.67 N 57.67 N 70.48 W 9'7.36 N46 23W 70.56 W 97.35 <] N46 27W 70.37 W 97.03 < N46 30W 70.2? W 96.76 ,~ N46 35W 69.69 W 95.44 < N46 55W 69.14 W 93.42 ~ N47 45W 68.78 W 92.53 < N48 OW 68.43 W 91.61 < N48 20W 67.61W 89.97 < N48 66.91W 88.54 C N4.9 ;W 66.81W 114.59 N49 I2W 66.81W 194.29 N49 12W ERSTMRN CHRISTENSEN ' -'i -' . .:,T~4N _.E C. ALL...ILAT I L,N OF LEAST D I'-'" c , BETWEEN WELLS Re~ . S07991 ..:,MA P,:,mition ,:,n ~el] M-.5 Closest Positi,:,r, on well M-z..., M D T V D N S E W M D T V D N S E W Distance Dir. ectio Bet~eer, Between We 1 1 s We 1 1 s 0.00 0,00 0.00 N 0.()0 E 0.00 0.00 62.03 N 100.00 100.00 0.00 N 0.00 E 99.82 99.82 62.15 N 200.00 200.00 0.00 N 0.00 E 200.31 200.31 62.04 N 300.00 300.00 0.00 N 0.00 E 300.66 300.66 61.82 N 72.40 W 95.34 N49 25W 72.,55 W 95.53 N49 25W 72.40 W 95.35 < N49 24W 72.03 W 94.93 < N49 22W 4.00.00 400.00 0.00 N 0.00 E 400.53 400.53 61.34 N 500.00 500.00 0.00 N 0.00 E 499.82 499.74 59.23 N 600.00 600.00 0.00 N 0.00 E 599.78 599.39 56.37 N 700.00 700.00 0.00 N 0.00 E 699.52 698.84 63.02 N 800.00 800.00 0.00 N 0.00 E 801.68 800.95 64.92 N 900.00 900.00 0.00 N 0.00 E 899.08 898.30 66.15 N 1000.00 1000.00 0.00 N 0.00 E 1000.96 1000.08 62.68 N 1100.00 1100.00 0.00 N 0.00 E 1101.25 1100.3'7 61.91N 71.72 W 94.37 < N49 28W 73.26 W 94.21 < N51 3W 75.81W 94.47 N53 22W 73.0i W 96.45 N49 12W 70.42 W ~'= ~] ?.2.79 < N47, W 70.56 W 96.73 N46 51W 72.61W 95.92 < N49 12W 72.91W 95.65 < N49 40W 1200.00 1200.00 0.00 N 0.00 E 1200.88 1200.00 61.69 N 1300.00 1300.00 0.00 N 0.00 E 1300.56 1299.68 61.86 N 1400.00 1400,00 0.00 N 0.00 E 1401.25 1400.37 62.04 N 1500.00 1500.00 0.00 N 0.00 E 1500.71 1499.82 61.73 N 72.61 W 95.27 < N49 39W 72.66 W 95.42 N49 35W 72.63 W 95.52 N49 30W 72.62 W 95.31 < N49 38W 1600.00 1600.00 0.00 N 0.00 E 1600.67 1599.78 61.72 N 1700.00 1700.00 0.00 N 0.00 E 1700.86 1699.98 61.90 N 1800.00 1800.00 0.00 N 0.00 E 1800.79 17~9.90 62.11N 1900.00 1~00.00 0.00 N 0.00 E 1900.98 1900.10 62.10 N 72.88 W 95.51 N49 44W 73.00 W 95.71 N49 42W 72.99 W 95.84 N49 36W 73.21 W 96.00 N49 41W 2000.00 2000.00 0.00 N 0.00 E 2000.64 1999.76 62.00 N 2100.00 2100.00- 0.00 N 0.00 E 2101.34 2100.46 62.14 N 2200.00 2200.00 0.00 N 0.00 E 2200.69 2199.80 61.81 N 2300.00 2300.00 0.00 N 0.00 E .2300.80 2299.92 62.02 N 73.16 W 95.90 < N49 43W 73. ')~ W · (. --, W ~._,. 9 0 N 4 ;~ .. 73.01 W 95.66 7 .... C.~ W 81 N49 40W 2400.00 2400.00 0.00 N 0.00 E 2400.87 2399.98 62.20 N 2500.00 2500.00 0.00 N 0.00 E 2501.45 2500.56 62.22 N 2600.00 2600.00 0.00 N 0.00 E 2601.36 2600.47 61.81N 2700.00 2700.00 0.00 N 0.00 E 2701.38 2700.49 61.27 N 72.85 W 95.79 < N49 31W 72.87 W 95.83 N49 30W 72.40 W 95.19 < N49 31W 72.35 W 94.81 < N49 44W 2800.00 2800.00 0.00 N 0.00 E 2801.46 2800.56 60.57 N 2900.00 2900.00 0.00 N 0.00 E 2901.41 2900.51 60.19 N 3000.00 3000.00 0.00 N 0.00 E 3001.44 3000.54 59.81N 3100.00 3100.00 0.00 N 0.00 E 3101.35 3100.45 59.31N 72.04 W 94.12 <] N49 57W 71.61 W 93.54 <: N49 ~._7W' 71.34 W 93.C29 < N50 OW 70.?-~~~~R~~9 ,r_ N50 6W CHRISTENSEN Position on well M-5 MD TVD NS ~200.00 3200.00 3300.05 3300.00 5400.37 3400.00 ~501.25 3500.00 ~:602.98 3600.00 .~:705.90 3700.00 · ~:810.34 3800.00 0.00 N 1.26 S 5.05 S 11.39 8 20.35 S 32.00 S 46.46 S CALCULATION OF LEAST DISTANCE BETWEEN WELLS Closest Position on well M-25 EW MD TVD NS EW 0.00 E 2.30 E 9.21 E 20.77~ E 3201.42 3200.51 3300.87 3299.95 3400.57 3399.64 3501.58 3500.65 58.55 N 57.27 N 56.42 N 57.37 N 37.15 E 58.42 E 84.80 E 3603.40 3602.26 3702.55 3700.71 3800.00 3796.76 61.72 N 69.42 N 81.50 N Ref : S07971.8MA Distmnce Dipectio Between Between Wells Wells 70.88 W 91.94 < N50 27W 71.41W 94.12 N51 33W 72.31W 102.0~ N53 OW 71.58 W 115.16 N53 20W 67.06 W 132.66 N51 47W 58.42 W 154.72 N4~ 2W 47.35 W 183.98 N45 56W ERSTMRN CHRISTENSEN Position on well M-5 MD TVD NS 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 CALCULATION OF LEAST DISTANCE BETWEEN WELLS 800.00 900.00 1000.00 Closest Position on well ~M-32 EW MD TVD NS EW # 100. 200. :_--:00. O0 0.00 N O0 0.00 N 00 0.00 N O0 0.00 N 0.00 E 0.19 0.19 66.26 N 0.00 E 100.30 100.29 66.24 N 0.00 E 199.82 199.81 66.39 N 0.00 E 300.16 300.16 66.16 N 75.89 W 75.6i W 75.42 W 75.4(} W 400. 500. 600. 700. O0 O. O0 N O0 O. O0 N 00 O. O0 N O0 O. 00 N 0.00 E 401.45 401.44 0.00 E, 500.28 500.25 0.00 E 600.48 600.44 0.00 E 699.61 699.56 65.07 N 75.26 W 63.23 N 75.34 W 61.82 N 75.88 W 6C).90 N 76.48 W 61.03 N 79.09 W 61.81N 84.18 W 61.97 N 85.92 W 800. 900. 1000. O0 0.00 N O0 0.00 N O0 0.00 Iq 0.00 E 796.87 796.78 0.00 E 895.36 895.14 0.00 E 928.00 927.73 Ref : S07877.8MA Distance Between Wells Dir. ecti~. Between Wells 00. 00. 00. 00. 75 52 48 31 .::] .....] .::: N48 N48 N48 N48 .,1~-~ ", i. i 47W 39W 44W 99.50 ..'.'] N49 9W 98.36 .::] N50 OW 97.87 -{ N50 50W 97.76 '::.' N51 28W C)C'.,, '~ ~ '-::"--' ..... rY._, N.., .-'. 104.54 N53 43W 128.24 N54 12W ERSTMRN CHRISTENSEN Position on we 1 1 CALCULATION OF LEAST DI:STANCE BETWEEN WELLS Closest Position on wel i M-2 MD TVD NS EW MD TVD NS EW 0.00 0.00 100.00 100.00 · .-:()t 00 00 . ~ .) (.). 300.00 300.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E -0.01 -0.01 0.00 E 99.96 99.96 0.00 E 200.00 200.00 0.00 E 300.04 300.0:3 6. 6. 6. 54 6:.: 86 51 S S S S 400.00 400.00 500.00 500.00 .600.00 600.00 700.00 700.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 400.02 400.02 0.00 E 499.99 499.99 0.00 E 599.98 599.97 0.00 E 699.87 699.85 . 6. 7. 8. 28 50 14 06 800.00 800.00 900.00 900.00 1000.00 1000.00 1100.00 1100.00 0.00 N 0.00 N 0.00 N (}.00 N 0.00 E 799.42 799.36 0.00 E 898.36 898.07 0.00 E 995.68 994.72 0.00 E 1090.48 1087.90 10. 16. 27. 44. 63 92 78 52 4.94 E 5.11 E 5.59 E 6.0:2 E 1200.00 1200.00 1300.00 1300.00 1400.00 1400.00 1500.00 1500.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 1187.19 1181.39 0.00 E 1275.91 1265.15 0.00 E 1359.08 1341.60 0.00 E 1438.4B 1412.77 68. 96. 127. 160. 52 49 61 80 5.'75 E 5.2'7 E 4.77 E 4.34 E 0 i s t m n c e [ii r' e c t i c Between Between Wel 1 s Wel 1 s 8.20 S37 OE 8.41 S37 26E 8.85 S39 12E 8.87 S42 47E 8.51 < S42 29E 8.37 < S39 4E 8.58 S33 44E 9.15 S28 19E 8 4.26 E 17.55 S 6.77 E 29.08 S13 42E S 11.08 E 47.45 S13 58E S 16.78 E 72.96 SIB 46E S 24.90 E 105.57 S14 28E S 34.72 E 144.57 S15 13E 8 45.69 E 188.56 S15 52E ERSTMRN CHRISTENSEN Position on well M-5 MD TVI] 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. 500.00 500. 600.00 600. 700.00 700. 00 O. 00 N O0 O. O0 N 00 O. O0 N 00 O. O0 N 800.00 800.00 ?C)O.O0 ?00.00 1000.00 1000.00 1100.00 1100.00 1200.00 1200.00 1300.00 1300.00 1400.00 1400.00 1500.00 1500.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N CALCULATION OF LEAST DISTANCE BETWEEN WELLS Closest Position on uJe11 M-1 S"F ~1 EW MD TVD NS EW 0.00 E 0.04 0.04 7.18 N 0.00 E 100.08 100.08 6.77 N 0.00 E 200.06 200.05 5. S;S; N 0.00 E 300.01 2'~)'.-.-;. 9'.-.'; 5.4?) N Re~ : S06771.8MA 0.00 E 399.96 399.95 5.83 N 0.00 E 499.98 499.96 6.51N 0.00 E 599.99 599.97 6.89 N 0.00 E 699.92 699.89 7.2:3 N Distance Directio Betu~een Between Wells Wells 0.00 E 799.70 799.66 8.53 N 0.00 E 898.95 898.76 13.50 N 0.00 E 997.28 996.55 23.29 N 0.00 E 1093.82 1091.87 38.09 N 3.78 E 8.12 N27 47E 3.31E 7.53 ~ N26 3EE 2~53 E 6.50 E N22 52E 1.95 E 5.83 ,C N19 33E 0.00 E 1189.30 1185.06 58.29 N 0.00 E 1280.98 1273.06 83.20 N 0.00 E 1368.57 1355.51 111.89 N 0.00 E 1454.77 1434.85 144.69 N 1.67 E 6.06 N16 OE 2.30 E 6.91 N19 28E 3.01E 7.52 N23 35E 3.55 E 8.06 N26 8E 4.. 54 E 9.67 N28 A 12 E 14.o7 N24 ..._ 8.49 E 25.03 N20 2E 11.'F~3 E 40.73 N17 24E 16.45 E 62.38 N15 45E 22.60 E 90.33 N15 12E 29.42 E 123.95 N14 44E 36.85 E 162.90 N14 17E ERSTMRN CHRISTENSEN .=,TANL. E CALCULATION OF LEA'.:;T DI"' BETWEEN WELLS Position on well M-5 Closest Position on well M-1 ST $~1 MD TVD NL-': EW MD TVD NS EW O. O0 0. 100.00 100. 200.00 .----: '--'~'' .~ ~.~. 300. O0 :BOO. O0 O. 00 N O0 O. O0 N 00 O. 00 N O0 O. 00 N 0.00 E 0.04 0.04 7.18 N 3. 0.00 E 100.08 100.08 6.77 N 3. 0.00 E 200.06 200.05 5.99 N 2. 0.00 E 300.01 299.99 5.49 N 1. Re J:.' ::;067'72_ . ,_,'--'MA 400.00 400. 500.00 500. 600.00 600. 700.00 700. O0 0.00 N 00 0.00 N O0 O. O0 N O0 O. O0 N 0.00 E 399.96 399.95 5.83 N 1. 0.00 E 499.98 499.96 6.51N 2. 0.00 E 5~.~ 5~.~7 6.8~ N 3. 0.00 E 67~.~2 6~.8~ 7.23 N 3. Distance Dir. ectio Between Between Wells Wells 800.00 800.00 900.00 900.00 1000.00 1000.00 1100.00 1100.00 0.00 N 0.0() N 0.00 N 0.00 N 0.00 E 799.70 799.66 8.53 N 4. 0.00 E 898.95 898.76 13.50 N 6. 0.00 E 997.28 996.55 23.29 N 8. 0.00 E 1093.82 1091.87 38.09 N 11. 78 E 8.12 N27 47E 31E 7.53 < N26 3EE 53 E 6.50 < N22 52E 95 E 5.83 < N19 33E 1200.00 1200.00 1300,,00 1300.00 1400.00 1400.00 1500.00 1500.00 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 1189.30 1185.06 58.29 N 16. 0.00 E 1280.98 1273.06 83.20 N 22. 0.00 E 1368.57 1355.51 111.89 N 29. 0.00 E 1454.77 1434.85 144.69 N 36. 67 E 6.06 N16 OE 30 E 6.91 N19 28E 01E 7.52 N23 35E 5:5 E 8.06 N26 8E 54 E 9.67 12 E 14.87 N24 49 E ":' ?, ...... ' 0._-, N2~] ~E '?:2, E 40.7:':: N 17 45 E 62.38 N15 45E 60 E 90.33 N15 12E 42 E 123.95 N14 44E 85 E 162.90 N14 17E ,} ERSTMRN CHRISTENSEN CALCULAT I ON OF L_EA'.::T D I'-".:, rANt' BETWEEN WELLS Position on well 19-5 C 1 c, ~ e s t P o s i t i o r, c, n w e 1 1 G-- 1 '-' ~'l]'-.' MD TVD NS EW MD TVD NS EW 5';' 3 9.0 6 5 5 0 0.0 0 :,070 14 ~ ..... . ._~ 6 d"L). 0 0 Re~-" " '='( .... . . ..-., .)6 7(.)U 7MA DistAnce Directio Between Between Wells Wells ~'-" 1:34 '.":' 32'7. ,'-2:7 92".'.'. = .- .,- .... 1 E 17..., N47 OE · _, ;~(.). 1 ./:, SI .:, 7._,. 15 E 1 .=;._ ~..'-':' :36 'C N 47 :z: 9 E ERSTMRN CHRISTENSEN CALCULATION OF LEAST DISTANCE BETWEEN WELLS Positi,-,n or, well M-5 Closest Position or, well G-l'-""n"'....ru..,:: MD TV[; NS EW MD TVD i',IS EW :] 93 9.06 5500.00 i, 070.14 =-~-,' ' .J,:z 0 t). 0 (") 651..:,6 S /',92 ._. t')°o .:,'"' Re-F : :.-:~J67 .)~. ()MA Distance Dir. ectio Between Between Wel 1 s Wel i s ERSTMRN CHRISTENSEN Position on well M-5 CALCULATION OF LEAST DISTANCE BETWEEN WELLS Closest I=osition on well G-12RD2 MD TVD NS EW MD TVD NS EW 5~73'.~. 06 5500. O0 ~-,070.14 5600.00 651.36 S 692.08 S 1188.~'~ E 1263.32 E 7634.46 5532.~ 7753.30 5617.~3 Ref : S06705.7MA Distance Directio Between Between Wells Wells 521.84 S 1327.87 E 1~2.75 N47 OE 590.16 S 1375.15 E 152.36 ~ N47 3~E ERSTMRN CHRISTENSEN Position on ~ell M-5 MD ]'VIi) NS .700. O0 1'700.00 ,800.00 1800.00 · 900.00 1 '.~00.00 "000.00 2000. O0 0.00 N 0.00 N 0.00 N 0.00 N CALCULATION OF LEAST DISTANCE BETWEEN WELLS Closest Position on well RLF-1 EW MD TVD NS EW 0.00 E 1899.58 1753.09 56.34 N 0.00 E 1975.6'7 1809.33 94.60 N 0.00 EE 2050.08 1864.31 131.61N 0.00 E 21'22.61 1917.31 168.16 N Re~: : S07638.8MA Distmnce Dir. ectio Between Between Wells Wells 154.69 E 172.98 N70 OE 120.59 E 153.56 < N51 53E 86.76 E 161.62 N33 24E 5:3.35 E 174.84 N17 36E ERSTMRN CHRISTENSEN CALCULATION OF LEAST DISTANCE BETWEEN WELLS Position on well M-5 Closest Position on well RLF-1 MIl TVD NS EW MD TVD NS EW .300.00 1300.00 .400.00 1400.00 :500.00 1500.00 i600.00 1600.00 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 1653.77 1456.41 1702.76 1480.67 1752.09 1505.00 1801.41 1529.33 5.96 S 22.11N 50.68 N '79.26 N Rmf : S07644.8MA L700.00 1'700.00 0.00 N 0.00 E 1850.74 1553.66 Distmnce Directio Between Between Wells Wells 113.05 E 193.08 S87 OE 81.06 E 116.48 ~ N74 45E 49.05 E 70.71 < N44 4E 17.05 E 107.55 N12 8E 107.84 N 14.96 W 182.40 N 7 54W ERSTMRN CHRISTENSEN CHECK LIST FOR NEW WELL PERMITS Company ~or,/L=~ 63,7 Co, Lease & Well No. . . ITEM AP.PROVE DATE ~ NO (1) Fee ~ ' ~f/,~//~ 1. Is the permit fee attached .......................................... /(2 thru (3) Admin~F~ ~ 9. (9 thru 10. (10 and 13) 12. 13 (4) Casg ~..f%',/~ (14 thru 22) (5) BOPE ~~/,/2'.,¢...~'..'~' (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 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 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 ...................... 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 hav~a~nique 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 all casing give adequate safety in collapse, tension and burst.. 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 ~OO~$M~O psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER '(29 thru 3~)-- (6) Add: Geology: EngineerinE :__ 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 Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~o Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is acCumulated at the end of the file under APPENDIX. No speCial'effort has been made to chronologically organize this category of information. REC£ V£D ~laska Oil & Gas Cons. Anchorage * ALASKA CO~PUTING CENTER * ****************************** CUMPANY NAME : ~ARATHON OIL CO~'iPANY ~ELL NA~E FIELD NA'~ : TR&DI~G BAY BOROUGN : KENAI STATE RE~ .......... ~-~ NO : 73669 ICI OFII. MED ,I8 ~'ape verification I..,ist.i. nq ;chlUmher~'~er AlasKa Cor~o,.lt. ing Center SF'RVTCE ~E : E~b].i~ C~T~ : q0t03i~6 RFPL ~A~,~F : 73669 P~VIOUS REEL : CC~.MENT : ~APATHO~ [)1[, CD~4PA~Y,T~ADING BAY,~-5, APl ~50-733-204~3 **** TAPE HEADFR SERVICE NA~E : EDIT DATE : 90103116 T~PE NAME : 7:~669 CONTINUATION ~ : 1. PREVIOUS TAPE : COMMENT : ~ARATBD~ OIL COMPANY,TRADInG BAY,~-5, **** FILE HEADE~ **** FILF NA~E : EDIT ,001 SER'V!CE : FLIC VERSION : 001, A04 DAT~ : 90/03/16 M~X REC SIZE : 1024 FII, E TYPE : LO L~ST FILE : ******************************************************************************* ******************************************************************************** ** ** ** ** ** SCHhUMBERGER ~EL6 SERVICES ** ** ** ** ** ******************************************************************************* ******************************************************************************** COMPANY NAME.: MARAT}'~OM 016 COMPANY WFLL ', FI'ELD: TRADING BAY BOROUGH: KEN ii STATE: AI,..,AS K A bOCATION: 1037' F~h & 598 ~ FWb SECTIO~: 33 TOW?~SHIP: 9~ PERMANENT DATUM': MSh ELEVATION LOG MEASURED FROg'S' RKB 160 bEG 8-2 SL()T 11 RANGE: 13W ABOVE PERMANENT DATU~ ,IS Tape verifl, cation LI, stl. na ~chlumberger Alaska Co.'putinO Center 16=~AR-1990 18:43 E[,EVATIONS KB: 160 ******************************************************************************* DATE LOGGED: 2B-jAN-g0 RUN NUMBER: T~ DRILLE~: 970 I'D LOGGER: CASING: 30" ~ DRILLEP DEPTH OF 0 TO 480' AND LOGGER DEPTH OF 482' TYPE FLUID IN HOLE: SPUD MUD DENSITY: 9 F!bTRATE RESISTIVI'fY: 3,43 0 65 ~UD CAKE RESISTIVITY: 3,35 ~ 64 TI~qE CIRCULATION Ei~DED: 10:00 28-JAN TIME LOGGER ON BOTTO~: 12:30 28-JA~l MAXIMUM TE~P RECORDED: 76 LOGGING DISTRICT; '~613 I,,,OGGING ENGINEER: S~ITH ~,'ITNESS: ROY TCC]L NU~,~BERS: DIC 44 DIS-E 42 SGT-~;A 577 TCC-g 22 A~'{$ 968 TC~ 108 BGT 70! SGT-dC 1512 FIELD REd, ARKS: DATE JOB STARTED: 3-F~]B-90 dOB REFERENCE NO: 73.669 I,.,DP/ANA: KOHRING DATE bOGGED: 4-FEB-90 RUN NUMBER: 2 TD DRILLE~: 1450 TD LOGGER: ~,442 IS Tape Verificat,~on Listinq chlt]mberoer Alaska Computin~ (]enter 16-~AR-I 990 CASING: BIT SIZE: ],7.5" 9 !.450 TYPF FLUID ]t~ HO[,E: SPIED ~!OD DENSITY: 9,2 PH: 9,2 ~UD RESISTIVITY: 7,31 8 78 FILTgATE RESISTIVITY: 6,61 ~ 57 ~UD CAEE RESISTIVITY: 4,74 s 60 TIME CIRCULATION ENDED: ~0:30 4-FEB TI~E LOGGER ON BOTTf]i~q: 14:00 4-FEB ~A×IM[!~q TEMP RECORDED: 105 bOGGING DISTRICT: KENAi bOGGING ENGINEER: ~CCRO$SAN WITNESS: THOMPSON TOOL NUMBERS: DIC-E 44 SGT-SA 577 AMS 968 FIELD 20" ~a DRILLER OEPT~ OF 936' VISCOSITY: 54 DIS-E 42 TCC-A 22 THREE 3 INCE{ STANDOFFS RUN ON DiTE, TOOL RUN ECCENT~ALIZED ~6It~G BIGHOLE BOWSPRIMG, CONPUTI. NG CENTER RE?~ARK$: IT WAS DETER~,INED T'taAT THE RUN #2 bOG O,ATA WAS 1/2 FT TOE] SNAhhOW ...... ""R ' ' H~ T 0 5' IN RE,~E, ~,NCE TO T E,, E'RE~Ir,"~US RUN ~],, ~.}~EREFORE WAS ADDED DATE JOB STARTED: jOB REFiETRENCE N0: 7~669 LDP/ANA: KOH.~,ING ******************************************************************************* ******************************* RUN ~3 ***************************************** ******************************************************************************** D~TM hOGGED: ~4-FEB-90 RUN NUMBER: 3 TD DRILLER: 2650 TD LOGGER: 2646 C,~SING 1: ~I$ Tape Ver1~icat. lon Listinq ;chlumt:erger AlasKa Comput..1.~q Center 16-~t4R,..1990 18:43 PAGE~ BlT S~ZE 1: 17,5" BIT SIZE 2; 17.5" 1N HOLE: GEL X ~UD DENSITY: 9.3 VISCOSITY: 54 FILTRAblE RESISTTVITY: CAKE RESISTIVIYY: 4.2J0 ¢ 66 2,82 ~ 65 'I'I~,;F CI~CULAT!Ot~ EivDED: 08:00 14'FEB TT;'-,~E LOGGEF? Oi~ r~O'l!'I'O~i: ll:CO !.4-FE~.:~ LO(;~ I ,~,G DTSTi.~ICT: ~ OY !.,~ I C- E ,:.~ 4 SGT-SA 577 ~'~CD-G 8. 8 TCC-A 22 FIEL!) REMARKS: THREE 3 INCH STAN[)OFFS RUN 0~'~ DI. TE, TOOL RAN CENTRALIZE[~ CO~POTING CENTEI~ REMARKS: IT WAS DETERMINED THAT THE .RUN ~2 bOG DATA WAS 1/2 FT TOO SHALLOW IN REFERENCE TO THE PREVIOUS RON ~1 THEREFORE, 0,5' ~AS ADDED TO ALL bOG DATA DF RU~iS ~.2, ~3, & #~ AND 'rHO,.,..m' S S[]BSEO[IENT RUNS DO NOT ~ATCH THE FIELD PRINTS, THE CHANNE[..~ HD.DTE (HOLE DISOBEYER) EXISTS OVER RU~ ~.3 ONLY, NO AMS DA..AT ~AS bOGGED OVER RUN ~3, DATE JOB STARTED~ 12-MAR-g0 OOB REFERENCE NO; 73669 LDP/ANA~ KOHRING ******************************************************************************** ******************************** RUN #4 **************************************** ******************************************************************************* DATE LOGGF..D: RI,)N NUMBER: 4 TD DRILLE:Rt 5600 TD ..LOGGER CASIL~G 1: CASING 2: 20" M DRILLER DEPTH OF 9?]0 AND 50GGER DEPTH OF 926' '~ . '"~ ,.~ , .... 16" (a DRIL'£~ER DEPTH ~....~ 1440 AND bOt;GEF~ OEPTH OF 14~2' BiT SIZE 11 !,7 1/2" BIT SIZE 2: 17 i/2" ,IS Tape Verificatj. on Listinq ;chlumberoer Alask8 ComDut. inO Center 16-~AR-1990 DENSITY PH: 'VISCOSITY: 46 FLUID LOSS: 6,6 ~I~D RESISTIVITY: FILTPATE RESISTIVITY: 3.37 ~ 68 ],06 ~ 65 TI~E CIRCULATION EMDED: 02:00 25-FEB TIME LOGGER ON BOTTOM (DTE/SOT PASS): 11:19 25'FEB TI~E LOGGER ON BOTTO~ (LDT/C~.iL PASS): 1~:04 25-FEB ~AXIMUN TENP RECORDED: 120 LOGGING DISTRICT: LOGGING EMGI!~EE~: ~ITNESS: KENAI ~IbLER COX/WINDSTRUP TOOL NUMBERS (D'rE/SDT DIS-HC 42 SbS-V~ 26 SDC-C~ 14 TCC-A 1255 STM-CA 238 WD~-AA 491 DIC-EB 44 SbR-BB 44 SGC-SA 577 A~-AA 783 TCM-AB 278 DE[J-BAA 203 TO[~L NUMBERS (LDT/C~L PASS): DRS-B 4824 GSR-jD 7200 NSR-F 2513 SGC-SA 577 ~MM-AA 783 CPj-AAA 1BO NSC-E 789 CNC-HA 108 CNB-AB 3092 TCC-A 1255 TCM-AB 278 FIELD RE~,~ARKS: PH.ASOR RUN AT 20 K.HZ WiTH 3" STANDOFFS IN COMBINATION WITH ARRAY SONI'C. DTE/SDT G,R MISSINGTFO~ 32' AT. 5020' BECAUSE OF A LACK OF OVERLAP WHEN SPLICING TOGE HER FILES POR(]SITY RUN lin 2,65 G/CC ~ND SAND ~ATRIX, hDT/CNL/GR/AMS RUN IN' COMBINATION, COMPUTIMG CENTER REMA. RKS: IT WAS DETERMINED THAT THE RUN #2 bOG DATA WAS I/2 PT TOO SHALLOW IN REFERENCE TO THE PREVIOUS RUN $~ THEREFORE, 0 5' WAS ADDED TO ALL LOG DAT,A oF RUNS ~2, ~3, &.~ AND TflOSE SUB~EQU,E:NT RUNS DO ..... ~ "'~ ~ NOT MATCH TH~f FIELD.PRINTS. IN ADDITION T.~; bDT/CNL DATA 0~. RUN ~ WAS UEPT.H ADUus'rED TO MATCH THE DTE/S~T ' ...... PA~S USING THEIR ASSOC!ATED GAMMA RAYS FOR CORrELaTION, ", %8 h~NE;ISS PRUCESSED AT A. KCC: L!ST OF ARR.AY 50~',~IC wAVEF'OR~ PF,~OC~;J,;ING C~,~.A PAGE) ,IS Ta~e Verification Ll. stinq ;cblumberger AlasKaComDutin~ Ce.ter SHE,AR ~-~UALITY ~'LAG DATE JOB STARTED: 15-gAR-gO JO~ REFERE"JCE NO: 73669 LDP/AMA: KOHRING , * , , , , , , , * , , , , * , , , , FILE gARATHUN OIL CO~PANY TRADING BAY ~-5 50-7]3-20413 DATA SAMPLED EVERY -,5000 F~]EY DATA I NCbllDED TOOL EXTENSION T Y P E U $ E D DIT-E ,DTE PHASOR DIiAL INDUCTION SFb 5583' TO 482' RUN #4 DTE ~ERGED TO RUM ~3 {~2636' & GR ()~0~' Rt]:~,~ ~3 DTE ~.:RG,E[3 TO RUN ~2 ~a1433' & GR ~ 0 ' R[.J~q ~2 DTE MERGED TO RUN ~1 0950' & GR (~911' SDT .S.DT ARRAY SONIC 5551' TO 2624' , Sf]E AE{OVE REMARKS F6R 'LIST OF SDT CURVES PROCESSED (a~C * LDT ,LDT bll~{. [~ENSITY 5586' TO 26 * CNT-A/.O/H' ,CNL COMPENSATED NEUTRON 5570' TO 2624' * BGT ,SGT BOREHOLE GE;O~E:TRY TOOL 942' TO 390' ******************************************************************************* TABLE TYPE DEFI , OIL COMPANY Comp ~ Name ~ AADTH(~N',~.~A Y ~ame ~IS Tape Yerifi. cat. ion Listlng ;chlumberger Alaska Com~:uting Cer~t. er 18:4] PAGE~ 7 TI, J ~ I VAil] DEF I -~ ..................... .. .... . ........ ~-] ........ . .................... .. .... . ....... . ................ 0 7' FNL & 598' F~L Field Location SECT 33 Section ,ro,~ N 9N Township RA ~,~G 13~ Range C~UN KENA.I. County STAT ALASKA State or Province NaTl. USA Nation WI. TN COX/WINDSTRUP ~itness ' SON 548559 ServJ ce bider "'umber PD~T ~.~SL Par~,qa~ent datum EPD FT 0. APD FT i 6C EF B F'T l. 60: F. F: ~' F' T - g 99.25 ~:G~. ,'T -999.~5 P.[.,I FT 5588. 14otto~r LOO 'Interval ']'~.I F~' 2624. '].'op [..,gq ]nterv8l "t'CS O2:0(3 ~5-FE[~ Time CJ, rcu.l~tion Stoppec~ T~.~P ~. ~: l. ~ 25-~"~E~ Time ,..,.,. ~,,', f',epth Cn nne I LD IDPH IMPH IFRE i~OF' CIDP CIMP iIRD IIXD iIR~ T~NS H T ~ N DT D T ~ DTLN DTLF SFL Resi. stiv~ty (unaveraged) ~!ediu,~ In~Juction Standard Processed !~esistivity Deep Induc'tior~ Standard Processe(~ Resistivity Spontaneous Potential INDUCTION DEEP PHASOR RESISTIVITY INDUCTION MEDIU~ P.HASOR RESISTIVITY Induction Calibrated CreQueDc , IDQF DEEP .INDUCTION Q{JAI~ITY F~C!~OR IMQF MED INDUCTION QUAE, ITY FACTOR , ~ N INDUCTION DEEP PHASOR CO DUCTIVITY INDUCTION MEDIUM PHASOR CONDUCTIVITY [)eep Induction Real Intermediate Conductivlt¥ Deep I~dUCtion Quad Int. ermediate ConduCtivity ~edltlm Induction Real Inter~}edXate Conduct. lvlty Gamma Ray Tension Mud Temperature ~UD Res St, lvlty 8ole Diameter ~ead Tension DELTA-T DEbTA-T LONG SPACING DELTA-T LONG SPACING NEA~ DTLF ,IS Tape Verification Listing ;chlumberoer Alaska Computing Center 16-MAR-1990 18:43 PAGE: COST TT1 TT2 TT3 TT4 LTT1 LTT2 LTT 3 LTT4 WFC WFSM GR TENS ~TEF HTEN DT DTSP DTSN TENS OFCO QFSH R8~C OPM I L U L L blTH :SS2 SSHV C~LI HTEN NP.H~ COHERENCE VALUE AT STONELEY PEA~ CSAT TraDsit Time for CS~T 1 CSAT Transit TI. me for CSAT 2 CSAT Transit Time for CSAT 3 TRANSIT TIME 4 LONG SPACING TRANSIT TI~E MODE 1 LONG SPACING TRANSIT TI~E ~ODE 2 LONG SPACIMG TRANSIT TIME ~ODE 3 LONG SPACING T~ANSIT TIME MODE 4 Warning Flag For Compressional warning Flag For Shear Spontaneous Potential Gamma Ray Tension Mud Temperature MUD Reslsttv.lty Head Tension DELTA-T DTS~q DELTA-T DTS~ Gamma Ray Tension QUALITY FLAG COMPRES$IONAL QUALITY FLAG SHEAR RATIO SHEAR TO CO~PRESSIONAL DELTA T Density Poroslt~ Bulk Density Delta RHO Photoelectric Factor Ouality c.ontrol of ~onq spacin~ for bO~ Quali. ty control,, on hort S~acl g ~or LDT Long .Spacing Co~IPtlted Count Rate (LL+LU/2) Lon~ upper ~-2 ~,indow Count Rate (LUi+LU2) Lonq Lbwer Window Count Rate Lit~o.log Window Count Rate Short Spacing 1 '~indow Count Rate ShOrt spa ¢~n6 2 W'indow e Count Rat Long Spa l,ng"'Hlah V ].taqe Output Short Sp[ o ci.~o Hiqh Volt~qe LoOp OutPut:. Short Spacln~ 1 DenSi. tY Long Spacino"RHGB (Uncorrected) Long Upper RHC)B Ca.li~er Gamma Ray Tension ~ud Temperature ]gUD Res stlvit, y Head Tension Neutron Porosity Thermal Neutron Porosity ~IS Tape Yerification Listinq ;chlumberoer Alaska ComDutin~ Center 16-~AR-1990 TN Calib ted The I ,~ utron SPOR ~eutron Porosity Output From an Application ProQram RCN7 RCNT R¢~FT RCFT CNTC cN'rc CFTC CFTC GR Gamma Ray CALI Caliper T~NS Tension MRE$ ~UD Resistivity ~TE~ ~t]d Temperature HTEN Head Tension GR Gamn~a Ray C~ Caliper 1 - ] C2 Caliper 2 - 4 TENS Tension PAGE~ ** SET TYPE; - 6''~'' 4t,,t~ ** ''''''''''TYPE ~EPR~ COD'"~"'''';XE~:'" 1 66 0 2 66 0 3 73 376 4 66 5 66 6 73 7 65 8 68 0 5 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 ** SET TYPE - ---,,.,,,--,.,,-,,,,,,----.---,-------.-,---, ID ORDER ~: bOG T'¥PK CLASS ~IOD ~.,~B SA,~v~P EbE.~.~ CODE (HEX) [> K P T F T 54, 8559 00 000 0 o 0 1 1 1 4 68 () 000000000 SFI.,H D'i."F {D!..:~,~,~ 54~559 O0 (>O() O0 0 I 1 1 4 68 ()000000o00 I L ~,~ D T f~,; O ~{ .?: ~,~' 5,48559 00 0 :) 0 0 O 0 1 1. 1 q, 68 000 () 000000 .,.IS Ta~'e verificat, ion List_ir~rl ~ch].u~f, bergor Alaska Computinq Center ILD DTE OH,q:'4 548559 SP DTE ~v 548559 IDPH D'rE OH~M 5i8559 l~P~ DTE OHM~ 548559 IFRE DTE HZ 548559 IDOF DTE 548559 I~QF DTE 548559 C~DP DTE ~RO 548559 CI~P DTE ~HO 548559 I~D DTE ~i4HO 548559 XI×D DTE ~4~0 548559 IXR~ DTE ~HO 548559 ~R DTE GAP! 548559 TE~$ DTE LB 548559 ~TE~ D?E DEGF 548559 kBE$ DTE OH~ 548559 ~D ~TE IN 548559 HTE~: DTE LB 548559 D~ SDT US/F 548559 DTL SDT US/F 548559 DTLN SDT US/F 548559 DT~,F SDT US/F 548559 COHC SDT CO~S SDT COST SDT TT! SDT $ TT2 SDT S TT3 SDT S TT4 SDT US LTT1SDT US I,,TT~ BDT US 5TT3 SDT US LTT4 SDT US wFC SDT WES~ SDT SP SDT ~V 548559 548559 548559 548559 548559 548559 548559 548559 548559 548559 548559 548559 548559 548559 G~ SDT GAPI 548559 TENS SDT [,B 548559 ~TE~ SDT DEGF 548559 NRES SDT OH~ 548559 ~TEN SDT LB 548559 DT PTE US/F 548559 DT$~ PTE US 548559 OT ITP US/F 548559 DTS~ ITP US 548559 G~ GTS G,~PI 548559 TENS GTS LB 548559 OFCO REC 548559 QFS}'~ REC 548559 ~SHC REC 548559 ,'DPHI LD'r PU 548559 O0 000 O0 0 I 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 I 1 I 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 I I 4 68 0000000000 O0 000 O0 0 1 I 1 4 68 0000000000 O0 000 O0 0 i 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 I 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 O 1 1 1 4 68 0000000000 O0 000 O0 0 1 I I 4 68 0000000000 O0 000 O0 0 I 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4, 68 0000000000 O0 000 O0 0 I 1 1 4 68 0000000000 07 520 80 0 1 1 I 4 68 0000000000 07 520 80 0 ! 1 1 4 68 0000000000 07 520 80 0 1 1 1 4 68 0000000000 07 520 80 0 1 1 1 4 68 0000000000 07 000 O0 0 1 I 1 4 68 0000000000 07 000 O0 0 1 1 1 4 68 0000000000 07 000 O0 0 1 1 1 4 68 0000000000 07 522 83 0 ! I 1, 4 68 0000000000 07 522 83 0 1 1 I 4 68 0000000000 07 522 83 0 1 I I 4 68 0000000000 07 522 83 0 i 1 1 4 68 0000000000 07 522 83 0 ! 1 1 4 68 0000000000 07 522 83 0 i 1 i 4 68 0000000000 07 522 83 0 I 1 1 4 68 0000000000 07 522 83 0 1 1 1 4 68 0000000000 07 000 O0 0 1 1 I 4 68 0000000000 07 000 O0 0 i 1 ! 4 68 0000000000 07 010 01 0 1 1 I 4 68 0000000000 07 310 O1 0 I 1 1, 4 68 0000000000 07 635 21 0 l 1 1, 4 68 0000000000 07 000 O0 0 I 1 1 4 68 0000000000 07 000 O0 :0 1 i 1 4 68 0000000000 07 000 O0 0 1 I 1 4 68 0000000000 07 000 O0 0 1 1 1 4 68 0000000000 07 000 O0 0 1 I 1 4 68 0000000000 07 000 O0 0 1 I 1 4 68 0000000000 07 000 O0 0 I 1 1 4 68 0000000000 07 000 O0 0 i I 1 4 68 0000000000 07 000 O0 0 I 1 1 4 68 0000000000 (i) 7 000 O0 0 1, 1 1 4 68 0000000000 07 000 O0 0 1 I 1 4 68 0000000000 07 000 O0 0 1 !. 1 4 68 0000000000 42 890 O1 0 I 1 1 4 68 0000000000 ,IS Tape V'erifl. catlom Listinq ;chlumberger AlasKa Computi. nO Center 16-~!AR-1990 ~8:43 PAGE: 11, ID CRDER # LOG TYPE CLASS MOD N[i~B SAMP EbE~4 CODE (HEX) RHO G 42 0 0 0 1 1 68 0 0000 47 356 0~. 0 1 I 1 4 68 0000000000 DRHO LDT G/C3 548559 PEF LDT 548559 42 QLS LDT 548559 42 QSS LDT 548559 42 LS LDT CPS 548559 42 LU LDT CPS 548559 4~ /,L LDT CPS 548559 4~ LITH LDT CPS 548559 42 SS1 LDT CPS 548559 42 SS~ LDT CPS 548559 42 LSHV LDT V 54~559 4~ SSNV LOT V 548559 42 S1RH bDT G/C3 548559 42 LSR~ LDT G/C3 548559 4~ LURH LDT G/C3 5485'59 42 CALI bDT IN 548559 42 G;~ LDT GAPI 548559 42 TENS LD? LB 548559 42 MTE~ LDT DEGF 548559 42 ~RES LDT OHMM 54~559 42 HTE[ 5QT [.~B 548559 42 NPH! CNL PU 54~559 42 TNP}~ CNL PU 548559 42 TNR.~ CML 548559 42 NPOR CNL PU 548559 42 RC~T CNL CPS 548559 42 RCFT CNL CPS 548559 42 CNTC CNL CPS 548559 42 CFTC CNb CPS 548559 42 GR CNL GAPI 548559 42 CAI,,,I CN5 lin 548559 42 T~$ CNL bB 548559 42 ~RES CNL aHeM 548559 42 ~TE~ CNL DEGF 548559 42 HTEN CNL LB 548559 4.~ GR BGT GAPI 548559 76 C1 BGT IN 548559 76 C2 BGT I~ 548559 76 TENS SGT LB 548559 76 358 O1 0 I 1 1 4 68 0000000000 354 01 0 1 I i 4 68 0000000000 354 O1 0 1 1 l 4 68 0000000000 354 O1 0 1 1 I 4 68 0000000000 354 O1 0 1 1 1 4 68 0000000000 354 O1 0 1 1 1 4 68 0000000000 354 O1 0 1 1 1 4 68 0000000000 354 02 0 1 1 I 4 68 0000000000 354 02 O 1 1 1 4 68 0000000000 354 O0 0 1 1 1 4 68 0000000000 354 O0 0 I 1 1 4 68 0000000000 350 02 0 1 1 1 4 68 0000000000 350 02 0 1 1 1 4 68 0000000000 350 02 0 I 1 1 4 68 0000000000 280 O1 0 1 1. I 4 68 0000000000 310 01 0 I I 1 4 68 0000000000 635 21 0 1 1 1 4 68 0000000000 000 00 0 1 1 I 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 00 0 1 I 1 4 68 0000000000 890 00 0 I 1 1 4 68 0000000000 890 O0 0 ! 1 1 4 68 0000000000 420 01 0 1 1 1 4 68 0000000000 890 O0 0 1 1 1 4 68 0000000000 420 01 0 1 1 1 4 68 0000000000 · 420 Ol 0 1 1 1 4 68 0000000000 420 O1 0 1 1 i 4 68 0000000000 420 01 0 i 1 1 4, 68 0000000000 310 Ol 0 I I 1 4 68 0000000000 280 01 0 1 1 1 4 68 0000000000 635 21 0 i 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 00 0 i 1 1 4 68 0000000000 000 00 0 1 1 1 4 68 0000000000 310 01 0 I 1, I 4 68 0000000000 280 13 0 1 I 1 4 68 00000(,()000 280 24 0 1 ! 1 4 68 0000000000 635 21 0 ! 1 1 4 68 0000000000 DATA ** DEPT 8P DTE IDOF DTE IIRD DTE TENS DTE HTEN DTE ~,~41,500 80.000 3,000 104,188 9 0 0 , 0 0 0 1.131,000 SFLU DTE IDPH DTE IaOF DTE I IXD DT,E MTEM DTE DT 7,547 8 71.9 2 000 3 83O 117 50(,) 96 000 289 ILO DTE 8,492 .o .0o 0 l o:so0 301 ~[) DTE .-99 000 DT.hN SDT 78,200 ~IS Tar2e verlf, l..cattom Listino ;cblumberoer ^lasKa Computi. no Center DTLF.SDT 77.400 COHC,SOT TT ! . SDT O. O01 TT2. SDT [,TT1 .SDT 995.600 LTT2.SDT wFC.SDT 0.600 WFSH.SDT TFNS.SDT 3900.000 DT.PTE -999.250 9TS;~. PTE G~.GTS -909.250 TENS.GTS ~SFIC.REC -999.250 ')PHi.bDT ~EF. LDT -999. 250 0t, 8. LDT !,,,II. LDT -999. 250 LL. SS2.LDT -999.250 LSHV. i.,DT 1.SgN. bDT -gQq. 250 ~,~IRF{. LDT TE~S. LF, T -999.25 O ,qTE:q. :~[:Fi 1', CN T, -999.253 T!iPH, Ct..:L [~C~"'~ ,Ch'L -999.z5i.. GR,C~:[, -999.250 CAL, I.Cb~L C2. BGT -999. 250 'FCNS. 6CT 56O -38 10 357 98 7 99 357 -99 57 211 7 ! 74 10 11 -99 0. 000 0. 000 3,000 4,1~8 0,000 7 000 7 4:00 0 001 5 6OO 0 000 0,0o0 9,250 9,250 9,250 2,645 ,500 74 ' 750 1 959 4 000 7 456 8 249 ,4,875 8 , 625 9,250 SFLU. OTE IDPlf, OT.E; 1:i!4 O F, [ l E, IIXD ~,'!T E A~ ' .DT~ D'r SDT TT2,SDT t,'.r T SDT WFSH, 5DT '~" SDT D T $ M, P T E: T E~$, GTS DPB I . LDT 0 L $, L, O T LL. BDT SNV, LDT [! ~ H, L DT gTE~q, bDT T ['~t P H ~ C N L R. CFT, CNb CAB I, CN I..., ~ T E N, C N L TENS. 8GT 5so 9 18 354, 98 :10 121, 354 O, 6, O, 7, 4, 0. O, 4. oo 0 188 000 5O0 000 000 ]00 001 o00 000 000 16-HAR-1990 18:43 0,000 COHS,SDT 0,000 TT SDT 870,400 LTT3' 3,SDT 0,000 SP.SDT 117,5(}0 aDKS,SDT -099.250 DT,ITP -999.250 OFCO,REC -999.250 R}if)B,LDT -o99.250 ()SS.!,DT -999,250 LITH.LDT -999.250 SSHV.LDT -099.250 CALI.i~i)T -999.250 ~'~RES.LDT -999.250 TNRA.CNL -999.250 CF,!~C, CNL '999.250 TKI,JS. C~JL '999.250 '999.250 7,547 8.711 2,000 ,830 ,500 ,000 .000 ,000 ,400 000 50O 250 250 246 032 75O 000 954 625 479 517 '6~7 ,000 ,250 3 1.7 196 0 0 870 0 117 '999 -999 42 '""0 319 1207 90 311 5 -147 ,,999 000 ~00 9~? ,000 ,800 ,000 .6!3 I CI II D CO T LT RH L! SS TN CN TE I :IM C! II ~ R D CO T bT ~ R 5 4 0 16 117 1 O5 0 0 1014 10 1, I7 L !4, D T E P H, 0 T E D P, 0 T E R ~, D T E E:S,DTE TL, SDT MS'$DT T 3, SDT T3,SDT SiP, SDT ES,SDT DT, CO, REC 08, LDT SS, LDT T f"t, b D T HV, bDT LI, bDT ES, LDT R A, C N L TC, C.NL NS,CN'b GR, BGT L M, D T E PH,OTE DP, DTE R i~, 0 T E I!:$ DTE Tb SOT HS SDT T3,SDT T ], SDT SP ;SDT ES,SDT 0.00o 0.001 1.1.81.600 -3~0.000 2 301 -99q[250 -999,250 i999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25O -999.250 2999.250 999,250 8.289 8 438 114 750 113 938 2 301 95 000 0 000 0 00! 1181 600 -38O 000 2 ~01 -999 50 -999 250 1 953 -0 014 1 000 5 6~? 2 264 5 183 1549 224 2114 000 -999 250 4,762 4 809 209 125 197 250 2287 105 500 0 252 o 001 1419200 -96 188 2 287 COST 6DT LTT4.SOT GR.SDT HTE~.SDI' DTSg. ITF QFSH.~EC DRHO.LDT [,,S.LDT SS1.LDT S1EH.LDT C: R. I., 0 T HTEN. LDT ~,, P ('3 R. C N I, CFTC. CNL ~ES.C~L CI.BG~ ILD.DTE IFRE.OTE CI~P.DTE GR,DTE HD. DTE DTI,,~*SDT C05 8DT TT~:SDT LTT4.'SDT GR SDT ,HTEN SDT QFSH DRHO bOl bS bDT SSl bDT S1RS LDT GR LDT HTE~ bDT ~POR CNL CFTC CN5 CI..,gG IFRE TE CIMP ~TE HD,DTE DTLN"SDT COST,SDT TT4.SDT hTT4,'SDT GR.SDT HTEN,SDT PAGE: 0,000 648,800 1058'000 49.656 1131.000 -999'250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999 250 -999:250 -999.250 -999,250 -999.250 8,492 20,000 1'18,500 9,656 '97~250 0 .200 ,000 648,800 1.058,000 49 56 987 ~00 -999 250 -999 250 -0 015 , !25 2 018 104 875 - 000 304 261 2,264 '999,250 4 715 20 000 20'7 750 48 281 -999 250 105 200 0 679 688 400 121,~.200 48 281 987 000 12 ~IS Ta,.ep verification Listir~ .chlu~.berger Alaska Co~ptltino Center 16-~AR-.!990 18143 D~.PTE 104,652 DTSiq,PTE 999 GR.GTS 49,594 TENS,GTS ~560'' RSMC,REC -999,~50 DPHI.LDT 23 . PEF,bDT ~,484 OLS,LDT 0. LU.bDT 336.500 LL.LDT 196. SS~,LDT 310.000 LSHV.DDT 1~08. LSR~,LDT 2,246 I,URH.L~T 2. TENS,LDT 3054.000 izTEa.LDT 118. NPHI,CNL 2~,098 T~PH C~L 30 RCN~,CNL 327~,235 ~CFT:CNL 1030 GR,CNL 44,188 CALI,CNL 12 ~T~,CNL 118.962 HTEN.CNI... 543 C~.BGT -999,250 TENS,8GT -999 5400. !)TE -46, DTE O. DTE 163. DTE 3574 DTE 973: BDT 96. IDT O, DT 1.1115, SDT 0, SDT 3574, PTE 94, GTS 77, REC '999. bDT 3 LDT 264 LDT 298 LDT 2 LDT 3064 CNL 36 CNL 2493 BGT -999, 000 656 000 625 000 5OO 000 001 20O 000 000 964 5O ~50 205 500 500 000 072 1.50 :125 738 250 SFbU, DTE IDPH. DTE I?4OF,DTE I IXO, DTE a T E'~. DTE DT,SDT COHC. SDT TT 2. SDT LTT2 SDT NTK~ ~ SDT DT~M,PTE TENS GTS DPHI LDT Q!~S LDT Lh bDT bSRV LOT LURH LOT M T E ~ L 0 T T ~P'H CNL RCFT CNb C~LI CNL HTEN TENS 8GT DEPT. SP. IDQF, IIRD, TENS, HTEN. DTLF' TT1, LTT1, WFC, TEES. DT, RS~C, LU LSRH TE~S RCNT GR C~, OTE DTE DTE DTE SDT SDT s 0T SD ,T SDT PTE REC LDT LDT 5300 000 -93 3:!3 0 000 10 234 3594 000 969,500 247 '800 0,001 1129,600 0 000 3594[ 000 10.3 928 39 281 1 656 2 500 372 000 DEPT, IDQF' I I R D, TENS, }'t T E'N, DTLF, TT~. LTTI , WFC, TENS, DT, GR. RSHC 117. 96. 0. 0, 935, 1.17 '999: 3634, 13, 0 1208 2 11.8 37 637 1.2 606 -999 !.71. !58 0 1.15 99 0 0 950 10 27 '0 212 250 OT,ITP 000 OFCO,REC 379 RHOB,LDT Oll OSS,LDT 125 LITH.LDT 000 SSH~,LDT 256 CALI,LDT 962 MRE$.LDT 407 TNRA.CNL 503 CNTC,C~L 133 TENS.CNL 000 GR,BGT 25O 180 IL~ OTE 51.6 I~PH:DTE 000 CIDP,DTE 852 IIRM,DTE 838 ~RES,DTE 100 DTb,SOT 938 COHS,SDT 000 TT3,SOT 200 LTT3.SDT 000 SP,SOT 838 MRES,SDT 250 DT,ITP 000 QFCO,REC 249 RHOB:,LOT 000 OSS,hDT 500 LITE,bDT 000 $SHV,LDT 400 CALI,LDT 738 MRES,LDT 447 TNRA,cMb 465 CNTC,CNL 797 TENS,CNb 500 GR,BGT 25O oo0 375 000 157 669 900 8O3 0 O0 400 0 O0 50 ~0 .I.I.., ~ DTE IMPH DTE ClDP OTE IIRM DTE 6~RE$ DTE DTh,SDT COH$, SDT TT3, SDT LTT 3, SDT SP. SOT NtRES, SDT DT iTP QFCO REC RHOB bDT QSS LOT [,, I T~ LOT 104.652 0.000 2.264 0.017 122 438 . 1309.000 12.133 2.170 2 897 27941353 ~054.000 999,~50 5 289 5:348 181 250 1771875 2 191 95 800 o:96 0 o1 1308.000 -46.656 2~191 94,964 0 000 0,015 8(1,438 1309,000 12.797 2 168 3 394 21,91 248 3064 000 -999 250 1.73,750 241.750 6 313 5 480 2 215 96 800 0 485 0 001 1335 600 ~93 313 · 2 215 ~o~ ~ 'o gg 2 203 0 017 1.32 750 DTSM I. TP OFSH:REC DRHO.LDT LS,LDT SS1.LDT S1RM.LDT GR LOT HTEN!LOT NPOR CNL CFTC.CNL MRES CNL CI:BGT ILD,DTE IFR£.DTE CI~P.DTE GR,DTE HD,DTE DTLN,,$DT COST,SDT '' 4 · rr ,SDT bTT4 ,'SDT (; R,, S 0 T HTCN,SDT DTS~';. ITP OFSH.REC DRMO,LDT L $, L D T SSI.LDT S1RH LDT GR LOT ~TEN LOT NPOR CNL CFTC CNL MRE8 CNL C 1 BGT ILD.DTE IFRE,DTE CIMP~,DTE R,DTE D,DTE DTL~.,SD~ COS 'SDT TT4~SOT bTT4,SDT (;R,'SDT DTSM.ITP: QFSH,REC DR.HO.bDT t;,,$,LOT SS1,LDT PAGE: 13 -999,250 10.000 0 364:500 209.625 2,215 44,~88 543 OOO 28 9]9 970 755 2 170 -999 250 5 316 2O 000 186 875 77 563 -999 250 95 100 0 811 640 000 !132 000 77 563 93 500 -9~9 250 lO 000 0 025 278.750 2O7 50O 87 . 606 500 37 088 655 089 99 500 20 000 4 13.3 ,40 156 -999 250 106 300 0 807 651 200 1125 600 40'156 969,500 1:72,141 5.000 206 ,750 ,500 ,IS TaDe verification Listinq ichlumherger Alaska Computin~j Center S52.LDT 308.500 q . _ [.~c M v LOT LSRH,LDT 2.~95 bUR.q, bDT TENS.bDT 3110,000 ~TE~4, LDT NPH!,CNL 17.297 T~}PH,CNL RCNT,CNL 3734.530 RCFT.CNL GR.CNL 40.000 CALI CNL ~TE~C~, C~L 118 .344 HTE~4~CN,L_r .BGT -999.250 TENS,BG DFPT, 5200,000 SFLU.DTE SP.DTE -27,766 IDPq.DTE IDOF,DTE 0,000 IIRD.DTE 79.68~ IIXD,DTE TE,~S.DTE 3490.000 ~TE~,DTE }~TEN.DTE 94~ .500 DT,SDT DTLF,SDT 91,600 C~]BC. SDT TT1 ,SDT O, 001 TT2,SOT ~TT1 ,SDT 1108,800 bTT2,SOT WFC,SDT 0.000 ~;FSH, SDT T~NS.SDT 3490,000 DT.PTE 89,702 [)TSM, PTE GP.GTS 93,625 TE~,~S, GTS R¢~C,RFC -999,250 EF,LDT 3.4'51 OhS. l~! LOT 248,375 LL~L[)T L[)T 292 750 LSHV.LFT LS~ H, .,,.,,,., 2,434 LUR~'{. LDT TENS.L. DT 30~t, 0.000 RCa~:"'.CNL 267. 8., 182 RCFT,'CNL GR,CNL 97,125 C~'SGT -999.250 TEi~S, BdT ,OF, PT, SP ' DTE IDOF, DTE I IRD, DTE TE~$, DTE HTEN ' DTE D T L F, S D T TTI. SDT ,..~ ,, 1,SDT WFC SDT TENS SDT DT PTE RSP~C. REC ~ E F ' L a T LU LDT 882 bDT LSRH bDT TENS bDT RCNT CML 5100, '21, O, 85, 3354 1004 257 0 !!8~ 3354 ~99~ 307 2 3029 29 2904 000 844 O00 313 O00 5OO 7OO OOf 6OO 000 000 581 938 25O 236 234 O68 3O5 563 510 1.25 1.6-MAR-1990 18:43 1208,000 SSHV,LDT 2.197 CALl,bDT 118,344 t~RES,bDT 17.547 TM~.CMb 1727 2~0 CMTC,Ci~L 12i070 TENS.CNL 583 500 GR,SGT '999,250 0 11, O. 1. 117. 93 o: 0, 925. 10. ~999, 440. 10 1207 2 1.17 35 13 613, -999, 11. .11' O, 6, 1,1.6, O, 0, 990, 116 ~0 172 1208 2 976: 945 !L~,OTE 047 IMPH,DTE 000 CIDP.DTE 671 IIRM,DTE 444 ~R~S,DTE 900 DTL.SDT 931 COHS,SDT 000 TT3,SDT 200 LTT].SDT 000 SP.SDT 444 .~ES,SDT 25(I UT . ITP 000 OFCO, R .,u 501 RH[)B, bi r 001 QSS, I.,DT 125 !,, I T F,. L D T 000 SSHV"LDT 441 CALI,LOT 8 3 8 ~ ~ E S. L O T 161 TMRA,CNL 613 CNTC,CNL 000 G R, B G'r 250 0,47 0,47 OUO 48O 88 :I 600 826 000 000 000 881 25O OOO 582 OO4 ,520 000 8O3 543 000 IL~,DTE i~!PH,OTE CIDP,DTE iIR~,DTE T ~RE$,DE DTb~SDT T..3',SDT LTT3,SDT SP,SDT ~ES SDT DT ITP OFCO REC RHO.8 bDT QSSLDT LITH bDT SS~V bDT CALI bDT MRES bDT TNRA,CNL CNTC,CNb 1309,000 12.070 2.164 2.108 3373.089 3110'000 '999.250 10.328 10 547 90 438 91 625 2 166 93 700 0 250 0.001 1296.000 -27 766 2~166 89.702 0.000 2.476 0.018 71...438 1309.000 1.3.875 2'193 3,:378 23'17.586 040,000 999,250 Il, 273 11 602 90 438 83 938 0 250 0 001 1379 ~00 -21 844 2 8 104 [6 0 000 2 343 0 6 1,309 879 13 232 2656 781 StR}f,LDT GR,LDT MTEN,LDT NPOR.CML CFTC.CNL ~RES,CNL CI.BGT I LD. IF[~E.DTE CiMP,OTE GR. DTE HD.DTE OTLN.SOT COST.SOT TT4 SOT !.,TT 4: SDT (;~. SOT Fi T ~', ~. S D T OFSH. REC t,) a H 0. h D T [,S. LDT SSi .LOT $1 a}~, LOT d~ . LDT H. TEN. hOT el,aG !LD,OT.~ IFRE.DT CI~P DTE GR DTE DT~ SDT COST SOT TT4 SDT LTT4 SDT GR 'SOT OFSH REC DRHO LDT bS LOT $'$1 bDT $1RH LOT GR bDT ,HTEN.~DT NPOR, .NB CFTC,CNL PAGE: .14 2 207 40 000 583 5OO 18 077 1672 229 2 164 '999,250 11,148 20 000 94:750 92.188 -999 250 92 100 0977 632 800 1105 200 92 188 941,500 -999.250 10,000 0,030 260,250 206,375 2.348 97.125 613,:000 35,237 733,521 2,193 '999~250 10 680 2O 000 86 188 8.2 ~5 ~999 105 ?00 0 54 683 ~ 00 5OO ,o 325 637 2!3 209 2 226 79 66O 66~ 439787 9~8,75~ ,IS Tape Verification Listinq ichlumberoer Alask:a ComPuting Center GR,CN[, 79.660 CALI,C~tL ~TE~.CNL 116.803 HTEr~ . CMl.., C2.BGT -999,250 'r.ENS. i]GT DEPT. 5000.000 SFLU.DTE SP,DTE -33.094 IDPH.DTF. ID(IF,DTE 0.000 I~OF.DTE IIRD.DTE 94,060 IIXD.OTE TENS DTE 3434,000 ~TEM. DTE HTEM :DTE 937,000 DT'SDT DTLF,SDT 101 600 COMC,SDT TT~ .MDT O:O01 TT2.SDT LTT1 .MDT 1192~ 400 LTT2, MDT WFC,SDT 0,000 wFSH.SDT TENS,MDT 3434 000 MTE':~ MDT GR.GTS 86 500 TENS.GTS RSHC,.REC -999: 250 DPHI, LDT PEF, LDT 3. 236 OLS. LDT LU. LDT 290,961 LL, bDT SS2,LDT 307.135 LSHV I,,DT LSRH. LDT 2. 333 ~IJR~ ~ ~DT TENS,bDT 2749.375 ~TE~.~: LDT NPHI,CNL 29,088 TNPH CML RCNT,CNL 2925,500 RCFT,CNL GR,CNL 90,691 C.~%L I, CNt~ MTE~,CNL 116,319 4,FEN CML C2,RGT -999,250 TENS,BGT OEPT, SP' DTE IDOF, D ' I IRD DTE TENS DTE PITEN DTE DTLF MDT TT 1 MDT LTT ! MDT WFC'SDT TENS, MDT DT, PTE GR, GTS ' P E F ,, L D T ,LU. LDT SS~, LDT b~RH. bDT TENS, LDT NPHI ,CML RCNT, CML GR, CN'L MTEM~CNL C2,BGT 4900,000 '52,500 0,000 8,547 3364,000 99t~,500 1!6,000 0 001 1~99 600 0 000 3364 000 ~44 -999'250 2,291 375,359 310,965 2 ~4 2970 625 21 38,4 3419 188 45 152 115 652 -999 250 SFLU.DTE IDPH,DTE IMOF,DTE II, XO OTE MTEM DT£ DT 8DT COHC SDT TT2 SDT LTT2 SDT wF'SH MDT ~TEMSDT DTSa PTE TENS GTS DPHI LDT QLS,LDT LL, LDT LSHV, bDT L U R H L D T a T E ~ b D T TNP~ CML RCFT CML C,~LI CML HTE~ TENS,SGT 16-~AR-~, ggO 18:43 13.232 TEHS,CML 662,43~ GR.{~GT -999.250 ~,820 9.875 0.000 7,156 116.150 106,700 0,896 0,000 996.400 3 000 116 150 -999 250 3414 000 17 425 -0 1207,230 2,342 129,382 95 6 614 078 -999 250 90.750 127,250 0,000 0.384 !.15;925 1,29.000 0,840 0,001 i179,600 10,000 115,925 ~99 250 .000 8 258 0 007 220 571. 1207 857 :1,15 652 22 808 1308 031 12 117 609 859 ~999 250 ILM,DTE IMPH,DTE CIDP.DTE IIR~.DTE MRES.DTE DTL.SDT CUMS,SDT TT3.SDT LTT3.SDT SP.SDT MRES.SDT DT,ITP QFCO,REC R~O~, I~DT QSS, LDT [.., I T ti, b D T SSH'V,bDT CALl,bDT ~RES,bOT T~!RA.CML CNTC~CNL TENS,CML G~,BGT 3029 563 ~RES.CNL -999:250 Ct.BGT 9,648 II.,D,DTE 9.'727 IFRE DTE 101 188 CI~IPiDTE 98~000 GR DT~; 2 238 MD DTE 103:700 DTLN SOT 0,000 COST!MDT 0.001 TT4 SD~ ~].094 G~ 2 238 HTEN SDT 98 624 DTS~ ITP 0 000 GFSH.REC 2 362 DRHO,LOT 0 009 l,S LDT 85 087 SSI':LDT 1309,000 S1RH,LDT 13,026 GR,LDT 2,205 HTEN.LDT 2.920 NPOR.CNL 2634,094 CFTC.CML ~749.375 MRES,CNL 999.250 C1,BG'I 1!2.563 3 117 8 2 121 0 0 161,8 -52 2 461 GR 197 HD 400 DTI, N 315 COST 001 TT4 000 DTT4 500 GR 197 HTEN IbD DTE DTE DTE OTE DTE SDT SOT ,SDT SOT SDT 129 0 000 2 184 DR~O 0 000 LS 1,44 500 SS~ 1308 857 SIR 2 ;382 NPOR ~998 688 CFTC 2970 625 MRE$ -999 250 C1 227 DTSM LDT ,,hOT LDT LDT bDT CML CML .C'NL .BG'I PAGE: 15 2 170 -999:250 9 586 20 000 102 750 86 50O -999 250 101 900 0 963 688 000 1184 000 86 500 937 000 -999 250 10 00o 0 017 308 441 209 19] 90 . 614 078 ~9 986 927 375 . 2205 ~,999 250 107 688 4996,9 -999 ~50 119 ~00 0 922 ~795 600 1398 000 49 96 998 o 4 152 6~ 656 .2 214, -999:250 .IS TaDe Verification ListJ. r:g ich]umberger Alaska Computing Center - . DT E DEPT. 4800.000 SP.DTE 15.109 IDPH.DTE IDOF.DTE 0.000 I~OF,DTE IIRD.DTE 16o84~ IIXD.DTE TENS,DTE 3314.000 ~TEM,DTE ~TE~,DTE 948,000 PT.SOT DTLF,SDT 131.300 CDHC.SDT TTI.SDT 0,001 'FT2.SDT bTTIoSDT 1478.400 LTT2.SDT WFC SOT @.000 ~FSH.SDT TEN$iSDT 3314,000 >~TE~.SDT DT.PTE 123,557 DTS~.PTE G~.GTS 1g.313 TE~.$,GT$ RSHC,REC -999.250 OPHI.~DT PEF.~DT 1,217 Qb$.LDT LU,LDT 1~32,438 LL.LDT SS2.LDT 412.6~0 LSHVoI...OT ~SR~,I. DT 1,3~3 bURH.LDT T~NS.LDT 3051.125 ~PHI,CNI... 71,591 TNPa. CNL RCLT.CNL 1552,875 RCFT ,CNL 114,969 gTEN,~N'L C2,BGT -999,250 TENS,OGT DEPT IDOF Il. RD HTEB:, DTLF TT1 LTT1 WFC DT PEF L U TENS ~ P H l: RCHT DS~PT SP IOOF I IR,[" 4700.000 ~,. LU,D E 'DTE. 13,336 IDPH,DTE ,DTE 0,000 IMQF,DTE · DTE 29,609 .IlXD, DTE ,DTE 3474,000 ~TE~' DTE ...... "' DT ,OTE 1014,500 DT~S . .SOT 79,000 C(3HC, SOT ' S D T 0,001, T T 2, S D T 'SOT 1328,400 LTT2, SD.~ 'SOT 0,000 WFSH.SD , : ~ ' , SOT 3474,000 aTE~, SOT , PTE 105,491 DTSM, PTE GTS 36,250 TENS.GTS R E C 1.6 ~ 2 D P ~ ,l, L [> T LOT 2,859 OLS, bDT ~DT 32~.287 LL.LDT DT 30 ~357 LOT 2,270 I, tlRH,LDT . L D T 287.4.844 ~ T E ~. L D T . C 71 b 2 2.8 1 4 T :'.'~ 'P H, C ~ L i:~ L 3542.625 R C F T. C ~l L ~l~L 37,563 CALI CML ~% G T - 999.250 T E N S, B G T 16-~*AR-1.990 18:43 207.875 IL~,D'rE 83,375 I~PH,DTE 0.000 CIOP,DTE 1,604 IIR~,OTE 115,588 ~.~RES.DTE 144.200 OTb,SOT 0.250 COHS,SDT 0,001 TT3.SDT 1218.400 LTT3,SDT 0.000 SP SOT 115,5~ ~RETiSDT 99.250 DT,ITP ;~b0,O00 ~FCO.REC 79,337 RHOB,LDT 0,004 DSS,LOT 955 859 [.ITH,LDT 1204:000 SS~V,t. DT 1.366 C~LI,bDT 114,969 MRES.LDT 86,646 TNRA,CN'L 275.563 CNTC,C~5 737, 5 GR,.~G -999,250 2~,156 3 ,156 ,6 ! ]oo 0 0 000 1093 200 10 o00 114 74:4 '999 250 34~.4 0£1'0 1 772 O, 1208 000 2 280 14 1.~67 313 12 273 593 855 -999 250 232.750 105,438 0.000 3,557 I l.. P~I, UTE I ~i P ~,~, DTE CIDP. OTE :I IR i~, t)TE 59,094 76 875 11:984 16,109 2.201 129 100 0 001 1734:400 1.5,109 2.201 123 557 0 000 1 341 0 000 774 357 1309 000 17 ]66 2 211 5 405 1382 227 305 125 .994: so 29 422 30 234 29 250 32 281 2 188 116 600 0 255 0 001 1563 200 1~ 336 105 491 0,000 2,291 0,0i7 110,652 1309 000 12.273 2,211 2.482 159,094 874.84.4 999,250 1~7,375 157-625 9,477 8.109 ILD,DTE 1FRE,DTE CI~P,DTE GR,DTE BD.DTE DTLN.SDT COST.SOT TT4,SDT LTT4,SDT GR.SDT HTEN,SDT DTS~ DRBO.LDT I.$.LDT SB1.LDT S1RH,LD? GR,LDT HTEN,LD? NPOR.CNL CFTC,CNL ~RES,C~L C1,BGT :I LD, DTE IFRE.DTE CIMP,DTE GR.DTE MD,DTE [:) T,[.. N ,S D ? COST,BDT LTT4 DT GR,$DT ,HTE.~ .SOT (,',].F $ H ,~ E C o R H 0, L D ~ LS, LDT SSI"LOT S 1 RH. GR, LOT H TEN:. LOT ~ P 0 R, C :N L C F'I;C, C,~ L CI,,SGT I[.D, i F R g, D T K C I'~P, G R, D T E PAGE: 58 875 20!000 13 000 20,141 -999.250 131 800 0 910 799 600 1476 400 20 141 948 000 -999 250 10 000 -0 005 1872 156 232 232 ! 364 20 992 737 875 86 963 274 070 2,211 -999,250 30 406 20 000 33 031 34 313 -999250 11.9 800 0 749 730 005 131~31200 1014 50~ 1,71 0 010 ~47 ~21 209 446 2 2~2 59'3 855 23 611 1306 406 2 211 -999 250 69,31,3 20 ,~00 6' 36 1,5,14~ 16 Tape Verification List. lr~q ichlumberoer AlasKa Com~utinO Center TBNS,DTE 3384,000 ~TEM,DTE H%EN,DTE 1028.000 DT.SDT DTI..F,SDT 133.000 CyHC.SDT TT!.SDT 0.001 T2.SDT LTTI,$DT 1482 800 LTT2.SDT WFC,SDT 3:000 WFSH.SDT T~S.SDT 3384.000 ~TEM,SDT DT.PTE 129,750 DTS~,PTE G~.GTS 14.922 TENS.GTS RSHC.REC -999.250 DPHI,LDT PEF,LDT 0.529 QLS.I,,DT LU,LDT 2094,000 LL,LDT SS2,LDT 416,750 bSHV.LDT LSRH.LDT 1.301 LURH.LDT TENS,LOT 2790.000 STEM,LOT NPHI.CNL 77,135 RCNT.CNL 16!0 599 RCFT,_NL G~,CNL ~6:547 CALI,CNL MTE~.CNL 113,450 HTEN CNL C2'BGT -999.250 TENS:BGT DFPT, SP, L PE IDQ. F.DTE I IRD, D..-TE TFN'$ DTE HTE~ DTE DTLF SDT TT1 SOT LTT1 SDT WFC SOT TENS SDT DT PTE GR GTS RSHC REC PEF LDT l,,,U LOT $S~ bDT LSRH, LDT TENS, LOT N P H I, C N b RCNT,CNL GR, ~NL C2,B,,T 4500 0 224 3160 1031 122, O, 1,374, O, 3160, 120, 40 -999 2 .312 2, 2705, 1,9. 3832, 39, 1.11, '999. 000 SFLU. 645 IDPH 000 IlXO, 000 STEM, 000 [ 700 COHC,. O01 TT2, 800 LTT2, WFSH, 000 000 M T E ~', 741 D r S,~, 875 TENS, 250 DP~I, 399 QLS.~ 914 Lb 556 91 LURH 592 T N P H 563 RC'FT 39 C A L ~94 HTE~ 250 TENS [> T E DTE DTE DTE DTE D' S ~ SDT SDT SOT SOT SDT P T E GTS L D T bDT b D T LDT b [) T L D T CNL CNb ~ G T 4400, 22, O, 50. 31,84, 969 120 0 137.6, 000 641 ~. 00 50 000 90O O01 400 16-aAN-199() 18:43 11 ,~3 120 1 11 -99 339 102 120 11 9 25 1 60 -99 2 11 12 0 1132 10 113 -999 214 1,207 11 2 lz~9 1. 61 ,1 1 1.13 4 238 5:700 0.250 0 00f 0 0 4 238 9 250 0 000 1 862 0,035 0.000 4,000 1,300 3.450 2.793 2,644 2,930 1.500 9.250 7,891 3,879 0,000 9,516 3,450 6,300 0 92! 001 40O 000 450 25O 000 081 006 94i 000 2 1~5 1 806 656 2 266 8 000 9 250 4,758 7,578 0,~00 1, 34 3,169 3,200 0,845 0,001 8,000 DTI.SOT COHS.SDT TT3,SDT LTT3,SDT SP.SDT ~RES,SDT DT,ITP OFCO,REC RHO8,bDT OSS LOT LITH:GDT SSHV,LDT CALI.LDT MRE$. LOT TNRA, CNL CNTC,CNL TEN$.C~L GR,£~GT IMP~,I.)TE CIDP,DTE IIRM DTE ~RES DTE DTb SOT COMS SDT TT~ [,,TT3 SDT S~,SDT NRES,SDT T DT, I ~ P QFCO, REC RHOB bDT QSS LDT bITS bDT SSHV bDT CALl.bDT MRE$,LDT TNRA,CNL CNTC,CNL TENS,CNb GR,BGT I b~, OTE :Ii ~ P H ' , DTE CIDP DTE IIRM DTE ~ES DT£ DTL SOT COHS SOT TT3 SOT [,TT3 SOT 2 186 133:500 0 325 0:001 1746.000 52.813 2,186 129.750 0 000 1:299 0.000 1158.000 1308 000 12i930 2 211 5 591 1.390 007 2790i000 -999 250 4.043 4 O98 257 750 231 625 2 21! 122 800 0 325 0 001 1612 400 1 645 2 211 120 741 0 000 2 203 0 015 !36 708 1308 000 1~ 266 242 2 266 3313 000 2705 336 -999 250 14,148 14,023 56,844 67,000 0.556 0,001 1619,600 UD,OTE DTLN.SDT COST.SOT TTI,SDT LTT4.$DT GR.SDT HTEN.SDT DTSM.iTP QFSH,REC DRHO.I,DT LS,LDT SS1,LDT S1RH LOT GR:LDT HTEN,LDT NPOR.CNL CFTC,CNL NRES,CNL C1,BGT IbD DTE IFREiDTE CIMP DTE GR.,DTE HD.OTE DTLN"SDT COST,'SDT TT4,SDT LTT4,SDT R.,SDT HT N,SDT DTSM,ITP OFSH.REC ORHO,I..,OT bS*LDT SSI.,LDT $1~H,LOT _ GR,L, OT HTEN.LDT NPOR'CNL CFTC,CNL MRES,CNL CI.,BG~ ~I~D,DT~ IBRE,DT CIMP.DTE GR"DTE ,HD'DT,~ D]~LN.;SD TT4"$DT T MDT PAGE: 17 -999 250 134:100 0,852 791,200 1416,800 5,148 1028 000 -999 250 10 000 -o 004 2066 000 232 875 I 316 16 54? 601 500 9O 457 270 959 2 2~ -999 250 3 797 20 000 243 875 40 313 '999 250 123 300 0 670 760000 !372 000 40. 313 1031000 "999,250 ,10,000 0,000 40~.,492 208 27 9 20 27 1477 ~7:0 17,281 20,000 .71 25O 63 75O '999 250 117 600 0 81 763 ~00 I37~ 200 ,IS TaDe Verlficatlon Llstln(j icblumb, erger AlasKa Computlnq Center WFC,SDr 0.000 WFSH.SDT TENS,SDT 3184,(,00 ~TEM.SDT DT.PTE 120,170 G~,GTS 62,906 TENS,GTS RSHC.REC -999.250 DPHI.LDT PEF. LDT 2 587 LU, IoDT 395 .' 891, LL, bDT SS2, LDT 313; 139 [,SHV. LDT LSR~.LDT 2,1.53 Lt!RH,LDT TEN$.LDT 2655.547 ~TEM. LDT NPHI,CNL 22.,41~ TNPH CNL RCNT,CNL 3344,250 RCFTiCNL GR.CNL 60,260 CALl CNL ~TE~,CNL 111,563 HTE~!,CNL C2,BGT -999,250 TENS.BGT DEPT SP TENS HTEN DTLF TT { L T T 1 W FC TENS DT G~ RSHC PEF L U NP~I RCNT MTE~~ C2 . 4300 .DTE 'DTE 0 .DTE 12 . DTE 3134 . DTE 1012 'SOT 117 , S D T 0 ,SDT 1,416 .SDT 0 , SDT 3 134 ,PTE 113 GTS 42 REC -999 bDT 2 LDT 430 bDT 31 ! LDT 2 LDT 2680 C~L CNL 4677 CML 4.3 CNL 11 ! BGT -999 .000 ,859 ,000 .$20 ,000 ,500 .300 ' ,0.%.01' O0 ,000 000 250 365 250 000 100 000 8 '52 854 031 ,200 250 DEPT, 4200 SP · DTE 83 IDOF ,, DTE 0 IIRD DTE 110 T FNS '. DTE 2974 ~IEN,DTE 970 ~ 'LF,SDT 109 TT1 SDT 0 LTTi SDT 12.79 WFC SDT 0 TENS SDT 297.4 DT PTE i 01 O~ GTS ]5 ~S~C ~EC -999 ,00 .31, ,00 ,~7 ,00 ,00 ,10 ,00 ,~0 00 O0 57 37 25 16-MAR-199o I8:43 10.000 SP.SDT 113,1~9. MRES.SDT -999,250 DT,ITP 3~54,000 OFCO.REC 29.589 RHO6,LDT -0.003 OSS,LDT 230,598 LITH,LDT 1207.000 SSHV,LDT 2.161 CAI, I.LDT ill. 563 ~RES,LDT 23i776 TNRA.C~L 1240 750 CNTC,CNL 12,290 TENS,CNL 593,000 GR*BGT -999,250 154 8'7 137~50 0,00 !,22 1,12,94 127.70 0,87 0,00 468,40 10,00 11.2,94 ~999,25 31.~4,00 3,86 0 ~2 260 5 1207 O0 2 ll 111 ~0 597 O0 -999 25 0:00 112, 112,60 0,82 0 O0 1068 80 10 00 1.12 21 -999 25 2974 O0 17 65 5 ILIa. 0 I~PH, 0 CIDP. 3 IIRM, 4 ~RES, 0 DTL, 7 COHS, 1 TT3, O bTT3, 0 4 ~R:ES. 0 DT, 0 QPCO, 2 RHOB ! OSS 0 blTH 0 SSH¥' 5 C.AI~I 0 0 TNRA 0 CNTC 3 TENS 0 GR, 0 0 IL~, 3 IbtPH, 0 CIDP' 3 MRES, 0 D ~ L, 7 COHS, 1 TT3, 0 LTT3, 0 S P, 3 ~R ES, 0 0 OFCO, 9 RHOB, DTE DTE DT£ DTE OTE SOT SDT S D T SDT SDT SDT ITP REC .'.GOT bDT b D T bDT bDT bDT C N b CN L CNL 8GT DTE DTE DTE DTE DTE SDT $ D T SDT SDT SDT ITP REC b D T 22,641 2,211 120,170 0.000 2 162 . 0, O23 133,000 1308.000 12 290 2:234 2,456 3071.875 2655.547 -999,250 121 125 177!125 7 ~66 7.863 2 236 131 500 0 311 0 001 1656 000 1,859 12,236 1.1.3.347 0 000 2 091 0 012 t67 500 1308 000 12 133 303 547 4215 570 2680 000 -999 250 · 7 887 7 992 122 813 119 750 2 242 109 800 0 31.1 0 001 1480 800 83 313 2 242 10~,575 0.000 2,359 GR,SDT HTEN.SDT DTS~,ITP QFSH.REC DRHO,LDT LS I..DT SSI~LD? S1RH,LD~ GR bDT HTEN:LDT NPOR,CNL CFTC.CN[, MRES,CNL CI,8GT ILD DTE IFRE:DTE CIMP.DTE GR,DTE HD,DTE DTLN,SDT COST,SOT TT4,SDT LTT4,SDT GR,SDT HTEN.'SDT DTSM,ITP OFSH,REC DRHO bDT LS LDT $$1 LDT $1RH LOT CRt, DT HTEN LDT MPCR CML CFTC CML ~RES CML CI,.BGT PAGE: 63 750 969 500 -999 250 10 000 -0 001 428 556 209 583 2 158 6 6O 59~ 2 000 24 977 1258 ~13 2 234 -999 250 82 563 20 000 5 645 43 938 '999 250 121:600 0 702 78~;600 0192,500 '190 ,250 to,ooo -0;01:8 4 6 2~2'000 ;875 .031 597,000 9,662 294~, 173 "999,250 .7 9'77 000 77 6 5 -999 2~0 10~ 800 982 .743 600 12,74 000 77 625 970 000 -999 250 I0 000 0 O67 1.8 ,IS Tape Verification l. jstinq ;Chlu~nberger AlasKa Computin~ Center PEF. bDT 2,982 OI.,S. bDT LU L[)T 317.750 LL.LDT SS2~I, DT 323,000 LShV,LDT LSR~, I.,DT 2.279 LdR~. I..DT TENS. bDT 2584. 000 ~TEM. I..DT ~PHI. CND 40.91 ~ TNPH. Ct, iL RCNT. CNL 2318. 227 RCFT. CNL G~.CML ~4.750 CALI.CNL ~E~.CNL 110,469 HTEN,CNL C2.BGT -999.250 TENS.BGT DFPT, SP.DTE IDQF.DTE IIRD,DTE TENS,DTE HTEN,DTE DTIaF.SDT TT1,SDT [.TT1,SOT WFC SDT TENS:SDT DT,PTE GR,GTS RSHC,~EC PEF.LDT LU,LDT S.$~, bDT LSRH, bDT TENS bDT NPM! CNL RCNT CNb _G~ CND STEM CNL C2,BGT 4100 0 133 2974 983 106 0 ~.289 0 2974 108 69 -999 3 338 332 2 2524 41 ~27! 7O ~09 -999 ,0o0 SFLU. .375 IOPH, ,000 IMOF, .375 IIXD. ,000 ~TE~. ,000 DT, ,000 (:(3MC, ,001 TT2 .600 bTT2: 000 WFSH. 000 STEM, 642 DTS~. 250 ,096 ,500 ,750 LSHV, ,250 LURH ,000 ,160 TNPH ,999 RCFT '313 CALI ,85() HTEN .~.~0 TE.~'.S DTE DTE DTE DTE DTE SDT SDT SDT SDT SOT SDT PTE GTS bDT bDT bDT bDT ~DT bDT CNL CNh CN'L C~b BGT DEPT, SP, DTE IDOF, DTE 'I ][RD, DTE TENS DTE H T E N'' ,DTE P T L F ' $ D T TT 1, SDT LTT ~ ~ $ DT WFC, SPT TE~S,SDT DT, PTE GR,GT8 RS~,C , REC PEF LDT $$2 bDT LSRH I.!DT TENS LOT 400O 89 0 2944 990 1,33, O, 1462, O, 2944, 135, 39 -999 0 1724 1 2514 000 SFLU,DTE. 625 IDPH,DTE 000 IMQF,.DTE 375 IIXO'.DTE 000 MTE~,DTE 000 DT,SDT 600 COHC,SDT 001 TT2,SDT 800 LTT2,SDT 000 WFS~,SDT 000 MTE~ S~T 429 DTSM P 906 TENS GTS 250 DPHI LDT 584 000 Lb.bDT 750 b $ ~ V, L 0 T 89 .[, U R H ~ h D T O0 MTE~,LDT 16-~AR-1990 18:43 0.004 QSS,LDT 1B1.875 LITH,LDT 1207.000 SSHV,LOT 2.289 CALI.LDT 110.469 A~RES,LDT 40,482 TNRA CNL 572 232 C~TC' , . , .-,CNL 13.945 TENS.C~L 616.500 GR.~GT '099.250 , 6. O. 10. 111, 107. O, O, 1069. 10, 111 -999 3000 18 -0 189 1208 09~ 141. 56~, 1 , 613. -g99, 35, 13. O, li,, 0 o' 2940 76 876 1206 109 910 !Lq,OTE 711 !~PH,OTE 000 CIDP,OTE 758 IIR~,DTE 706 ~ES,DTE 900 DTL,SD? 955 COHS,SDT 001 TT3,SDT 2()0 LTT3,SDT 000 SP,SDT 706 ~ES,SDT 250 DT,ITP 000 QFCO,REC 344 RHOB.LD'r 020 QSS,LDT 000 blTI'{,hDT 000 SSHV,LDT 252 CALI,LDT 50 ~RES,LDT 87 T:N~A,CNL 944 CN C,CNL 867 T£NS,CNh 000 GR,BGT 25O 469 ILM,DTE 953 IMPH,DTE 000 CIDP,DTE 758 IiRM,DTB ~2 MRES,DT~ 0 DTL,SD 835 COHS,SDT 001 TT3,SDT 800 bTT3,SDT 000 SP,SDT 250 DT;ITP 000 OFCO'REC 282 020 QS$'LDT 000 LITH,LDT ;'6 CALI',hDT .c, bDT 681 0.029 103.000 1308,000 13.945 2.275 3.640 2114.248 2584.000 -999.250 6.383 6.500 148.875 147.625 2.258 1. 06 500 0 31.1 0 001 1506 800 89 375 2 258 108 64:2 0 000 2 347 0 032 103 188 1307 000 13 867 2 309 .25 000 17 01.6 151836 55, 2,244 132,900 0.255 0,00! ~701,600 89,625 2,244 135,429 0,000 1,391 821,,, 0 1~07.,000 2,656 12,295 [.,S.LDT SS1.LDT $1~H LDT GR~L!')T HTEM bDT CFTC,C~L ~RES.CNL CI.BGT ILD.DTE FREDTF I NP: DTE G~.DTE HD,DTE DTI..N. SOT COST,SDS[' TT4,SDT [aTT4. SDT GR.SDT HTEN.SDT DTSM .~SB,REC DRHO. bDT LS, LOT S$! . bDT $1RH'LDT GR,bDT HTEN~LDT NPOR, CFTC,CCN ~R~$,CNL CI.BGT II,D,DTE IFRE,DTE ClMP.DTE GR,DTE ),H'D,O'T[ CCST'$DT TT4.'SDT LTT4'SDT HTEN,,~OT DT$~,'ITP DRHO,LDT LS,LDT SSI;bDT S!RH,LDI GR,LD HTEN,LDT P~GE: 340 750 2,129 84.750 616.500 41. 831 591i797 2 275 -999250 6.566 20 000 153 750 74 375 -999 250 105 500 0 975 80O 12 74 375 98 o0o o o86 ~8 250 232 250 2 066 70 13 61~ ~o0 77 ,2 309 -999 250 1,3 23 -999 0 0 830 0,0 t458 0,0 38.~25 990 000 -999 250 goo o1 619'S00 19 ,IS Tape Verification l..istlno ;chlumberger Alaska ComputinO Center NPHI,CNL 70,640 TqPd,¢NL RCNT.Cr~L !563 220 t~c~'r.C~L CF.Chh 40~813 C.~LI CNL ~TE~.C~L 109.681 ~TE~t:CNL C2,BGT -999.250 TENS.BGT DEPT EP IDOF DTLF WFC G~ RSHC LSR~ T~NS GR , 3900.000 SFLU.OTE ,DTE 68,500 IDPH.DTE DTE 0.000 IaQF.DTE :DTE 11,984 IIXD,DTE ,DTE 2904 000 ~TE~,DTE .UT~ 989~500 vT.s~,r .SDT 118,600 COMC,$DT ,SDT 0,001. TT2,SDT .SDT ~556,400 LTT2.SDT EDT 0,000 ~FS~.SDT .'SDT 2904,000 ~TEM,SDT .PTE 138.971 DTS~.PTE (;'rS 46,500 TENS <;TS .'~EC -999,250 OPHI:I..,D'~ .LDT 2,317 OLS.LDT ,LDT .428,281 LL,LDT ,LDT 317,929 LSHV.LDT ,LDT 2,112 LURH,LDT LDT 2489,438 N]'"E~, LDT CNL 15,076 TNPM CNL CNL, 3661,344 RCFT', ,CNL CNL 4.4,567 CALI,CNL BG -999,250 TEN$,BGT DEPT SP IDOF iIRD TEnS DTLF TTI, LTT1 DT ~SHC LU TENS RCNT ~TE~ C~ DTE DTE DTE DTE ,DTE ,SDT ,SDT 'SDT ,SDT ,SDT ,PTE ,GTS ,REC ,LDT ,LDT ,bDT ,LDT .LDT , C N L , C N L 3800,00 99.37 0.00 43.1.2 2900,00 1.012,00 I47 O0 0 O0 1624 40 0 O0 2900,00 146,43 54,03 '999 25 2 6~ 410 13 314 77 2,13 2438,4'4 23,94 3221 15 56 76 !08 05 '999 25 DTE DTE DTE DTE DTE SDT $ D T SDT SDT S D T SDT PTF, GT$ L D T L D T LDT L D T L D T bDT C~L C N L CNL CNL BGT :I6-~IAR-IOO0 18:43 91. 745 TNRA,CNL 280:228 CNTC,CMI. 12 656 TENS,C~!L 619:560 GR.dGT -999.250 98.688 ILi'~,DTE 119.81.3 I~PH.DTE 0.000 CIDP,DTE 1.135 IIR~,DTE 110.806 ~RES,DTE 148,300 DTL,SDT 0,549 COHS.SDT 0,001 TT3.SDT 1287.600 LTT3,SDT 0,000 SP,SDT 110 806 M~E$,SDT '9991250 DT,ITP 2844 000 OFCO,REC 33 034 RHOB,LDT '0,001 OSS,LDT 251,445 LITH,LDT 1207,000 SSHV, LDT 2,117 CAL1,LDT 108.~1 ~RE8. L,D 15, 3 TNRA,CNL 1753 125 CNTC,CNL 12:39B TEN$,CNL 634,00(:) GR,.BGT "999,250 21, 0,00 ,06 156, 0,99 28~6.00 '31 61. 0 O0 24 41 120~ 0o lo8 24 62 I156 ~5 1239 626 55 ~999 25 5.229 1365.522 2514 000 -999~250 86 313 107 313 8 336 11 023 2 270 142 100 0.953 0.001 1819.600 68 500 2i270 138 971 0 000 2 105 -0 005 164 391 1307 000 12 398 I 9~9 3233 750 2489 438 -999 250 1.8,875 19.531 45,969 50,313 2,256 147,500 0,951 0 OOl 1915 200 99 375 2 256 146 438 0 000 2.128 0.006 I47, 1307.~60 12,398 2'315 ,2,560 2822~500 2438,445 -999,250 NPOR.,CNL CFTC,CNL MRES.CNL CI,BGT ILD DTE IFRE;:DTE CI~P.DTE GR,DTE HD,DTE DTLN,SDT COST 8DT TT4~SDT LTT4.SDT GR,SDT HTEN.SDI DTSM,ITP OFSH.REC DRHO.LDT LS.LDT SS1,LD~' 81RH,LDT GR.LDT HTEN LD~ CFTC,CNL MRE$,CNL CI,BGI ILD DTE CI~P DYE GR DTE HD DTE DTLN SOT COST SDT TT4SDT LTT4 SOT GR.SDT DTSM,ITP OFSH,R,EC DRHO,LDT h$,LDI SSI,LDT S1RH,LDI GR LDT HTEN LDT NPOR CNL CFTC CNL ~RES,CNL CI,SGT P AGE: 20 90 483 267,068 2,295 -999,250 81,000 20,000 9'313 44,918 -999 250 141 900 0 929 883 600 1.555 600 44 938 989 500 -999 250 10o00 -0 01.7 46 20] 641 768 2 181 44 567 634 000 15.68~ 1703 938 .99~1 313 ]0.,922 0;000 51,156 50,656 :'999,250 !45,700 162,,200 50,656 ,1012,000 '999,250 10,000 -0 012 4.?~ 204 2,,, 7 .56 764 626 "~5 .24 i 9 15 .IS Tame Verification [,isti~q ;cb].umberger Alaska Com.put. ini~ Center DEPT, 000 SFLU.DTE SP. DTE 500 IDPH, DTE IDQF,DTE 000 I ~OF'. DTE IIRD,DTE 063 IIXD.OTE TENS.DTE O00 ~TEM, DTE NTE~ DTE 000 DT,SDT DTLF:SDT 100 COHC.SDT TT~ .SDT 001 TT2,SDT LTT~ ,SDT 800 LTT2,SDT WFC,SDT 000 wFSH,SDT TENS,SDT 000 MTEM,SDT DT,P?E 719 DTSM,PTE GR.GTS 188 TENS,GTS ~SMC.REC 250 DPHI.LDT PEF. LDT 3~4 QLS, LDT LU LDT 000 LL, LDT SS2[LDT 500 LSHV.LDT LSR~,LDT 654 LURM,LDT TENS,LDT 000 MTE~4,LDT NPHI,CNL 883 T,CNL 809 RCFT.~Nb RC,.,~ CNL 094 CAbI. NL C2,8G 250 TENS,BGT D E P ]7, TE SP, D I'DOF DTE ! IRD' , DTE 3700. 130, O. 92. 2744, 983. 124. 0, 1496. 0, 2744, 124. 53, '999, 2, 1032, 376. 1. 2364, 53, ~989, 51. 107. -999, 3600. 130, O, 33, 2744, 10!9, 13l, O. 1509, 0. 2744, 130, 22 '999 0 1932 411 1. ~2~4 70 1~22 3500, 13~, , 16, 000 SFL[) 1.25 IOPH, 000 IMQF, 250 000 MTE~, 500 D T 800 COHC. 001 TT2' 600 LTT2. 000 M....E~, 64:4 797 TENS 250 672 QLS, 000 b L 250 LSHV' 330 b U R H 000 MTEM 028 012 RCFT 891 C A 475 gTEN 250 T E N S D T El DTE DTE DTE DTE SDT SOT SDT SDT SDT S DT PTE GTS LDT LDT LOT L O T L D T LDT CNL CN'L CNL CNb BGT i6-~AR-1990 18:4] 14.086 10,070 0.000 5,773 !09 681 122:400 0.637 0 001 1222:400 0.000 109 681 -999:250 2764,000 60.293 -0,012 560.000 1205,000 51 07'7 384 859 12 719 612 500 '999 25O 48,969 32,844 0,000 I0~ 484 950 152 700 0 933 0 000 000 108 950 -999 250 2760 000 80 017 '0,~1:8 973, 00 I204 000 1 339 106 4,75 89 137 2~ 616 ,, 383 648 500 ~999 250 000 $.FbU DTE 121,625 625 IOP~"! DTE 1.02.,125 000 I~OF DTE 0,000 766 IIX[) DT~,] 2.031 ILM,DTE I~PH,DTE CIDP,OTE IIRM,DTE MRES,DTE DTL.SDT COHS'SDT TT3.SDT LTTB,SDT SP,SDT ~RES,SDT D'r,ITP QFCO,REC RHOB.LDT OSS,LDT LITH,LDT SSHV LDT CALI:LDT ~RE$,LDT TNRA,CNL CNTC,CNL NS,CNL TEGR,BGT IL~,[.1E IMPH,OTE ClDP'DTE IIRM~DTE MRES~DTE DTL,SDT COH$,SDT TT3,SDT LTT3,SD~ SP,SD MRES,SDT DT,ITP QFCO,REC RHOB,LDT 0S$ bDT L I T H b D T SSHV bDT CAbI LDT MRES LDT T~RA CNL CNTC CNL TENS CNL GR .BGT DTE I M P H, i' ' C I O P, ),% E I I R M, O T E 8,313 10.078 99.250 113,625 2.271 122.600 0.908 0.001 1753.200 130,500 2.271 124.719 0.000 1 655 01015 5555OO 1306 000 2 719 12~334 4 31~ 16192295 364 000 40,938 38,188 0,422 3.234 2 283 !34,400 0.923 0,ool 1.~40,400 30.1,25 2 283 130 644 0 000 ! 330 0 O07 940 500 ~307 000 12 383 2,350 5.189 46'397 1~54,000 ~999,250 101 063 133 000 9 781, g 422 ILD.DTE IFRE DTE CI~:P:DTE GR.DTE HD.DTE DTLN.SDT COST.$DT TT4 MDT LTT4:SDT GR.$DT HTEN SDT DTSM:ITP OFSH,REC DRHO,LDT LS.LDT SS1,LDT S1RH.LOT GR.LDT HTEN,,LOT NPOR.CNI, CFT'C.CNL '~,~RES,CNL C1.BGT I LD. DTE IFRE,DT~ CIF, P,DTE G R, D T'E HD,DTE DTLN, SDT COST 'SDT T1 , SDT LTT4. SDT GR,$DT H P,.,N '.SOT DT$.~ , I TP QFSH,REC DRHO, LDT l.,,S LDT SS1 LDT S1RM LDT GR LDT HTEN bDT NPOR CNL CFTC CNL, MRES:CNL CI,BGT ILD,DTE IFRE,,DTE CI:MP~DTE GR,DTE PAGE~ 21 9,820 20,000 99.125 49.063 '999,250 130.400 0,865 797 200 149~ 200 49 06~ 983 000 -999 250 10 o0o -0 005 1076 000 227 875 1' 676 500 46 546 390 564 2 334 -999 250 29,156 20,000 ,156 ~.859 "999'250 132,800 0 951 822 000 1504000 19 859 1019 500 -99~ 250 1 00o :-0 003 2~ 343 64~ ~00 8~ 987 26 33 2 ~50 -999 250 64,4~8 20,000 7,512 15,977 ~IS Tape Verification Llst:lnq ;chlu~.berqer Alaska ComDutinq Center TENS.DTE 2580,000 t.{TEt4, DTE HTF. N. OTE 965,500 DT, SDT DTLF,6DT !35,400 COHC.S TTI ,SDT 0.001 TT2.SDT I..TT 1 ,SDT 15~2.400 LTT~.SDT WFC, SDT 0. 000 WFSH. SDT TF~S,SDT 2580.000 MTE~4.SDT DT.PTE 133,884 DTSM,PTE GR.GTS 13,703 TENS.GTS RSHC.REC -990,250 OP~I.LDT PEF LDT 0.508 {~LS. L[)T LU: LDT 2 ~ 88,000 L[.. bDT SS21LDT 422.000 LSHV.LDT LSRN,LDT 1;275 LURH,LDT TENS.LDT 2260.000 MTE~ LDT NPHI.CNL 72.032 T~4PN, CN I..~ RCN'T, CNL 1531.650 RCFT.CNL MTE~.CNL 106,531 C2.BGT -999,250 TENS,BGT DF. PT, 3400 SP DTE 144 IDQF * DTE 0 I I RD, DTE 83 TENS,DTE ~430 MTEN, DTE 952 DT [..~F * SDT 133 TT ~.. SDT 0 LTTI. ' SDT 1514 WFC,SDT 10 TENS,SDT 2430 DT,PTE -999 GR, GTS 42 RS~C, REC -999 PEF ~ LDT 3 1:~", L D T 351 SS2, LDT 307 2 L S R }'1 L D T TENS' NPHI'LDT 2150 . C'~L 28 ~CNT, CNL 2663 GP,CNL 45 MTEI~.CNL 104 C~, ~'~GT '999 ,000 SFLU,DTE ,750 IDPH, DTE' ,0()0 I}IOF,DTE ,125 IIXD.DTE ,000 MTE~, DTE ,500 DT.SDT .200 CO~C'SDT .00~ TT2,SDT ,400 I.TT2,SDT ,000 WFSH,SDT ,000 ~.'~.'I'E ~, SDT ,250 DTS~,PTE ,500 TENS,GTS ,250 OPHI L[)T O e' DT , 150 . l.,,,,, L ,1.45 LS, LDT ,658 b S ~ V, L D T ,218 LURH, LDT 31, 3 M T E ~ · L D T 462 TNPH CNL 625 RCFT CNb ~58 CAbI CNL 779 MTEN CNL 250 TENS,BGT IDOF .IIRP TENS HTEN DTLF TT.1 LTT .~ . 3300,00 , DTE 1 37,, 50 Ii. T E 0,00 DTE 4. 0.34. DTE 2390,00 DTE 930,00 SDT 346,50 SDT 0. O0 'SDT 1424, O0 16-~AR-lO90 ~8:43 109,~75 ~!PES DTE 135.500 DTL[SPT 0 255 COHS,SDT O:O01 TT3,SDT 1250.400 bTT3,SDT 0.000 SP.SDT 109 175 ~RES,S.~T 'g99~250 DT.I P 2570 000 ~FCO~REC 83~625 RHOB.LDT -0.034 GSS,LDT 1061,000 LITH,LDT 1203.000 SSHV.LDT 1 278 CALI,LDT 106i531 gRES,LDT 106 551 TNRA,CNb 271.44~ CNTC,CNL 1~,531 TENS,CN~ 63 ,000 GP,BG -999,250 9,7~1 IL,q, DTE 10,930 IMPH,DTE 0,000 CIDP,DTE 107~ 8 MRES,DTE 1 '36,500 D T L, $ D T 0,295 cO~S,SDT 1240, 0 I.,TT3, SDT O, 000 SP,SDT 107,488 MRES,SDT ~1,250 DT,ITP .... ,000 OFCO,REC 26,008 ~ l"t 0 B, ~ D T 0,010 QSS, L I r},, bDT 20~,5~9 120 ,000 S6'flV, LDT 1 ,779 ~RES, bDT 849.~6 TNRA~ :, ,CNL , 7 C,,;~, C, CND 12,544 TENS,CNL 612,316 GR. ~999~250 ~,6B8 ,ILa DTE ~,,98.4 IMPH'DTE I I R ~,~, D T 1,214 0 ' 0 D T b ~ S D T ,63() CO~O,SDT 0,000 TT3,SDT 11.14,400 LTT3.SDT 2 285 135:g00 0.943 0.001 1797,600 136.625 2.285 133,884 0.000 1.270 0.014 11~9.000 1306.000 12.531 2.~54 5,302 1.335.556 2260,000 '999,250 9 664 97 875 2 322 134 300 0 958 0 001 1773 200 1.44 750 2 ~22 132 944 5 000 0 022 1.~0 3 ~ 1306 812 12 544 2 398 2 865 2432 648 21.50 313 -999 2150 19,750 21,891 43 469 4.8 063 147 00 0,250 0.001 1.732,800 HD.DTE DTI, N SDT C6STiSO TT4.SDT LTT4oSDT GR;SDT HTEN,SDT DTSM.I~P QFSH.REC DRHO.LDT LS.LDT SSI.LOT SIRH.LDT GR, L DT [.{TEN LDT NPOR: CNL CFTC.CNL MRES,CNL CI.*BG~ ILD.DTE IFRE.DTE CIMP'DTE GR,DTE HD,DTE DTbN.SDT COST'SDT TT4,SDT LTT4,'SDT GR SOT HTEN:$DT DT$~i,ITP QFSH,REC DRMO LDT LS bDT $S1 LDT S1RM LDT GR LOT HTEN,LDT NPOR.CN5 CFTC.CN5 ~""S C~ REt, CI,.BG~ ILD DTE IFRE DTE CIMP DTE GRDTE HD,DTE DTLN,SDT COST,SDT TT4,SDT LTT4,$DI PAGE: 22 -999,250 135,600 0 874 825:200 1518,000 15,977 965.500 '999,250 10,000 '0,008 2156 000 230 375 1 306 1.2 258 632 000 104 93a 250 698 2 354 -999 250 10 688 20 000 102 813 44 750 -999 250 131, 800 0 96! 832 000 1510 400 44 750 952 500 '999 250 10 o00 '0 008 20~ 2,51 45 45 61,2 31~ 32, 040 834 12,5 2~,95 2.00~ 656 -999 250 128 200 0 795 · 798 800 !419 600 .IS Tape Verification Listlnq ~ChlUmberger Alaska Computtng CeDter ~FC.SD'.r C,O00 TKNS.SDT 239o.000 NI'E'~, SPT DT,PTE 153,276 DTS?'~. PTE GR.GTS 4~.~44 TENS.GTS RSHC.REC -999,250 DPMI.LDT ~EF. LDT 2,365 OLS. LDT bU. LDT 388,750 LL. LDT SS~.I,DT 306,500 LSHV,LDT .bS~.LDT 2 15~ LURH.LDT TENS,LDT 2110:000 ~TEq.LDT NPHI,CNL 24,435 RCNI,CNL 2802.331 ~CFT*C~b G~ CNL 45'3~3 CALi.C~L gTE~CNI, .104,~38 HTEN.C~L CP BGT -999,250 TENS. BGT 3200,000 1.51,375 O.O00 71.688 P330 000 933:000 13~,900 .001 1626,800 0,000 2330,000 134,491 67,688 '999,250 2,929 350 781 ~06 643 2 211 19~0 32 523 2438 375 74 456 103,671 -999.250 SFLU,DTE IDPH,DTE I~QF.DTE IIXD,DTE M'TE~i,DTE DT,SDT COHC,SDT TT2.SDT LTT2.SDT W.FSH.SDT ~TEM,SDT TEN$.GTS DPHI'bOT QLS,LDT bSHV bDT bUR~ LDT ~TEM LDT TNPH CNL RCFT CNL CALl CNn ~TE~,C~L TE~$,,B:T 3100,000 166,875 0,000 101,500 2160,000 922.000 134'100 O.OOl:~ I499,20. 0000 2160 000 -999 250 59 344. -999 ~50 1,6-~AR-lggO 18:4,3 3,000 107.31.9 -~99o250 2354 000 30 290 0 031 236 875 1207 000 2.172 J. 04,338 23,771 985,767 12.664 628,500 -999,250 10.141 13,148 0.o0o 3'615 107,488 144,100 o,g~ 0,0 1. 1324~0~0 0,000 107,488 '999,250 2384 000 26 ~47 o ¢o 210 3 1206 857 2 231 . 629 674 742 12 157 586 48 -999 ~50 8.211 8,984 0 000 6 707 105 913 1.71 000 0,985 0 !2so: go 0 000 105 50 -999 ~00 2200 24 893 SP.SDT MRES.SDT DT, ITP OFCO.REC ' 0 LD'r ~H ~, QSS,LDT LITH.LDT SSH¥.LDT CALI,LDT ~RES,LDT THRA,CNL CNTC.C~L TENS.C~L GR;BGT ILM DTE IMPH DTE CIDP DTE IIR~ DTE MRES DTE OTL SPT COHS,SDT TT3,SDT bTT3,SDT SP,SDT MRES,SDT DT,ITP QF~O,REC RhOB,LDT QSS.LDT LITfl,LDT SSH¥,bDT CALI,LDT NRES,LDT TNRA.CNL CNTC, CNL . CN h TENS,, GR,BGI 137,500 GR.SDT 2. 320 HTEN,SDT !53 276 DTSM.ITP 0~000 0FSH,REC 2 150 DRHO LDT oiol7 21396 HTE:N. LDT 600 2391:823 CFTC,CNL 110 000 MRE$ CNL 10 703 ILD,DTE 11:164 IFRE.DTE 76.000 cz~ ~E 88,438 GR:DTE 2 318 HD.DTE !31:000 DTL~,SDT 0.921 COST SDT 0.001 TT4:SDT 1.883,200 LTT4,SDT 151.3'75 GR,SDT 2.318 HTEN.$DT 1.34.491 DTSM,ITP 0 000 QFSH,REC 2:21.9 DRHO,LDT 0.015 t.S.LDT 123,740 $S1 LDT 1306,000 S1RH bDT 2,757 GR bDT !2.431 HTEN LDT 3,141 NPOR,CNL 2!.06,125 CFTC,CML 1940,000 NRES gNL -999.250 C1,: G? 8.297 IL, D.DTE 8.461 IFRE.DTE 11t,188 CIMP.DTE 11~,875 ~R.DTE 13 983 COST,SPT O, 001 ]..F...,SDT 1765.200 LTT~..'SDT .]67 "' ..... .ITP 13~i859 000 QFSN,R'EC '2 239 DRHO.LDT PAGE:: 23 43.625 930,000 -999,250 10,000 -0 013 431 250 203 250 2 203 628 5 22,565 973,443 2 396 -999:250 12 727 2O 000 89 500 64 750 -999 250 131. 900 0 953 ,oo 16 200 64 750 933 000 '999 250 ,10 000 '0 003 205 2 225 71 456. 48 652 063 8.766 20 000 118 063 56 031 '-999 250 134400 0 972 1492 0 56 031 922 000 '999 2,50 10 000 0 013 .IS Tar. e Verification Listin9 ;Cb]umheroer 6].aska Computinq Center PEF. LDT 3,545 QL$. bDT LU, LDT 349,500 L[..,, LDT SS2,LDT ]J. 5.0OO LSHV,LDT LSRM,LDT 2,215 LL]RH,LDT TE6]S,LDT J. 925,000 hlTE~.~, LDT NPHI,CNL 46.380 TNPH.CNL RCNT,CNL 1655.309 RCFT.CNL G~,C~L 58.063 CALI.CML ~TE~.CNL 10~.719 RTEM.CNL C~.BGT -999,250 TENS.SGT DFPT, SP IDOF: IIRD, TENS H T E ~ DTLF TT1. LTT 1. WFC. TENS DT RSPC PEF L U N P H ! RCNT 3000.000 SFLU,DTE DTE 175,000 IDP~,DTE DTE 0,000 IMOF.DTE DTE 34,75(~ IIXD,DTE DTE ~190,000 ~TE~4. DTE DTE 9~5,500 DT,SDT SDT 134.200 COMC.SDT SDT O, 001 ]~T2, SDT SDT 1576,000 I,TT2 gDT SDT 0,000 WFSH:SDT SDT 2190,000 ~'tTEM. SDY PTE 137,755 DTS~4. PTE GTS !2,391 TENS,GTS REC -999. 250 DPHI' LDT LDT O. 703 QLS, LDT LDT 2232,000 LL~ LDT BDT 422,750 LSHV.LDT LDT !,263 LURH LDT LDT 1840.000 ~l~'~,''' C'NL 68,194 ~...~PH CNL CNL 1408,54:] RC 7,CNL C N I., 13 ' 922 C A b I. C N L CNL 102.031 ~tTEN, ~GT LG.~ -999,250 TENS, DF. PT, SP.DTE IDOF,DTE IIRD,DTE ENS, DTE ~TEN,DTE DTLF ' SDT TT1 ,SDT LTT1 ,SDT WFC SDT TENS SDT DT PTF.. G~ GTS RSMC REC PEF LDT LU LDT $S2,5DT LSRM, bDT TENS, LDT ' ' ) ' { E :29(.0,000 $[~LU ,DT 1,75,750 IDPH,DTE 0,000 IMOF,DTE ~ 5.438 ,1 !: X D, D T E 2190,000 914,000 DT,SDT 135,700 C [] H C. S D T O. O01 TT2,SDT 1.58~ 400 LTT2,SDT PO0 WFSH,SDT 2190 000 MTEM,SDT 146 69 DTSM,PTE 55' 625 TENS' GTS -999,250 DPBi,LDT 3,403 0 b S, L D T ,347.129 Lb' LDT 304.543 L. SHV,LDT 2. 237 LURH. LDT 1826,7.42 iqTE:~,LDT 16-~,'IAR- 1990 18:43 0 013 205 ~ 250 12(:,7. 000 2,232 103.719 47 911 421 833 13 867 591 000 -999 250 58.500 31.406 0.000 2,289 104.169 184,500 0,798 0 001 1321 60O 0 000 10 169 -99~ 250 21~0 000 ~3 990 -0 034 10~2 000 1205 000 1 2~9 102 0 ~ s5 ~36 3 4 12. 30 573 ~00 -999 250 11,508 :I, 0,~'~9 O. 0 5,484 56 0 9~7 o 0 1, 1317 6~0 0 0 0 104 056 -999 250 220 2~ 000 363 -0 2 ,193 ~7~ 1206 087 2 237 10.1 295 0 S S, b D T LITH, LOT $ShV. LDT CALI,LDT ~RES,LDT TMRA.CNL CNTC,C~L TENS,CNL GR,BGT IL{~.DTE I~PH,DTE CIDP,DTE IIRM,DTE ~RES,DTE DTL,SDT COHS,SDT TT~,$DT LTT3.SDT S:P,SDT ~RES,SDT DT,ITP OF'CO,REC RHOB,LDT OSS,LDT LITH, bDT SSHV. LDT CALl LDT ~RES LDT TNRA C~L C~TC CN5 TENS C~ GR BGT IL~ DTE !MPH DTE CIDP DTE IIRH DTg .~RE$, E L I. L, S D T COHS SDT TT3 SDT bTT3 SOT SP SPT MRES SDT DT ITP OP"CO REC RHOB, bDT OSS, LOT L ITH. bDT SSHV:. LOT CALl, LOT ERgS, LDT 0,025 105,688 1306,000 13.867 2,436 3.936 1454,402 1925,000 -999.250 34.063 50 344 31:828 27,906 2.410 137.900 0,973 0,001 1852.800 175.000 2.410 137.755 0,000 1 264 .oloo2 1088,000 !306.000 2 930 1277 25.3 1840.~00 -999, 50 10, 5 92,625 94,500 2 406 138 6O0 0 995 0 001 1885 2OO 175 750 2 406 146 691 0 000 2 248 0 105 ~]0 5 1,306 000 12 398 2 487 LS.LO]' SS1,LDT S1RH.LDT GR.LDT HTEN.LDT NPOR,CNL CFTC.C~L MRES,CNL C1.BGT ILD.DTE IFRE.DTE CI~P.DTE G~.DTE HD.DTE DTLN.SDT COST.SDT TT4 SDT LTT4:SDT GR,SDT HTEN,SDT DTSM ITP OFSH:REC DRHO,LDT L$,LDT SSI,LDT $1RH,LDT GR bDT HTEN LDT NPO~ CNL CFTC CNL ~RES CNL Cl'BGT IL, D,DTE 'IFRE;DTE CI~P,DT~ GR,pTE ,HD,oTE DrLN;$DT COST,MDT TT4'SDT GTT4,'$DT GR.SDT HTEN.SDT DTSM,~TP QFSH, ~EC DRFtO, LDT LS, b DT SS1..,LDT HTEN,LDT PAGE: 24 38O 000 214 375 2 164 58 063 591-000 47 465 362 418 2 436 -999 250 27,813 20 000 19 859 12 070' -999 250 135 200 0 936 887 600 1575 200 12 070 925 500 '999 250 10 000 -0 234 375 li 267 922 573 500 87 896 2 -999 1¸0 20 96 938 56 250 -999 250 136 800 0 932 888 000 1604 000 56 25O 914, 000 lO o ~67' 206 . 5 2 584 523 ,IS wa. me Verification Listinq ;chlumberger Alaska Computinq Center NPMI.CNL 43.564 TNPH.CNL RCNT.CNL 2059,781 RCFT.CNL GR,CNL 61,247 CALI,CNL MTE~.C~:'L 101.295 HTE~.CNL C~,BGT -999.250 TEN$,BGT DEPT. 2800.000 SFLU.DTE SP,DT~ 186,000 IDPH.DTE IDQF,DTE 0.000 I~QF.DTE IIRD.DT~ 15~,625 IIXD.DTE TFNS,DTE 2025.000 MTE~,DTE HTEN,DTE ~33,000 DT.SDT DTLF SDT ~9..300 COHC SDT TTI:SDT 0,001 TT2:SDT LTT1,$DT ~5~2.000 LTT2.SDT WFC,SDT 0.000 WFSF.SDT T~;.SDT ~25 000 MTE~ SDT ..PTE 99:250 GR,GTS 55,313 RSHC.REC -999,250 DPHI.LDT PEF,LDT ~ 551 t,U,I,,DT 41~ :250 Yb,LDT SS2,LDT 333,500 LSRM,LDT 2,135 LURHiLDT. "'~ TENS.LDT 1800,000 ~fE LDT NPHI,CNL 48,708 TNPH.CNh RCNT,CNL 1792,470 RCFT GR.CML 55.531 CAL'.I:C~L ~TE~,CNL 1.00'175 MTEN.CNL - T~No.,BGT C2.BGT 999,250 DEPT SP DTE IIRD DTE TENS DTE MTEN DTE OTLFSDT TT LT~SDTgDT WFC SDT TENS SDT DT PTE GR GTS RSHC REC PEF LDT SS~'bO~ 5SRM,bDT TENS,bDT RCET'C~L G ~. C N b ~ T E ~, C N b C2,BGT 2700 000 !.78 750 0 000 46 688 2040 O00 941 000 ~90 700 0,001 1744,800 0,000 2040,000 '999'250 46,500 '999,2~9 377'000 311,o00 2,174 1750,000 ~25,945 .2637,443 4.4,594 . 99.~444 999,250 SFhU DTE IDPH DTE IMOF DTE II×D DTE M, TEM DTE DT ,SDT COMC SDT TT2 SDT bTT2 SDT WFSH SDT ~TEM SDT DTS~ PTE TENS, GTS DPHI LDT OLS LDT LL,LDT LURM'I.,DT MTE~ LDT TNPH CNb ~CFT CNL C A g I, C N I,,, H T E N, C N TENS,BGT 16-~AR-19g¢) 1~:43 41,887 TNRA,CNL 493,703 CNTC,C~JL 12.398 ?EN$.CNL 584 523 GF.SG'r -9992250 5,586 5,832 0'000 11'45~ 1.03,831 170.400 0,988 0.001 1268,400 0 000 i03:831 ~999.250 90,000 028.353 '0,018 236.000 1.207,000 2,1,39 100,175 48.444 443 ~92 12i 98 580 000 -999,250 19, 9 0,000 549 ooo 2 0 997 0 001 1448 000 0 000 lo -99~ 250 2070 000 28 37 0 ~13 223 1207 000 2 189 99 444 27 ~32 902 89 12 617 596 500 -999 250 I~PH,OTE CIDP,DTE IIR~,DTE MRES.DTE DIL'SDT Cf]MS SDT TT]:SDT LTT3.SDT SP,SDT MRES,SDT DT,ITP OFCO,REC RHt')B,hDT QSS,bDT 5ITH.LDT SSHV.SDT CAbI bDT ~gS bDT TNRa CNL CNTC C~l,. TENS CNL GR,BGT ! L :~, P T E !~IPM, DTE DTE ClDP,. > ', IIRM,[.TE MRE$,DTE DT5 SDT COHS SDT TT3 SDT LTT3 SDT SP SDT MRES SDT II.'.P OFCO REC D~ RHOB,D O$S,LDT [~ITH,bDT SSHV,LDT CALI,LDT MRES,LDT TNRA,CNL C~TC,CNb 'N CNL ~E...S, GR,~GT 3.744 ~POR.CNL 1834.273 CFTC.CmL 1826,742 F. RES.C~L -999.250 CI.,OGT 5.375 ILD.DTE 5.469 IFRE.DTE 171 375 CIMP.DTE 175:000 GR,DTE 2.395 hD,DTE 127,100 DTLN.SDT 0.727 CDST.SDT 0 001 TT4.$DT 186 000 2i395 HTEN.SDT 129 477 DTS~..ITP -5 000 OFSH.REC 2:182 DRHO.i, DT 0 032 L$ LDT ,2:ooo 1306 000 SIRH'LDT 12 398 GR..LDT 2 508 HTEN,LDT 4 025 NPO~.CNL 1651 707 CFTC,CNL 1800 000 gRES,CNL -999 250 C~.,SGT 16 891 17 50 56 2 1,56 0 0 1.1~ 2172 142 344 344 CI~P 156 GR 432 HD 100 DTb~, 917 COST 001 TT4 lbD DTE DTE DTE OTE DTE SDT 400 bTT4 SDT 750 GR HTEN ~DT '5 000 OFSM,REC 2 181 DR'MO,bDT 0 018 124 250 ,.~SI'bOT 1306 000 2 3 ~ ..... I.,DT ~ 699 i~POR.C~ 23{$ 296 CFTC,C~L 1750 000 -999 250 CI~BG~ PAGE~ 25 42,122 509.078 2 487 -999:250 5,695 20.000 182,750 55 938 -999 250 118 000 0 923 868 400 I547 200 55 938 933 000 -999 250 lO ooo 0 037 442 250 ~26 000 580,000 50,545 413,336 2,508 ~999,250 19 297 20 000 344 -999 250 ~.49 000 .0 964 968 400 747 200 45 344 94!. 000 -999 250 10 000 -o oo 3 ooo 2 3~5 ! 6 4.4, 594, 596, 500 27 144 859 197 "'99~ 523 25O .IS Ta ~eri. fica List. in ,ch ]ll~e t.', 1. on a ether Alaska Co,~.puti. n~$ Center DEPq'. 2600. .DTE SP, DTE -37. . DTE IDOF.DTE O. .bTE IIRD.DTE 72, ,DTE TFNS. DTE 1640. . DTE HTKN. DT.E~ 944. SDT DT[,,F.SD.... 42, :SDT T~ 1 .SOT O, SDT LTT1 ,SDT 802, SDT wFC, SOT O. 5DT TFNS, SDT 20(,)5, SDT DT. PTE 999, PT~ GR.GTS ~999, GTS RSHC. REC -999, LPT PEF, LDT 60, LDT LU. LDT 179. LDT SS2,LDT 79, LDT LS~H, LDT 2, LDT TENS, LDT !7 ! O. LDT NPH~,CNL 74, CNL RCNT, CNL 1479, CNL G~ CNI., 19. CNb MTE~ :CNL 99, CNL C~,BGT -999' BGT DEPT,DTE IDO~,DTE IiR..,DTE 2500, '25, 0 76 ]645 946 61 0 604 0 1910 -999 -999 '-999 58 80 2 l~70 68 1458 99 -999 2400 ,, -22, 112' O00 313 IDPH 000 IMOF 000 II, XD 000 000 ~T 000 CO~C O00 TT2, 000 LTT2. 000 ~FSH. 000 ~TEM. 250 DTS~. 250 TENS. 250 DPHI 281 OI,.S~ 375 188 LSHV. 566 LURH. 000 MTEM, 002 TNPH. 008 RCFT. 375 CALI, 50 HTE~ 50 GO0 8, 375 IDPH, 000 iMQF, 500 IIXD. 000 NTEM 500 DT 10o co~c 000 TT2 000 LTT2 000 WFSH 000 MTE~ 250 DTS~ 250 TENS 250 OPHI 031 (~bo, 375 000 b,:) H V, 561 I.,[JR.H, 000 MTE~, 1,82 ~NPH, 685 RCFT, 859 CALl, 275 HTEN, 250 TENS, 000 eFLU, 828 IDPH, 000 IMQF. 6~8 IIXD, E DTE DTE DTE $ D T SDT SDT SPT SDT PTE GTS LDT LDT bDT l,, D T LDT LDT CNL CNL C~5 ', ~ ~ DTE DT E DTE 16-MAR-1990 1R:43 40,503 1.3.227 0.000 2.432 103.100 57,400 0.650 0.000 670.800 3.000 103,1.00 -999.250 -999,250 74,2~9 0.308 108,158 1208,000 2 664 99 950 9 23~ 4 1 180 12 266 598 500 -999 250 1.5 617 o 0 lbo 1.02 538 5g 300 0 74,5 0 ~ o00 102 538 -999 ~50 -999 50 75 060 1209 OO0 2 660 99 275 74 014 245 180 1~ 539 508.000 -999'250 7.453 7,984 0,000 6.168 ILM,DTE IMPH,DTE CIDP,OTE IIR~.DTE MRES,OTE DT[,,SDT COh$'SDT TT3,SDT bTT3,SDT SP,SDT ~RES,SDT DT,ITP OFCO,REC RHOB,LDT OS$,LDT LITH,LDT SSHV,LDT CALI,LDT MRES,LDT T~RA,CNb CNTC,CNL TENS,CML GR.BGT ILM, DTE I ~PH, DTE CIDP,DTE I I R ~ D T E MRES DTE DTL SDT COH$ SDT TT3 SDT LTT3,$DT S P, S D'T ~ES,SDT DT., I~P QFCO, REC RMOB, L DT 'OSS, LDT bi T H, L DT SSHV, I..~ OT CAI, I, bi,, r MRES, bDT TNRA, CNb CNTC,CNL TENS, CNL GR, BGT I L M, D T E CIDP, DTE I IR !',~. DTE 14.977 17 859 75:563 63 313 2i422 85 000 0.250 0.001 91!,600 160 375 21422 -999,250 -999,250 I 425 -0~103 21,406 1309 000 2i266 12 504 5 403 1282,406 1710,000 '999,250 1~,203 1 .445 84.125 77 625 2 4]4 71000 0 25O 0 001 9O8 40O 162 8'75 2 434 -999250 -999 250 ! :412 -0 119 21 281 1307 000 !2 539 2 531 5 092 1234 124 1670 000 -999 250 7 . 4:41 7 126,875 ILD.DTE IFRE.DTE CIMP.DTE GR.DTE HD,DTE DTI,,N.SDT COST.SDT TT4.SDT LTT4.SDT GR,SD~~ MTEN.SDT DTSM.ITF OFSH.REC DRHO [,DT LS~LDT SS1,LDT Si~H,LDT GR,LDT HTEN.LDT NPOR CNL CF~'C~CNL MRES CNL CI:BGT ILD.DTE IFRE,DTE CIMP.pTE HD.DTE DTbN'SDT COST,'SDT TT4.,SDT LTT4.SDT GR,SDT HTE'N~SDT DTSM,I'TP OFSH,REC DR~O.LDT LS bDT SS{ bDT SIRH LOT GR LD~ HTEN,LDT NPOR,CNL CFTC,CNL MRES.'CNL CI,BGT IL, D,DTE MP,DTE PAGE: 26 12.711 20,000 55,938 24,031 12.203 56.000 0,961 456,800 804,400 17,797 944,000 -999 250 -999:250 -1 146 197:a75 47'094 4,867 19,375 598.500 89 508 251. 124 2 504 -999 250 11. 586 20 000 80 250 39 844 12 367 55 400 o 4~0 456 758 0 o 946 500 .-999 250 '-999 250 "1,, 152 200 000 46 500 4 88~ 25 85 °°° 655 25~ 220 '"999 250 7 852 20 0 0 !33 0~0 59 0o0 Tape VertiIcatIon Llstil'~Cl ;chlUmberger Almska Computind Center TEN$.DTE 1540.000 .HTE~!. DTE 9~6 500 DT.SDT DTI. F,SDT 56~800 C/3HC.SDT TT1,8DT 0'000 TT2.SDT LTT1,SDT 754,000 LTT2'SDT WFC,SDT ').000 WFS.W,SDT TFNS SDT 1940.000 MTF. M SDT DT~PTE -999.250 DTS'.q'PTE. G~.GTS 999,250 TENS.GTS RSHC,REC :999,250 DPFii.LDT PEF, LDT ! 96,875 OLS. LDY LU. LDT 159,125 LL. I,DT SS2.LDT 82.000 bSH¥ LDT LS[~M, LDT 2.711 I..~]RH: LDT TE~,{S. LDT ~ 660,000 i~TE?~, LOT NPHI.CNL 6.],85] TUPFI.CN L RCc~T,CNL 1,422,822 ECFT.CNL ~R,CNL 28.719 CALI.CNL F, TE~,CWb 98,769 C2,BGT -999.~50 TENS,BGT DEPT. 2300, SP.DTE '18, I~OF.DTE O. . IIRD.DTE 140, TE~.!S.DTE ~670. HTEN.DTE 947, DTLF,SDT TT},SDT 0 LTT ,$DT 74.4 WFC SDT 0 TENS'' ,SDT !885 DT,PTE '999 GR,GT8 '999 RSHC,REC -999 PEF.LDT -999 I,,,U.LDT '999 SS2.LDT "999 LSR, ,bDT -999 TEN$,LDT -999 NPHI.CNL -999 RCNT,CNL '999 G~,CML :~999 ~TE~,CNL '-999 C~.BGT -999 000 8FLLI. DT~i 531 IDPH,DT£ 000 .!MOF,DTE 125 IIXD,DTE 000 MTEM. DTE 000 DT SDT 500 000 TT2. SDT 400 LTT2,SDT 000 WFSH.SDT 000 t~1TEM. SDT 250 DTSM, PTE 250 TENS,GT~ 250 DPMI,LD~ 250 ~L $. L DT 250 Lb,LDT 250 hSHV,LDT 250 250 ~'~ T E ~': L P T 250 T 250 RCFT.CNL 250 CaLI,CNL 250 H T E N, C N L 250 TENS, BGT DEPT, 2200. SP, ...... ',rE 22, IDQF".DTE O, .,DTE iSlO, HTEN,DTE 999, ,SDT 999,, T ,SDT :999, LTT1,SDT -999. 1.6-~ R-1990 1.8:43 101,919 I~RE$,DTE 56,500 DTL.SDT 0.532 COHS,SDT 0.000 TT3,SDT 646,000 LTT~.SDT 10.000 SP.SDT 10]. 919 MRE$,SDT '999~250 DT.ITP -999.250 CFCO.REC 63,191 RHOO.LDT 0"110 QSS.LDT 79.313 LITH.LDT 1~08.000 $SHV,LDT 2,756 CAI.,I.LDT 98'769 MRES,LOT 73.827 TNRA,CNL 276,595 CNTC,CNL 12,664 TENS,CML 621,500 GR,~:Gr -999.250 6. 0 11 101 56 0 O, 636, O, 101, -999 -999 -999 -999 -999 -999 '999 -999 -999 -999 '-999 '-999 -999 4, 4, O, 17. '999 '999 '999 '999 '999 406 IbM, DTE 464 IMPH,DTE 000 CIDP,DTE 453 IIRb!,DTE 188 900 DT.[, SDT 507 COHS,SDY 000 TT3~SDT 400 LTT3.SDT 000 SP SDT 188 250 BT ' SOT ,ITP ~50 OFCO,RE~ 250 R}~OB, hD 250 OSS,bDT 250 LITH,LDT 250 SSHV,LDT 50 CAhI, bDT ~50 MRE'$, hDT ~0 TNRA,CNL,. c 0 CN r j CML 250 GR'BGT 25O 3 O 5 I [, t~!, .D T E 551 I~,PH, OTE 000 CIDP,OTE 95 ~ I I R 250 :~ R E S · O T g 250 250 COHS,SDT 250 T T 3,8 D T 250 bTT3,S, 2 449 s6: Oo 0.297 O.O01 904 000 1411250 2.449 -999.250 -999.250 1.607 -0 174 16:422 1309,000 12.664 2.551 4,859 1,263.855 1,660 000 .999:250 5.930 5 961 154 125 158 750 2 465 58 100 0,307 0,001 857.200 19 422 2 465 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 50 -999 250 -999 2,50 -999 250 -999 250 -,999 50 -999 ~50 4 234 4. 254 219 500 221 375 .-999 250 -999 250 -999 250 ,999 250 ,999 250 HD.DTE COS SDT TT4 SOT LTT4,SOT GM,SDT HTEN,SDT DT$~,I~P OFSH.REC DRHO.LDT L$,LDT S$1.LDT S1RH,LDT GR,LDT HTEN,LDT NPOR,CNL CFTC.CMl., MRES.CNL C1.BGT IbD.DTE IFRE,DTE CIMP,DTE GR,DTE H~,DTE i)T!..,N,SDT COS~*SDT TT4,$DT LTT4,SDT GR,SDT HTEN,SDT DTSM~ITP OFSH REC DRHO bDT b$ LDT 881 LDT S!RH LD~ GR LDT HTEN bDT NPOR CNb CFTC CN5 MRES.CNL Ci.,.BGT IhD DTE IFRE DTE CI~P DTE GR DTE HD.DTE DTLN'$DT COST,SDT TT4,SDT bTT4.SDT PAGEt 27 12 273 55 900 0 979 463 600 761 600 35 500 946 500 -999 250 -999.250 -1 110 158~875 45,156 5 027 28 719 621 500 74 003 26B 560 2 551 -999 250 6,191 20,000 167,625 ~8'375 2.305 449 200 749 0 47 0~0 -999 i 0 -999 ~0 '-999 -999 0 '999 0 '999 ~50 '-999 0 "999 250 :'999 250 4 449 20000 234 875 4~625 ~2 352 .-999 250 -999 250 99~ 250 ,IS Tar, e verifi, catien Listing ;CblUmber.qer Alaska Comout. ir,~ Center WFC.SDT -999.250 WFSH.$DT TFNS.SDT -999,250 MTEiM. SDT DT.PTE -999 250 ~TSM. PTF, GR,GTS -999 ~ 250 ENS'GTS RSHC,REC -999.250 DPHI.LDT PEF, LDT -999. 250 L]LS. LDT LU. LDT -999. 250 I~L. I.,DT $S2, [,DT -999. 250 LSHV. bDT LSRH,LDT -999.250 [,URH LDT TENS.LDT -999.250 MTE~" LDq' ~PHI,C~L -999,250 TNPH CNL RCNT. CNL '999. 250 RCFT: CN [,, GR CNL -999.250 CAI, I.CNL ~4TE~,'CNL -999 250 I4TEN CNL , . . . , C2.BGT -999.250 TE~$.BGT DE PT, 2100 SP.DTE -5 iDOF,DTE 0 IIRD.DTE 144 TE,~ S DTF 1480 HTEN' DTE -999 DTLF ~ SDT -999 TT1 ,SDT -999 [~TT1 , SOT -999 WFC, SDT -999 TENS, SDT -999 DT,PTE -999 GR,GTS -999 RS[{C, REC -999 PELF, LDT -999 LU, LDT -999 8S2,'bDT -999 ,bSR, H, LDT '999 TENS, LDT -999 NPH'I , CNL -999 RCNT. CNL -999 GR, CNL '999 MTE~, CNL -999 C2, BGT -999 .000 .813 .000 875 '000 25O 25O 25O 250 25O 25O 250 25O 25O 25O 25O 250 25O 25O 250 250 25O 25O 250 SFLU. DTE I[)PH. DTE iMOF.DTE IlXD.DTE b! TE!~t, DT,E DT,SD r COHC. TT2'SDT LTT2, SDT WFSH, SDT ~TF:~, DTSM, PT TENS, GTS DPHI, LDT OLS. LDT bP. bDT LSHV LDT L U R H L D T M'I'E~ LDT TNPH RCFT CNb CALl CNL HTEN, CNL TENS, BGT , 2~00 DTE 28 DTE 0 DTE 256 DTE 1435 DTE ~999 SDT -999 SDT -999 8DT '-999 8DT -999 SDT -999 .PTE -999 ,GTS -999 ,REC -999 .000 ,016 .000 250 000 250 250 250 250 25O 250 2:50 250 ,2,,,50 16-~,AR-1.990 18:43 999 250 SP.SDT :999~250 MRES,SDT -~99.250 DT ITP -699.250 -999.2b0 RHOB,LOT ..99.250 SSHV.LDT -999'250 CALI.LOT -999.~50 NRES.SDT -999,250 T~,'RA,CNL -999.250 CNTC,CNG -999.250 -999,250 GP.BGT -999.250 4.230 5,898 0.000 6,563 '999~250 '999.250 '999 250 '999 250 -999 250 -999 250 -999 250 '999 250 '999 ~ '999 ~ 0 0 :999 0 . 999 250 -999 ~50 -999 250 ~999 250 "999 ~50 "999 2~0 "999 250 "999 250 3,752 3 336 0 000 34 000 '999 250 '999 250 '999 250 "999,250 '999,250 "999'250 "999,250 '999,250 '999.250 ~999.250 I b~'.~. DTE I ~. P}i, DT£ CIDP.DTE I IR~}, DTE MRES, DTE DTL,SDT COHS. SOT TT3.$DT LTT3.~DT SP, OT ,..RLo. SDT DT ITP qFCO REC RHOB LOT QSS bDT blTH bDT SSHv' LDT CALl LDT ~RES bDT TNRA CNL CNTC CN.L TEN~ CNb G,R, BGT -999.250 -999.250 999 250 29992250 -999.250 -999.250 99.250 -999.250 -999.250 -999 250 -9991250 -999,~50 -999,250 5.574 5.152 169.375 168.875 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 50 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999250 3.354 3 389 299 500 278 500 -999 250 -999 250 -999 250 -999 250 -'999 250 -999 250 -999 250 -9'99 ' -999 250 GR.SDT hTEN,SDT DTS~.ITP OFSH.REC DRHO.LDT LS.LDT SS1,LD? SIRH.[,D~ GR.LDT HTEN,LDT NPOR CNL CFTC:C~L ~RES.CNL CI,.BG~ ILD.DTE IFRE.DTE CI~P DTE GR:DTE HD . rE DTLN ~ S D~ COST,$DT T T 4, S D T bTT4. SOT G R, S D T HTEN,SOT: DTS'~.ITP OFSH REC DRHO LOT bS bDT SSlbDT SIRH LDT GR LOT },!TEN LDT NPOR CNL CFTC CNL MRES CNL C1BGT I[,D.DTE iFRE,DTE CIMP.DTE GR*DTE [,~D,i,)TE DTLN.SDT COST.SDT TT4.SDT bTT4,SDT G'R, D,t HTEN,SDT DTSM',ITP OFSH.REC DRHO,LOT PAGE: -999 -999. '999, -999. '999, -999, -999 -999 -999 -999 -999 -999 -999: -999, 5 20 193 59 12 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2O 295 47 :-999 -,999 -999 "999 '999 :-999 '-999 -999 28 25O 250 25O 25O 25O 25O 250 25O 25O 25O 25O 25O 250 250 86'1 000 875 5O0 242 25(3 250 250 250 25O 25O 250 250 25O 25O 250 25O 25O 25O 25O 250 25O 25O 279 000 000 000 305 250 25O 250 25O 250 250 250 25O 25O Tape Verification ;ct~lumberger Alaska Computing.)Center PEF .LOT -999,250 OLS. LOT I.,U.LDT -999.2..50 LL, LOT SS2,LDT -999,250 LSHV.I.,DT I..,SRH, LOT -999,250 LUSH,LOT TENS LDT -999,250 MTEM,LDT NPHI~CNL -999,250 TNPH,CNL ~', CNL -999 250 RCFT,CNL UTE~,CNL -999 250 ~TEN,CNL C~.. BGT -999:250 TENS,BGT DEPT. SP. DTf IDGF,DTE IIRD,DTE TFNS,DTE HTEN , DTE DTLF,SDT TT1 ,SDT LTT ]., SDT WFC,SDT '.1'~ N S, SOT DT.PTE CR GTS ~SHC REC PEF bDT LU LOT SS2 LOT LSRH LDT TENS LDT NPHI CNL RCNT CNL GR,~N'L C2,BGT 1900,000 -34,563 0,000 172 375 1390~000 -999.250 -999'~50 -999,250 -999,250 :999,250 999,250 -999,250 -999,250 -999,250 -999,250 ~999,250 999,250 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999 250 SFLU DTE IDPH:DTE IMOF,DTE I!XD,DTE MTE~.DTE DT,$DT COHC.SDT TT2.SDT LTT2,SDT WFSM,SDT MTEM,SDT DTSM.PTE TENS,GTS bDT DPHI,. QLS,LD LL,LDT LSH¥,LDT L U ~ H ,' L D T MTEi~, LDT T N p H, C ~ R C F T, C iN L CALI,C~L HTEN'CNI[I TENS,BG~ DEPT, SP,DTE IDQF DTE IIRD DTE TENS DTE HTEN DTE DTLF SOT TT1SDT LTT~, SDT WFC SOT TENS SOT 5T PTE sG~ GTS R~C ~EC PEF bDT LU bDT $$2 LDT LSRH LOT TENS bDT ,496 0,000 98,438 1.275 000 -999 250 -999 250 -999 250 -999 250 "999 250 -999 250 -999 250 -999 250 -999,250 -999,250 -999,250 '999,250 '999,250 '999,250 16-~AR-1990 18:43 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 -999 250 -999.250 8,195 5.082 0,000 18,141 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 '999.250 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 ~50 -999 250 -999 250 -999 250 -999 -999 ~50 -999 ~50 9.344 9 695 0 000 8 859 -g99 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -9992.50 -999 250 -9~ 250 '9 250 -999 250 -999 250 -999 250 -999 250 QSS.LDT LITH,LDT SSMV,LDT CALI.LDT MRES,LDT TNRA,CNL C~TC.CNL TEN$,CNb GR,BGT IL~,DTE I~PN,DTE CIDP,DTE IIR~,DTE ~RES,DTE DTL,$DT COHS,SDT TT3,SDT LTT3,SDT SP,SDT MRES,SOT DT'ITP OFCO,REC RHOB,LDT OSS,LDT LITH,LDT SSHV,bDT CALl,LOT ~RES,bDT TNRA,CNL CNTC,CNL TENS,CNL GR,BGT ILN DTE I~4PH DTE CIDP OTE IIRl~ DTE MRE8 DTE [)TI,, SDT COHS,SDT TT3,SDT LTT3,SDT S~, SDT MRES SDT DT :I T P QFCO REC RHOB bDT QS8 LDT LITH LOT S, SHV,LDT CALl,LOT M~ES,LDT -999,250 LS.LDT -999.250 SS1.LDT :999 250 SlkH.LDT 999:250 GR,LDT '999,250 HTEN,LD~ '999.250 NPOR,CNL 250 CrTC.C ,., :9991250 ~RES,CNL -999.250 C1,BGT 5.320 ILD.DTE 5.379 IFRE.D~E 196,625 CI~P"DTE 176.750 GR,DTE -999.~50 HD.DTE -999 ~50 DTLN SDT CUST:$DT ,999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 250 250 TT4,SDT 250 BTT4,SDT 250 GR,$!)~ 250 HTEN,SDT ~50 DTSM,ITP 50 OFS~,REC 250 DRHO LDT 250 LS LD~ 250 SS1 LDT 250 $1RH LOT 250 GR bDT 250 HT[:N LOT 250 NPOR CNL 250 CFTC CML 250 C1,BGT 9 10 103 -999 -999 -999 -999 -999 -999 -999 531 375 IFRE 125 CI~P 250 GR 5 0 ~D 50 DTbN 250 COST 2:50 TT4 250 LT~4 2'50 R 250 HTEN 250 250 QFSH 250 DRHO DTE DTE DTE DTE DTE '$DT SDT SOT 'SOT SOT ITP REC LOT -999 2,50 L$ I2DT -999 250 SS1 !,,DY '999. 250 S.1RM '999,250 GR LOT -999,250 H.TEN,LDT PAGE: .29 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 '999,250 5 0O8 20 000 185 750 43 344 12 531 '999 250 '999 250 '999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 :-999 250 -999 2.50 .-999 250 -999 250 -999 250 -999;250 :999,250 999,250 :'999,:250 9,422 20,000 ,313 .250 '999 250 -999 250 -999 250 '999250 "999 250 '999 250 "999 250 '999 250 '999 250 -999 250 -999 250 -999 250 -999 ~50 IS Tape Verification t.,istinq ehlUmberger AlasKa Computin~ Center NPHI,CNL -999,250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL GR,CNL -999,250 CALI,CNL MTEF,CNL -999,250 HTEN,CNL C2,BGT -999.250 TENS,BGT DEPT. SP,DTE IDOF,DTE TEMS,DTE HTEN.OTE DTLF.SDT TT~,SDT LTTi,SDT WFC.SDT TEMS,SDT DT,PTE Gm GTS RSMC:REC PEF.LDT LI!,LDT $ L$~ 'LDT ,LDT TENS,LDT NPMI CNL RCNT CNL GR CML MTE~ CNL C2 BGT 1700 000 SFLU.D%E 4:109 IDPH.DTE 0.000 I~OF.DTE 161,~75 IIXD.DTE ~225.000 ~TEM.D~E 999,250 DT,SDT '999,250 COHC.SDT '999,250 TT2 SDT 9g9,250 LTT2iSDT :999.250 WFSH SOT -999.250 MTEM.SDT -999,250 DTSM,PTE -999,250 TENS,GTS -999,250 DPHi,LDT :~99 250 QLS.LDT 99:250 LL,LDT -999,250 ~.E~,LDT '999.250 TNPM CNL '999,250 RCFT'CNL '999,250 CALI:CN[~ -999,250 'CE CNL -999,250 TEN .:BGT DEPT, SP,DTE IDQF,DTE IIRD DTE TEN~:DTE HTEN,DTE DTLF,SDT TTI,$DT LTT1.,SDT WFC,SDT TEN$.SDT OT,PTE G~,,GT$ R;HC.,REC EF,LDT L~.LDT SS ,bDT LSRH,LDT TENS NPH! CNb RC~T CNL GR CML ~TEM CNL C2 BGT 1600,000 .30,609 O,O00 162,125 1180.000 -999,250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 -999 250 -999 250 -999 250 -999 250 SFLU.DTE iDPH DTE IMOF, DTE IIXD DTE ~TE~{ DTE DT SDT COHC SDT TT2 SDT LTT2 SDT WFSH SDT ~I'EM SDT DTS~ PTE TENS GT$ DP[~I bDT OLS bDT LL LDT I, S H V. L D T L U R H. I.., D T lq T E M, I., D T CALI~C~I, MTEU.C~I, TENS.BGT 16-MAR-1990 18:43 -999 250 TNRa. CNL -999~250 CNTC.CNL -999 250 TENS,C~L -999:250 GR,BGT -999,~50 4,309 5,516 0.000 12 758 2999i250 999 250 -999,250 -999,250 -99q,250 -999 250 -999 25O -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 -999 250 -999 250 -999 250 4,3]~5 5,! 2 0.000 -999 0 -999 ~50 -999 50 -999 250 -999,250 -999 ~50 -999 50 -999 ~50 ~999 50 -999 250 -999 250 ~999 0 -999 250 -999'~50 '999, 50 '-999,250 '999,250 -999,250 ~999,250 ILU,DTE IMPH,DT£ CIDP.OTE IIR;'~,OTE MRES.DTE DTL.SDT COHS,SDT TT3,SDT bTT3.SDT SP.SDT ~RE$,SDT DT,ITP OFCO,REC RHOB,LDT QSS,LDT LITH,[,DT SSHV,LDT CALI,LDT MRES,LDT TNRA,CML TE..,S,CNb GR,BG'r ILM,DTE IM.P.~'DTE ClDP'DTE IIRM.DTE MRES,'DTE DTL,SDT COH$'SDT TT3,SDT iL T T 3, S DT SP MDT ~R,E,$,SDT DT ITP QFCO REC RMOB LDT ~$S bDT LITH LDT SSHV LDT CAL~,LDT MRE$ bDT TNRA CNL CNTC T E N $ .C N b -999.250 NPOR,CNL -999'250 CFTC,CNL -999.250 NRES,CNL -999.250 C1.BGT 4 684 ILD.DTE 4i711 IFRE,DTE 1~! 250 CI~P,DTE 200,375 GR,D~E 999,250 MD,D g :999.~50 DTbN.SDT -999.250 COST SDT 999.250 TT4 gDT 999 250 LTT4 SDT 999:250 GR SDT -999.250 ~TEN SDT -999 250 DTSM.ITP -999 250 QFSH.REC -999 -999 -999 -999 -999 -999 -999 -999 -999 -999,250 250 DRHO,LDT 250 LS,LDT 250 SSI.,LDT 50 SIRH,LDT 50 GR,LDT 250 HTEN bO~ 250 NPOR CNL 0 ~RES NL C1BGT 4.617 4,758 I~..:E 193,250 CIMP 203'250 GR -999 250 HO -999 250 [)TLN -999 250 COST -999 250 TT4 -999 250 LTT4 -.999 -999 -999 -999 -999 1'999 -999 -999 999 -999 -999 -999 -999 ILD DTE DIE DTE DTE SDT 'SOT .SDT 250 GR'SOT 250 HTEN'SDT 250 DTSM ITP 250 0~.. H. REC 0 DRHO 250 $51 250 $1, R~ 250 G~ 250 ~TEN 250 NPO~ 5O CFTC ~50 ~RES 250 cl. LDT LDT LDT LDT LDT bDT C 'N L C N ,.BGT .PAGe: 30 '999,250 '999,250 '999,250 '999.250 5 352 20 000 212 125 59 813 12 461 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '-999 250 -999 250 "999 250 -999 250 -999 0 :-999 2 0 -999 250 -999 250 -999 ~50 -999 250 5 168 2§0O0 21 000 52 313 12 672 -999 250 '999 250 '999 250 '999 250 '999 ~50 "999 250 '999 250 -999 250 '-999 250 '999 2'50 -999 250 .-999 250 ,-999 250 1-999250 "999 250 '999 250 "999 250 '999 250 ,IS Tape Verification [,istir~q 'Cblumberoer AlasKa Computino Center 16-MAR-1990 1.~:43 DFPT. 1500.000 SFLU,DTE 24. SP.DTg -8,352 IDPM.OTE 29. IDOF.DTE 0.000 I~OF,DTE IIRD.DTE 36,406 II×D DTE 1 TENS,DTR 1245.000 MTE~'DTE -999~ HTEN.DTE -999.250 DT:SDT -999 DTLF.SDT -999.250 COHC.SDT -999 TTI.SDT -999 250 TT2,SDT -999 LTT1.SDT -999~250 LTT~'SDT -999 WFC.SDT -999 250 WFSH,SDT -999 TE~S,SDT -999:250 MT~.SDT -999' -999. DT,PTE -999,250 DTS~,PTE GR,G~'S -999,250 TENS.GTS -999 RSHC,REC -999.250 DPHI,I, DT -999 PEF.LD~ -999.250 QL$.LDT -999 LU.LDT ~999,250 LS,LDT '999 SS2,LDT 999.250 LSHV,LDT '999 TE-~,LDT -~99.250 ~TEM:LDT -999 NPHI,CNL -999,250 TNPH,CNL -999 RCNT,CbL 99 250 RCFT..N GR,CNL "99 250 CALI,C.L -999 MTEM,CNL 99 250 HTEN,CNL -999 C2,BGT -999,250 TENS.EST -999, 1400, 70., O. 6~5, 547, -999, ~999, .999, ~999; ,999, ~999, 999; -999' -999 -999 -999 -999 -999, -999. ~999 -999 -999 .-999 000 SFLU.DTE 7'50 IDPH,DTE 000 IMOF,DTE 313 IIXD,DTE 000 MT'EM,DTE 500 DT,SDT 250 CO~C,SDT 250 TT2,SD~ 250 LTT2'SD 250 WFS~'SDY 250 MTEg:'~S,~T 2.50 DTSM,P $ ~0 TENS,GTS 0 [')PHI .bDT LDT 250 250 LL,I.~[~ 250 LSHV.LDT 250 LURH,LDT 250 MTEM,bDT 250 TNPH,CNL 250 (~CFT,CNL 2.50 .ALI,CNL 250 HTEN,CNL 250 TENS,BGT DEPT'DTE SP, IDQF,DTE IIRD,DTE TENS,DTE HTEN,DTE DTLF,SDT TT1,SDT LTTI,$DT WFC,SDT TEN$,SDT DT.PTE Gn (;TS RSHC REC PEF LDT LULDT SS2 LDT LSR. H bDT TENS.LDT NPHI~NL RCNT~ 'NL G~,CNL MTE,~'CNL C2.BGT D[.P'r., 1300 000 SFLU DTE; SP,DTE 69 750 IDPH DTE .IDQF,DTE 0 000 I~.~OF DTE IIRD,DTE 106 438 IIXD DTE 6~ 9, O, O. 104, -999' -99 -999, -999, -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 0, 359 ILM.DTE 344 IMPH,DTE 000 CIDP,DTE 549 IIRf~,DTE 250 MRE:$,DTE 250 DIL,SDT 250 COHS.SDT 250 TT~,S~T 250 LTT3,SDT 250 SP,SDT 250 MRES.SDT 250 DT,ITP 250 QFCO,RFC 250 RHOB.LDT 250 OSS.LDT 250 LITH,LDT 250 $SHV,LDT ~50 CALI,LDT 250 MRES,LDT 250 TNRA.CNL 250 CNTC,CNL 250 TENS.CNL 250 GR,BGT 25O 551 ILM,DTE 1~8 IMPH, DTE 000 CIDP,DTt~ 000 IIRM,DTE ~63 'fRieS, DT'E 50 D L,SDT 250 CDH'S, SDT 250 TT3 , SDT 250 LTT3,SDT 250 SP, S DT 250 MRES,SDT 250 D T ' I T P 250 O F C 0, R E C 250 RHOB,LDT 250 (~SS, bDT 250 .LITH, LDT 250 SSHV~ LDT 250 CAIJI, LDT 250 MRES, LDT 250 TNRA.CNL 250 C,,~1, C, CNL, 250 T E N $ ,. C N b 250 GR, ..:~ ~,, 250 457 IbM DTE 320 IMPH DTE 000 CIDP DTE 000 IIR~ DTE 23.031 26.281 34.06] 41 219 -999:250 -999 250 -999:250 -999 250 -999:250 -999 250 -999:250 -999 250 -999:250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 -999.250 -999.250 B 336 8:367 108,750 113,375 4'303 -999,250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999,250 -999.250 -999.250 -999,250 -999,.250 -999,250 8 031 8 734 120 125 117 625 ILD.DTE IFRE.DTE CIMP.DTE GR.DTE HD.DTE DTLN.$DT COST SBT T'r4:sb~ LTT4 8DT GRiSDT HTEN SDT DTSM,ITP OFSH.REC DRHO.LD~ LS.LDT SSI.LDT SIkH.bDT GR,LDT HTEN.LDT NPOR,CNL CF~C,CNL MRES,CNL C1.BGT I~D.DTE IF E,DTE CI~P,DTE GR,DTE HD.DTE DTLN,$[.)T COST'$DT TT4,$DT LTT4;SDT GR,SDT HTEN,$DT DTS~.ITP OFSH,REC DRHO,LDT L,S,LDT SSI,bDT SikH,bDT GA LOT HTEN LDT NPOR CNL CFTC CNL MRES CNL C1 BGT ILD, [, TE I ~ E. D T E CIM~P 'DTE (;R, DTE PAGE: 31 26,531 20.000 38 031 53 625 12 531 -999 250 -999 250 '999 250 -999 250 -999 250 -999 250 -999 250 -999.250 ~999.250 999.250 -999 250 -999 250 -999 250 -999 250 -999"250 -999,250 -999,250 -999,250 8992 20 o00 fig 175 51~ 13 -999 250 · -999 250 -999 ~50 · -999 50 -999 250 -999 250 -999 250 -999;:;250 -9~9..250 -g 9 250 ~999 250 ~999 250 '999 250 '999 250 '999 250 '999 250 "999 ~50 -999 250 ~999 250 8,234 20,000 11.4,438 46",,:031 !IS Tape Verification List,ir, q ;chlUmberg'er Alaska Computing Center TENS,DTE 680.000 P.~TEi~, DTE HTEN. DTE 552,000 DT. SPT DTLF SPT 999 250 C3HC.SDT TT 1. SDT -999. 250 TT2. SPT LTT1 ,SPT -999.250 5TT2.SDT wFC,SDT -999,250 WFS~,SDT TENS.SPT -999,250 ~TE~,SDT DT.PTE -999.250 DTS~.PTE G~,GTS 19n9'250 TENS GTS RSHC.REC 999,250 ~PHI:LDT PEF. LDT -999. 250 QLS, LDT LU. LDT -999,250 Lb, LDT SS2. LDT -999,250 LSHV. LDT TENS,LDT -999.250 ,~ E~'4 LDT NPH] ,CNL -999,~50 T~4P~4: CNL RCNT.CNL -999.250 ~CFT,CNL GP CNL -999.250 CALI,CNL ~TE~:CNL -999,250 MTEN.CNL C~.BGT -999,250 TENS.BGT DEPT. SP,DTE IDOF,DTE IIRD,DTF TEN S, DTE HTEN , DTE DTLF, SDT TT1.SDT LTT 1 SPT WFC SPT TENS SPT DT PTE G~ GTS ~, C REC RSH ,,, PE~, LDT LU, LDT SS2,LDT LSRH,LDT TENS, LDT GR,CNL M T E~, C N L C2.8GT 1200.000 62,938 o'o0o 84'250 635,000 562,500 '999.250 '999,250 '999.2:50 '999 250 '999 250 '999 250 ~999 250 -999 250 -999 250 -999 250 -999 250 '999 250 '999 250 '999 250 -999 ~50 '999250 '999 250 -999 250 SFLU,DTE IDP~..DTE IIXD.DTE ~qTE~.DTE DT.SDT COHC,$DT TT2,SDT LTT2,SDT WFSH,SDT MTE~'SDT [)PHI ~ LDT 0 L S, L D T L b, L D T LSH. V LDT hURH bDT ~TEM LDT TNPH CNL RCFT C~L CALI CNL MTEN CML TENS,BGT DEPT SP DTE ID II~ DTE DTE TENS DTE HTEM DTE DTLF SPT TT~..SDT LTT~,SDT 1100.000 27,075 0,000 59,531 635,000 596,000 '999,250 '999,250 '999,250 SFLU..OTE IDPH.DTE I~OF,DTE IIXD.DTE MTEM,DTE DT.SDT ''' SDT TT2.~DT LTT2,SDT 16-NiAR-1990 18;43 104.250 -999,250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 2999.250 999'250 -999 ~50 -999!250 -999 250 -999250 -999,250 -999,250 '999,250 -999,250 9.211 10.750 o oo0 0 000 {.02 188 -999 250 -999 250 · -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ~999 250 ~999 250 -999 250 -999 50 -999 ~50 ~999 0 -999 50 -999 ~50 · ~999 250 13,5~1 15,5 0 0 ' 000 00 -999 250 -999 250 -999 250 -999'250 ILM.QTE IMPH,DTE ClDP.DTE I'IR~,DTE MRES,.DTE ~ · ~..., ,SDT COHS. SPT TT3 SPT LTT3 SDT SP SOT ~RES SDT DT ITP RHOB,bDT QSS,LDT LITH LDT SSMV LDT CALI bDT ~RES 4DT TNRA C~I., CNTC CML TENS,CML GR,BGT 4.414 HD.DTE -999.250 DTI,N.SDT -999.250 COST,SOT -999.250 TT4.SDT 999 250 bTT4,$DT 2999:250 GR,SDT 99,250 DTS~.ITP -999 250 DFSH,REC '9991250 DRHO.bDT -999 250 LS.LDT -999 250 SSI.LDT -999.250 S1RM LDT 999 250 GR:LDT ~999!250~TEN.LDT 999 250 NPOR,CNL ~999i250CFTC,CNL 999 250 999 250 C1.BGI 10.328 ILD,DTE 10.5~9 IFRE.DTE 92.9 8 CIMP,DTE 91 625 GR.DTE 4 4.18 HD'DTE -999 250 DTbN'SDT -999 250 COST.$DT -999 250 TT4,SDT -999 250 LTT4..SDT -999 250 GR,SDT -999 250 HTEN;SDT -999.250 DTSM,ITP -999. ~50 QFSN,REC -9991 50 DRHO LDT -999 -999 -999 -999 -999 -999 '999 ~999 -999 ~50 SSI,, LDT 50 $1~ [,DT 250 GR bDT 250 HTEN LDT 250 NPOR,CNL 250 CFTC,CNL 250 MRES,CNL .250 C~.BGT 15,328 15.578 64,188 61,875 4.418 -999,250 -999.250 -999,250 -999.250 IbD.DTE IFRE,DTE CIMP'.DTE GR.DTE HD.DTE DTLN,,SDT COST,~SD'T TT4,SDT LTT4,SDT PAGE: 32 -999.250 999250 999:250 999.250 999,250 ~999.250 -999 250 -999 250 -999 250 '999 250 '999 250 '999 250 -999 250 '999 250 999'250 '999, '999,250 10 539 2O 000 94 813 55 -999 250 -999 250 -999 250 -999 250 ~-999 250 :-999 250 -999 250 -999 250 -999 250 -.999 2.50 2'0 "'999 2~0 "999 250 '9994250 '999,250 :'999,.250 2 9 9; 2 s o 999,;250 15 070 2O 000 64125 34 594 -999 250 -999 250 -999 2.50 -999 250 -9992~0 IS Tape Veriflcatlon Listlnq ~chlumberger AlasKa Computino Center WFC.SDT -999,250 wFSii. SDT TENS'SOT -9~9.25C. ~TEM. MDT DT. PTF~ -999,250 DTS.~. PTE G~,GTS -999.250 TENS.GTS RSHC,REC -999.256 DP~I LDT PEP, LDT -999,250 OLS: LDT LU LDT -999.250 LL. ~.DT SS~:LDT ~999,~50 'LSHV, LDT LSRH,LDT 999,250 LURH.LDT TENS. LDT 999. 250 MTE~ 'LDT NPBI,CN5 -999.250 TNPH~CNL RCNT.CNL -999.250 RCFT CNL GR CML -999,250 CALI.CNL ~T~[CNL :999,250 HTEN.CML C2 'SGT -999.250 TEN&, BGT DEPT, SP,DTE IDOF.DTE IIRD,DTE TEMS,DTE HTEN..DTE DTLF,$DT TT~.SDT LTTI,SDT WFC'SDT TENS,MDT DT PTE .GR GTS RS~C REC PEF LDT LU LDT SS~ LDT TENS LDT NPH! CML ~C~T G~ C~L ~TE~. CNb C~ BGT 1000.000 27,063 0,000 81,125 925 000 581 000 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 50 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 -999 28 -999 250 -999 250 -999 250 -999 250 SFt. U,DTE IDPH,DTE IMOF,DTE IIXO,DTE MTEM,DTE DT.SDT COHC,MDT TT2'SDT !,TT2.SDT WFSH MDT ~TEM MDT DTSt~ PTE TENS. GTS DPHI. LDT OL LDT Lb gDT bSH¥ LDT LURHLDT M'r~ LDT TNPH CNL RCFTCNb CALl CN5 {TEN,CNL TENS.BGT DEPT SP DTE IDQF DTE !IRD DTE TFNS DTE HT~,DTE D'TLF,SDT 'TT1,SDT LTTI.SDT WFC SD? TE~S SOT DT.PTE GR UTS RSHC REC 900,000 23,438 0,000 72,438 485 000 618 500 -999 250 -999 250 -999 250 -999,.250 -999,250 -999.250 -999,250 -999,250 16-~AR-1990 18:43 -q99.950 SP.SDT -999,250 ~RES,SDT -999.250 DT,ITP -999.250 QFCO,REC -999.~50 RHOB,LDf :999,250 QMS.BDT 999.~50 LITH,bDT -999,250 SSHV.LDT -999,250 CAL1.LDT -999,250 ~RES,LDT -999.250 TNRA,CNL -999,250 CNTC,CNL -999,250 TENS.CNL -999.250 GR.BGT -999,250 10,078 ll.O00 0,000 0.000 102~625. '999.250 '999.250 '999.250 '999 ~50 "999 250 '999 250 "999 250 -999 250 -999 250 '999 -999 250 -999 250 "999 2 *999 ~00 -999 0 9 414 12 5O8 0 000 0 000 76 563 -999 '999 0 '999 250 -999250 *999,250 ~999.250 "999,~50 '999, ~0 -999,2 0 IL~.. DTE IMPH,DTE CIDP,DTE IIR~,OTE MRES, DTE DTL,SDT COHS,SDT TT3 .$DT LTT3, MDT SF, MDT MRES,SDT DT, ITP OFCO, REC RHOB , LDT L I f H, L D T "MSHV, LDT ~CALI,LDT MRES ' LDT TNRA,CNL CNTC, Nb 3CENt, , G R, a G T -999.250 GR,SDT -999,250 HTEN.SDT -9q9,250 DTSM,ITP -999,250 QFSH.REC -999.250 ~999.250 LS,LDT 999.250 SS1 LDT -999,250 S1RH~LDT -999 250 GR.LDT -999!250 HTEN.LD~ -999 ~50 NPOR.CNL -999 250 CF?C,CNL -999,250 MRES,CNL -999.250 C1.BGT 10 992 ILD DTE 86,125 GR]DTE 4.38] HD,DTE '999,250 DTLN'SDT -999.250 COST.MDT -999'~50 TT4,SDT -999. -999' -999. -999, -999, -999' -999 250 S1RH -999 250 GR -999 250 -999 ~50 NPOR -999 ~50 CFTC -999 250 ~RES -999 ~50 C1 250 [.,TT4 MDT 250 GR:$DT 250 HTEN,SDT 250 DTSM,ITP 250 OFSH REC 250 DRHOLDT 250 bS bDT 250 SSI. LOT bDT CNL L 9 10 79 95, -999 -999 999 -9gg -ggg -ggg -999 -999 53 ILD ]05 'IF'RE 000 GR 564 HD ~50 DTLN ,250 COST 250 TT4 250 hTT4 250 GR 250 250 DTSM 250 QFSH :250 D T E DTE DTE DTE ;MDT MOT 'MDT MDT MDT REC LDT PAGE: 33 -999 250 -ggg 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999,250 '999.250 lO906 ,0~000 88'4~8 51,6 5 '99~1250 -99 250 -999 250 999 250 999 250 -999 250 -999 250 ,-999 250 -999 250 -999 250 -999250 -999 250 -999 R50 -999 250 "999 :250 "999250 '999 250 '999250 *999 250 12 313 20 000 97 000 ~25 297 -999 250 :-999 25O '999 250 -999 250 -999 250 -999 250 -999 250 '999 250 '999250 '999 250 .IS Tape Yerlflcation Listlnq ;ehlumberger AlasKa Computin~ Center PEF.LDT -999,250 OL$,LOT - LU LDT -999,250 Lb,LDT SS2iLDT -999,250 LSHV,LDT LSR~ bDT -999,250 [,URH, LDT ~ENS.LDT -999,250 ~TEM.LDT NPHI.CNL -999,250 TNPH,C~L ~CNT CNL -999,250 RCFT.CNL G~:CNL -999,250 CALI.CNL UTE~,CN[. -999,250 HTEN,CNL C~,BGT 24,719 TENS.BCT 800,000 45,938 0,000 125,813 505.000 625.000 -999,250 -999,250 -999,250 99,250 :999,250 999'250 -999 250 -999 250 -999 250 '-999 250 -999'250 -999°250 -999 ~50 -999 250 -999 250 -999 250 19,821 SFLU.DTE IDPH.DTE ImOF.DTE !IXD,DTE MTEM DTE DT:SDT CDHC,SDT TT2.SDT LTT2,SDT WFSH.SDT MTFM,SOT DTSM,PTE ENS,GTS ~PHI.LDT ~i~LS,LDT LL,LDT LSMV,LDT LURH. LDT MTE~, LDT T ~ P H ' C ~ b RCFT ' CAt, i'CNt' TEN$.,BG~ DEPT, SP.,DTE IDOF,DTE IIRD,DTE TENS DTE HTEN DTE DTLF SDT TT1 MDT LTTI.,SDT WFC~SDT TENS~$DT DT'PTE GR GTS RSHC REC PEF LDT LU LDT SS2,LDT I,SRH,LDT 'rE~S,LI)T 7~0,~00 2, 91 0'0o0 62,719 495,000 643~500 '9~9,250 '9 9,250 '999 250 ~999 250 '999 250 "999,250 -999.250 -999,250 '999 250 "999 250 '999 250 '999 250 ~999 250 SFLU DTE IDPH DTE IMOF DTE IIXD DTE MTE~ DTE DT SDT COHO, SDT ]~T2 ,SDT LTT2, SDT i~ T 8'.: ~, SDT DTSM, PTE TENS GTS DPH'.I. LDT QLS LDT bh bDT LSHV LDT bURH bDT MTEM LDT 16-~4AR-1. 990 18:43 '999.250 OSS.LDT '999,250 LITH,LDT -999,250 8SH~.I, DT '999,250 CALI.LDT -999,250 NRMS,LDT -999.250 TNRA.CNL -999.250 CNTC,CML '999.250 TENS.CNL -999,250 GR.BGT 305,000 8.2~9 6,969 O,OOO 0 000 76 313 -999 250 '999 250 '999 250 -999 250 -999 250 -999.250 '999.250 '999 250 '9~9 250 -9 9 250 -999 250 -999 250 "999 250 "999 250 ~999 250 "999 250 '99~ 250 -99 250 319 285 ,297~ ,195 0.000 0 oo0 76 375 -9~9 250 -9 9 250 "999 250 "999 ~50 '999 50 "999 250 "999 250 "999 0 '999 250 "999 250 '999 ~50 '999 50 "999 250 IL~,OTE I~PH,DTE CIDP,DTC IIR~,OTE MRES,DTE DTL,$DT COH$,SDT TT3,SDT LTT3,SDT SP,SDT ~RES,SDT DT,ITP QFCO,REC RHOB,LDT O$S,LDT LITH,LDT SSH¥,LDT CALI,LDT MRES,bDT TNRA,CNL CMTC,CNL TENS,CML GR,SGT IbM DTE I.~P H DTE CIDP DTg IRM DTE MRES DTE DTL SDT 3. SDT LTT3 ' SDT SP,SDT DT, OFCC],REC H 06, bDT OSS bDT LITH bDT SSH"V bDT CALI LDT ~RES ~ LDT -999 250 LS.LDT -999:250 SS1.LDT -999.250 $1RH.LDT -999,250 GR.LDT -999.250 HTEN LDT -999.250 NPOR:CNL -999.250 CFTC.CNL -999.250 MRE$.CML 24.656 C1,BGT 7.066 ILD.DTE 7 500 IFRE.DTE 143:375 CIMP.DTE 133 500 GR.DTE HD.DTE 3 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 19 324 250 DTLN.SDT 250 COST.SDT 250 TT4.SDT 250 LTT4.SDT 250 GR.SDT 250 HTEN.SDT 25'0 DTS~.ITF 250 OFSH.REC 250 DRHO bDT 250 L$ LDT 250 SS1, bDT 250 $1RH 250 GR 250 HTEN :250 NPOR 250 CFTC 250 ~IRES 511 C! LDT LDT ,bDT cnn NL 13 563 ILD,OTE 14 859 ~FRE;DTE 65 750 cI~!P;DTE 69 875 GR~DTE 3 686 ~D,.DTE -999 250 I)TLN'SDT -999 250 CO~T,SDT '999 2'50 T'..4.SDT -999 250 LTT4,SD~ -999 250 GR.SD -999 2.50 HTEN,SDT -999 250 DTSM,ITP -999 2.50 QFSH,REC -999 250 DRMO.LDT -999 250 LS LDT '999 250 SS]. LDT '999 250 S1RH LDT -999 250 GR LDT -999 2:50 MTEN,LDT PAGE: 34 -999,250 -999.250 i999i250 999 250 999250 '999 250 -999 i250 -999 250 22,906 6 910 20~000 1,33.250 22,953 -999 250 -999 250 .-999 250 -999 250 -999 250 -999 250 -999 250 ~999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '-999 250 · -999 250 -999 250 -999 250 :20 loo :14 641 2 000 6~ 250 32 500 -99~ 250 -99 250 '999 250 -999 250 -999 250 -999 250 -999 250 -999 250 5O '999~50 -999 -999 250 :-999 250 -999 250 -999 250 :-999 250 .IS ?ave Verification L.istim~ iChlUmberqer AlasKa Co~putim9 Cemter DEPT. SP,DTE IDOF,DTF IIRD.D?E TK~S.DTE MTE~.DTE DTLF.SDT TT~SDT LTT1.SDT WFC.$DT TENS.SDT DT,PTF GR.GTS RSHC.REC PEF LDT LU LDT SS2 LDT LS~M LQT TENS bDT NPHI ~CNT C~}L G~ C~L ~'YE~ CNL C2 BGT 600. 18, O, 87, 475, 628. -999. -999, -999, -999. :999, 999, -999, -999, -999 '999 -999 '999 -999 '999 2999, 999, '999' 16, 000 SF!,t~.DTE 5O0 IDPH.DTE 000 IMOF,DTE 625 IIXD,DTSI 000 ~TE~.DTE 500 DT,SDT 250 CO}4C,SDT 250 TT2.SDT 250 LTT~,SDT 250 WFS~{,SDT 250 MTE)4.SDT 250 OTSi~,P?E 250 TENS.GTS 25O OPHI,LDT 250 ObS.LDT 250 LL,LDT 250 LSH¥.LDT 250 I,,lJRH,LDT 250 HTE~i,LDT 250 TNPH.CNL 250 RCFT,CNt...~ 250 C.AhI,C~L 250 ~TE~.CNL 828 TEN~.,BGT DEpT, .,- SP, DTE IUOF.~ DTE IIRD DTE TENS HTEN DTE DTLF SDT TT1,SDT LTT 1 .~' $1)T WFC, ,SDT TENS, SDT DT.PTE GR GTS RS[~.C REC P E F I, D T bU LDT SS2 LDT bS R, H, l.,~ DT T E' ~ S ' LDT N P.HI, ~ ~ L RCNT. G R, C ~:t' l, IV T E ~ ', C r~ L C , 500, 0 106 440 602 -999 -999 -999 -999 -999 -999, '999, -999, '999, '999, '999 '999 '999 '999 "999 16 0O 0 398 000 5O0 000 5O0 ,250 250 25O 25O 250 250 25O 25O 250 250 250 250 ~50 25O 25O 250 25O 766 SFLU, DTE IDP~t, DTE I ;'~OF, DTE IIX[) DTE ~ "'DYE DT.SD., C07MC,SDT TT2, SDT b T T 2, S 0 T wFSH' SDT ~TE~, SDT DTS~ ~ PTE TE'NS, GTS OPHI. LDT 0 L S L D T LOrrY 5DT bt{Ri,{ LDT MTE~,~ LDT TNP~H RCFT CN[, TENS 8GT 16-~AR-1990 1,8:43 '999,250 T~{RA,CNL -999.250 '999,250 C~TC.C~L -999 250 '999.250 TEI~S,CNL -999~250 -999.250 GR,aCT 24.578 310.0(}0 8,477 IL'~.DTE I0,195 I~PN,[)TE 0,000 CIDP.DTE 0,000 IIRM.DTE 77.063 ~RES,OTE -999.250 DTL,SDT -999 250 CD~S,SDT -999~250 %T3,SDT -999.250 LTT3.SDT 2999,250 SP,~ 999,250 MRE$,SDT '999,250 DT,ITP -999,250 OFCO,R~C -999,250 RHOB.LDT -999,250 OS$,.LOT '999,250 L~TI'~,LDT '999,250 SoHV,LDT '999.250 C,ALI.LDT -999.~50 ~RES,bDT '999,250 T~!RA.CNb . "999 250 CNTC CML '999 ~50 .[E S,CNh '999 50 GR,OGT 255 000 O, 0 77 '999 '999 '999 '999 '999 '999 '999 '999 '999 '999 ~999 ~999 -999 -999 ~999 -999 220 4~4 g~& CIDP,DrE 000 IIR~4,DTE 5 250 ' COHS'SDT 250 TT3.SDT 250 LTTB,SD? 250 SP,SDT 250 ~ES,SDT 250 DT,ITP 250 OFCO,REC 50 RHOB,*bDT 50 oSS,LDT 250 bITH,LDT 250 SSHV,:t,.OT 250 CADI,LDT 250 ~ R E $, [~ iD T 2~0 20 G~,BGT 000 9,641 10,070 98.000 98.125 4,051 -999,250 -999.250 -999,250 2999.25o 999,250 '999.250 i999,250 999.250 999.~50 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999,250 '999,250 4~,906 8 773 9 32O 246 750 107 I 0 -999 -999 250 -999 0 -999 250 -999 250 '999,250 -999~25'0 '999,250 2999'250 999,250 -999'250 -999 250 '999 250 '999 250 '999 250 '999 250 51 750 CFTC.CNL ~!RES,ChL C1.OGT !I.,D.DTE IFRE,DTE CI~P.DTE GR.DTE HD DTE DTI.,N:SDT COST.SD% TT4,SDT bTT4,SD? GR,SDT HTEN.SD~ DTS~.ITF QFSH REC DRHO:LDT LS SSI~LDT SI~H bD~~ GR~LD]: ~..2&N,bDT CFTC ,C~k ~ RES. CNI~ C~.BGT IL.D,DTE !F~E,D]>E CIMP,DTE GR.DTE HD,DTE OTL~t.SDT COST*SDT TT4,SDT LTT4~$DT GR,SDT HTEN.SDT DTS~.ITP QFSH,REC DR~iO,I.~f.)T bS,LDT SS1,LDT $1RH,LDT GR,LDT MTEN,LDT NPOR,CNL CFTC,CNL CI.,8GT -999 250 '999:250 -999.250 17,14! 10,000 20,000' 99 188 40.875 -999,250 -999.250 -999 250 -999:250 -999250 -999:250 '999,250 '999,250 '999 250 -999 250 -999 250 :-999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 17'094 8 367 20 000 107. 250 52 531 '999 250 :'999 250 '999 250 '999 250 ''999 250 '999 250 '999 250 :'999 2.50 "999 250 "999 250 '999250 '999 '999 250 '999 250 :'999250 '999 250 "999 250 "999 250 16 719 ,IS Tame verification Listinq ;cbl. umberqer Alaska ComOutin{] Center DEPT, 400.000 SFLU.DTE SP.DTE -999.250 !DP[i. DTE IDQF,DTE -999'250 I~QF.!)TE IIRD,DTE -999,250 IIXD.DTE TFNS,DTE ~999 250 MTE~,DTE HTEN,DTE §99~250 DT,SDT DTLF.SDT -999,250 COHC,SDT TT1,SDT '999,250 TT2 SDT LTT].SDT -999,250 LTT2~SDT ~FC,SDT -999,250 WFSH SDT TEN$,SDT -999,250 MTE~SDT DT.PTE -999,250 DTS~.PTE GR.GTS -999,250 TENS.GTS RSHC.REC -999 250 DPHI,L[)T PEF,LDT -999~250 OLS,[,,DT LU.LDT 999,250 LL.LDT SS2.bDT :999,250 LSH¥.LDT LS~H,LDT 999 250 4UR~.[0DT TENS.LDT ~999:250 MTEM.LDT NPHI,CNL -999'250 RCNT,CNL -999 250 RCFT,CNL GR,CNL -999' ,250 CALI,CNL MTE~.CNL -999,250 C~,BGT 26.609 TENS,BGT DEPT, IDOF, TENS, HTEN, DT~.,F, TT1, LTTI. WFC, TENS,' RSMC, PEF LU LSRH NPHI RCNT . C2, 390 DTE -999 DTE -999 DTE -999 DTE -999 DTE -999 SDT -999 SDT -999 SDT '999 SDT -999 SDT -999 PTE -999 GTS -999 R~iC -999 LDT -999 bDT '-999 bDT -999 bDT -999 bDT -999 CN[,, -999 CNL -999 CML -999 CNL -999 BGT 26 ** END OF DATA ** 50O 250 250 250 250 250 250 25O 250 250 250 250 250 250 250 250 25 0 25O 25O 25O 250 25O 25O 563 SFLU DTE IDPH DTE I~OF DTE IIXD DTE )~TEM DTE DTSDT COHC SDT TT2 SDT LTT2 SDT WFSH SDT ~TEM,SDT DTSM,PTE DPHI,LD I.[.,LDT LSHV,bDT LURH,LDT MTEM'LDT TNPH,C~,b ~CF'T;CNL CA~I,,CNL, H'TEN'CNh TEN$,BGT 16-~AR-19qO 18:43 -99 -99 -99 -99 -99 -99 -99 -99 -99 -99 -99 99 99 -99 -99 -99 -99 -09 ,'99 22 -99 -99 -99 -99 ~99 -99 "9 '99 "99 '99 '*99 '99 "99 "'99 "99 9,250 9,250 9.250 9,250 9.250 9.~50 9.250 9,250 9,250 9,250 9.250 9,250 9,250 9,250 9,250 9.250 9.250 9 250 9 250 9 250 9 250 9 250 9 250 0 000 9 250 9 250 9 250 9 250 9 50 9 ~50 9 250 9 250 9 250 9 250 9 250 9 250 9 250 9 250 9 250 9 250 9 250 9 25O 9 250 9 250 9 250 0 000 IL~.DTE IMPH,DTE CIDP,DTE I!RM,DTE ~.~RES.DTE D~L,SDT COHS SDT TT3:S~T LTT3,SDT SP,SDT MRES,SDT DT,ITP OFCO.REC RHOB,GDT QSS,LDT LITH,LDT $SHV,LD? CAbI,LDT MRES,LDT TN~A,CNL. CNTC,CNL TENS,C~5 GR,BGT IMPH, CIDP, ~RES, DT5, COHS, TT3, 5TT3~ MRES, mFco; LI, TH, SSHV, CALI, MR. ES TNRA CNTC TENS GR DTE DTE DTE DTE DTE SOT SDT SDT SDT SDT MDT ITP REC bDT b D T LDT LDT LDT LDT C}~b BGT -999.250 : 99 29o 999:250 -999.250 -999.250 -999 250 -999:250 -999.250 -999 250 -999i250 -999 250 99,250 '999,250 '999.250 '999 ~50 -999}250 -999 250 -999 250 -999 250 -999 250 -999 250 ~2~578 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 '999 250 -999:250 -999 ~50 -999 250 -999 250 -999 ,250 -999 250 -999 ~50 -999 ~50 -999 250 -999 250 -999 250 1~ 094 ILD,DTE iFRE.DTF CI~P.DTE GR,DTE HD.DTE DTLM.SDT COST.SDT TT4 SDT LTT4:SDT GR SDT HTEN:SD~ r)TS~ ITP QFSH:REC DRHO.I, DT LS'LDT SSI,LDT S1RH.LDT GR LDT HTEN:LDT NPOR,CNL CFTC,CNL ~RES CNL CI~BGT ILD, DTE IFRE,DTE CIMP,DTE GR,DTE DTLN DT COST TT4 DT bTT4 8.OT GR HTEN SDT DTSM ITP QFSH REC DRHO LDT , I..,S. LDT SS1.LD~ S ~ RH, bDT GR, bDT' H ~. L ,N ,, C~ TC, CNL ~ R F. 8 ,. C N L Ct.,BGT i999,250 999,250 999,250 '999,250 '999,250 '999.250 '999 250 '999 250 '999 250 -999 250 -999 250 '999,250 -999,250 '999,250 -999.250 -999.250 -999,250 -999.250 -999.250 -999'250 '-999.250 -999,250 25.656 -999 0 -999 0 -999<250 -999 250 -999 250 -999 250 .-999 250 :-999 250 :-999 250 -999 250 -999 250 ,,-999 250 =-999 250 -999 2'50 -999 ~50 :~999 50 -999 250 ~999 1250 -999 250 25 688 36 ~I$ Ta~e Ver.~[f,i. cat~ior~ Llst:J. ng ~ehlUm erger Alaska Cor~,Dutinq Center PAGE~ 7 **** FILE TRAILER **** SERVICE ! F[,IC VERSION : 001~04 DATE : 90/03/16 MAX REC SIZE : ~074 FILE TYPE **** TAPE TRAILER **** SERVICE MAME : EDIT DATE : 90/03/16 ORIGIN : FLIC TAPE NAME : 73669 CONTINUATION # : ~ COMMENT : MARATHON OIb COmPANY,TRADING BAY,M-5, API #50-733-20413 **** REEL TRAILER SERVICE; NA~E : EDIT D~TE : 90/03/16 ORIGIN : FblC REEL NAME : 73669 CONTINUATION # : pREVIOUS REEb CO~ENT : ~ARATMO,N OIb CO~PANy,TRADING BAY,M-5, API #50'733-20413