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HomeMy WebLinkAbout201-1711. 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 6,690 feet N/A feet true vertical 4,131 feet N/A feet Effective Depth measured 6,690 feet See schematic feet true vertical 4,131 feet See schematic feet Perforation depth Measured depth 3,723 - 6,680 feet True Vertical depth 3,534 - 4,131 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 5,525 (MD) 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: Intermediate 2,279 9-5/8" 2,812 2,811 6,330psi 3,810psi 13 322-679 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 1192 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 945 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 945 N/A 25 Size 944 1,457 0261386 0 110 13-3/8" 10-3/4" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-171 50-733-20408-01-00 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-14RD Plugs Junk measured Length measured TVD Production Liner 533 3,113 1,134 Casing Structural 532 4,119 4-1/2" 533 5,687 6,680 4,131 1,458 2,713 1,458Conductor Surface Intermediate 20" 16" 4,020psi 7,020psi 2,630psi 3,090psi 6,450psi 8,160psi 2,713 2,712 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 10:27 am, May 15, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.05.15 09:51:56 - 08'00' Dan Marlowe (1267) RBDMS JSB 051623 Updated by: JLL 05/09/23 SCHEMATIC Trading Bay Unit Steelhead Platform Well: M-14RD PTD: 201-171 API: 50-733-20408-01 Completed: 09/10/2001 CASING DETAIL SIZE WT GRADE CONN TOP BOTTOM 20” 94 X-56 73.5’ 945’ 16” 75 K-55 73.5’ 1458’ 13-3/8” 61 K-55 BTC 73.5’ 2713’ 10 3/4” 55.5 N-80 BTC 73.5’ 533’ 9-5/8” 43.5 N-80 BTC 533’ 2812’ (window) 7” 29 L-80 BTC 2574 5687’ TUBING & TAIL PIPE DETAIL: 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 73.5’ 3671’ 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 3693’ 5525’ 4 ½” SCREEN LINER DETAIL: 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 5546’ 5673’ 4-1/2” 11.6 N-80 BTC SSWW Screen 5673’ 6680’ JEWELRY DETAIL NO. Depth ID Item 1. 420’ 3.812” Baker 4-1/2” TE-5 TRSSSV (ID = 3.813”) 2. 1,986’ 3.958” 4-1/2” SFO-2 SPM w/ 16/64” GLV 3 2,574’ 7” x 9 5/8” HMC/ZXP Liner Hanger/Packer w/ tie-back receptacle 4. 3,586’ 3.958” 4-1/2” SMOR-1A spec. clr. SPM w/ 20/64” orifice 5. 3,671’ 3.958” Baker 7” Premier Hydr. Packer 5A. 3,681’ 3.812” Baker 4-1/2” CMU sliding sleeve 6. 3,691’ 3.812” Baker ”X” nipple (profile = 3.813”) 7. 5,537’ 3.867” 4 ½” x 7” Baker SLZXP liner top packer w/ 4 ¾” ID x 12’ 80-47 PBR on top (seal ass. ID = 3.88”) 8. 3,724’-3,734’ Tubing punched on 3/28/09 (4spf, 0 deg) TD = 6690’ MD/4131’ TVD 4-1/2” L-80, 12.6# tail pipe from Premier packer to SLZXP packer 4-1/2” SS WW 12 ga. SS WW Dura-Grip Screen from 5673’ to 6680’. KB elevation = 160.0’, KB to Flng = 73.5’ 5A 1 2 4 9-5/8” Window at 2812’ MD, 7” liner cemented at 5,687’ MD / 4,120’ TVD, 85 deg hole 3 Note: Packer, SSD & ‘X’ nipple positioned @ < 58 degrees inclination 7 5330 –5390’ C3 Perforations (TCP/high angle/ 6 SPJ/ 4 5/8” guns) Note: No blast jts. were used to minimize cost, CTU plug inside 4 ½” required if C3 is to be produced. 6 5 8 Tubing Punch 3,724’-3,734’ on 3/28/09 B-5 B-6 C1 B-8 Updated by: JLL 05/09/23 SCHEMATIC Trading Bay Unit Steelhead Platform Well: M-14RD PTD: 201-171 API: 50-733-20408-01 Completed: 09/10/2001 OPEN HOLE / CEMENT DETAIL 7" 8-1/2” Hole: 109bbls 12.0ppg LiteCrete cement pumped. Lost returns after 100bbls displacement (of 150bbls)Volumetric ToC assuming only 59bbls on backside with 10% washout = 3312’ MD. PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status B5 Upr 3,723' 3,753' 3,534' 3,549'30' 08/18/21 Open B5 Lwr 3,776' 3,876' 3,560’ 3,602’100’ 08/18/21 Open B6 Lwr 4,083' 4,118' 3,682’ 3,695’35’ 08/18/21 Open B8 Mid 4,493’ 4,511’ 3,823’ 3,828’18’ 03/04/23 Open B8 Lwr 4,511’ 4,525’ 3,828’ 3,832’14’ 03/04/23 Open C1 Stray 4,671’ 4,689’ 3,876’ 3,881’18’ 03/04/23 Open C1 Upr 4,718’ 4,732’ 3,890’ 3,894’14’ 03/04/23 Open C1 Upr 4,736’ 4,776’ 3,895’ 3,906’40’ 08/18/21 Open C1 Mid 4,849' 4,889' 3,927’ 3,938’40’ 08/17/21 Open C1 Lwr 4,940' 4,980' 3,953’ 3,965’40’ 08/17/21 Open C3 5,330’ 5,390’ 4,063’ 4,076’60’ 5,673’ 6,680’ 4,119’ 4,131’1,007’ Rig Start Date End Date Eline 3/3/23 5/6/23 03/03/2023 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20408-01-00 201-171 Well Name M-14RD 03/04/2023 - Saturday AK E-line flies to the platform PJSM and PTW M-14RD is flowing 1.25MMCFD @11psi. M/U Lubricator, re-head wire Tool string: 3.125"OD CCL, Gamma, shock sub, roller bogies, and 14ft Geodynamics 2.75"OD, 6SPF, 15gm gun. CCL to top shot 10.8' Platform shutdown, M-14RD offline. Stab on well and pressure test lubricator to 250psi/1500psi -Test good. Build 2X 18ft gun while waiting on the platform to come back online. Stand-by for the platform to come online. Lay down lubricator, break off gun, secure the well, and SDFN. PJSM and PTW M-14RD online flowing 1.235MMCFD @ 11psi. M/U Lubricator MU 2.75"OD CCL, Gamma, shock sub, 3.61"OD roller bogies, and 14ft Geodynamics 2.75"OD, 6SPF, 15gm gun. CCL to top shot 10.5' RIH and pull correlation pass. Send to town - Shift log (-2ft). Pull on depth and perforate the C1u sands from 4,718- 4,732'. POOH, all shots fired, gun was dry with sand on the outside. Tubing Pressure/Rate: 0min - 11psi/1.2MMCFD No pressure change and 1.1MMCFD flow rate after 15min. MU and RIH w/ 2.75"OD CCL, Gamma, shock sub, 3.61"OD roller bogies, and 18ft Geodynamics 2.75"OD, 6SPF, 15gm gun. CCL to top shot 10.5' RIH and pull correlation pass. Send to town - On depth. Pull on depth and perforate the C1-Stray sands from 4,671- 4,689'. POOH, all shots fired, gun was dry with a few scrape marks (probably from perf debris) Tubing Pressure/Rate: 0min - 11psi/1.2MMCFD No pressure change and 1.1MMCFD flow rate after 15min. MU and RIH w/ 3.125"OD CCL, shock sub, 3.61"OD roller bogies, and 14ft Geodynamics 2.75"OD, 6SPF, 15gm gun. CCL to top shot 7.5' RIH and pull correlation pass. Pull second pass for better CCL. Send to town - Shift +1ft. Pull on depth and perforate the B8L sands from 4,511-4,525'. POOH, all shots fired, gun was dry with a little sand. Tubing Pressure/Rate: 0min - 11psi/1.2MMCFD 5min - 13psi/1.6MMCFD 10min - 13psi/1.5MMCFD 15min - 13psi/1.5MMCFD Rig Start Date End Date Eline 3/3/23 5/6/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20408-01-00 201-171 Well Name M-14RD MU and RIH w/ 3.125" OD CCL, shock sub, 3.61"OD roller bogies, and 18ft Geodynamics 2.75"OD, 6SPF, 15gm gun. CCL to top shot 7.5' RIH and pull correlation pass. Send to town - On depth. Pull on depth and perforate the B8M sands from 4,493-4,511'. POOH, all shots fired, gun was dry with a little sand. Tubing Pressure/Rate: 0min - 15psi/1.5MMCFD 5min - 16psi/1.8MMCFD 10min - 13psi/1.7MMCFD 15min - 13psi/1.7MMCFD. MU and RIH w/ 3.125" OD CCL, shock sub, 3.61"OD roller bogies, and 18ft Geodynamics 2.75"OD, 6SPF, 15gm gun. CCL to top shot 7.5' Could not get down past 4,470'. Made 3x attempts, all stopped in the same spot and had overpull coming off bottom. Choked back well to 1.5MMCFD and couldn't fall down. POOH to flow the well overnight. Lay down the gun and lubricator. Secure well and SDFN Secure well, RD AK E-line. Rig Start Date End Date Eline 3/3/23 5/6/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20408-01-00 201-171 Well Name M-14RD 05/06/2023 - Saturday Fly to platform, orientation, PJSM, and PTW M-14RD flowing at ~1.5MMCFD @ 13psi RU AK E-line. M/U 3.125"OD CCL, shock sub, 3.61"OD roller bogies, and 18ft Geodynamics 2.75" OD, 6SPF, 15gm gun. (CCL to top shot 7.4ft) Stab on well Pressure test lubricator to 250psi/1500psi - Test good Choke back well to ~1.2MMCFD @ 21 psi and RIH. Sat down at 4,017'. Work tools and get down to 4,439' running in at 300ft/min. Cannot get deeper. Shut the well in, tubing pressure builds to 37psi. Attempt to get guns down, tag at 4,439' Dump 10 gallons of diesel into the well. Attempt to get guns down, tag at 4,439' POOH. Gun coated in light to moderate fine dark sand. RD AK E-line. Secure well and turn back over to production. 03/05/2023 - Sunday PJSM and PTW M-14RD online flowing 1.6MMCFD @ 16psi Production choked it back to 1.2MMCFD @ 24psi. M/U Lubricator MU 3.125"OD CCL, shock sub, 3.61"OD roller bogies, and 18ft Geodynamics 2.75"OD, 6SPF, 15gm gun. CCL to top shot 7.5' Cannot get past 4,467ft. Slight overpull coming off bottom. Worked gun with no luck getting deeper. Talked to town and the decision was made to RDMO. POOH, Secure well, RD AK-Eline. Turn the well over to production. Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 03/10/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230310 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# TBU M-14RD 50733204080100 201171 3/5/2023 AK E-LINE Perf MPU L-02A 50029219980100 209147 3/5/2023 READ Caliper Survey SRU 23-33 50133101630000 161019 2/17/2023 AK E-LINE CBL CIBP Jet Cut SRU 23-33 50133101630000 161019 2/11/2023 AK E-LINE Plug Cement Punch Please include current contact information if different from above. TBU M-14RD 50733204080100 201171 3/5/2023 AK E-LINE Perf 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:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Dan Marlowe; Juanita Lovett Subject:RE: M-14 (PTD#201-171) proposed perf depths Date:Monday, December 5, 2022 5:19:00 PM Ryan, Hilcorp has approval to extend the perforated interval per the depths in your’ email below. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Monday, December 5, 2022 12:58 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: M-14 (PTD#201-171) proposed perf depths Bryan- Can we please extend the proposed perf depths within this sundry to the attached/below? Will just allow us to get all of the bottom sand package. All perfs still within the same pool, and covered by the same CO. B/C sands from: ±4,118’ - ±4,898’ ±5,090’ MD (±3,695’ - ±3,926’ ±3996’ TVD) 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, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. RBDMS JSB 120222 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/18/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL 7%80-14RD (PTD 201-171) PERF 08/19/2021 Please include current contact information if different from above. 37' (6HW Received By: 12/07/2021 By Abby Bell at 3:40 pm, Dec 07, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,690 feet N/A feet true vertical 4,131 feet N/A feet Effective Depth measured 6,690 feet See Schematic feet true vertical 4,131 feet See Schematic feet Perforation depth Measured depth 3,723 - 6,680 feet True Vertical depth 3,534 - 4,131 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 5,525 MD 4,102 TVD Packers and SSSV (type, measured and true vertical depth)See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD 944 measured true vertical Packer Production 7" 5,687 4,1193,113 9-5/8" 4-1/2" 20" 2,812 MD 945 1,458 2,713 6,680 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 120 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-171 50-733-20408-01-00 Plugs ADL0018730 Trading Bay Unit M-14RD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-298 12 Authorized Signature with date: Authorized Name: 0 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 105 N/A Oil-Bbl 465 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 2,092 McArthur River Field / Middle Kenai Gas PoolN/A measured 533 2,279 Size 44 Intermediate Casing Structural Liner 1,134 Length 945 1,458 2,713 Conductor Surface 3,810psi 16" 13-3/8" 10-3/4" 533 6,450psi 907 777-8376 6,330psi 1,457 2,712 532 2,811 4,131 8,160psi 7,020psi Collapse 1,020psi Katherine O'Connor Katherine.Oconnor@hilcorp.com Tubing Pressure 1,540psi 4,020psi 2,630psi 3,090psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:27 am, Sep 09, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.09.09 07:29:51 -08'00' Dan Marlowe (1267) BJM 10/28/21 SFD 9/9/2021DSR-9/9/21 RBDMS HEW 9/10/2021 Updated by: JLL 09/08/21 SCHEMATIC Trading Bay Unit Steelhead Platform Well: M-14RD PTD: 201-171 API: 50-733-20408-01 Completed: 09/10/2001 CASING DETAIL SIZE WT GRADE CONN TOP BOTTOM 20” 94 X-56 73.5’ 945’ 16” 75 K-55 73.5’ 1458’ 13-3/8” 61 K-55 BTC 73.5’ 2713’ 10 3/4” 55.5 N-80 BTC 73.5’ 533’ 9-5/8” 43.5 N-80 BTC 533’ 2812’ (window) 7” 29 L-80 BTC 2574 5687’ TUBING & TAIL PIPE DETAIL: 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 73.5’ 3671’ 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 3693’ 5525’ 4 ½” SCREEN LINER DETAIL: 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 5546’ 5673’ 4-1/2” 11.6 N-80 BTC SSWW Screen 5673’ 6680’ JEWELRY DETAIL NO. Depth ID Item 1. 420’ 3.812” Baker 4-1/2” TE-5 TRSSSV (ID = 3.813”) 2. 1,986’ 3.958” 4-1/2” SFO-2 SPM w/ 16/64” GLV 3 2,574’ 7” x 9 5/8” HMC/ZXP Liner Hanger/Packer w/ tie-back receptacle 4. 3,586’ 3.958” 4-1/2” SMOR-1A spec. clr. SPM w/ 20/64” orifice 5. 3,671’ 3.958” Baker 7” Premier Hydr. Packer 5A. 3,681’ 3.812” Baker 4-1/2” CMU sliding sleeve 6. 3,691’ 3.812” Baker ”X” nipple (profile = 3.813”) 7. 5,537’ 3.867” 4 ½” x 7” Baker SLZXP liner top packer w/ 4 ¾” ID x 12’ 80-47 PBR on top (seal ass. ID = 3.88”) 8. 3,724’-3,734’ Tubing punched on 3/28/09 (4spf, 0 deg) TD = 6690’ MD/4131’ TVD 4-1/2” L-80, 12.6# tail pipe from Premier packer to SLZXP packer 4-1/2” SS WW 12 ga. SS WW Dura-Grip Screen from 5673’ to 6680’. KB elevation = 160.0’, KB to Flng = 73.5’ 5 1 2 4 9-5/8” Window at 2812’ MD, 7” liner cemented at 5,687’ MD / 4,120’ VD, 85 deg hole angle 3 Note: Packer, SSD & ‘X’ nipple positioned @ < 58 degrees inclination 7 5330 –5390’ C3 Perforations (TCP/high angle/ 6 SPJ/ 4 5/8” guns) Note: No blast jts. were used to minimize cost, CTU plug inside 4 ½” required if C3 is to be produced. 6 5 8 Tubing Punch 3,724’-3,734’ on 3/28/09 B-5 B-6 C1 Updated by: JLL 09/08/21 SCHEMATIC Trading Bay Unit Steelhead Platform Well: M-14RD PTD: 201-171 API: 50-733-20408-01 Completed: 09/10/2001 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status B5 Upr 3,723' 3,753' 3,534' 3,549'30' 08/18/21 Open B5 Lwr 3,776' 3,876' 3,560’ 3,602’100’ 08/18/21 Open B6 Lwr 4,083' 4,118' 3,682’ 3,695’35’ 08/18/21 Open C1 Upr 4,736’ 4,776’ 3,895’ 3,906’40’ 08/18/21 Open C1 Mid 4,849' 4,889' 3,927’ 3,938’40’ 08/17/21 Open C1 Lwr 4,940' 4,980' 3,953’ 3,965’40’ 08/17/21 Open C3 5,330’ 5,390’ 4,063’ 4,076’60’ 5,673’ 6,680’ 4,119’ 4,131’1,007’ ()()()() B5 Upr 3,723' 3,753' 3,534' 3,549'30' 08/18/21 Open B5 Lwr 3,776' 3,876' 3,560’ 3,602’100’ 08/18/21 Open B6 Lwr 4,083' 4,118' 3,682’ 3,695’35’ 08/18/21 Open C1 Upr 4,736’ 4,776’ 3,895’ 3,906’40’ 08/18/21 Open C1 Mid 4,849' 4,889' 3,927’ 3,938’40’ 08/17/21 Open C1 Lwr 4,940' 4,980' 3,953’ 3,965’40’ 08/17/21 Open ()()()() p Rig Start Date End Date E-Line 8/16/21 8/18/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20408-01-00 201-171 Well Name M-14RD 08/16/2021 - Monday Arrive OSK heliport. Fly to platform. Platform orientation. PJSM w/ Production operators & permit. Pull well hatch covering & set wireline bridge. MU riser from WH to deck surface of wireline bridge. Install WLV. MU grease head to lubricator. PU lubricator. MU GR/CCL, roller boogie & Firing Head BHA. Surface test GR/CCL & fire check FH. PU Per Gun #1: 2-7/8" X 20' Razor Low Swell HSC, 6 spf, 60 deg. 15 gm charges. MU roller boogie to bottom of gun. CCL-to Top Shot = 10.20'. Move to well. PT WLV & Lub= 250/1500. Open swab & RIH. Tbg = 12 psi w/ Flow Rate = 0.685 MM/day. RIH to tag @ 4700' CCL. PUH 100', unable to fall. PUH to 4500' & able to fall. Fall to 4800', PUH. Unable to fall below 4500'. Fall to 4860'. PUH, fall to 5100'. PUH, fall to 5125' CCL. Log up to 4500' CCL. Correct -4.0'. Send log for review & verification. Log on depth. RBIH to 5080' CCL tag depth. Log up to 4949.8' CCL (4949.8 + 10.2 = 4960' TS). Fire Perf Gun #1 to perf Zone C1 Lower 4960' - 4980'. Tbg = 9 psi & FR = 0.28 MM/day. Log up 200' & POOH. PUW =1000#. Hang up @ 3650' CCL. Unable to move wire in or out of hole. PU working wire weight up in 100# - 200# increments. Set brake between PUs to see if wire stretch will pull BHA free. Pull thru rope socket weak point @ 2750# w/ brake set. Have Prod. Operator shut in flow line. CCL depth = 3650', End of tool depth = 3684' RKB. POOH. RD ELU. All wire recovered w/ rope socket tattle tail @ end of wire. Call for Slickline crew to fish tools & gun tomorrow. Secure deck & turnover well to Production to bring online & flow over night. Eline operator creates lost in hole drawing. Copy saved to Project file. SDFN. Job in Progress. Fire Perf Gun #1 to perf Zone C1 Lower 4960' - 4980'. T Rig Start Date End Date E-Line 8/16/21 8/18/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20408-01-00 201-171 Well Name M-14RD 08/17/2021 - Tuesday Simops meeting w/ production. PJSM & crane permit. EL crew moves ELU off to side & spots SLU & SL toolbox on NW corner drill deck. Waiting on SL crew to arrive. SL crew arrives platform. PJSM & permit. RU SLU. MU SL1-3/4" toolstring w/ 3.70 OD LIB. Move to well. PT WLV & Lub = 250/1500. Replace leaking lubricator o-ring. Retest - PASS. Prod. Operators shut in well. RIH w/ 3.70" LIB to 3851' KB for tag @ top of PG#1 fish. OOH w/ clear pic of clean rope socket. RBIH w/ JD overshot to 3851' & latch fish. PU for 150# overpull jar lick. Set down & RIH freely. PUH clean & clear nipple & SS profiles. POOH. OOH w/ fish on. LD fish & RBIH w/ 3.55" OD bell guide & 3.60" roller boogie to 3800' clean. Make multiple passes from 3800' - 3500' w/o restriction. Continue RIH freely to 5200'. POOH. RD SLU & fly crew to beach. RU ELU. MU perf gun tool suite w/o roller boogies. Surface test GR/CCL. Fire check FH. PU Perf Gun #2: 2-7/8" x 20' Razor low swell HSC, 6 spf, 60 deg, 15 gm. CCL-to-Top Shot = 8.3'. PT = 250/1500. Prod. Operators bring well online. Tubing = 13 psi, FR = 0.520 MM/day. RIH w/ PG #2 to 5048' CCL resistance depth. Log up to 4500'. Correct +12'. Send log for review. Drop back down & slack off @ 4850'. PUH to 4000', RBIH & slack off @ 4855'. PUH to 3700' & have Prod. Op. drop FR = 0.24 MM/day. RBIH to 5048'. Log up to 4931.7' CCL to put shots on depth (4931.7 + 8.3 = 4940' TS). Fire Perf Gun #2 perfing Zone C1 Lower 4940' - 4960'. Log up 200'. POOH passing 3691' nipple & 3681' SS clean. OOH w/ all shots fired & dry gun. Surface test GR/CCL & fire check FH. PU Perf Gun #3: 2-7/8" x 20' Razor low swell HSC, 6 spf, 60 deg, 15 gm. CCL-to-Top Shot = 8.3'. Tubing = 22, FR = 0.210 MM/day. RIH w/ PG #3 to 5184' CCL. Log up to 4350' & continue PUH to 3700'. Correct -6.0'. Send log for review. RBIH to 4938' CCL slack off. Log up to 4860.7' CCL to put shots on depth (4860.7 = 8.3 = 4869' TS). Fire Perf Gun #3 perfing Zone C1 Mid 4869' - 4889'. Log up 200' & POOH. OOH w/ all shots fired & dry gun. Surface test GR/CCL & fire Check FH. PU Perf Gun #4: 2-7/8" x 20' Razor low swell HSC, 6 spf, 60 deg, 15 gm. CCL-to-Top Shot = 8.3'. Tubing = 34, FR = 0.250 MM/day. RIH w/ Perf Gun #4 to 5053" CCL. Log up to 4350' CCL. Correct -6.5'. PUH to 3200'. Send log for review. RBIH to 4951' CCL slack off. Log up to 4840.7' to put shots on depth (4840.7 + 8.3 = 4849' TS). Fire Perf Gun #4 perfing Zone C1 Mid 4849' - 4869'. Log up 200' & POOH. OOH w/ all shots fired & dry gun. Stand back from well. Secure well, drill deck & ELU. Turnover well to Production Operators. SDFN. Job in Progress. Fire Perf Gun #3 perfing Zone C1 Mid 4869' - 4889' Fire Perf Gun #2 perfing Zone C1 Lower 4940' - 4960'. e Perf Gun #4 perfing Zone C1 Mid 4849' - 4869'. Rig Start Date End Date E-Line 8/16/21 8/18/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20408-01-00 201-171 Well Name M-14RD Simops mtg w/ production. PJSM & permit. RU ELU. Surface test GR/CCL & fire check FH. PU Perf Gun #5: 2-7/8" x 20' Razor low swell, 6 spf, 60 deg, 15 gm. CCL-to-Top Shot = 8.3'. Tubing = 12, FR = 0.490 MM/day. RIH w/ Perf Gun #5 to 4886' CCL slack off. Log up to 4350', correct = -5.5'. PU to 3200'. Send log for review. RBIH to 4886' CCL slack. Log up to 4747.7' CCL to put shots on depth(4747.7 + 8.3 = 4756' TS) Fire Perf Gun #5 to perf Zone C1 Upper 4756' - 4776'. Log up 200' & POOH. OOH w/ all shots fired & dry gun. Surface test GR/CCL & fire check FH. PU Perf Gun #6: 2-7/8" x 20' Razor low swell, 6 spf, 60 deg, 15 gm. CCL-to- Top Shot = 8.3'. Tubing = 12, FR = 0.32 MM/day. RIH w/ Perf Gun #6 to 4760' CCL slack. Log up to 4350' & PU to 3200'. Correct +5.5' & send log for review. RBIH to 4756' CCL slack. Log up to 4727.7' CCL to put shots on depth. Fire Perf Gun #6 perfing Zone C1 Upper 4736' - 4756'. Log up 200' & POOH. OOH w/ all shots fired & dry gun. Surface test GR/CCL & fire check FH. PU Perf Gun #7: 2-7/8" x 20' Razor low swell, 6 spf, 60 deg, 15 gm. CCL-to- Top Shot = 8.3'. Tubing = 12, FR = 0.29 MM/day. RIH w/ Perf Gun to 4750' CCL #7 slack. Log up to 4350' & PU to 3000'. Attempt to drop back down & RBIH 4460' slack depth. PU to 2800' & RBOH to 4650' slack depth. Unable to drop below C1 Upper perf depths of 4716' - 4736'. Call Ops. Engineer. Decision to abandon attempt to perf C1 Upper @ 4716' - 4736'. Will come up hole & perf Zone B6 Lower. PUH logging up 4300' - 3500' & PU to 3000'. Send log for review, correct -2.0'. RBIH to 4234' CCL. Log up to 4089.7' CCL to put shots on depth (4089.7 + 8.3 = 4098' TS). Fire Perf Gun #7 perfing Zone B6 Lower 4098' - 4118'. Log up 200' & POOH. OOH all shots fired & dry. Surface test GR/CCL & fire check FH. PU PG #8: 2- 7/8" x 15' Razor low swell, 6 spf, 60 deg, 15 gm. CCL-to- Top Shot = 8.3'. RIH w/ PG #8 to 4340' CCL. Log up to 3500' & PU to 3000'. Correct +5.0'. Send for review. RBIH to 4240' & log up to 4074.7' CCL to put shots on depth (4074.7 + 8.3 = 4083' TS). Fire PG #8 perfing Zone B6 Lower 4083' - 4098'. Log up 200' & POOH. OOH all shots fired & dry. Surface test GR/CCL & fire check FH. T = 12, FR = 0.30 MM/day. PU PG #9: 2-7/8" x 20' Razor low swell, 6 spf, 60 deg, 15 gm. CCL-to- Top Shot = 8.3'. RIH w/ PG #9 to 4270' CCL. Log up to 3500'. Correct +5.0'. Send log for review. RBIH to 4170' CCL & log up to 3847.7' CCL to put shots on depth (3847.7 + 8.3 = 3856' TS). Fire PG #9 perfing Zone B5 Lower 3856' - 3876'. Log up 200' & POOH. OOH w/ all shots fired & dry. Surface test GR/CCL & fire check FH. T = 30, FR = 0.60 MM/day,PU PG #10: 2- 7/8" x 20' Razor low swell, 6 spf, 60 deg, 15 gm. CCL-to- Top Shot = 8.3'. 08/18/2021 - Wednesday Fire PG #9 perfing Zone B5 Lower 3856' - 3876' Fire Perf Gun #5 to perf Zone C1 Upper 4756' - 4776' Fire Perf Gun #7 perfing Zone B6 Lower 4098' - 4118'. Fire Perf Gun #6 perfing Zone C1 Upper 4736' - 4756' Fire PG #8 perfing Zone B6 Lower 4083' - 4098'. Rig Start Date End Date E-Line 8/16/21 8/18/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20408-01-00 201-171 Well Name M-14RD RIH w/ PG #10 to 4110' CCL. Log up to 3500'. Correct +5.0'. Send log for review. RBIH to 4000' CCL & log up to 3827.7' CCL to put shots on depth (3827.7 + 8.3 = 3836' TS). Fire PG #10 perfing Zone B5 Lower 3836' - 3856'. Log up 200' & POOH. OOH all shots fired & dry. Surface test GR/CCL & fire check FH. T = 12, FR = 1.30 MM/day. PU PG #11: 2-7/8" x 20' Razor low swell, 6 spf, 60 deg, 15 gm. CCL-to- Top Shot = 8.3'. RIH w/ PG #11 to 4120' CCL. Log up to 3500'. Correct +4.0'. Send log for review. RBIH to 3910' CCL & log up to 3807.7' CCL to put shots on depth (3807.7 + 8.3 = 3816' TS). Fire PG #11 perfing Zone B5 Lower 3816' - 3836'. Log up 200' & POOH. OOH all shots fired & dry. Surface test GR/CCL & fire check FH. T = 16, FR = 1.75 MM/day. PU PG #12: 2-7/8" x 20' Razor low swell, 6 spf, 60 deg, 15 gm. CCL-to- Top Shot = 8.3'. RIH w/ PG #12 to 4110' CCL. Log up to 3500'. Correct +1.0'. Send log for review. RBIH to 3890' CCL & log up to 3787.7' CCL to put shots on depth (3787.7 + 8.3 = 3796' TS). Fire PG #12 perfing Zone B5 Lower 3796' - 3816'. Log up 200' & POOH. OOH all shots fired & dry. Surface test GR/CCL & fire check FH. T = 16, FR = 1.75 MM/day. PU PG #13: 2-7/8" x 20' Razor low swell, 6 spf, 60 deg, 15 gm. CCL-to- Top Shot = 8.3'. RIH w/ PG #13 to 4097' CCL. Log up to 3500'. Correct +5.0'. Send log for review. RBIH to 3857' CCL & log up to 3767.7' CCL to put shots on depth (3767.7 + 8.3 = 3776' TS). Fire PG #13 perfing Zone B5 Lower 3776' - 3796'. Log up 200' & POOH. Pulling heavy @ 1300' & line is covered w/ thick schmoo. OOH all shots fired & dry. T = 19, FR = 2.0 MM/day. Lay down grease head & lubricator. Inspect grease head tubes, packed w/ scale. Clean grease head assembly & install new packing O-rings. Surface test GR/CCL & fire check FH. PU PG #14: 2-7/8" x 30' Razor low swell, 6 spf, 60 deg, 15 gm. CCL-to- Top Shot = 8.3'. RIH w/ PG #14 to 4016' CCL. Log up, PUW = 2.5K, very heavy off bottom. Correct +5.0'. Log up to 3714.7' CCL to put shots on depth (3714.7 + 8.3 = 3723' TS). Send log for review. Log on depth. Fire PG #14 perfing Zone B5 Upper 3723' - 3753'. Log up 200' & POOH. OOH all shots fired & dry. T = 14, FR = 2.03 MM/day. Stand back from well & lay down lubricator. Nite cap WLV. Turnover well to production. Secure ELU & drill deck. SDFN. Job Complete. e PG #11 perfing Zone B5 Lower 3816' - 3836' Fire PG #14 perfing Zone B5 Upper 3723' - 3753' Fire PG #10 perfing Zone B5 Lower 3836' - 3856' Fire PG #13 perfing Zone B5 Lower 3776' - 3796'. Fire PG #12 perfing Zone B5 Lower 3796' - 3816'. 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): 6,690'N/A Casing Collapse Structural Conductor 1,020 psi Surface 1,540 psi Intermediate 4,020 psi Intermediate 3,810 psi Production 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:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 6,450 psi Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 6,330 psi N/A 945' COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 201-171 50-733-20408-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-14RD CO 228A 12.6# / L-80 TVD Burst 5,525' 8,160 psi Tubing Size: MD 2,630 psi 3,090 psi 1,457' 2,712' 2,811' 1,458' 2,713' 944' 533' 532' 945' 20" 16" 13-3/8" 1,458' 9-5/8"2,279' 2,713' 533' 10-3/4" 5,687' Perforation Depth MD (ft): 2,812' 5,330 - 6,680 3,113' See Schematic Tubing Grade:Tubing MD (ft): 4,063 - 4,131 Perforation Depth TVD (ft): Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 6/28/2021 4-1/2" Daniel E. Marlowe See Schematic 4,131' 6,690' 4,131' 0 psi 1,134' 4-1/2" 4,119'7" 6,680' 4,131' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:50 am, Jun 16, 2021 321-298 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.06.16 10:26:31 -08'00' Dan Marlowe (1267) BJM 06/23/21 DSR-6/17/21DLB 06/16/2021 10-404 X  dts 6/24/2021 JLC 6/24/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.24 13:02:33 -08'00' RBDMS HEW 6/24/2021 Well Work Prognosis Well Name:Trading Bay Unit M-14RD API Number: 50-733-20408-01 Current Status:Gas Well Leg:A-1 (SW corner) Estimated Start Date:6/28/21 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:201-171 First Call Engineer:Katherine O’Connor Office: 907-777-8384 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Office: 907-777-8434 Cell: 907-570-1801 Current Bottom Hole Pressure: 165 psi @ 4,125 TVD Based on offset M-22 RFT data in 2018 Maximum Expected BHP: 311 psi @ 3,680’ TVD Based on offset M-22 RFT data in 2018 Maximum Potential Surface Pressure: ~0 psi @ 3,680’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) **Well to be perforated while flowing Brief Well Summary: M-14RD is currently a lateral in the Tyonek/GGS C-4 sand, with an additional perf added in the C-3. We plan to add perforations the B-5, B-6 and C-1 sands. 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 M-14RD Schematic 9-10-01.doc Updated: 06/14/21 DRAWN BY: CVK SCHEMATIC Trading Bay Unit Steelhead Platform Well: M-14RD PTD: 201-171 API: 50-733-20408-01 Completed: 09/10/2001 CASING DETAIL SIZE WT GRADE CONN TOP BOTTOM 20” 94 X-56 73.5’ 945’ 16” 75 K-55 73.5’ 1458’ 13-3/8” 61 K-55 BTC 73.5’ 2713’ 10 3/4” 55.5 N-80 BTC 73.5’ 533’ 9-5/8” 43.5 N-80 BTC 533’ 2812’ (window) 7” 29 L-80 BTC 2574 5687’ TUBING & TAIL PIPE DETAIL: 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 73.5’ 3671’ 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 3693’ 5525’ 4 ½” SCREEN LINER DETAIL: 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 5546’ 5673’ 4-1/2” 11.6 N-80 BTC SSWW Screen 5673’ 6680’ JEWELRY DETAIL NO. Depth ID Item 1. 420’ 3.812” Baker 4-1/2” TE-5 TRSSSV (ID = 3.813”) 2. 1,986’ 3.958” 4-1/2” SFO-2 SPM w/ 16/64” GLV 3 2,574’ 7” x 9 5/8” HMC/ZXP Liner Hanger/Packer w/ tie-back receptacle 4. 3,586’ 3.958” 4-1/2” SMOR-1A spec. clr. SPM w/ 20/64” orifice 5. 3,671’ 3.958” Baker 7” Premier Hydr. Packer 5A. 3,681’ 3.812” Baker 4-1/2” CMU sliding sleeve 6. 3,691’ 3.812” Baker ”X” nipple (profile = 3.813”) 7. 5,537’ 3.867” 4 ½” x 7” Baker SLZXP liner top packer w/ 4 ¾” ID x 12’ 80-47 PBR on top (seal ass. ID = 3.88”) 8. 3,724’-3,734’ Tubing punched on 3/28/09 (4spf, 0 deg) TD = 6690’ MD/4131’ TVD 4-1/2” L-80, 12.6# tail pipe from Premier packer to SLZXP packer 4-1/2” SS WW 12 ga. SS WW Dura-Grip Screen from 5673’ to 6680’. KB elevation = 160.0’, KB to Flng = 73.5’ 5 1 2 4 9-5/8” Window at 2812’ MD, 7” liner cemented at 5,687’ MD / 4,120’ VD, 85 deg hole angle 3 Note: Packer, SSD & ‘X’ nipple positioned @ < 58 degrees inclination 7 5330 –5390’ C3 Perforations (TCP/high angle/ 6 SPJ/ 4 5/8” guns) Note: No blast jts. were used to minimize cost, CTU plug inside 4 ½” required if C3 is to be produced. 6 5 8 Tubing Punch 3,724’-3,734’ on 3/28/09 Updated by: JLL 06/14/21 PROPOSED Trading Bay Unit Steelhead Platform Well: M-14RD PTD: 201-171 API: 50-733-20408-01 Completed: 09/10/2001 CASING DETAIL SIZE WT GRADE CONN TOP BOTTOM 20” 94 X-56 73.5’ 945’ 16” 75 K-55 73.5’ 1458’ 13-3/8” 61 K-55 BTC 73.5’ 2713’ 10 3/4” 55.5 N-80 BTC 73.5’ 533’ 9-5/8” 43.5 N-80 BTC 533’ 2812’ (window) 7” 29 L-80 BTC 2574 5687’ TUBING & TAIL PIPE DETAIL: 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 73.5’ 3671’ 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 3693’ 5525’ 4 ½” SCREEN LINER DETAIL: 4-1/2” 12.6 L-80 AB Mod IBTC (Spec. Cl.) 5546’ 5673’ 4-1/2” 11.6 N-80 BTC SSWW Screen 5673’ 6680’ JEWELRY DETAIL NO. Depth ID Item 1. 420’ 3.812” Baker 4-1/2” TE-5 TRSSSV (ID = 3.813”) 2. 1,986’ 3.958” 4-1/2” SFO-2 SPM w/ 16/64” GLV 3 2,574’ 7” x 9 5/8” HMC/ZXP Liner Hanger/Packer w/ tie-back receptacle 4. 3,586’ 3.958” 4-1/2” SMOR-1A spec. clr. SPM w/ 20/64” orifice 5. 3,671’ 3.958” Baker 7” Premier Hydr. Packer 5A. 3,681’ 3.812” Baker 4-1/2” CMU sliding sleeve 6. 3,691’ 3.812” Baker ”X” nipple (profile = 3.813”) 7. 5,537’ 3.867” 4 ½” x 7” Baker SLZXP liner top packer w/ 4 ¾” ID x 12’ 80-47 PBR on top (seal ass. ID = 3.88”) 8. 3,724’-3,734’ Tubing punched on 3/28/09 (4spf, 0 deg) TD = 6690’ MD/4131’ TVD 4-1/2” L-80, 12.6# tail pipe from Premier packer to SLZXP packer 4-1/2” SS WW 12 ga. SS WW Dura-Grip Screen from 5673’ to 6680’. KB elevation = 160.0’, KB to Flng = 73.5’ 5 1 2 4 9-5/8” Window at 2812’ MD, 7” liner cemented at 5,687’ MD / 4,120’ VD, 85 deg hole angle 3 Note: Packer, SSD & ‘X’ nipple positioned @ < 58 degrees inclination 7 5330 –5390’ C3 Perforations (TCP/high angle/ 6 SPJ/ 4 5/8” guns) Note: No blast jts. were used to minimize cost, CTU plug inside 4 ½” required if C3 is to be produced. 6 5 8 Tubing Punch 3,724’-3,734’ on 3/28/09 B-5 B-6 C1 Updated by: JLL 06/14/21 PROPOSED Trading Bay Unit Steelhead Platform Well: M-14RD PTD: 201-171 API: 50-733-20408-01 Completed: 09/10/2001 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status B5 Upr ±3,722' ±3,755' ±3,534' ±3,550'±33' Future Proposed B5 Lwr ±3,769' ±3,880' ±3,557' ±3,604'±111' Future Proposed B6 Lwr ±4,081' ±4,118' ±3,682' ±3,695'±37' Future Proposed C1 Upr ±4,717' ±4,889' ±3,889' ±3,938'±172' Future Proposed C1 Lwr ±4,912' ±4,980' ±3,945' ±3,965'±68' Future Proposed C3 5,330’ 5,390’ 4,063’ 4,076’60’ 5,673’ 6,680’ 4,119’ 4,131’1,007’ e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q ð L - 11 J Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: c¡¡:;; ¿ (Count does include c7 sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date:~ /301 o(p If NO in stage 1, page(s) discrepancies were found: Organizing (done) D Two-sided 1111111111111111111 RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, Norrype: D Poor Quality Originals: D Other: NOTES: Date1:6/\30,'Ob BY: ~ Project Proofing Date ~ Ido '0" I ~ x 30 = t()(} Date: ~ /(in /0 h BY: ~ Scanning Preparation BY: ~ BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed 1111111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: 151 1111111111111111111 151 + ;J I = TOTAL PAGES (Count does not include cover sheet) 151 1111111111111111111 NO YES 151 VVt P NO 151 1111111111111111111 1111111111111111111 151 Quality Checked 111111111I111111111 V11f ~f <öj MP 10/6/2005 Well History File Cover Page.doc UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~~ / / 7 / FILE # ~- c~~ - / ~J /- i ~/ / - -~ ~~. - ~w~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 ~o Page 1 of ~ ~„ Maunder, Thomas E (DOAj From: Maunder, Thomas E (DOA) Sent: Thursday, April 16, 2009 1:27 PM To: 'Kanyer, Christopher V' Cc: Tyler, Steve L Subject: RE: TBU M-14RD (201-171) Thanks for the confirmation. C~ ~~~r.~~~7 ~~ From: Kanyer, Christopher V [mailto:Chris.Kanyer@chevron.com] Sent: Thursday, April 16, 2009 1:20 PM To: Maunder, Thomas E (DOA) Subject: RE: TBU M-14RD (201-171) Tom, The tubing was punched in an effort to flow the C3 perforations. Multiple attempts were made to open the sliding sleeve at 3,681' RKB, with no indication of flow from the C3 zone. Decision was made to punch tubing from 3,724'-3,734', which resulted in increased gas flow and indicating flow from the C3 perfs. Please let me know if you need any further information on these well operations. Thanks, Chris Kanyer ~• Technical Assistant Wellbore Maintenance Team Office: {907) 263-7831 Cell: (907) 250-0374 Chevron North America Exploration and Production MidcontinentiAlaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 __ __ _. _ __. __ From: Tyler, Steve L Sent: Thursday, April 16, 2009 1:10 PM To: Kanyer, Christopher V Subject: FW: TBU M-14RD (201-171) From: Maunder, mailto:tom.maunder@alaska.gov] Sent: Thursday, April 16, 2009 12:48 To: Tyler, Steve L Subject: TBU M-14RD (201-1 4/16/2009 Page 1 of 1 C~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, April 16, 2009 12:48 PM To: Tyler, Steve L Subject: TBU M-14RD (201-171) Steve, Not sure this is "yours", but I'll be you know whose it is. '*A{'as the tubing punched to allow access to the C3 pen`s? i Hanks in advance. Tom Maunder, PE AOGCC 4/16/2009 I STATE OF ALASKA ~;~` ALAS~IL AND GAS CONSERVATION COMMIS~N REPORT OF SUNDRY WELL OPERATIONS ~~pp ~ 2003 1. Operations Abandon Repair Well Plug Perforations Stimulate ~aSi~~ ~t~ Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver ^ Time ExtensioA prage Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development^ Exploratory^ 201-171 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ ~ Service ^ 6. API Number: 50-733-20408-01 - 7. KB Elevation (ft): 9. Well Name and Number: 160' Trading Bay Unit M-14RD 8. Property Designation: 10. Field/Pool(s): ADL0018730 [Steelhead Platform] McArthur River Field /Middle Kenai Gas ^ 11. Present Well Condition Summary: Total Depth measured 6,690 - feet Plugs (measured) N/A true vertical 4,131' feet Junk (measured) N/A Effective Depth measured 6,690 feet true vertical 4,131' feet Casing Length Size MD TVD Burst Collapse Structural 945' 20" 945' 944' Conductor 1,458' 16" 1,458' 1,457' 2,630 psi 1,020 psi Surface 2,713' 13-3/8" 2,713' 2,712' 3,090 psi 1,540 psi Intermediate 533' 10-3/4" 533' 532' 6,450 psi 4,020 psi 2,279' 9-5/8" 2,812' 2,811' 6,330 psi 3,810 psi Production 3,113' 7" 5,687' 4,119' 8,160 psi 7,020 psi Liner 1,134' 4-1/2" screen 6,680' 4,131' Perforation depth: Measured depth: See Attached Schematic True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 4-1/2" L-80 12.6# 5,525' Packers and SSSV (type and measured depth) Baker Premier Packer 8 3,671' & 5,537' / 420' Baker Liner top Packer / TRSSSV 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2940 1 200 psi 155 psi Subsequent to operation: 0 3200 1 180 psi 155 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Chris Kanyer 263-7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~ .- Phone 276-7600 Date 4/1/2009 Form 10-404 Rewsed 04/2006 ~ Submit Orig' al ly r~ , Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M-14RD TRADING BAY UNIT M-14RD ADL0018730 5073320408 IY1342 - 152.00 - -- Jabs. ~, - k ~, ~~ , Prima Job T e Job Cate o Ob ective ry yp g ry t Aau al Start Uate Actual End Uate Complete Well 3/26/2009 3/29/2009 Services Primary Wallbore Affected Wellbore UWI Well Permit Number M-14 _ 5073320408-00 1890570 Daily Operations ~-'_ -- --- _ - - . -- - 3/26/2Qp9 00:00 - 3/27/2009 00:00 _ _ _~ _ ___ _ _ _ Operations Summary RU slickline. PT 250psi low/ 2500psi high. Ran 3.8" GR to 3675' RKB and sat down on sliding sleeve, brushed sliding sleeve with braided line brush, Ran 4.5" BO shifting tool in close configuration sat down on sleeve indicating sleeve is open. Reversed 4.5" BO shifting tool to Open configuration and ran past sliding sleeve 10 times with slite over pulls indicating sleeve is open. RD slickline. 3127!2009 00:00 -3/28/2009 00:00 ___ - -- - _ - -- - - _ ______ Operations Summary ~ ~ ~~ Standby for hellicoptor to release slickline crew. 3!28/2009 00:00 -3/2912009 00:00 _ __ __ _ Operations Summary - _ RU Eline Unit. PT 250 psi low/ 2500psi high. Run 10' Tubing puncher and punch 41 holes at top of second joint of 4.5" tubing below X-Nipple from 3724' to 3734'. RD Eline. • Trading Bay Unit V N ~ CA ~® Steelhead Platform Well # M-14RD Completion Date 9/10/01 CASING DETAIL KB elevation =160.0', KB to Fing = 73.5' SIZE WT GRADE CONN TOP BOTTOM 20" 94 X-56 73.5' 945' 16" 75 K-55 73.5' 1458' 1 13-3/8" 61 K-55 BTC 73.5' 2713' 10 3/4" 55.5 N-80 BTC 73.5' 533' 9-5/8" 43.5 N-80 BTC 533' 2812' (window) 7" 29 L-80 BTC 2574 5687' TUBING & TAIL PIPE DETAIL: 4-1/2" 12.6 L-80 AB Mod IBTC (Spec. CI.) 73.5' 3671' 4-1/2" 12.6 L-80 AB Mod IBTC (Spec. Cl.) 3693' 5525' 4 %:" SCREEN LINER DETAIL: 4-1/2" 12.6 L-80 AB Mod IBTC (Spec. Cl.) 5546' 5673' 4-1/2" 11.6 N-80 BTC SSWW Screen 5673' 6680' JEWELRY DETAIL NO. Depth ID Item 3 1. 420' 3.812" Baker 4-1/2" TE-5 TRSSSV (ID = 3.813") 2. 1,986' 3.958" 4-1/2" SFO-2 SPM w/ 16/64" GLV 3 2,574' 7" x 9 5/8" HMC/ZXP Liner Hanger/Packer w/ tie-back receptacle 9-5/8" Window 4. 3,586' 3.958" 4-1/2" SMOR-lA spec. clr. SPM w/ 20/64" orifice at 2812' MD ' 5. 3,671' 3.958" Baker 7" Premier Hydr. Packer SA. 3,681' 3.812" Baker 4-1/2" CMU sliding sleeve 6. 3,691' 3.812" Baker "X" nipple (profile = 3.813") 7. 5,537' 3.867" 4 ''h" x 7" Baker SLZXP liner top packer w/ 4'/a" ID x 12' 80-47 PBR on top (seal ass. ID = 3.88") 8. 3,724'-3,7 34' Tubing punched on 3/28/09 (4spf, 0 deg) 5 O O 5 ~ Note: Packer, SSD & `X' nipple positioned @ < 58 degrees inclination 4-1/2" L-80, 12.6# tail pipe from Premier packer to SLZXP packer g 4-1/2" SS WW 12 ga. SS WW Dura-Grip Screen from 5673' to 6680'. Tubing Punch 3,724'-3,734' 7 on 3/28/09 Vii' -~- - -~-~-~-~- - -~- -~- - - -~-~- -~-~- - -~-~- 5330 - 5390' C3 Perforations ~ V (TCP/high angle/ 6 SPJ/ 4 5/8" guns) Note: No blast jts. were used to TD = 6690' MD/4131' TVD minimize cost, CTU plug inside 4 ''/z" required if C3 is to be produced. 7" liner cemented at 5,687' MD / 4,120' VD, 85 deg hole angle M-14RD Schematic 9-10-Ol.doc Updated: 04/01/09 DRAWN BY: CVK . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc ) L D & ÀN'-O} DATA SUBMITTAL COMPLIANCE REPORT 10/3/2003 Permitto Drill 2011710 Well Name/No. TRADING BAY UNIT M-14RD Operator UNION OIL CO OF CALIFORNIA )/4d ~ tflJ.,,; ;{fiõ( API No. 50-733-20408-01-00 MD 6690"/ TVD 4131 - Completion Date 9/10/2001 ....- Completion Status 1-GAS Current Status 1-GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset Type MedlFrmt Number Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No Interval OH 1 Start Stop CH Received Comments . Well Cores/Samples Information: Name Cuttings Interval Start Stop 2795 6690 Sent Received Sample Set Number Comments 0823 -- ADDITIONAL INFORMATION Well Cored? Y .õ;¡) Daily History Received? (yyN cr 1 N Chips Received? _ Y 1 N ~. Formation Tops Analysis Received? - Y II.J Comments: t-,... tv.1- t "",...::t¡w.:.L U (J'\---" ~ f'J\ 0 ~ "" h"t'1 . 't-V ~ ß v. u \o,~ . Compliance Reviewed By: \.n~i." ~ìlì MÐ 'hI') ,~ Date: g o[f~4J J ß, ,L- () ",-L'1 ß. - L 1\ '" ~J r.> ~ ..~J\J~t. \} # \ ~M):J ~. h ~ ,n ~ K r tÓIf~l~ ~ V'ý"c.<.. t. t3t... o.,~ h'/ ~ ' . Unocal Corporation . P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 aoJ-J, ) UNOCALe Dan Williamson Drilling Manager 11/15/01 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Attn: Commissioner Julie Heusser Re: Well Completion Or Recompletion(Form 10-407) Steel head, Well M-14RD Trading Bay Unit, McArthur River Field Commissioner Heusser: Enclosed for your review is a Well Completon or Recompletion Report and Log (Form 10- 407) for Steel head Well #M-14RD. The abandonment and re-drill operation was successful and no additional work is planned for Well M-14RD at this time. If there are any questions, please contact Jerry Bowen at 263-7640. ~CerelY' . } Danill~ Drilling Manager ' RECEIVED NOV 2 O· ,/(\il1 L u.~ , AlaskaOíl & Gas Cons, COmmlSSí(ft Anchorage AOGCC cover letter404.doc Tim Billingsley ORIGINAL · STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG OIL: GAS: X 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P. O. Box 196247, Anchorage, AK 99519 4. L~~~~~nF~fL~:~;.t;~~~~ec. 33, T9N, R13W, S.M. :-èÕf'~!;~l r-ì.OCAtJåi~ :::::J.:~~~~~S~33'T9N'RI3W'SM __ ~¡~lj k$ 1395' FSl:, , FWL, Sec. 33, T9N, R13W, S.M. C-c---""!-~f'__""·~'···","'·"~" 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 160' KB to MSL ADL-18730 12. Date Spudded 13. Date T.D. Reached 114. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions Aug-24-2001 Sept-4-2001 Sept-10-2001 182 feet MSL 1* 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 6690'MD/4131'TVD 6690'MD/4131'TVD Yes: X No: 420 feetMD NlA 22. Type Electric or Other Logs Run Anadrill LWD - Induction/NeutronlDensity 23. 1. Status of Well SUSPENDED: ABANDONED: SERVICE: Classification of Service Well 7. Permit Number 201-171 8. API Number 50- 733-20408-01 9. Unit or Lease Name Trading bay Unit 10. Well Number M-14RD 11 . Field and Pool McArthur River Field Grayling Gas Sands WT. PER FT. 75 61 55.5 & 43.5 29 GRADE K-55 K-55 N-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM 0' 1458' 0' 2713' 0' 2812' window 2574' 5687' 6680' AMOUNT PULLED 0' 0' 0' 0' 0' CASING SIZE 16" 133/8" 10314" x 9 5/8" 7" 4 1/2" screen 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) C-4 Sand horizontal completion interval = 5687' - 6687' MD (4124' - 4132' TVD) (currently producing) *C-3 Sand Perforated in the interval 5330' - 5390' MD (4063' - 4076' TVD) for future production (currently isolated behind closed SSD) HOLE SIZE 22" UR 171/2" 121/4" 8 1/2" 6" 25. SIZE 4 1/2" 12.6# L-80 CEMENTING RECORD 1480 sx 1650 sx 2150 sx 246 sx 12 ppg LiteCrete NIA (uncemented) TUBING RECORD DEPTH SET (MD) 5534' PACKER SET (MD) 3668' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED NlA NlA 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Sept-11-2001 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF Oct-4-2001 24 TEST PERIOD => 0 11,100 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF Press. 653 790 24-HOUR RATE => 0 11,100 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. WATER-BBL 2 WATER-BBL 2 CHOKE SIZE I GAS-OIL RATIO NlA NlA OIL GRAVITY-API (corr) NlA NlA RECEIVED NOV 2 0 2001 AlaSka Oil & Gas Cons. (;omm~SSK¡1 Anchorage Ø3,/ .~ CONTINUED °ðRREIG rN A L IÞ: iMJ'-' S"bmll '" d"pll"te Form 10-407 Rev. 7-1-80 . . 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. Tyonek'B'Zone 3157' 3144' N/A Tyonek'C'Zone 4598' 3852' N/A RECEIVED Nov 2 0 2001 AlaauOil& Gas . A~ CarrIJÎSSlt); 31. LIST OF ATTACHMENTS Wellbore Schematic, Daily Report of Well Operations, MWD Directional Survey Record 32. I hereby c "fy that the foregoing is true and correct to the best of my knowledge Signed a Williamson Title Drilling ManaQer Date ¡!/I¡;!OI INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- 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 OR\G\t'~AL KB elevation = 160.0', KB toFlng = 73.5' 20" 94 X-56 73.5' 945' 16" 75 K-55 73.5' 1458' 13-3/8" 61 K-55 BTC 73.5' 2713' 103/4" 55.5 N-80 BTC 73.5' 533' "'- / 9-5/8" 43.5 N-80 BTC 533' 2812' (window) 7" 29 L-80 BTC 2574 5687' ~ 4-1/2" 12.6 L-80 AB Mod IBTC (Spec. CL) 73.5' 3671' L 4-J!2" 12.6 L-80 AB Mod IBTC (Spec. Cl.) 3693' 5525' 2 4-1/2" 12.6 L-80 AB Mod IBTC (Spec. CL) 5546' L ~ 4-1/2" 11.6 N-80 BTC SSWW Screen 5673' 6680' :k Baker 4-1/2" TE-5 TRSSSV (lD = 3.813") 4-112" SFO-2 SPM wi 16/64" GLV 4-112" SMOR-l A spec. ell'. SPM wi 20/64" orifice Baker 7" Premier Hydr. Packer Baker 4-112" CMU sliding sleeve Baker "x" nipple (profile 3.813") 7" x 9 5/8" HMC/ZXP Liner HangerlPacker wi tie-back receptacle 4 Yz" x 7" Baker SLZXP liner top packer wi 4%" lD x 12' 80-47 PBR on top (seal ass. lD = 3.88") Z ---0 ~ 4 ~ Note' Pooke" SSD & 'X' nipple po,itioned 216 1. 420' ~ 2. 1986' \ 3 3586' 4. 3671 ' 9-5/8" Window 5. 3681 ' at 2812' MD, 5A. 3691' 6. 2574' 3 7. 5537' L < 58 degrees inclination - ~5A 5330 - 5390' C3 Perforations /.... (TCP/high angle/6 SPJ/4 5/8" guns) Note: No blast jts. were used to minimize cost, CTU plug inside 4 Yo," required if C3 is to be produced. 4-112" L-80, 12.6# tail pipe from Premier packer to SLZXP packer 4-1/2" SS WW 12 ga. S5 WW Dura-Grip Screen from 5673' to 6680'. Î I TD = 6690' MD/4131' TVD 7" liner cemented at 5,687' MD I 4,120' VD, 85 deg hole angle M-14RD Schematic 9-1O-01.doc Drawn: 10/05/01 DRAWN BY: JFB Date 8/17/01 8/18/01 8/19101 8/20101 8/21/01 8/22/01 8/23/01 8/24/01 . . Daily Report of Well Operations Steel head Well M-14RD Abandonment of Existing Completion & Re-Drill Horizontal C-4 Completion AFE numbers 150797 & 150799 Summary Skidded rig from leg B-1 to leg A-I. While skidding rig, RU injection lines to LS, SS & annulus. Tested lines to 4000 psi. Established injection rate down SS, bullheaded 97 bbls FIW at stabilized 5 BPM, 950 psi. Established injection rate down LS, bullheaded 75 bbls FIW at stabilized 2.8 BPM, 2750 psi. Bullheaded 45 bbls 15.8 ppg neat 'G' cement down LS, displaced with 47 bbls FIW wI final pressure 3130 psi. Bullheaded 29 bbls 15.8 ppg neat 'G' cement down SS, displaced with 47 bbls FIW wI final pressure 1500 psi. Top of cement in LS & SS at 5500' as per program. Finished skidding rig over M -14. Secure storm clamps. Set V -door & catwalk in place. Pressure tested LS & SS to 2000 psi, no leaks. Tested csg to 2000 psi. Set BPVs in LS & SS. ND dual X-mas tree. Inspected hanger threads. Plugged chemical injection lines & locked open SSSVs. Started NU BOP riser. Continued NU BOP riser. Stopped work on well M-14 to NU 30" riser on well M-12. NU BOP stack. Changed top rams to dual 3 Yz" rams (already had 3 Yz" single ram in lower BOP). NU choke/killlines. Attempted to repair top drive IBOP, could not, ordered new parts. Tested choke manifold to 50013000 psi. Recovered both BPVs. MlU dual landing joints. Attempted to test BOPs, leak at riser connection. Repaired riser leak. Tested dual rams to 250/3000 psi. Pulled one landing joint & tested lower rams to 25013000 psi. Tested Koomey unit, gas detectors, TIW valve & dart valve. Recovered second landing joint & tested blind rams to 25013000 psi. Attempted to repair IBOP, could not, sent crew to get IBOP actuator from rig 428. RU GBR dual equipment. Install dual landing joints in hanger. Backed out pins & unlanded complation. RU APRS. RIH & jet cut LS at 5050'. RIH & jet cut SS at 5050'. Stuck cutter in SSSV of SS while paR. Pulled until weak point failed. paR leaving weight bar, CCL, & fired cutter in SS. RD APRS. Pulled dual hanger to rig floor & UD. Pulled dual strings to SSSVs and LID SSSVs. Re-Ianded LS. paR & LID SS. Started paR & LID LS. Continued paR & LID LS. RD GBR. Changed top rams to 5". Repaired & tested top drive IBOP. Ran test plug & attempted to test 5" rams to 250/3000 psi, unsuccessful. Open bonnet of upper BOP. Inspected 5" rams, found seal element ruined & wear plate damaged. Repaired top rams & tested to 250/3000 psi. Pulled test plug & installed wear bushing. PU window mills & RIR P/u drill string. Stand pipe in derrick & continued P/u pipe until entire drill string picked up. paR. RU E-line. RIH & set 9 5/8" CIBP & 2815'. paR & RD E-line. FINAL REPORT for abandonment of well M-14. M/U Window Master whipstock & starter mills. RIH to 2777'. RU E-line. RIH wI gyro tool. Oriented whipstock to S24°E. paR. Set whipstock. Displace hole to 9.0 ppg WBM while milling window. Milled & polished window to 2832'. Performed FIT to 10.7 ppg EMW. paR. 8/25/01 8/26/0 1 8/27/01 8/28/01 8/29/01 8/30101 8/31/01 9/1/01 9/2/01 9/3/01 9/4/01 9/5/01 9/6/01 . . LID window mills. PIU 8 Y2" BHA. Loaded source & programmed L WD tools. RIH to 2717'. RU E-line. RIH wi gyro steering tool (to kick off from vertical well). Installed side entry sub. Drilled & kicked off from 2832' to 2914'. POH to 2777'. LID side entry sub & RD E-line. Directionally drilled from 2914' to 3179'. Directionally drilled from 3179' to 3554'. SD 8 Yz hrs to repair top drive blower motor. Drilled from 3554' to 4360'. Directionally drilled from 4360' to 4842'. Unable to slide. POH. Re-positioned HWDP farther up the string. Started RIH. FIR. Drilled from 4842' to 5450'. Drilled from 5450' to 7" casing point in C-4 sand 5690' (inclination 86°, azimuth 206.3°). Pumped out of hole to 2690' wi excess drag, recovered large amount of cuttings. RIH to 5690'. Circulated Hi-Vis sweep. Had 956 units trip gas. Well stable. POH. Recovered L WD source & downloaded data. Retrieved wear bushing & installed test plug. Changed top rams to 7" & tested to 250/3000 psi. PU additional HWDP & stood in derrick (weight needed to set ZXP packer). RIH wI 75 joints of 7" 29 ppfL-80 TKC BTC liner & running string to 5690'. M/U cementing head. Dropped ball to set hanger, did not seat. Dropped ball #2 & pumped down at 3 Yz BPM. Pressured up to 1800 psi to set hanger & to 2700 psi to shear ball seat & release from hanger. Cemented liner wI 60 bbls 9.6 ppg mud push followed by 109 bbls 12.0 ppg LiteCrete cement. Displaced cement with 150.25 bbls FIW & bumped plug. Pressure increased from 650 to 1950 psi, but lost returns after 100 bbls of displacement. Floats held. Set ZXP liner top packer. Tested packer & 9 5/8" csg to 2000 psi. Reversed clean. POH & LID running tool. Changed top rams to 3 Yz" & tested to 250/3000 psi. Recovered test plug & set wear bushing. RIH wi 6" bit PIU new 3 Y2" HT -38 DP breaking in new tool joints as required. Continued RIH wI new 3 Y2" DP followed by 5" DP. Tagged landing collar at 5557'. Pressure tested 7" & 9 5/8" to 2000 psi. Drilled 7" shoe track to 5670'. POH. M/U 6" steerable BHA wI full LWD & RIH to 3238'. Continue RIH. Continued drilling shoe track from 5670' to 5687'. Drilled 6" horizontal hole from 5690' to 5995'. Drilled 6" horizontal hole from 5995' to 6575'. Slow ROP due to continuous sliding. Drilled 6" horizontal hole from 6575' to TD at 6690'. Circ clean. Spotted 35 bbls solids free KCI-polymer fluid in horizontal hole. POH & LID BHA. RIH wI 25 jts 4 Yz" SS WW screen, 4 jts of 4 Yz" tubing & SLZXP packer on 3 Yz" DP. FIH wi 4 Y2" SS WW screen liner. Dropped ball & set SLZXP with top of packer at 5536.5'. POH w/3 Yz" DP. SIH wI TCP gun on 3 Y2" DP. FIH wI TCP gun. RU E-line. Attempted to log RA marker, marker set too deep at high inclination. RD E-line. POH wi 1182' of 3 Y2" DP. RU E-line unit. Ran CCL log to correlate gun with L WD log (1' correction required). Re-tallied pipe & RIH to position guns. Perforated C-3 Sand from 5330' to 5390' LWDLM w/4 5/8" gun, 6 SPF. Observed well, stable. POH LID 3 Yz" DP. 9/7/01 9/8/01 9/9/01 9/10/01 . . FOH LID 3 ¥2" DP. LID TCP gun, all shots fired. Pulled wear bushing. Set test plug. Changed top rams to 4 ¥2" & tested to 250/3000 psi. RIH wI seal assembly, 4 Y2" tubing, Baker Premier Packer, 4 ¥2" tubing wI GL Vs & TRSSSV. Maintained control line pressure at 5000 psi while stinging in/out for space out. Displaced WBM out of lower portion of well wI 3% KCL-FIW. Landed tbg in neutral position. Tightened hold down pins & tested hanger seals. RU S-line unit. RIH & set RHCP plug in 'X' nipple at 3691'. Pressured up to 3000 psi & set packer. Held pressure on tbg while pressure testing csg & packer to 2000 psi. Bled pressure on csg & tbg to 0 psi. RIH & recovered GL V from SPM at 3586'. Circulated remaining WBM out of well. Re-installed GL V. Attempted to recover RHCP plug, unsuccessful. RIH & retrieved RHCP plug. Recovered RHCP plug body after four runs wI slickline (had to bail small amount of barite off of plug body). Closed SSSV. Set BPV. ND BOPE. NU 4 1116" 5M X-mas tree. Pulled BPV. Installed TWC valve. Tested tree to 5000 psi. Turned well over to Production. FINAL REPORT. I, " 1 I I I I I I I I I I I I I I I I I . . Schlumberger Section 3 Final ~s . . . . . . . . . .. .. .. . . . . . II '.- M-14RD Schlumberger UNOCALe Survey Report - Geodetic Report Date: 21-Sep-2001 Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Client: Unocal Vertical Section Azimuth: 187.260° Field: Trading Bay Unit Vertical Section Origin: N 0.000 It, E 0.000 It Structure 1 Slot: Steelhead / M-14 (leg A 1 slot 5) TVD Reference Datum: KB Well: M-14 TVD Reference Elevation: 152.000 It relative to Mean Sea Level Borehole: M-14RD Sea Bed I Ground Level Elevation: 0.000 It relative to Mean Sea Level UWIIAPI#: 507332040801 Magnetic Declination: +20.776° Survey Name / Date: M-14RD / September 10,2001 Total Field Strength: 55353.983 nT . Tort 1 AHD / DDII ERD ratio: 178.796° 13367.93 It /5.989/ 0.815 Magnetic Dip: 73.513° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: September 10, 2001 Location LatILong: N 60 49 54.476, W 151 368.640 Magnetic Declination Model: BGGM 2000 Location Grid NIE YIX: N 2499454.353 ItUS, E 214079.805 ItUS North Reference: True North Grid Convergence Angle: -1.39929107° Total Corr Mag North -> True North: +20.776° Grid Scale Factor: 0.99999302 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim I TVD VSec NI-S E/·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) ("/1000) (ftUS) (ftUS) Tie-In 2700.00 0.03 286.13 2699.92 13.92 -13.73 -2.42 2499440.69 214077.05 N 60 49 54.341 W 151368.689 2837.04 3.61 156.00 2836.87 17.61 -17.66 -0.70 2.65 2499436.72 214078.67 N 60 49 54.302 W 151368.654 2926.63 9.79 156.00 2925.80 26.54 -27.20 3.55 6.90 2499427.07 214082.69 N 60 49 54.208 W 151 368.569 3019.57 16.28 159.50 3016.30 44.84 -46.64 11.33 7.03 2499407.45 214089.99 N 60 49 54.017 W 151368.411 3112.49 23.01 160.55 3103.76 72.62 -76.00 21.95 7.25 2499377.84 214099.89 N 604953.728 W 151368.197 3207.72 29.96 160.63 3188.95 110.55 -116.03 36.05 7.30 2499337.47 214113.01 N 60 49 53.334 W 151367.913 3301.65 36.64 161.67 3267.41 156.84 -164.82 52.67 7.14 2499288.30 214128.43 N 60 49 52.853 W 15136 7.iIt 3395.34 43.15 162.79 3339.25 211.28 -222.03 70.96 6.99 2499230.66 214145.32 N 60 49 52.290 W151367. 3488.88 50.22 162.27 3403.38 273.05 -286.90 91.39 7.57 2499165.31 214164.16 N 6049 51.651 W 151 366.7 3583.83 56.49 160.65 3460.03 341.58 -359.07 115.64 6.74 2499092.57 214186.65 N 60 49 50.940 W 151366.307 3675.56 57.11 160.47 3510.25 410.15 -431.45 141.19 0.70 2499019.58 214210.42 N 60 49 50.228 W 151 365.792 3766.52 62.74 159.62 3555.82 480.12 -505.40 168.06 6.24 2498945.00 214235.47 N 60 49 49.499 W 151365.250 3861.43 66.64 159.91 3596.39 556.21 -585.89 197.73 4.12 2498863.81 214263.16 N 60 49 48.707 W 151364.652 3952.71 67.21 159.49 3632.16 630.66 -664.65 226.86 0.75 2498784.36 214290.36 N 6049 47.931 W 151364.064 4046.39 67.10 158.50 3668.53 706.69 -745.25 257.80 0.98 2498703.04 214319.33 N 60 49 47.137 W 151 363.440 4138.65 69.22 160.32 3702.86 782.41 -825.41 287.91 2.94 2498622.17 214347.47 N 60 49 46.348 W 151362.833 4233.30 69.78 160.19 3736.00 861 .40 -908.85 317.86 0.61 2498538.02 214375.37 N 60 49 45.526 W 151362.229 4327.01 70.18 159.39 3768.09 939.52 -991.48 348.28 0.91 2498454.67 214403.76 N 60 49 44.713 W 151361.615 4420.85 70.65 159.26 3799.54 1017.63 -1074.20 379.49 0.52 2498371.22 214432.95 N 60 49 43.898 W 151360.986 Unocal M-14RRD EOW Report.xls Page 1 of 2 9/24/2001-9:29 AM ~....._..__.. . .. .. . . .. Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI-S EI-W DLS Northing I Easting Latitude I Longitude (ft) n n (ft) (ft) (ft) (ft) (0'100ft) (ftUS) (ftUS) 4514.61 72.44 159.34 3829.22 1096.18 -1157.39 410.93 1.91 2498287.28 214462.34 N 60 49 43.079 W 151 360.352 4608.12 72.75 159.21 3857.19 1174.98 -1240.84 442.50 0.36 2498203.08 214491.87 N 60 49 42.257 W 151 3559.715 4700.77 73.16 158.46 3884.35 1252.88 -1323.45 474.49 0.89 2498119.73 214521.83 N 60 49 41.444 W 1513559.070 4764.89 73.52 158.60 3902.73 1306.74 -1380.61 496.97 0.60 2498062.03 214542.91 N 60 49 40.881 W 1513558.616 4855.75 73.49 161.55 3928.54 1384.23 -1462.51 526.66 3.11 2497979.43 214570.59 N 60 49 40.074 W 1513558.018 4948.66 72.84 167.40 3955.47 1466.17 -1548.15 550.45 6.07 2497893.24 214592.29 N 60 49 39.231 W 151 3557.538 5042.16 73.49 172.36 3982.56 1551.55 -1636.22 566.17 5.12 2497804.82 214605.84 N 60 49 38.364 W 1513557.221 5137.22 74.10 174.25 4009.09 1640.13 -1726.87 576.81 2.01 2497713.93 214614.27 N 60 49 37.471 W 151 3557.006 5232.09 72.93 180.27 4036.03 1729.67 -1817.69 581.17 6.21 2497623.03 214616.41 N 604936.577 W 1513556.918. 5327.17 75.17 186.49 4062.18 1820.82 -1908.89 575.75 6.72 2497531.99 214608.77 N 604935.679 W 151 3557.028 5421.62 78.78 192.78 4083.49 1912.70 -1999.54 560.33 7.53 2497441.75 214591.13 N 604934.786 W 1513557.339 5516.77 80.50 197.96 4100.61 2005.32 -2089.75 535.52 5.65 2497352.17 214564.13 N 60 49 33.898 W 1513557.839 5609.26 83.55 203.21 4113.45 2094.41 -2175.45 503.31 6.52 2497267.28 214529.84 N 60 49 33.054 W 151 3558.489 5754.86 87.42 212.31 4124.93 2230.18 -2303.72 435.76 6.77 2497140.70 214459.18 N 60 49 31.791 W 1513559.851 5849.26 88.59 220.07 4128.22 2312.68 -2379.80 380.10 8.31 2497066.00 214401.68 N 604931.041 W 151 360.974 5943.45 89.93 227.33 4129.44 2388.40 -2447.84 315.08 7.84 2496999.57 214335.01 N 60 49 30.371 W 151362.286 6039.75 90.31 234.05 4129.24 2458.29 -2508.81 240.61 6.99 2496940.44 214259.08 N 60 49 29.771 W 151363.788 6132.77 89.42 241.31 4129.46 2517.52 -2558.51 162.05 7.86 2496892.67 214179.33 N 60 49 29.282 W 151365.372 6223.85 88.28 246.78 4131.29 2567.38 -2598.35 80.21 6.13 2496854.84 214096.54 N 60 49 28.889 W 151367.022 6316.81 90.48 248.18 4132.29 2613.55 -2633.95 -5.65 2.81 2496821.35 214009.84 N 60 49 28.539 W 151 368.754 6408.09 90.65 248.79 4131.39 2657.48 -2667.43 -90.56 0.69 2496789.96 213924.13 N 604928.209 W 151 3610.467 6499.26 90.34 248.75 4130.61 2700.97 -2700.44 -175.54 0.34 2496759.03 213838.37 N 60 49 27.884 W 151 3612.180 6595.57 89.62 249.01 4130.64 2746.75 -2735.14 -265.38 0.79 2496726.53 213747.71 N 60 49 27.542 W 1513613.992 6636.22 89.66 249.10 4130.90 2765.96 -2749.67 -303.35 0.24 2496712.93 213709.40 N 60 49 27.399 W 151 3614.758 6690.00 89.66 249.10 4131.21 2791.34 -2768.86 -353.59 0.00 2496694.98 213658.71 N 604927.210 W 1513615.77. Survey Error Model: (No Error Model Selected) Unocal M-14RRD EOW Report.xls Page 2 of 2 9/24/2001-9:29 AM .,.c ........ I' "' \ - <J rzJ ANADRILL SCRLUMBERGER Survey report Client. . . . . .. . .. .. .... . ..: UNOCAL Field. . . . . . . . . . . . . . . . . . . .: McArthur River Well. . . . . . . . . . . . . . . . . . . . .: M-14RD API number.... ...... .....: 50-733-20408-01 Engineer.................: Leafstedt ~G:................. ....: Steelhead ..ATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference.. ........: Driller's Pipe Tally GL above permanent.......: 0.00 ft KB above permanent.......: n/a DF above permanent.......: 152.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft .-~- Platform reference point--------------- tltude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 192.21 degrees 4-Sep-2001 04:11:00 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey. .......: Page 1 of 3 25-Aug-01 04-Sep-01 46 2700.00 ft 6690.10 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2000 Magnetic date... ... ......: 25-Aug-2001 Magnetic field strength..: 1107.13 RCNT Magnetic dec (+E/W-) .....: 20.79 degrees Magnetic dip. ............: 73.51 degrees ----- MWD survey Reference Reference G..... ..... ....: Reference R..............: Reference Dip............: Tolerance of G. ..........: Tolerance of R........... : Tolerance of Dip..... ....: Criteria --------- 1002.03 mGal 1107.13 RCNT 73.51 degrees (+1-) 2.50 mGal ( + I -) 6. 00 RCNT (+1-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 20.79 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/w-) ....: 20.79 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 4-Sep-2001 04:11:00 Page 2 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 2700.00 0.03 286.13 0.00 2699.92 13.93 -13.73 -2.42 13.94 190.00 0.00 TIP 2 2796.00 0.07 349.87 96.00 2795.92 13.88 -13.67 -2.45 13.88 190.18 0.07 MWD 3 2812.00 1. 85 156.00 16.00 2811.92 14.07 -13.89 -2.35 14.09 189.61 11. 99 MWD 4 2837.04 3.61 156.00 25.04 2836.93 15.04 -14.98 -1.87 15.10 187.10 7.03 MWD 5 2926.63 9.79 156.00 89.59 2925.86 23.47 -24.53 2.38 24.64 174.45 6.90 MWD 6 3019.57 16.28 159.50 92.94 3016.36 40.82 -43.97 10.17 45.13 166.98 7.03 MWD 6-axis . 7 3112.49 23.01 160.55 92.92 3103.82 67.27 -73.32 20.79 76.21 164.17 7.25 MWD 6-axis 8 3207.72 29.96 160.63 95.23 3189.01 103.41 -113.36 34.89 118.60 162.89 7.30 MWD 6-axis 9 3301.65 36.64 161. 67 93.93 3267.47 147.58 -162.14 51. 50 170.13 162.38 7.14 MWD 6-axis 10 3395.34 43.15 162.79 93.69 3339.31 199.63 -219.35 69.79 230.18 162.35 6.99 MWD 6-axis 11 3488.88 50.22 162.27 93.54 3403.44 258.71 -284.22 90.23 298.20 162.39 7.57 MWD 6-axis 12 3583.83 56.49 160.65 94.95 3460.09 324.12 -356.40 114 .48 374.33 162.19 6.74 MWD 6-axis 13 3675.56 57.11 160.47 91. 73 3510.31 389.46 -428.78 140.03 451.06 161.91 0.70 MWD 6-axis 14 3766.52 62.74 159.62 90.96 3555.88 456.06 -502.73 166.90 529.71 161. 63 6.24 MWD 6-axis 15 3861.43 66.64 159.91 94.91 3596.45 528.45 -583.22 196.56 615.45 161.37 4.12 MWD 6-axis 16 3952.71 67.21 159.49 91.28 3632.22 599.27 -661.98 225.70 699.40 161. 17 0.75 MWD 6-axis 17 4046.39 67.10 158.50 93.68 3668.59 671.50 -742.57 256.64 785.67 160.93 0.98 MWD 6-axis 18 4138.65 69.22 160.32 92.26 3702.92 743.48 -822.73 286.75 871.27 160.79 2.94 MWD 6-axis 19 4233.30 69.78 160.19 94.65 3736.06 818.70 -906.18 316.70 959.92 160.74 0.61 MWD 6-axis 20 4327.01 70.18 159.39 93.71 3768.15 893.02 -988.80 347.11 1047.96 160.66 0.91 MWD 6-axis .21 4420.85 70.65 159.26 93.84 3799.60 967.27 -1071.52 378.33 1136.35 160.55 0.52 MWD 6-axis 22 4514.61 72.44 159.34 93.76 3829.28 1041. 93 -1154.71 409.77 1225.26 160.46 1. 91 MWD 6-axis 23 4608.12 72.75 159.21 93.51 3857.25 1116.82 -1238.17 441. 34 1314.47 160.38 0.36 MWD 6-axis 24 4700.77 73.16 158.46 92.65 3884.41 1190.79 -1320.77 473.32 1403.02 160.28 0.89 MWD 6-axis 25 4764.89 73.52 158.60 64.12 3902.79 1241. 91 -1377.94 495.81 1464.42 160.21 0.60 MWD 26 4855.75 73.49 161.55 90.86 3928.60 1315.67 -1459.83 525.49 1551.53 160.20 3.11 MWD 6-axis 27 4948.66 72.84 167.40 92.91 3955.53 1394.34 -1545.47 549.29 1640.18 160.43 6.07 MWD 6-axis 28 5042.16 73.49 172.36 93.50 3982.62 1477.09 -1633.54 565.00 1728.49 160.92 5.12 MWD 6-axis 29 5137.22 74.10 174.25 95.06 4009.15 1563.45 -1724.19 575.64 1817.75 161.54 2.01 MWD 6-axis 30 5232.09 72.93 180.27 94.87 4036.09 1651.28 -1815.01 580.00 1905.43 162.28 6.21 MWD 6-axis . ANADRILL SCHLUMBERGER Survey Report 4-Sep-2001 04:11:00 Page 3 of 3 -------- --.---- ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 5327.17 75.17 186.49 95.08 4062.24 1741.57 -1906.21 574.59 1990.93 163.23 6.72 MWD 6-axis 32 5421.62 78.78 192.78 94.45 4083.55 1833.43 -1996.86 559.16 2073.67 164.36 7.53 MWD 6-axis 33 5516.77 80.50 197.96 95.15 4100.67 1926.85 -2087.07 534.35 2154.39 165.64 5.65 MWD 6-axis 34 5609.26 83.55 203.21 92.49 4113.51 2017.42 -2172.77 502.15 2230.04 166.99 6.52 MWD 6-axis 35 5754.86 87.42 212.31 145.60 4124.99 2157.07 -2301.04 434.60 2341.72 169.30 6.77 IMP 6-axis .36 5849.26 88.59 220.07 94.40 4128.28 2243.20 -2377.12 378.94 2407.13 170.94 8.31 IMP 6-axis 37 5943.45 89.93 227.33 94.19 4129.50 2323.46 -2445.16 313.91 2465.23 172.68 7.84 IMP 6-axis 38 6039.75 90.31 234.05 96.30 4129.30 2398.80 -2506.14 239.45 2517.55 174.54 6.99 IMP 6-axis 39 6132.77 89.42 241.31 93.02 4129.52 2463.99 -2555.83 160.89 2560.89 176.40 7.86 MWD 40 6223.85 88.28 246.78 91.08 4131.35 2520.24 -2595.67 79.05 2596.88 178.26 6.13 IMP 6-axis 41 6316.81 90.48 248.18 92.96 4132.35 2573.19 -2631.27 -6.81 2631.28 180.15 2.81 IMP 6-axis 42 6408.09 90.65 248.79 91.28 4131.45 2623.87 -2664.75 -91.73 2666.33 181.97 0.69 IMP 6-axis 43 6499.26 90.34 248.75 91.17 4130.67 2674.11 -2697.76 -176.71 2703.54 183.75 0.34 IMP 6-axis 44 6595.57 89.62 249.01 96.31 4130.70 2727.03 -2732.46 -266.55 2745.43 185.57 0.79 IMP 6-axis 45 6636.22 89.66 249.10 40.65 4130.96 2749.26 -2746.99 -304.51 2763.82 186.33 0.24 IMP 6-axis Projected to TD 46 6690.10 89.66 249.10 53.88 4131.28 2778.69 -2766.21 -354.84 2788.88 187.31 0.00 . ·. . {rs~ M-1L.{V'~ Enclosed are the following samples collected for Marathon's Steelhead Well M-14rd 7 ( JO{- / Depth From (Feet) 2795 3960 5310 6280 Steelhead Well M-14rd Dry Samples Depth To (Feet) 3960 5310 6280 6690 Box No. 1 2 3 4 #8~J Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY fÝ¡~~ Kaynell Zeman Enclosures Hand Delivered Received by: Date: JJc(J)LvJ L , N~À..~r-J7 · Marathon Oil Company November 19,2001 Geologic Materials Center 18205 Fish Hatchery Rd. Eagle River, AK 99577 ATTN: John Reeder RE: Marathon Steelhead Dear Mr. Reeder AlaSka_ion Domestic Production P.o. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 LETTER OF TRANSMITTAL Hand Delivered Enclosed are the following samples collected for Marathon's Steelhead Well M-12. Depth From (F eet) 471 1610 3080 4640 6200 7740 9600 Steelhead Well M-12 Dry Samples Depth To (Feet) 1610 3080 4640 6200 7740 9600 10710 Box No. 1 2 3 4 5 6 7 Enclosed are the following samples collected for Marathon's Steelhead Well M-4 Depth From (F eet) 1473 2440 3340 4210 5410 A subsidiary of USX Corporation Steelhead Well M-4 Dry Samples Depth To (Feet) 2440 3340 4210 5410 6430 Box No. 1 2 3 4 5 Environmentally aware for the long run. Daily Operd&ø.s Report Well Name: M-14 Abandon . .~.".'''''-.JI'''''.''''_. UNOCAL8 . Dale" Report #: August 22, 2001 7 Bit # Size (in) 1:= -r:1~1 py 1 yp 1~J ES I OIWI ~ I :n/ mud CI- WP F:=1 3 I 6 /100 /200 1300 I_ 9 .,.: 54 8 .:s ~'L J.s.~ø:oc I I ----1:~-~5 32. 36 .::.s (Connection gas@ 10,601'.) Dist Ratate ROP HIs (MH) 0.0 Type Serial Nmnber DepIh (It) From To o D Condition L B G o R Fluid Type F:iwIKCL Brine Sample Loc.: Pits MF BHA' NO From To LengIh~, =) ~~, .. I HcMøs on Jars: da\-\~ \ ~~ u.\\~\.-.~ ~(::)~~~\- Weight-On -Bit Drag Values: Torque Values: RoIaIing Values: \01' Drive h4\""øaIion: Average: _Kips 1Iuimum: Kips RoIaIing: Kips Sliding: Kips PU: Kips SO Kips ROT: Kips On: ft.Ibs 011: ft.Ibs Max: ft.Ibs DP: rpm IIoIor: rpm ToÞI: rpm lID lid Azimuth I,h, lID IncL Azimuth 1 VU ...., incl· Azimuth IYU lID IncL Azimuth I'¥II Ircïg ~ .__4 Down: Rig sub air tugger. IlotaI KI!J UIIIIN 1-= 0.00 hrsl I ¡-About: Back loading boat and picRing up BHA, observing good crane practices. 00:00 to 06:00 Summaty: 00:00-01 :00: Complete repairs to 5" pipe ram blocks and re-install in the upper BOP. -01 :00-01 :30: Test 5" pipe rams to 250/3000 psi. Good test. Perform accumulator drill 1375 psi final pressure (closed annular, opened HCR, closed and -1 ~ then opened the 5" pipe rams). 200 psi recovery with electric pump only was 50 seconds full recovery to 3000 psi with the electric pump r and two air pumps was 3 minute and 54 seconds. 01 :30-02:30: Pull the test plug and run the wear bushing. 02:30-06:00: Pick up window mills, jar/bumper sub, drill collars and start picking up 5" HWDP. General CoInmenIs, Planned Operations, Notes.....: Need to off load tubing and production handling equipment. Need cement before milling the window. (should have 500 SX Neet G Coming out to day.) MR-SH-M-14 ABAND OB-n-C1.xIs Page 2 0'2 Revised:10128199 by MWD " " . Daily Operations Report Well Name: M-14 Abandon . _'".t....'".JlJJ~.."._. UNOCALe . Date: Report #: August 22, 2001 7 'PIaIrarm: Steel head Field: McArthur River Rig: UNOCAL Rig #51 [)rig ContradIIr: Nabors Alaska Project Objective: Cement & Abadon, Pull Tubing & Set Retainer for whipstock. N=E f.: 150797 Spud Date: Present DepIh: ft RKB Height (ft:): 73.53 AFE Cost $ 484,161 Project: ~days - In DriIing Hours: In Last BOP Test 8/20101 Daily Cost $ 45,248 FISpud: -days In FooIage DriIed: ft Pressure (High): 3,000 Previous CUm: $ 208,339 CIBIeIII: Hole Size: ~ .Average ROP: ftIhr Pressaøe (Low): 250 C....utatïve Cst: $ 253,587 tES CommenIs: None. Days WiIhoUt Accident 62 Dale: I~: 0 I Spills to dale: 0 I AM DrIll: s..tety1ll'US.: Pre-tour safety meetings (both crews) I PM Dr1B: Present Operation: Picking up HWDP and 5" 19.5# G-105 drill pipe. Boals: 2 lIalícn,A. ..: Casing ShoeIJ'ubing L.....dion: Slow Pump Rates: Size IbIft MD 1VD LOTIPPG Pump: #1 #2 13-3/8" 61 SPII 10 3/4" Pn!ss: 9-518" 43 Liner: 31/2" 9.3 9,450 8,417 DUAL S1rtc DepIh Total POB: 60 76 DRLG: 2 CaIering: Prod: 13We1ders: Rig Coot: 22 OIlIer: DriIing 1: Doug Nienhaus 5 Foreman 2: StocklFahrlender 6 Tool Pusher: Page 1 Sandidge 12 6 12 51/2" 12 3 L-O-P From To HRS op8n.'01l5 Detail P 0:00 5:30 5:30 Pull out of the hole laying down the long string of31/2" Hydril CStubing 153 joints and one cut piece. P 5:30 7:00 1:30 Rig down GBR tubing equipment and clear production equipment off the rig floor. P 7:00 9:30 2:30 Change top pipe rams from 3 112" duals to 5" single rams and close bonnets. L 9:30 12:00 2:30 Rig down bails, torque arrestors and link tilt assembly to change out the Inside BOP valve. (clean well bay rooms and the rig floor while rigging down the top drive). L 12:00 17:00 5:00 Change out the IBOP valve, lower kelly valve and the saver sub. Install stabilizer tubes and link tilt assembly L 17:00 17:30 0:30 Test the IBOP and lower kelly valve to 250/3000 psi. L 17:30 20:00 2:30 Install and adjust the pipe handler assembly. P 20:00 21:00 1:00 Make up test plug and test stand. Set the test plug and attempt to test the 5" pipe ram without any success. L 21:00 0:00 3:00 Open bonnets on the 5" top pipe rams and found the top seal torn and the leading end rolled out of place on one ram block. Remove top seals from both ram blocks and clean and polish seal grooves. Smooth and grind wear plates inside the ram cavity. Installed Anadrils "Tee" to the mud line goose neck. Note: Comments on 3 1/2" CS Hydril Tubing, Has good external Appearance. After further inspection I noticed the internal was becoming pitted. It looked like a lot of it was at connections. Note of the events of the day: Work on PVT equipment. Working on camera installation in derrick having problems with the monitors. MR-SH-M-14 ABAND 08-22-01.xls Page 1 of2 Revioed:10128199 by MWD . Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb@unocal.com . UNOCAL Beverly Harrison Business Ventures Assistant November 14, 2001 DATA TRANSMITTAL To: Lisa Weepie 333 W 7th Ave, #100 Anchorage, AK 99501-3539 Alaska Oil & Gas From: Beverly Harrison 909 W. 9th Avenue Anchorage, AK 99501 I Unocal Alaska Transmitting the following: ..,_..' ·'")~!W-.~."1W~I".!.. .......... t_ll.illlll,"i¡·"¡II._''_'';;:t;<;f4fJI'k_\..".... .':;"~' M~"~$"""w,,," N ._ "~__I{II_%lli¡¡L'__~___A__<,,.."L__"'__'«...,..,_,..,~,. <, ,UTA-._. -A '.,' N~_'__'" ,._ -N'" "~,, ,~x:%~'" ,_ ,','.. .. ~"~""',' _ . v"""~_"_"_YA_A_A__'__ _~_A_-"~_A~__,_,_......_J_~jIL....__,___________, ......"., _z-liw;g(WL""""""-'.._"'''''T'_'_ x,,~^ _N.""'- ISION DENSITY NEUTRON TRUE INCH - 715 11TBU M-12 ERTICAL DEPTH ,·,mw"mm'W~"w.~~~n~""~"'=."m·.¥..m'··"W·_'A_V__NW.·.'.".......,,_..w...........wwm_·._._·._·__...... ISION DENSITY NEUTRON TRUE 0-6690 11TBU M-14RD ERTICAL DEPTH RESISTIVITY MEASURED 0-6690 ·'=,~m=wN~'~~w_wmN=N_ B-L¡~!B dOI"Î~ B:Gne~~~~j a 01-' J J 11TBU o U 11TBU ¡ 570-4130 RELATION GRlCCL 9/61200 570-4130 i I JTBU 12 V I~Cj,.Op Î t ~OJ' '1 l." 5 INCH 8/23/2001 2590-2949 11TBU M-14 CPST SETTING TOoL. "W"W COR - RESIS-rívín'MEASÜREÖ DEPTH -'__'__h_~__,~·".n·_p="""""""'N"'N."'N.~,,,,·^,~_~ CDR - RESISTIVITY TRUE DEPTH "" mm~~~mmm.wm~'·v "_,,,,,,,"~,,.,,"v,,n~~m"'m "w"wm......m.'^~...m.....m_.mw .. ".' 'A_r "_,",¥,_," '.wm.._·'WA_m_m............wm...._......w....w.......mn', _......w..~n,¡·'~w_w.w·,·· ",_" ····'ff.w.·..'m"__· W"_" ,. ··.·,,~=.·v·w 2001 480-10715 1 iTBU M-14 11TBU M-12 5 INCH 8/23/2001 2590-2949 1215 INCH ON INCH 715 1 TBU M-12 9/4/01 _=,_w__,__'~~·~_w_c·~·_~__,._y___v"""·..........~w_· TBU M-14RD ,....¡ wAPER k90 ,., , í , APEFf~^^1 j - 0 Î I ! 'CE1VffD 1 TBU M-4 Please aCkn~Wled e receipt by signing and returning one copy of this transmittal or FAX tOÓ907) 263-7828. I IN V 1 :J 2001 I Received b . "<. ~iO ~ Date: U- Alaska Oil & Gas Cons. Commíssion Anch1)rage . ~~!Æ~ E (ID F !Æ ~!Æ~ ~~!Æ . ~ .,ASIiA. OIL Al'Q) GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Williamson Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 Re: Trading Bay Unit M-14RD Unocal Permit No: 201-171 Sur Loc: 1049' FNL, 463' FWL, SEC 33, T9N, R13W, SM Btmhole Loc. 1044' FSL, 467' FWL, SEC 33, T9N, R13W, SM Dear Mr. Williamson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. Annular disposal has not been requested as part of the Permit to Drill application for Trading Bay Unit M-14RD:. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~ .QU~ cam~sli Taylor Chair BY ORDER OF THE COMMISSION DATED this 13::. day August, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Redrill: X 11 b. Type of well Deepen: Service: 1a. Type of work Drill: Re-Entry: 2. Name of Operator Union Oil of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 4. Location of well at surface 1049' FNL, 463' FWL, Sec. 33, T9N, R13W, S.M. At top of productive interval 1838' FSL, 1161' FWL, Sec. 33, T9N, R13W, S.M. At total depth 1044' FSL, 467' FWL, Sec. 33, T9N, R13W, S.M. 12. Distance to nearest 13. Distance to nearest well property line (No other C4 completions 467 feet exist at this time) 16. To be completed for deviated wells Kickoff depth: 2780 feet 90° Maximum hole angle: 18. Casing program size Specifications Hole Casing Weight Grade Coupling Length exist 16" 75 K-55 BTC 1458' exist 133/8" 61 K-55 BTC 2713' exist 95/8" 43 & 47 N-80 BTC 2780' 8 1/2" 7" 26 L-80 BTC 3175' 6" 41/2" 11.6 N-80 BTC 1020' 19. To be completed for Red rill , Re-entry, and Deepen Operations. \ \") 0 Total depth: measured 9,190' feet true vertical 8749' feet measured 9,101' feet true vertical 8708' feet Lenath Size Cemented Measured depth 407' 34" Driven 480' 945' 20" 2200 sx 945' 1458' 16" 1480 sx 1458' 2713' 13-3/8" 1650sx 2713' 9190' 10-3/4" & 9-518" 2150 sx 9190' NlA NIA NIA NlA Measured: 8190-8231',8452-8462',8468-8494', 8574-8612', 8826-8842', 8908-8940' True Vertical: 7946-7982',8178-8187',8192-8215', 8285-8318', 8506-8520', 8577-8605' Short Strina Perforation depth: Measured: 6002-6036' True Vertical: 5994-6026' Tubing (size, grade, and measured depth) 3-1/2" 9.3#1ft N-80 CS Hydril to 5,958' (short str.) & 3-1/2",9.3 #/ft., N-80 CS Hydril to 8526' (long str.) Packers and SSSV (type and measured depth) Otis RDH Dual pkr. At 5942', Otis Versa-Trieve Pkrs. at 8,158' and 8,509', SSSVat416'. 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: NlA Drilling program: X Drilling fluid program: X Time vs. depth plot: Refraction analysis: Seabed report: 20 MC 25.050 requirements: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: . Effective depth: Casino Structural Conductor Surface Intermediate Production Liner Lona Strino Perforation depth: S;g"~),tW\ Approved by Form 10-401 Rev. 12-1-85 Exploratory: Stratigraphic Test: Developement Gas: X Single Zone: X 5. Datum Elevation (DF or KB) 10. Field and Pool 152' KB to MSL feet McArthur River Field 6. Property Designation ADL-18730 7. Unit or property Name Trading Bay Unit 8. Well number M-14RD 9. ApproxÏrnate spud date 08122/01 14. Number of acres in property . k¡,ç ð'i'\ >í í1,1ið\ Development Oil: Multiple Zone: Grayling Gas Sands 11. Type Bonc (see 20 AAC 25.025) Number Amount U 62-9269 $200,000 15. Proposed depth(MD and TVD) feet feet 3840 6875/4127 17. Anticipated pressure(see 20 MC 25.035 (e)(2)) Maximum surface 1721 psig At total depth (TVD) Setting Depth Top Bottom TVD 1458' 2713' 2780' 4127' 4127' MD MD 1458' 2713' 2780' KOP 5855' 6875' 0' 0' 0' 0' 2680' 2680' 5855' 4127' 5~S S ~''''-~'''''\ Pluas: Slickline blanking plug in long string tail pipe @ 8525' MI TVD 0' 0' Dan Williamson Title: Drilling Manager Commission Use Only Permit Number I API number I Approval date 4.. J Il~ I I See cover letter ~ .2..0/ - /7/ 50-733-20408- 0/ U ? f for other requirements Conditions of approval Samples required: [] Yes Xl No Mud log required: [] Yes þd' No Hydrogen sulfide measures [] Yes ~ No Directional survey required þ(Yes [] No Required working pressure for BOPE [] 2M; ~M; [] 5M; [] 10M; [] 15M Other: ,Ðriginal Signed 8, Cemmy Oechali Junk: (none) Commissioner by order of the Commission ORIGINAL 1787 psig Quantity of cement (include stage data) 1480 sx 1650 sx 2150 sx 204 sx NI A - SS WW screen True vertical deptt 480' 945' 1458' 2713' 8749' NlA Date: Aug. 8,2001 Data{; In /) Submit in triplicate , ~ . " ,¡ :J; I " '" ... í '" I :0 <D i ä: I UNOCALtÐ Trading Bay Unit Steelhead Platform ~ Well M..14RD..Horizontal I PROPERTY PLAT ADL-17594 Unocal Forcenergy End of Hz section (TB) J ADL-18729 Unocal Forcener I ADL-18730 Unocal Forcenergy i o 1,000 I 2,000 I I, I ! I ! t ' 3,000 I I SCALE I~ FEET I ,ç, !'\g! ff ç" A L-17579 Unocal . . Steelhead M-14RD Hazard Analysis for APD 20AA C 25.005 © 4 A. The maximum anticipated formation pore pressure gradient that will be encountered while drilling M-14RD in the grayling Sand series is a slightly above n0m181 gradient Of 8.9 ppg EMWgradient. This is the original pore pressure gradient for the entire series of Grayling Sands. It is U....,'ttøtmost of the Grayling Sands to be encountered, including the primary objective C4 Sand, will bepartiaHy depleted due to current or previous production. Based on previous C4 Sand production and P/Z data, a partially depleted gradient of 0.21 psi/ft is expected in the objective formation. Therefore, the worst case burst pressure scenario would be too assume that the C4 Sand is not partially depleted, and an unlikely 'full evac - replacement with gas' well control incident occurs. In this case, the maximum possible surface pressure would be 1838 psi (please refer to the Maximum Anticipated Surface Pressure attachment). B. Gas produced from the Grayling Sands has contained nosjgnäicaAt levels of H2S. AJthough it is highly unlikely that H2S gas could be encountered in this particular drilling operation, the rig and facility are designated as an H2S facility, and all required safety equipment and procedures for dealing with H2S gas will remain in place in case needed. C. Well M-14RD will be drilled with an 9.0 to 9.2 ppg water based mud. The goal will be to drill the 8 ¥2" hole section from the casing window at 2780' MD/VD, through various coal beds and partially depleted Grayling Gas Sands, to land the well at 90° inclination at approximately 5855' MD / 4127' VD in the C4 Sand. The plan is to drill the 3075' of 8 ¥2" hole in one bit run, and run the 7" liner immediately after pulling the bit out of the hole, to minimize formation exposure time, and minimize the risk of complications such as stuck casing which, in turn, potentially could lead to a well control incident. Sloughing shales/coals are considered less likely to be problem if exposure time is minimized. Lost circulation problems in partially depleted sands are a potential concern, but are considered to be unlikely based on historical data. The mud to be used will include additives to minimize shale/coal sloughing, and adequate lost circulation material will be kept on board in case lost circulation problems develop. APD Procedure & Hazard.doc 8/6/01 . . Steelhead M-14RD Cementing Program 7" Liner: 8 Yz" hole TD @ ±5,855' MD (4,127' VD), top of 7" liner @ ± 2680' MD/VD Top of highest hydrocarbon interval = ±3050' MD / 3045' YD. The planned TOC will be at the 9 5/8" window at 2780' MDND, which is only 270' above the expected shallowest pay sand. A 7" x 9 5/8" Baker ZXP liner top packer will isolate the 7" annulus from the 10 %" x 9 5/8" casing. Calculated cement volume for liner, based on open hole volume plus 30% excess, is: 3075 ft (5855' - 2780') x 0.1268 fe/ft (8 Yz" x 7") x 1.30 (excess) = 507 ft3 Cement will be 12.0 ppg Lite Crete with 2.48 fe/sk yield (507 ft3 = 204 sx.) Due to the high angle nature of the 8 Yz" section, the beginning and ending veertical depths will be approximately 2780' and 4127' respectively. Therefore, the additional hydrostatic head due to the cement column will be only approximately 210 psi. This relatively small amount of additional hydrostatic pressure is viewed as unlikely to cause lost returns during cementing. (4127' - 2780') x (12.0 ppg - 9.0 ppg) x 0.052 = 210 psi APD Procedure & Hazard.doc 8/6/01 . . Steelhead M-14RD Casing Design Existing 10 %" x 9-5/8" Production Casing: 10 %" 55.5# N-80 from 0' - 533' MD & 9 5/8" 47# S-95 from 533' - 2780' KOP (planned window depth) Worst case for burst is the unlikely event of a gas kick while drilling at TD: If the well bore filled up with gas as described on the Maximum Anticipated Surface Pressure attachment, the maximum anticipated surface pressure would be 1838 psi. Burst= 1838 psi 10-3/4" 55.5# L-80 rated @ 6450 psi for burst Safety Factor = 3.5 OK (Note: The 9 5/8" casing below 533' has a higher safety factor than the 10 %" casing.) Worst case for collapse is if lost returns occur while drilling below the 9-5/8" casing: The 9-5/8" 47# S-95 casing extends from 533' MD/VD to the window at 2780'MD/VD. In a full evacuation case, the highest possible collapse differential pressure would occur just above the window at 2780' MD/VD. Collapse pressure = (8.9 x.052 x 2780') = 1286 psi (assuming 0 psi internal pressure) The 95/8" 47# S-95 is rated @ 5080 psi for collapse resistance Safety Factor = 3.9 OK Tension = NI A (casing already in place and cemented) Planned 7" Production/Drilling Liner 7" 26# L-80 BTC to extend from 2780' MD/VD to 3655' MD I 4127' VD Pipe Ratings: Burst = 7240 psi, Tension = 604,000 lbs, Collapse = 5410 psi. Burst: There is no significant burst requirements for this particular drilling/production liner, due to the shallow depth and short vertical distance between the top and bottom of the liner; i.e. 2780' VD to 4127' YD. The pipe burst rating of 7240 psi is significantly higher than the maximum anticipated BHP of 1909 psi. Tension: The highest possible buoyed tensile load of 68,516 lbs. occurs when the 3175' string is hanging below the rotary table. Safety factor = 8.8 OK APD Procedure & Hazard.doc 8/6/01 . . Collapse: The highest possible collapse load would occur if the well is 100% evacuated internally with pore pressure acting on the external surface, as follows: Max. Collapse Pressure = (8.9 ppg EMW x 4127' x .052) = 1910 psi Safety Factor = 2.8 OK APD Procedure & Hazard.doc 8/6/01 . . Steelhead Well #M-14RD Maximum Anticipated Surface Pressure The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the sidetrack M-14RD. The worst case scenario was used for the pore pressure gradient in the following calculation; i.e. it was assumed that the objective C4 Sand is at the original pressure gradient of 8.94 ppg EMW (0.465 psi/ft) instead of partially depleted. Data obtained from numerous wells in the McArthur River Field indicates that a maximum gradient of 0.465 psi/ft is the highest pressure gradient to be expected I theGrayling Sand series, between the window depth of 2780' VD and the total vertical depth of 4127' YD. Max. BHP Depth Well llli TVD EMW,ppg Comment M-14RD 1787 4127' 8.33 Original C4 Sand pressure The fracture gradient at sidetrack window at 2780'MD/VD is estimated at 0.59 psi/ft or 11.3 ppg based on a leak off test performed in well K-19 at 2302' YD. In actuality, a higher frac gradient is likely in well M-14RD, since we have the ability to chose an optimum window depth in a competent formation after studying the well log. Casing Pore Frac or Casing Setting Fracture Pressure Mud Pore Max. Size Depth Gradient Gradient Weight Pressure ASP (in.) (TVD ft) (lbs/gal) (lbs/gal) (lb/gal) illill illill 10-3/4" 2780' 11.3 8.9 9.1 1633 1573 x 9-5/8" Window 7" liner 4127' 12.9 8.9 9.1 1909 1838 Procedure for Calculatin2 Anticipated Surface Pressure While Drillin2 In this particular case (i.e. in a shallow horizontal gas well), the worst case ASP is determined based on a full evacuation and replacement with gas scenario. Normally, the maximum ASP would be the lesser of; (1.) the surface pressure at breakdown of the formation at the casing seat (with a full column of gas), or (2.) formation pore pressure at the next casing point less gas gradient to the surface. For 8-112" Hole Section from 2780' TVD to 4127' TVD APD Procedure & Hazard.doc 8/6/01 . . 1) ASP = (FGx.052xD) - (gas hydrostatic head) = (11.3 x .052 x 2780) - (60) = 1573 psi OR 2) ASP = FPP - (gas gradient x D) = 1909 - (.017 x 4127) = 1838 psi Since the frac gradient at the 9 5/8" window is unknown, and frac gradients ranging from 0.55 to 0.75 psi/ft are possible based on the available data, the higher calculated ASP (1838 psi) based on the maximum expected BHP (i.e. 1909 psi) will be assumed to be the maximum ASP APD Procedure & Hazard.doc 8/6/01 Rig Sub Grating Upper well Bay Floor Top of Rotary Table A 163/4" BOP up KB" 71.81' 71.81' 6.75' 1:1. 23.47' 'Ii' ^ 12.51' .60' w IT Top of 11" 5 M Tbg Spool ^ 36.25' w ^ 59.76' w . . 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SPF' · .40'''8242' I SPf' · 8S4"-~1" · 1806'"8.''' · " . I",Ø...,Øo6 ".,. · ... ~:. .. All s..es. hote. ...sit.. ",0 1501 psi . .&:.m.A'tDl.J!AClŒLASUHlUEa· ....~ .,8.8 ppg __ " hoI.. I1SI' DiIa V.,...-T,.r.v."hckM I f""" ~ · ..z. hot.s ....-It.1o 4.0 pp, EW. 1175' OtIs XA St...... wn.7~ X Pron..... o~ó i-'4ø.~~. _ f-IS 6 /uls it/S1'- i£fC,'" "S~, 7/00 . "·o~ ~.4>~ ,.~ ' . ..L I /_ '_,..1_"\ .1.,'-8241' a Jts 3-Slr. UI. ...o. ð'. . . II> I· allA" (ln~ P'IIr.. ¡It pøu.t~. a,ç~~ lfM·.."...,..V Spc: CIr Jut.. ilia , AI Mod ~1rIp tI ð". Þ ;J .ISO' 01 CvfDI. "'..... .... frèIR .þ~: ,':::' E:.. !£B[n~T'QN-~ 81n'-1247' ,.., Me.... CI18S'-I23:s' J1L). - - - 8-loe '112'-6136' '7 IPF 120- Ph.... 1/,. '-7 .'1'-1216' 12.,.' · F-7 121"-1231' Fr.. oIf .pih perf. ,..to 1574/-HI2" · · G-13 1826'-1842" · · G-.4 "0.·...,40'· · · ~,. ..' . # ,. ,. U,. air. 11r..... Itot &.oed.. at,. Mot.it I..t UnIts (2.0') att. MuWsho. &.Ide COoS,') '.. .." eo,. ee' D1III V......-T,.,..,. Pack... Oils XN NIPø(. œ.7~ PIca lore, ur NoGõ). DiIa ~ .'-'Airy ..... t;¡ '-10 ) ).~ ;.: G-D3 &IGu,kfd off (a.IY'(þJ., ') 152" G-O. ../ E-Uw PJ7D . ,aft' Jm. M~H) PJTI I J101' TI I J19r ~ Revlslcn I.".. V2D1" ReVlS.d Iyt PMDIM't Reuctll New ....It Pr.VlOUS ..'ltlføn¡ NOM C L KB elevation::: 152.0', KB to Flng ::: 64.3' 20" 94 X-56 64.3' 945' 16" 75 K-55 64.3' 1458' 13-3/8" 61 K-55 BTC 64.3' 2713' 10 314" 55.5 N-80 BTC 64.3' 533' -....... - /' 9-5/8" 47 S-95 BTC 533' +/-2780' (window) 7" 26 L-80 BTC +1-2680' +1-5855' ~ TAIL 4-112" 12.6 L-80 4-112" 12.6 L-80 4-112" 11.6 N-80 ¿ BTC (Spec. Cl.) 64.3' BTC (Spec. Cl.) 3655' BTC SSWW Screen 5855' 3650' 5855' 6875' ¿ ~ 6 þ ~ \ 9-5/8" Window at +-2780' MD, 5. (vertical inclination) 6. L 2. 3 +1-400' n.y.d. +1-3620' Baker 4- ]/2" TE-5 TRSSSV (ID :;;: 3.813") 4-]/2" SPMs w/GLVs Baker 4-1/2" CMU sliding sleeve ¿ +/- 3685' +1- 2600' Baker "XN" nipple (profile:;;: 3.813") 7" x 9 5/8" HMC/ZXP Liner HangerIPacker wi tie-back receptacle 003 Z~4 ( . SSD, Packer & XN nipple @ +1-60 degrees inclination . . . .5 4-112" L-80, 11.6# blank from packer to 7" shoe 4-112" SS WW Dura-Grip Screen from 7" shoe to TD I I 7" liner TD ::: 15485' MD/9737' TVD M-14RD Proposed Schematic. doc Drawn: 07119/01 DRAWN BY: JFB . . M-14RD Procedure for Horizontal Re-Drill & Completion Mill Window 1 MU bottom-trip whipstock. 2 RIR with one trip whipstock assembly to 2780' MD. 3 RU E-line. Run gyro to orient whipstock. Set WIS. 4 Changeover well to WBM. 5 Mill & dress window in 9-5/8" casing. 6 Circulate bottoms up and perform LOT. 7 POR & LD window milling string. Drill & Case 8-1/2" Hole 8 M/U & RIR w/8 112" steerable BRA wI GR-RES. 9 RU E-line. Ru~gyro to orient BRA. RD E-line. 10 Steerable drill 8-1/2" hole to +1- 5000'. 11 Round trip for bit. 12 Steerable drill 8-112" hole to landing point (+1- 5855'). 13 POR wI steerable BRA. 14 Change rams to 7" & test. 15 RU casing crew. 16 RIR wi 7" production liner to TD 17 Cement 7" production liner. 18 Circulate clean & POR wi liner running tool. Drill 6" Horizontal Hole 19 Change rams to 3 1/2" & test BOPE 20 PU 3 1/2" drillpipe. 21 M/U & RIR wI 6" steerable BRA wI GR-RES. 22 Drill horizontal hole to 6875'. 23 Circ. Clean & spot solids free WBM in RZ hole. 24 POR wI steerable BRA to +1-5600'. 25 Displace WBM above +1-5600' wI FIW. 26 Finish POR. LID 3 112" DP & BRA. Run 4 1/2" Screen & Production Tubing 27 Change rams to 4 112" & test BOPE 28 Pull wear bushing. 29 RU casing crew 30 PU & RIR wi 4 112" WW screen & 4 1/2" blank pipe. 31 Make up packer assembly. 32 Continue P/U & RIH wi 4 1/2" production tubing. 33 Space out, install SCSSV, control line, and PU hanger. 34 Land tubing hanger. 35 RU slickline, RIH wI N test tool to XN nipple. 36 Pressure up to set packer & pressure test packer. 37 POR wI slickline & RD unit. Nipple Down Tree & Nipple Up BOP 38 Verify TRSSV closed & Set BPV. 39 ND BOPE. 40 Install tree and test. 41 Turn well over to Production. UNOCALe 2000 2500 - Q) > Q) --I Q) CO Q) Q) ~CJ) o c: o CO 10 Q) II :2: .5: Q) ..- > _0 .c,c _ CO Q.¢:: Q)o 00 ã5N 010 :e:s- Q)a::I >~ Q)- ::¡ Q) '::0:: > Q) W 3000 3500 M-14 4000 -......- ........-......................-....... 4500 -500 VERTICAL SECTION VIEW Client: unocal Well: M-14RD (PSI Field: McArthur River Unit Structure: Steel head Section At: 185.47 deg Date: June 25. 2001 Tfe..ln Survay2700 MD 2700 TVD i 0.03' 286.13·.. 14departure Top Wlnd0w:2800 MD 2800 TVO ~ 0.08' 350.67'.. 14depart... Bo.. Whlpetock2816 MD 26161VD 1.840 170.61- az 14 departure 'i ~ KOP/Crv711002829MD 2829TVD ~~ 1.840170.67°8% 14departure / =8C::O 35741VD 70.36' 159.79' az . 50s departunit Hold Angle 70.36° Cry 7/100 / 4Q45MD 3956TIID 70.36° 159.79" az 1470 departure ..................-...........-. Schlumbepgep . . EndC"Y/Tgt 1=~~~~~dAnge 90000ro 6875 MD 4121 TVD 90.00" 221.74° az 3134 departure o 500 1000 1500 2000 2500 Vertical Section Departure at 185.47 deg from (0.0, 0.0). (1 in = 500 feet) 3000 · UNOCALe PLAN VIEW Client: Well: Field: Structure: Scale: Date: Unocal M-14RD (P5) McArthur River Steelhead 1 in = 500 ft 25-Jun-2001 Unit Schlumberger -1000 -500 o 500 1000 , I True North Mag Dec ( E 20.77° 1500 End crv--------- 3808 MD 3574 TVO 10.36" 159.79" az. 525$ 182E -0 o Tie-In Surwy2700 MD 2700 TVO 0.03' 286.'3'.. '48 2W ~_. 4 TopWlndow2800MD 2800TVD ~C 0.08' 350.67'.. '48 2 W :.---- ~ '--:/ B... Whlpst0Ck2816 MD 281S TVD / / 1.84" 170.67"az 145 ~w KOP I Cry 7110028~9 MD 2829 TVD 1.84" 170.6'r'øz14S 2W ~ -500 -500 ~ -1000 ^ :c I- a::: o z -:r.. o 'ð- ~. % ~ .> ~ '<1:) tø. -1000 Cry 71100 4945 MD 3956 TVO 70.36" 159.711" 8Z 15308 5S2E -1500 -1500 :c -2000 I- ::> / -2000 0 (/) V ~b. V V ". {V ~ -2500 § ~~ ·2500 End CrYl TIt ¡:¡."Ò 5855 MD 4127 TVD ~ 90.00· 221.14" az 23598 379 E -3000 -3000 TO 6675 MD 4127 TVD 90.00- 221.74" 81 31205 300W -3500 -1000 -500 0 -3500 500 1000 1500 «< WEST EAST »> ~ M-14RD Schlumberger UNOCALe Proposed Well Profile - Geodetic Report Report Date: June 25, 2001 Survey I DLS Computation Method: Minimum Curvature Ilubinski Client: Unocal Vertical Section Azimuth: 185.470° Field: McArthur River Unit 0 Iy Vertical Section Origin: N 0.000 fl, E 0.000 ft Structure I Slot: ~";:""IM-14I",AhIoI5J . .r., stud)' n TVD Reference Datum: KB Well: TVD Reference Elevation: 152.0 fl relative to Mean Sea level Borehole: M-14RD Feas1bl I UWUAPI#: 507332040801 Magnetic Declination: 20.771° Survey Name I Date: M-14RD (P5) I June 25, 2001 Total Field Strength: 55375.384 nT . Tort I AHD I DDII ERD ratio: 141.403° 13539.64 fl 15.9211 0.85E Magnetic Dip: 73.5W Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: August 15, 2001 Location LaULong: N 60 49 54.476, W 151 368.64C Magnetic Declination Model: BGGM 2001 Location Grid NIE Y/x: N 2499454.351 flUS, E 214(179.805 flUS North Reference: True North Grid Convergence Angle: -1.3992910r Total Corr Mag North·> True North: +20.771 ° Grid Scale Factor: 0.99999302 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azlm TVD VSec N/·S EI·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) Tie-in Survey 2700.00 0.03 286.13 2699.92 13.89 -13.73 -2.42 0.00 2499440.68 214077.05 N 60 49 54.341 W 151 368.689 Top Window 2800.00 0.08 350.67 2799.92 13.82 -13.65 -2.46 0.07 2499440.77 214077.01 N 60 49 54.342 W 151 368.690 Base Whipstock 2816.00 1.84 170.67 2815.91 14.06 -13.89 -2.42 12.00 2499440.52 214077.05 N 604954.339 W 151 368.689 KOP I Crv 711 00 2829.00 1.84 170.67 2828.91 14.46 -14.30 -2.35 0.00 2499440.11 214077.11 N 60 49 54.335 W 151 368.687 2900.00 6.79 162.62 2899.69 19.43 -19.43 -0.91 7.00 2499434.95 214078.42 N 60 49 54.285 W 151 368.658 3000.00 13.78 161.09 2998.02 35.75 -36.36 4.72 7.00 2499417.89 214083.64 N 6049 54.118 W 151 368.545 3100.00 20.78 160.59 3093.45 62.72 -64.39 14.48 7.00 2499389.63 214092.71 N 60 49 53.842 W 151 368.348 3200.00 27.78 160.33 3184.54 99.95 -103.11 28.24 7.00 2499350.58 214105.52 N 60 49 53.461 W 151 368.070 . 3300.00 34.78 160.17 3269.96 146.89 -151.94 45.78 7.00 2499301.34 214121.86 N 60 49 52.980 W 151 367.717 3400.00 41.78 160.05 3348.41 202.83 -210.16 66.85 7.00 2499242.62 214141.50 N 60 49 52.407 W 151 367.292 3500.00 48.78 159.97 3418.73 266.94 -276.89 91.13 7.00 2499175.32 214164.15 N 604951.750 W 151 366.802 3600.00 55.78 159.90 3479.88 338.27 -351.14 118.25 7.00 2499100.43 214189.44 N 604951.018 W 151 366.255 3700.00 62.78 159.84 3530.94 415.74 -431.80 147.82 7.00 2499019.07 214217.04 N 60 49 50.224 W 151 365.658 3800.00 69.78 159.79 3571.15 498.22 -517.67 179.39 7.00 2498932.46 214246.50 N 60 49 49.379 W 151 365.022 End Crv 3808.38 70.36 159.79 3574.00 505.31 -525.06 182.11 7.00 2498925.01 214249.04 N 60 49 49.306 W 151 364.967 Crv 7/100 4945.28 70.36 159.79 3956.07 1470.30 -1529.89 552.09 0.00 2497911.45 214594.37 N 604939.411 W 1513557.505 5000.00 71.08 163.77 3974.14 1517.59 -1578.94 568.24 7.00 2497862.02 214609.31 N 604938.928 W 151 3557.179 5100.00 72.61 170.96 4005.34 1607.84 -1671.60 588.97 7.00 2497768.88 214627.77 N 604938.015 W 151 3556.761 M-14RD (P5) report.xls Page 1 of 2 6/25/2001-3:33 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI·S E/·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (It) (It) (0/1001t) (ltUSI (ftUS) 5200.00 74.39 178.02 4033.77 1701.90 -1766.96 598.14 7.00 2497673.33 214634.61 N 60 49 37.076 W 151 3556.576 5300.00 76.39 184.96 4059.02 1798.36 -1863.63 595.60 7.00 2497576.75 214629.71 N 60 49 36.124 W 1513556.627 5400.00 78.58 191.77 4080.71 1895.79 -1960.14 581.39 7.00 2497480.62 214613.15 N 604935.174 W 151 3556.914 5500.00 80.93 198.47 4098.52 1992.74 -2055.07 555.72 7.00 2497386.34 214585.17 N 604934.239 W 151 3557.432 5600.00 83.39 205.08 4112.18 2087.75 -2147.00 518.98 7.00 2497295.34 214546.20 N 604933.334 W 151 3558.173 5700.00 85.94 211.63 4121.48 2179.42 -2234.56 471.70 7.00 2497208.96 214496.79 N 604932.472 W 151 3559.127 5800.00 88.55 218.14 4126.30 2266.37 -2316.44 414.61 7.00 2497128.50 214437.72 N 604931.665 W 151 360.278 End Crv I Tgt 5855.48 90.00 221.74 4127.00 2312.09 -2358.96 379.00 7.00 2497086.86 214401.08 N 604931.247 W 151 360.996 . TO 6875.39 90.00 221.74 4127.00 3134.39 -3120.00 -300.00 0.00 2496342.64 213703.71 N 604923.752 W 151 36 14.690 Leqal Description: NorthinQ (Y) mus] EastinQ (X) rftUSl Surface: 4231 FSL 4817 FEL S33 T9N R13W 8M 2499454.35 214079.80 Tie-In: 4217 FSL 4819 FEL S33 T9N R13W SM 2499440.69 214077.05 End Crv I Tgt: 1872 F8L 4442 FEL 833 T9N R13W 8M 2497086.86 214401.08 TO I BHL: 1111 FSL 5122 FEL S33 T9N R13W 8M 2496342.63 213703.71 . M-14RD (P5) report.xls Page 2 of 2 6/25/2001-3:33 PM · Unocal Alaska Resourc§t Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCALe August 9, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Trading Bay Unit McArthur River Field Permit to Drill, M-14RD, ADL 18730 Request for Administrative Approval to Conservation Order 228 Dear Commissioners: Union Oil Company of California, as Operator of the Trading Bay Unit requests Administrative Approval to drill the McArthur River Field well M-14RD, Adl 18730, pursuant to Rule 3, Conservation Order 228 and the spacing requirements set forth therein. The proposed drilling and completion of this well will allow for additional gas recovery from the Middle Kenai Gas Pool. Enclosed with our Permit to Drill (form 10-401) is Unocal check No. 2004699 in the amount of$100.00 as required by 20 AAC 25.005 (c)(1). The specific location, interval and depth are as follows: Surface Location: 1049' FNL, 463' FWL, Sec. 33, T9N, R13W, S.M. Top of Productive Interval: 1838' FSL, 1161"FWL, Sec. 33, T9N, R13W, S.M. Total Depth: 1044' FSL, 467' FWL, Sec. 33, T9N, R13W, S.M. If you should require additional information, please contact the undersigned at (907) 263-7882 or Mr. Jerry Bowen, Drilling Department at 263-7659. We appreciate your review and trust the enclosed is satisfactory to complete this request. Very Truly yours, ~~ Shannon W. Martin Project Landman enclosures ORIGI~~l\i. C L Platform Well -14 RD McA hur River Unit UN Steelhe Prepared by: Lee Dewees Reviewed by: Presented to: Jerry Bowen M-I DriHing Fluids L.L.C 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax . . DRILLING FLUIDS M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 Phone (907) 274-5564 Fax (907) 2709-6729 Wednesday, July 25,2001 UNOCAL 909 West 9th Avenue Anchorage, Alaska 9950 I A TTN: Jerry Bowen Jerry; Enclosed is a drilling fluids program for the M -14 RD Well. This program includes the fluids program for both the 8 1/2 " and the 6" hole intervals. It also includes the displacement of a liner running com- pletion fluid. Included is a basic drilling fluid program. If additional inhibition is required or for mini- mizing formation damage, KCL can be added to the system, however concentrations in excess of 3% may cause LC 50 values to be exceeded, assuming that mud and cuttings are discharged under the NPDES permit. Mud and cuttings sheen testing, heavy metals, gas chromatograph, monthly and end of well bioassay testing and reporting will be required to comply with these regulations. The proposed system has been successfully used to drill similar intervals in Cook Inlet. Please call if you have any questions regarding the mud program. Lee Dewees Project Engineer M-I Drilling Fluids 907274-5533 Eco Set Whipstock $5000 $1875 $6875 3 3 8 1/2" Hole 8 $52500 $3 $58750 5 Hole 4 $25000 $2500 $27500 5 · Cost estimate does not include completion fluid · Cost estimate assumes discharge of mud and cuttings · Cost estimate does not include reserves for lost circulation III Cost estimate assumes normally pressured zones M-l Drilling Fluids L.L.Cc 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax . . Interval Summary 8 1/2" Well M-14 RD 2780' - 5855' MD Drilling Fluid System Seawater Bio-polymer Flo-Drill ~.Y~"()(j...çt$ Flo- Vis / Polypac UL / Asphosol/ MI Bar / Caustic Soda Resinex/ KlagaurdlLubetex/Dual Flo SOlid$<Contröl Swaco Shale Shakers / Mud Cleaner /518 Centrifuge Pôtê....tial·PI'oblel11$ Hole cleaning / coal sloughing / drill solids buildup / lost circulation! stuck pipe/shallow gas ~ ' - .Interval Drilling Fluid Properties 2780'-5855' 8-12 <5% 9.2-9.4 15-20 < 10 cc's 12-20 · Set whip-stock in filtered inlet water. Displace hole to Flo-Drill mud. Install ditch magnets to capture metal cuttings. · Run leak off test to establish fracture gradient at the kick off window. · Build Flo-Pro NT mud system with the following; 2.0 ppb Flo- Vis, 1 ppb Dual Flo, 2-4 ppb Soltex, 4-6 ppb Klagaurd. Adjust pH to 9.0 - 9.5 w/Caustic Soda. Adjust 3 RPM reading to > 8 w/Flo-Vis. Raise mud weight to 9.2 ppg. Increase mud weight as required. · If coal becomes a problem, increase Soltex (Asphsol) and Resinex concentration to 4 - 8 ppb. · Maintain 3-4 ppb Klagaurd to inhibit clay swelling. · Keep drill solids to a minimum by use of all solids control equipment and water additions. · Add Lubetex to system for lubricity and to help sliding. (pilot test to confinn sheen test compli- ance) · Monitor ALC 50 values to ensure ability to discharge mud and cuttings. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax r""f--j DRILLING r ~ FLUIDS . . Interval Summary 8 1/2" Well M-14 RD 2780'· 5855'· MD Seawater Bio-polymer Flo-Drill Flo- Vis / Polypac UL / Asphosol/ MI Bar / Caustic Soda Resinexl Klagaurdl LubetexlDual Flo Swaco Shale Shakers / Mud Cleaner /518 Centrifuge Hole cleaning / coal sloughing / drill solids buildup /lost circulation! stuck pipe/shallow gas I · Increase mud weight as required. Shallow gas can be a problem on the Steelhead Platform. · Consider the use of a Form A Set AK lost circulation pill if significant loss of returns are en- countered · Use MIX IT and/or calcium carbonate for losses ifthe drill string contains a MWD and a mud motor. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax rr"'f-i DRILLING , ~ FLUIDS . . Interval Summary 6" Well M-14 RD 5855'· 6875' MD Seawater Bio-polymer Flo-Drill Flo- Vis I Polypac UL I Asphosol/ MI Bar I Caustic Soda Resinex/ Klagaurdl Lubetex/Dual Flo/KCL Swaco Shale Shakers I Mud Cleaner 1518 Centrifuge Hole cleaning I drill solids buildup I lost circulation/stuck pipel formation damage I! ! Interval Drilling Fluid Properties Yield Point (lb/100ftZ) 12-15 <4% 5855'-6875' 9.2 8-12 < 5 cc's 6-8 1- · Utilize mud system from 8 112' interval. Ifpossible displace 7' casing with FIW and drill ce- ment, float collar and shoe with FIW. · Condition fluid as required to lower fluid loss to 5cc or less, lower drilled solids to less than 4%, and adjust rheology as required. · Drill to 6875' and displace well to liner displacement completion fluid. (see formula listed in next step) · Build Flo-Pro NT mud system with the following; 2.0 ppb Flo- Vis, 3 ppb Dual Flo, and 3 % KCl. Adjust rheology, mud weight, and alkalinity's as required. M-1 Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ~ DRilLING r ~ FLUIDS . LOAD - OUT LIST · FLO VIS PLUS · DUALFLO · DEFOAM X · CAUSTIC · LOWATE (CAC03) · SAFE CARD FINE · KLAGUARD · MI BAR · ASPHASOL/SOL TEX · LUBETEX · MIX II · POLYPAC UL M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax . Well M-14 160 SACKS 200 SACKS 10 CANS 60 SACKS 100 SACKS 100 SACKS 12 DRUMS 1000 SACKS 100 SACKS 4 DRUMS 40 SACKS 40 SACKS 2 PALLETS 4 PALLETS 1 PALLET 1 PALLET 2 PALLET 2 PALLET 3 PALLETS 25 PALLETS 2 PALLET 1 PALLET 1 PALLET 1 PALLET P""f-j DRilLING r ~ FLUIDS Pr Ject .. MI Project and Tech Service Engineer will coordinate between the Unocal office, rig, ware~ house, and the M-I field engineers. .. Well progress wiU be monitored to look for any changes which will improve the efficiency of the tion or avert trouble.. Project T earn Title Work Craig Bieber 907229-1196 District Manager 907274-5051 Deen Bryan Tech Service 907 274-5003 907 274-5533 907 Lee Dewees Project Engineer Gus Wik 907 776-8680 907 Warehouse Manager Terry Mason Field Engineer 907 776-6833 Kieth Olson Field Engineer 907 776-6833 M-I Drillîng Fluids 721 West First Avenue Anchorage, Alaska 99501 (907) 274~5564 (907) 279-6729 Fax . . Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263·7660 UNOCALe Dan Williamson Drilling Manager 08/07/01 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue Anchorage, Alaska 99501 Attn: Commissioner Julie Heusser Re: Application for Permit to Drill (Form 10-401) McArthur River Field Steel head, Well M-14RD Commissioner Heusser: Enclosed for your approval is an Application for Permit to Drill (Form 10-401) for Steel head Well #M-14RD. A separate Sundry Application (Form 10-403) has already been sent to you for the proposed abandonment of well M-14. We are planning to sidetrack well M-14 at ±2780' MDND, and drill 3075' of 8 Y2" hole to achieve 900 inclination in the C4 Sand before running a 7" liner. We then intend to drill approximately 1000' of 6" horizontal drain hole in the C4 Gas Sand. The well will be completed with a 4 Y2" screen throughout the drainhole, with a production packer followed by 4 Y2" production tubing back to surface. Although the well is expected to produce gas, gas lift valves will be installed in case they are needed to initiate production at any time during the life of the completion. We are planning to utilize a water base drilling fluid, and cuttings disposal will occur as per Steelhead NPDES Permit # AKG285019. The expected date for work to begin is approximately August 22, 2001, so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Jerry Bowen at 263-7640. Sincerely, ~~ Drilling Manager RECEIVED AUG 1 0 2001 Alaska Oil & Gas Cons. Commission Anchorage AOGCC redrill cover letter. doc ORIGINAl JFB . FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERE SUBMITTED . VOUCHER NO. 08-AUG-Ol DRILLPERMITM14RD 08013000351 ~ tv) -lqr2Ò ,,'" :ORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. )ETACH STUB BEFORE DEPOSITING CHECK 62-20 3iT OCALG )ay . 1031548 08-AUG-0~ 2004699 GROSS 100.00 100.00 100.00 100.00 2004699 d Dollars And 00 Cents****************************** OF ALASKA OIL & GAS CONSERVATION .ISSION 3 WEST 7TH AVENUE SUITE 100 ANCHORAGE, AX 99501 United States II- 200 L. b q qu- -:03. .00 20 q.: Date 09-AUG-Ol Check Amount *****100.00 :¿:;;~7h 3 q . .8 . 3 ? II- ... CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRlLL / EXPLORATION INJECTION WELL INJECTION WELL REDRILL . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME V--\,-\ R.\:::> CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNUL~AL ANNULAR DISPOSAL <--J YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well --' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <--J YES + SPACING EXCEPTION ~~(t C~~~\\ <Q"--\-~\~ Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved. subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. r/?ú 'Þ1-/1!.RLJ PROGRAM: exp _ dev ~ redrll GEOL AREA <::?" ::L~) N ~ ~ fI rrl~~ Ç'r ~ (1'01#7 G'DJ s:...h /, (C".",!b/,,) y ~ f ß-Ij(., / C 0. 22'6: ~~_ ,-,,».1./< a--~ ~A Nnr ~;:¡f; -D-/ CG--/ 40. ~ ~í- //).-//'..1:1 ~ ~ k k~ñ/)¿/ /~ 4e- C- 9 ~J {L ,J~ f}J ~ ~;(,l- <,<;e-/J .J/I ..-LI '~CM ~ .f'~ q . >"'" "'~.e- rA;d¡,J ,.). ~"t ~ ~ d:1 ~C- /'-">/ o-~ ê/u:l Ad-7 .I~~rjC/'IL (jc.uJ~ q.V~-1 wC/~--"~1C LV . Y N? ~ ~)~~~~~'\"\~\\ íy ~ ,<:..~~ <:t:)~~~o"~\a't-.~ N ~~~~ \C1..~ ~'\ . N30\-"")'\~~~~~\.~~~~~~~ ~ ~rf"\ f'\~E..~.1a...-\.'~_ If \C't.~\"\.~~ I~ ~ u'1\~~ ,,,;}, ~.,:\ Y~ . Y ~/ ~% AJA~ N N ADMINISTRA TION ':1J:R ~:JE ~ ï 0/ ENGINEERING ~~~- GEOLOGY ::ïr _ann. disposal para ON/OFF SHORE serv _ well bore seg UNIT# -/ 2..07 () .,¿. WELL NAME /-,?OJ COMPANY OA./ð/ __ / INIT CLASS LJe.V WELL PERMIT CHECKLIST FIELD & POOLS 2.. 0 . f S"O 1. Pennit fee attached. . . . . . . 2. Lease number appropriate. " 3. Unique well name and number. . 4. Well located in a defined pool. . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. 6. Well located proper distance from other wells.. . . . 7. Sufficient acreage available- in drilling unit.. . . . . . 8. If deviated, is wellbore plat induded.. . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . 11. Pennit can be issued without conservation order. . . 12. Pennit can·be issued without administrative approval 13. Can permit be approved before 15-day wait. . . . c o z o -I ~ ::u - -I m - z -I J: - en > ::u m » J ~~~~~ Commentsnnstructions: \...:¡~~.....~ú\~\~~~~~~~\ þ ~~.. k~ê)t~~~ ~~~d.~~ ~r-- ~~~~~l~ . . . . !3sig. Y N Y N Y N Y N Y N 'r/¡7!tY! COMMISSION: 8~s CfJ( JMft (jfMf- 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. ~PR J~ATp 33. /ífl'~ 7f//7Id> I 34. ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . (B) will not contaminate freshwater; or cause drilling waste. to surface; (C) will not impair mechanical integrity of the well used for disposal (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOL~~: ENGINEERING: UIC/Annular ~~B.nr/ ~~ w~ t~M ~ ,'7 t:¡ç( (ç Conductor string provided . . . . . . . . " . . . Suñace casing protects all known USDWs. . " . CMT vol adequate to circulate on conductor & suñ csg. CMT vol adequate to tie-in long string to suñ csg. . . . CMT will cover all known productive horizons. . . . .. Casing designs adequate for C, T, B & permafrost. . . Adequate tankage or reserve pit.. . . . . . . . . . . . . . If a re-drill, has a 10-403 for abandonment been approved. Adequate wellbore separation proposed.. . . . . . . . If diverter required, does it meet regulations . . . . . . Drilling .fluid program schematic & equip list adequate. BOPEs, do they meet regulation . . . . . . . . . . . . BOPE press rating appropriate; test to ~~ Choke manifold complies w/API RP-53 (May 84). . Work will occur without operation shutdöwn. . . . Is presence of H28 gas probable.. . . . . . Pennit can be issued w/o hydrogen sulfide measures. Data presented on potential overpressure zones Seismic analysis of shallow gas zones. . Seabed condition survey (if off-shore). . Contact name/phone for weekly progress 11/01/100) c:\msoffice\wordianldiana\checklist (rev. DATE APPR e e 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. ,.> . .....' aO/-/71 UNOCALe UNOCAL ALASKA RESOURCES, INC. M-14RD McARTHUR RIVER FIELD Section 33-T9N-R13W Cook Inlet, Alaska September 4, 2001 Tim Smith - Sr. Logging Geologist Brian O'Fallon - Sr. Logging Geologist . UNOCALe Unocal Alaska Resources, Inc. M-14RD McArthur River Field Cook Inlet, Alaska TABLE OF CONTENTS WEll RESUME.......... ......... ..... ........ ............. ...... ...... ........................................ ......... .......... 3 LITHOLOGY SUMMARy....... ........ ............... ..¡II.... ...... .... .... ......... ..... ... .... .... ... .... ... .... ...... ......4 . DAilY CHRONOLOGY ......................................................................................................12 MUD RECORD ..................... ....... ...... ......... ........ ........ ...... ........... ...... .... .... ............. ....... .....14 SURVEY RECORD ................................. ............... ......................... .......... ..................... .....15 BIT RECORD ...... ......... ... ...... ............. ............ ............ ..... ... ..... ........... ... ... ........ II.. ..... ....... .....17 DAilY REPORTS....... .............. ........... ................................. ........... ...................................18 WE LL LOGS......................... 11I1........................................................................... .APPEN·DIX 1 . ~ EPOCH 2 UNOCALe M-14RD . WELL RESUME UNOCAL ALASKA STEELHEAD PLATFORM M-14RD WELL NAME: M-14RD FIELD: McARTHUR RIVER REGION: COOK INLET, ALASKA SEC. 33 T9N R13W SM LOCATION: BOROUGH: KENAI BOROUGH STATE: ALASKA ELEVATION: RKB:100.0' AMSL . API NUMBER: OPERATOR: INC. #50-733-20408-01 Operator Representatives: Company Geologist: UNOCAL ALASKA RESOURCES, DOUG NEIHAUS, JIM BENSON ERIK GRAVEN CONTRACTOR: NABORS ALASKA DRILLING DRILLING RIG: STEELHEAD 51 MUDLOGGING COMPANY: Logging Geologists: EPOCH WELL SERVICES, INC. TIM SMITH, BRIAN O'FALLON MI KEITH OLSON, BRYCE MILLER ANADRILUSCHLUMBERGER ANADRILUSCHLUMBERGER MIKE WARD, MARTY RINKE DOWELUSCHLUMBERGER MUD COMPANY: Mud Engineers: MWD COMPANY: DIRECTIONAL COMPANY: Directional Driller: CEMENT COMPANY: WIRELlNE COMPANY: SCHLUMBERGER . ~ EPOCH 3 UNOCALe M~14RD . LITHOLOGY SUMMARY 2840' Tuffaceous claystone = very light gray to light brownish gray; very soft to soft; mod to high cohesive; high adhesive; mod to high hydrophilic; mushy to pasty; irregular to sub-blocky fracture; massive cuttings habit; earthy luster; clayey to ashy texture; massive bedded with sporadic laminae carbonaceous material and thin sands. 2895' Coal = black to grayish black to dark grayish brown; firm to slightly firm; pliable to slightly brittle to crumbly; flaky to platy; grading carbonaceous shale and carbonaceous matter; dull to earthy to shiny luster; slightly scattered isolated micropyrite specs. 2945' Sand = light gray to occasionally white; very fine to medium grains; subangular to angular; moderate sphericity; estimate moderately to poorly sorted with probable soluble clayey to tuffaceous matrix; 85% quartz, and 15% coal and carbonaceous matter, calcareous matter, and gray and greenish gray clays; estimate mostly fair to poor porosity and permeability; trace mineral fluorescence; no visible stain or cut. . 3015' Claystone = medium gray to light gray to occasionally white; very soluble and moderately to very hydrophilic rehydrated; smooth to silty/gritty texture; slightly ashy; massive to grading sandstone and siltstone; slight carbonaceous matter to trace interbedded coal; slightly calcareous including grading tuff. 3070' Conglomeratic sand = light gray; very fine to coarse grains and scattered pebbles; subangular to subrounded generally less angular in coarse to pebble sized grains; moderate sphericity; estimate poorly to moderately sorted with probable soluble clayey matrix; 70% quartz, and 30% black to gray to yellow to green mostly siliceous grains and calcareous matter (tuff); estimate mostly fair to poor porosity and permeability; no oil indicators. 3145' Coal = black to grayish black to dark brownish gray; moderately firm to slightly firm; moderately brittle to some flaky; subplaty to hackly; low grade some grading carbonaceous shale; dull to slight shiny luster; slight isolated micropyrite. 3205' Claystone = medium gray to medium light gray; soluble and moderately to very hydrophilic rehydrated; overall slightly silty/gritty texture overall; slight carbonaceous matter and trace disseminated mica; very slightly calcareous overall; massive to thinly interbedded with siltstone, sandstone, and minor coal. . 3260' Sand/conglomeratic sand = very light gray to light gray; very fine to medium grains to scattered and locally increasing coarse grains and pebble; subangular to generally subrounded in U EPOCH 4 UNOCALe M-14RD · coarse grains and pebbles; moderate sphericity; estimate moderately to poorly sorted with slight to moderate clayey/ashy matrix; 75% quartz, and 25% coal, clay, calcareous and tuffaceous matter and minor siliceous grains and feldspar; estimate mostly fair to poor porosity and permeability; no oil indicators. 3345' Sand/conglomeratic sand = very light gray to light gray; very fine to coarse lower and common scattered very coarse and pebble; subangular increasing to subrounded in coarser fraction; moderate sphericity; estimate moderately to poorly sorted with clayey/ashy matrix; 85% quartz and 15% gray to black siliceous and carbonaceous grains and minor calcareous to tuffaceous grains; estimate mostly fair to poor porosity and permeability; no oil indicators. 3425' Claystone = medium gray to light gray to occasionally white; very soluble and moderately to very hydrophilic rehydrated; smooth to silty/gritty texture; slightly ashy; massive to grading sandstone and siltstone; slight carbonaceous matter; slightly calcareous grading tuff. · 3475' Sand/conglomeratic sand = very light gray to light gray; very fine to coarse lower and locally scattered very coarse and trace pebble; subangular increasing to subrounded in coarser fraction; moderate sphericity; estimate moderately to poorly sorted with clayey/ashy matrix; 85% quartz and 15% gray to black siliceous and carbonaceous grains and minor calcareous to tuffaceous grains; estimate mostly fair to possibly good porosity and permeability; no oil indicators. 3570' Coal = black to brownish black, occasionally dark reddish brown; firm to moderately hard; brittle to sub-brittle; irregular to conchoidal fracture; wedgelike to tabular cuttings habit; subvitreous luster; smooth to matte texture; bituminous to subbituminous to occasional soft woody carbonaceous material; rare visible gas bleeds. 3620' Sand = white translucent to transparent to very light gray; upper fine to upper medium; well to fair sorted; subrounded, occasionally subangular; moderate to high spheroidal sphericity; no visible cementation; grain support with clay matrix support inferred; abundant carbonaceous flakes; no fluorescence or cut. 3670' Carbonaceous shale = brownish gray to reddish gray to medium gray; moderately firm to soft; sub-brittle to soft crumbly; irregular to blocky fracture; wedgelike cuttings habit; smooth to silty texture; well defined laminations of carbonaceous material; interbedded with thin bituminous coals. · 3720' Coal = black to brownish black, occasionally dark reddish brown; firm to moderately hard; brittle to sub-brittle; irregular to conchoidal fracture; wedgelike to tabular cuttings habit; subvitreous luster; smooth to matte texture; bituminous to subbituminous to occasional soft woody carbonaceous material. U EPOCH 5 UNOCALe M-14RD · 3770' Conglomeratic sand = light gray overall with salt and pepper appearance; fine to coarse and scattered to locally common very coarse and pebble; subangular to angular including some bit broken fragments; moderate sphericity; poorly to moderately sorted in probable clay matrix; 70% quartz, and 30% gray to brownish black to trace green, white, and red mostly chert and siliceous coal and clay metalithics, and trace feldspar and tuff; estimate poor to fair porosity and permeability; no oil indicators. 3845' Conglomeratic sand = light gray overall with salt and pepper appearance; fine to coarse and scattered to some common very coarse and pebble; subangular to angular including some bit broken fragments; moderate sphericity; moderately to poorly sorted in probable clay matrix; 75% quartz, and 25% gray to brownish black to trace green, white, amber, and red including mostly siliceous metalithics, siliceous coal and clay, chert, calcareous matter and trace tuff; estimate poor to fair porosity and permeability; no oil indicators. 3925' Coal = dusky brown to brownish black; moderately firm to very firm; slightly to moderately brittle; subplaty to subsplintery fracture; slightly siliceous; low grade grading carbonaceous shale; dull earthy to slightly shiny luster; very slow bleeding gas. · 3965' Claystone = medium gray to light gray to occasionally white; very soluble and moderately to very hydrophilic rehydrated; smooth to silty/gritty texture; slightly ashy; massive to grading sandstone and siltstone; slight carbonaceous matter; very slight calcareous matter and micas. 4015' Ash fall tuff = very light gray to white to occasionally light brownish gray; soluble and moderately hydrophilic; silty to sandy with moderate to abundant angular grains. Noncalcareous; trace with slight very finely disseminated carbonaceous matter; grading to tuffaceous siltstone and grading to and interbedded with sandstone. 4070' Sand = light gray to white; medium to very fine and slightly scattered coarse grains and locally trace pebble; angular to subangular; moderate to high sphericity; estimate poorly to some moderately sorted in ashy/clayey matrix; 75% quartz, and 25% coal and carbonaceous matter, reworked ash, and siliceous grains and metasediments; estimate fair to poor porosity and permeability; no oil indicators. 4135' Coal = black to grayish black to dark brownish gray; moderately firm to slightly firm; moderately brittle to some flaky; subplaty to hackly; low grade some grading carbonaceous shale; dull to slight shiny luster; slight isolated micropyrite. · 4180' Claystone = light gray to medium gray to light brownish gray; soluble and moderately to very hydrophilic; slightly to moderately silty/gritty texture; massive to including thinly bedded siltstone and fine grained sandstone mostly with angular grains especially silt; mostly with slight disseminated carbonaceous matter increasing in upper clays with possible thinly interbedded coals; slightly tuffaceous overall; non to very slight calcareous matter. fI EPOCH 6 UNOCALe M-14RD . 4255' Sand = light gray to white; medium to very fine and slightly scattered coarse grains and locally trace pebble; angular to subangular; moderate to high sphericity; estimate poorly to some moderately sorted in clayey/ashy matrix; 75% quartz, and 25% partially siliceous coal and carbonaceous lithies, siliceous clays and metasediments, and minor feldspar and ash lithics; estimate poor to fair porosity and permeability; no oil indicators. 4325' Sand = light gray to white; medium to very fine and slightly scattered coarse grains and locally trace pebble; angular to subangular; moderate to high sphericity; estimate moderately to poorly sorted in clay and slight ashy matrix; 75% quartz, and 25% partially siliceous coal and carbonaceous lithics, siliceous clays and metasediments, and minor feldspar and ash lithics; interbedded with coal in lower section; estimate fair to poor porosity and permeability; no oil indicators. 4415' Claystone = medium gray to medium light gray; soluble and moderately hydrophilic rehydrated; slightly silty to very slight gritty texture including mostly angular to subrounded silt to fine sand; slight disseminated carbonaceous matter; very slight finely disseminated clays and micas; noncalcareous. . 4465' Claystone = medium gray to medium light gray; soluble and moderately hydrophilic rehydrated; very slightly silty to gritty texture including mostly angular to subrounded silt to fine sand; slight disseminated carbonaceous matter and coal to locally interbedded with coal; very slight finely disseminated clays and micas; noncalcareous. 4520' Claystone = medium gray to medium light gray; soluble and moderately hydrophilic rehydrated; slightly silty to very slight gritty texture including mostly angular to subrounded silt to fine sand; slight disseminated carbonaceous matter; very slight finely disseminated clays and micas; noncalcareous. 4570' Claystone = medium gray to medium light gray; soluble and moderately hydrophilic rehydrated; very slightly silty to gritty texture including mostly angular to subrounded silt to fine sand;· slight disseminated carbonaceous matter and coal to locally interbedded with coal; very slight finely disseminated clays and micas; noncalcareous. 4625' Coal = dark gray to black to brownish black; slightly firm to moderately firm; brittle to crunchy; flaky to subplaty fracture; dull to moderately shiny luster; low grade; very slightly scattered isolated micropyrite flakes. 4665' Claystone = medium gray to medium light gray; soluble and moderately hydrophilic rehydrated; slightly silty texture including slight angular to subrounded silt and very fine sand; sUght disseminated carbonaceous matter; very slight finely disseminated clays and micas; noncalcareous. . U EPOCH 7 UNOCALe M-14RD . 4710' Sand = light gray; very fine to coarse grains; subrounded to subangular; generally rounder in coarser fraction; moderate to high sphericity; estimate moderately to poorly sorted with clayey matrix; 80% quartz, and 20% black to gray to rare amber and trace green mostly siliceous grains including metalithics and siliceous coals and clays; estimate fair to poor porosity and permeability; no oil indicators. 4775' Tuffaceous claystone = medium light gray to medium gray; very soft to soft, occasionally firm as grades to siltstone irregular fracture; amorphous cuttings habit; moderately cohesive and adhesive; moderately soluble; ashy to silty to gritty texture possibly due to thin interbeds of sand and siltstone or annular mixing. 4855' Conglomeratic sand = medium gray to light olive gray overall, individual grains transparent to very light gray to olive gray, occasionally yellowish gray, reddish brown; predominantly upper fine, generally lower fine to upper medium; fair sorted; subrounded to subangular, occasionally angular to very angular; larger grains moderate sphericity, finer grains high spheroidal sphericity; coarse grains dominantly argillite/phyllite, fine grains dominantly quartz and chert; unconsolidated and probably supported in tuffaceous clay matrix; poor estimated porosity; trace mineral fluorescence; no cut. . 4940' Tuffaceous claystone = medium light gray to medium gray; very soft to soft, irregular fracture; amorphous cuttings habit; moderately cohesive and adhesive; moderately soluble; ashy to silty to gritty texture; possibly thin interbeds o/w present as matrix fill in sands and conglomerate sands. 4985' Carbonaceous shale = brownish gray to reddish gray to medium gray; moderately firm to soft; sub-brittle to soft crumbly; irregular to blocky fracture; wedgelike cuttings habit; smooth to silty texture; well defined laminations of carbonaceous material. 5030' Conglomeratic sand = medium gray to light olive gray overall, individual grains transparent to very light gray to olive gray, predominantly upper fine, ranging from lower very fine to upper medium; fair to poor sorted; finer grains subrounded, coarser grains subangular to angular; moderate to high spheroidal sphericity; unconsolidated with probable clay matrix support; predominantly siliceous metalithics; no sample fluorescence; no cut. 5100' Coal = black to brownish black, occasionally dark reddish brown; firm to moderately hard; brittle to sub-brittle; irregular to conchoidal fracture; wedgelike to tabular cuttings habit; subvitreous luster; smooth to matte texture; bituminous to subbituminous; no visible gas bleeds. . 5145' Coal = black to brownish black, occasionally dark reddish brown; firm to moderately hard; brittle to sub-brittle; irregular to conchoidal fracture; wedgelike to tabular cuttings habit; subvitreous luster; smooth to matte texture; bituminous to subbituminous; no visible gas bleeds. U EPOCH 8 · · · UNOCAL. M-14RD 5190' Ash fall tuff = white to very light to light brownish gray; soft to slightly firm and soluble to moderately soluble; slightly hydrophilic rehydrated; some slightly carbonaceous to grading carbonaceous shale with possible interbedded coal; mostly silty to gritty texture; grading tuffaceous claystone and siltstone and grading to and interbedded with silty to fine grained sandstone; noncalcareous. 5255' Sandstone = light gray to white; fine to very fine grains and slightly scattered medium; subangular to angular; moderate sphericity; slight to moderate ashy/clay and silty matrix; poorly sorted grading ash fall tuff and tuffaceous siltstone and claystone; 80% quartz, and 20% black to gray to tan to grayish green lithics including coal and carbonaceous matter, slightly calcareous tuffs, clays, and trace micas; estimate poor porosity and permeability; no oil indicators. 5325' Sand/sandstone = light gray to occasionally white; very fine to coarse lower to some slightly scattered coarse to pebble sized grains; overall mostly fine upper to medium upper grains; subangular to angular; moderate to low sphericity; estimate moderately to some poorly sorted in mostly poorly consolidated ashy clay and silt matrix to rare well consolidated with calcareous cement; 75% quartz, and 25% black to gray to white to green to brown to red mostly siliceous grains and some chert and metalithics, coals and clays, tuff and calcareous matter, and trace feldspar; estimate fair to very poor porosity and permeability; no oil indicators. 5440' Tuffaceous claystone = medium light gray to light gray some with light brown hue; very soluble and mostly dissolved in sample to some soft cuttings; amorphous to subplaty; silty to slightly silty texture; some loose grains mostly fine sand and silt probably from dissolved clays; slight very finely disseminated carbonaceous matter and fine flakes; non to slightly calcareous. 5500' Tuffaceous claystone = medium light gray to very light gray to light brownish gray; very soluble to soluble and moderately hydrophilic; silty to smooth texture; some loose grains mostly fine sand to silt probably from dissolved clays and recirculated matter; very slight carbonaceous matter in claystone; some coal cavings and recirculated coal; non to slightly calcareous. 5560' Tuffaceous claystone = medium light gray to very light gray to light brownish gray; very soluble to soluble and moderately hydrophilic; silty to smooth texture; some loose grains including angular fine sands and silts probably cavings or recirculated matter; some coal cavings and recirculated coal; non to slightly calcareous. 5615' Sand/sandstone = overall light gray to light olive gray, individual grains transparent to white translucent, occasionally greenish gray, grayish red; upper fine to lower medium ranging to lower fine and lower coarse; moderately sorted; subrounded to subangular; high to moderate spheroidal sphericity; sandstone portion finer, more angular and better sorted; packed ashy matrix, poor visible porosity sand portion unconsolidated quartz w/ minor U EPOCH 9 UNOCAL. M-14RD . chert and rare metalithics; possibly clay matrix support w/ some grain support; no sample fluorescence or cut. 5740' Sand/sandstone = overall light gray to medium light gray, individual grains transparent to white translucent, occasionally light bluish gray to greenish gray, grayish red; upper fine to lower medium; well to moderate sorting; subrounded to subangular, occasionally rounded; high to moderate spheroidal sphericity; predominantly unconsolidated with occasional ashy matrix packed cuttings, olw grain supported; good visible estimated porosity; 60% quartz, 30% chert, 10% metalithics; no sample fluorescence; no cut. 5820' Sand/sandstone/conglomeratic sand = medium light gray to light brownish gray overall, individual grains predominantly transparent to translucent white, occasionally greenish gray to light bluish gray, light red to medium red; brownish gray to olive black; upper fine to upper medium grained; occasionally lower coarse and lower fine; well to moderately sorted; predominantly rounded to subangular, occasionally angular; high to moderate spheroidal sphericity; washed sample 60 to 80% unconsolidated grains, 20 to 40% weak matrix cemented sandstone; grain support inferred for loose sand; 40 to 60% quartz, 30 to 40% undifferentiated chert, 10 to 20% metalithics; good visual estimated porosity and permeability; no sample fluorescence; no cut. . 5950' Conglomeratic sand = light gray to very light gray; medium to very coarse grains and slightly scattered to locally common pebbles; subrounded to subangular and slight angular fragments; moderate sphericity; estimate moderately well sorted; 65% quartz and 35% chert, metalithics, and siliceous lithics; probable very slight ashy clay matrix overall; occasionally frosted calcareous cement; estimate good to some fair porosity and permeability; trace dead oil stain; no other oil indicators. 6040' Ash fall tuff = white to light gray to some with light grayish brown streaks; slight to moderately soluble and slightly hydrophilic; slight silty/ fine sandy texture some grading to tuffaceous siltstone/sandstone; some calcareous and occasionally with calcareous matter; some slight organic; thinly bedded and reworked. 6090' Sand = light gray to very light gray overall; lower medium to upper fine, occasionally ranging down to upper very fine; well sorted; predominantly subrounded to rounded, locally angular to subangular; high spheroidal sphericity, moderate discoidal sphericity with some high angular grains; unconsolidated with trace of matrix cemented sandstone; 50 to 70% quartz, 30 to 40% chert, 10% siliceous metalithics; grain support inferred with possible local matrix support in ashy zones; good visual estimated porosity; no sample fluorescence; no cut. . 6170' Sand = light gray to very light gray overall, individual grains predominantly transparent to white translucent, occasionally light bluish gray, pale red, yellowish gray, dark gray to brownish gray; lower fine to lower medium overall with localized ranges down to lower very fine and up to upper medium, rare lower coarse; generally well sorted, locally moderately sorted; subrounded to subangular, occasionally angular; high to moderate spheroidal n EPOCH 10 UNOCAL. M-14RD . sphericity; predominantly unconsolidated with varying amounts (trace to 30%) ash matrix cemented sandstone, slightly to moderately calcareous; loose sand 50 to 70% quartz, 30 to 40% chert, trace to 20% siliceous meta lithic fragments; grain supported with varying amounts of ash matrix; good visual estimated porosity and permeability; trace of mineral and mud product fluorescence; no cut. 6295' Ash fall tuff = white to light gray; soft and slightly to moderately soluble; chalky with slight silty/fine sandy texture; some grading tuffaceous siltstone/sandstone; locally slightly organic with brownish streaks and disseminated carbonaceous matter; probably thinly bedded to reworked in sand matrix. 6345' Sand/sandstone= light gray to very light gray; medium to very fine and slightly scattered coarse grains; subangular to some subrounded; slight angular fragments and trace pebble; moderate to some low sphericity; estimate poorly to some moderately sorted; predominantly loose grains occasionally lightly frosted ash to occasionally poorly consolidated with ash support matrix; some thin silty/sandy ash beds; 65% quartz, and 35% gray to very dark gray to dark green to brown to white metalithics and siliceous lithies and chert; estimate fair to some good porosity and permeability; no oil indicators. . 6440' Sand/sandstone = light gray to some white; very fine to coarse and scattered very coarse and trace pebble; angular to subrounded including slight bit broken fragments; moderate to high sphericity; moderately to poorly sorted; overall slight ashy clay matrix and grain supported to locally matrix supported and grading tuffaceous sandstone and minor siltstone; 70% quartz, and 30% gray to very dark gray to dark brown to green metalithies, siliceous lithies, lithies and chert; estimate fair to some good porosity and permeability where grain supported; no oil indicators. 6530' Sand/sandstone = light gray to very light gray; very fine to coarse grains especially medium to fine; angular to subrounded; moderate to some high sphericity; estimate moderately to poorly sorted overall slight ashy clay matrix to some matrix supported grading ash fall tuff; 65% quartz, and 35% gray to black to dark green to green to brown to white metalithics and siliceous lithics and chert; estimate fair to some good porosity and permeability where grain supported; no oil indicators. 6625' Sand/sandstone = very light gray to light gray; medium to very fine and scattered coarse grains; subangular to some subrounded; moderate to some high sphericity; moderately sorted with slight overall ashy clay matrix to some poorly sorted grading matrix supported ash fall tuff; 70% quartz and 30% gray to black to brown to trace green metalithics, siliceous lithics, and chert; estimate fair to good porosity and permeability in grain supported sand; no oil indicated. TOTAL DEPTH: MD: 6690'; TVD: 4131' . [:I EPOCH 11 . . . UNOCALe M-14RD CAlLY CHRONOLOGY 08/24/2001 : 2796-2832' Epoch arrived on location 10:50 am on August 20, 2001 and commenced with rig up. Epoch commenced logging on August 24, 2001 at 10:30 am at top of window. Window milled from 2796 to 2812', increasing mud weight from 9.0 to 9.2, and milled ahead to 2832', Pumped hi vis sweep, and circulated hole clean and conducted formation integrity test, 240 psi and 10.8 EMW. Tripped out of hole with drill pipe and tripping out with BHA. 08/25/2001: 2832-3180' Finished pulling out of hole with milling assembly and picked up and ran in hole with steerable BHA (#2) with LWD, new bit #1, and side entry sub. Tripped in hole to 2717' and cut and slipped drill line. Ran in hole with gyro at 2777', and tripped to bottom and circulated, 5 units of trip gas. Drilled ahead, sliding, from 2832' to 2913' utilizing gyro steering tool for direction. Pulled out of hole above window to 2775' and laid down side entry sub. Ran to bottom and drilled ahead, rotating and sliding, from 2832 to 3180'. 08/26/2001: 3180-4361' Drilled ahead, rotating and sliding, from 3180' to 3555'. Circulated out and pulled out of hole above window at 2717'. Worked on top drive and draw works. Tripped in and washed 90 feet to bottom. Drilled ahead, rotating and sliding, from 3555' to 4361'. 08/27/2001: 4361-4843' Drilled ahead, rotating from 4361' to 4836', and slide from 4836' to 4843'. Difficulty sliding, and circulated bottoms up. Pulled out of hole and changed bit (#2) and BHA (#3), including motor and MWD source, pumping out 4283' to 4210' and last four stands below window due tight spots. Preparing to run in with drill pipe. 08/28/2001: 4843-5456' Ran to bottom with drill pipe, reaming and working pipe last two stands in, 827 units of trip gas. Drilled ahead, rotating and sliding, from 4843' to 5456'. 08/29/2001: 5456-5690' Drilled ahead, rotating and sliding, from 5456'to 5690'. Circulate sweep and clean hole. Pump out of hole to 2820', tight from 4940' to 4824', and circulate and clean window and casing. Run in hole to bottom, and circulate and condition raising mud weight to 9.6, 958 units of trip gas. Pull out of hole with drill pipe, and begin laying down BHA. 08/30/2001 : 5690' Laid down BHA #3, including Anadril. Changed rams to 7" and rigged up and tested door seals. Stood back 6 joints of HWDP and rigged up and stood back cement head. Rigged up and ran in hole with 7" liner and packer, and circulated 15 minutes. Ran liner and packer fI EPOCH 12 . . . UNOCALe M-14RD to bottom with drill string, circulated and cleaned hole, 285 units of trip gas, and dropped ball. 08/31/2001: 5690' Dropped a second ball and cemented liner. Set and tested packer at top of liner. Circulated 2000 strokes, maximum 270 units of gas, and finished circulating at 10 units of gas. Rigged down cement tools, pulled wear ring, ran in with test plug, and changed bottom rams to 3 Y:æ". Tested choke manifold and BOPE. Pulled test plug and installed wear ring. Picked up BHA #4 with new bit #3 for drilling cement, and began to pick up and run in with 3 Y:æ" drill pipe. 09/01/2001: 5690' Finished picking up and running in with 3 Y:æ" drill pipe, total 4814'. Ran in hole with 5" and drilled out float collar. Circulated, pumped dry job, and pulled out of hole. Laid down BHA #4 and picked up steerable BHA #5 with new bit #4, mud motor, and MWD. Ran in hole with 3 Y:æ" drill pipe. 09/0212001: 5690-5996' Finished running in hole with 3 Y:æ" drill pipe, and ran to bottom with 5" drill pipe, washing down last stand. Drilled ahead, rotating and sliding, from 5690' to 5996'. 09/03/2001: 5996-6575' Drilled ahead, rotating and sliding, from 5996' to 6310'. Drilled ahead, rotating, from 6310' to 6575'. 09/04/2001: 6575-6690' (TOTAL DEPTH) Drilled ahead, rotating, from 6575' to 6690'. Well TD at 6690' MD, 4131' TVD. fI EPOCH 13 UNOCALe M14 RD MUD RECORD Date Depth TVD MW VIS PV YP Gel FL HTHP Cake Sol OIW Sand MBT pH Pom CI- Ca+ 8/24/01 2826 2826 9.2 45 6 29 13/18/19 8.0 1/ 4 0/96 0 0 8.5 0.5 14500 1600 8/25/01 3179 3165 9.3 41 6 20 9/10/12' 8.6 1/ 5 0/95 0.5 8.5 0.15 14500 1600 8/26/01 4360 3778 9.3 40 6 25 11/12/14 8.2 1/ 6 0/94 0.5 3.75 8.7 0.15 12500 840 8/27/01 4842 3924 9.3 41 8 23 10/12/13 10.0 1/ 5 1/94 0.5 4 8.7 0.15 12500 600 8/28/01 5450 4089 9.3 44 9 22 9/11/13 8.6 1/ 5 0'95 Tr 4 9.0 0.3 14500 600 8/29/01 5690 4122 9.4 42 8 25 10/12/14 9.4 1/ 6 0/94 Tr 5 8.9 0.1 12000 600 8/30/01 5690 4122 9.6 44 8 26 11/13/15 9.6 1/ 7 0/93 Tr 5 8.7 0.1 12000 600 8/31/01 5887 4127 9.7 34 12 10 7/9/11 9.8 1/ 5 0/95 Tr 5 8.8 0.1 12000 700 9/01/01 5690 4130 9.6 40 10 21 7/9/11 9.0 1/ 7 0/93 Tr 5 8.6 0.1 12000 750 9/02/01 6018 4131 9.3 44 12 21 7/9/11 2.4 1/ 4 0/96 Tr 3 9.1 0.2 12000 700 9/03/01 6574 4131 9.3 44 8 27 7/9/11 3.0 1/ 5 0/95 Tr 4 8.7 0.1 12000 700 9/04/01 6690 4131 9.3 44 9 22 7/9/11 4.2 1/ 5 0/95 Tr 4 8.8 .1 12000 750 . UEP~ . 14 UNOCALe M14 RD . SURVEY RECORD MD Incl Azim TVD VSec +N/S· +EIW· Total Displ Course DLS (ft) (0) (0) (ft) ~ft) (ft) (ft) (ft) (ft) (0/100ft 2700.00 0.03 286.13 2699.92 13.93 -13.73 -2.42 13.94 0.00 0.00 2796.00 0.07 349.87 2795.92 13.88 -13.67 -2.45 13.88 96.00 0.07 2812.00 1.85 156.00 2811.92 14.07 -13.89 -2.35 14.09 16.00 11.99 2837.04 3.61 156.00 2836.93 15.04 -14.98 -1.87 15.10 25.04 7.03 2926.63 9.79 156.00 2925.86 23.47 -24.53 2.38 24.64 89.59 6.90 3019.57 16.28 159.50 3016.36 40.82 -43.97 10.17 45.13 92.94 7.03 3112.49 23.01 160.55 3103.82 67.27 -73.32 20.79 76.21 92.92 7.25 3207.72 29.96 160.63 3189.01 103.41 -113.36 34.89 118.60 95.23 7.30 3301.65 36.64 161.67 3267.47 147.58 -162.14 51.50 170.13 93.93 7.14 3395.34 43.15 162.79 3339.31 199.63 -219.35 69.79 230.18 93.69 6.99 3488.88 50.22 162.27 3403.44 258.71 -284.22 90.23 298.20 93.54 7.57 3583.83 56.49 160.65 3460.09 324.12 -356.40 114.48 374.33 94.95 6.74 3675.56 57.11 160.47 3510.31 389.46 -428.78 140.03 451.06 91.73 0.70 3766.52 62.74 159.62 3555.88 456.06 -502.73 166.90 529.71 90.96 6.24 3861.43 66.64 159.91 3596.45 528.45 -583.22 196.56 615.45 94.91 4.12 3952.71 67.21 159.49 3632.22 599.27 -661.98 225.70 699.40 91.28 0.75 4046.39 67.10 158.50 3668.59 671.50 -742.57 256.64 785.67 93.68 0.98 . 4138.65 69.22 160.32 3702.92 743.48 -822.73 286.75 871.27 92.26 2.94 4233.30 69.78 160.19 3736.06 818.70 -906.18 316.70 959.92 94.65 0.61 4327.01 70.18 159.39 3768.15 893.02 -988.80 347.11 1047.96 93.71 0.91 4420.85 70.65 159.26 3799.60 967.27 -1071.52 378.33 1136.35 93.84 0.52 4514.61 72.44 159.34 3829.28 1041.93 -1154.71 409.77 1225.26 93.76 1.91 4608.12 72.75 159.21 3857.25 1116.82 -1238.17 441.34 1314.47 93.51 0.36 4700.77 73.16 158.46 3884.41 1190.79 -1320.77 473.32 1403.02 92.65 0.89 4764.89 73.52 158.60 3902.79 1241.91 -1377.94 495.81 1464.42 64.12 0.60 4855.75 73.49 161.55 3928.60 1315.67 -1459.83 525.49 1551.53 90.86 3.11 4948.66 72.84 167.40 3955.53 1394.34 -1545.47 549.29 1640.18 92.91 6.07 5042.16 73.49 172.36 3982.62 1477.09 -1633.54 565.00 1728.49 93.50 5.12 5137.22 74.10 174.25 4009.15 1563.45 -1724.19 575.64 1817.75 95.06 2.01 5232.09 72.93 180.27 4036.09 1651.28 -1815.01 580.00 1905.43 94.87 6.21 5327.17 75.17 186.49 4062.24 1741.57 -1906.21 574.59 1990.93 95.08 6.72 5421.62 78.78 192.78 4083.55 1833.43 -1996.86 559.16 2073.67 94.46 7.53 5516.77 80.50 197.96 4100.67 1926.85 -2087.07 534.35 2154.39 95.15 5.65 5609.26 83.55 203.21 4113.51 2017.42 -2172.77 502.15 2230.04 92.49 6.52 5754.86 87.42 212.31 4124.99 2157.07 -2301.04 434.60 2341.72 145.60 6.77 5849.26 88.59 220.07 4128.28 2243.20 -2377.12 378.93 2407.13 94.40 8.31 5943.45 89.93 227.33 4129.50 2323.46 -2445.16 313.91 2465.23 94.19 7.84 6039.75 90.31 234.05 4129.30 2398.80 -2506.13 239.44 2517.54 96.30 6.99 6132.77 89.42 241.31 4129.52 2463.99 -2555.83 160.89 2560.89 93.02 7.86 6223.85 88.28 246.78 4131.35 2520.24 -2595.67 79.04 2596.87 91.08 6.13 . U EPOCH 15 UNOCAL. M14RD · MD Incl Azim TVD VSec +N/S· +EIW· Total Displ Course DLS (ft) (0) n (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft 6316.81 90.48 248.18 4132.35 2573.19 -2631.27 -6.82 2631.28 92.96 2.81 6408.09 90.65 248.79 4131.45 2623.87 -2664.74 -91.73 2666.32 91.28 0.69 6499.26 90.34 248.75 4130.66 2674.10 -2697.76 -176.71 2703.54 91.17 0.34 6595.57 89.62 249.01 4130.70 2727.02 -2732.46 -266.55 2745.43 96.31 0.79 6636.22 89.66 249.10 4130.95 2749.25 -2746.99 -304.51 2763.82 40.65 0.24 Projection toTO 6690.00 89.71 249.22 4131.25 2778.58 -2766.12 -354.77 2788.78 53.78 0.24 · · (J EPOCH 16 UNOCAL. M14 RD BIT RECORD Bit # Size Vendor Type Serial # Jets In Out Feet Hrs-On Hrs-Off ROP WOB 1 8.5 SECURITY FM2665 5010898 6X11 2832 4842 2010 18.3 18.9 109.8 2-20 2 8.5 SMITH MF10TODGPS LW7603 3X15 4842 5690 848 22.0 11.3 42.4 10-20 3 6 HUGHES AT J-4 A21JM 3X12 5690 5690 CLEAN OUT CASING 4 6 SMITH XR20HTDGPS MH0864 3X12 5690 6690 1000 38.8 20.1 34.3 10-23 . U EPijH . . . . UNOCALe M14RD CAlLY REPORTS EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M-14 RD, STEELHEAD PLATFORM DATE: August 25.2001 DAILY COST: $1710 CUM COST: $10225 12:01 AM DEPTH: 2832' ROP (FT/HR): YESTERDAY: ~ PRESENT: 5.1 24 HR FTG: 36' 24 HR AVE: 4.9 CURRENT BIT INFORMATION: NO.: : MAKE: MILL ASSEMBLY TYPE: NA DEPTH IN: 2796' Footage Hours On Bottom 36 9.5 7.4 o 0 0 36 9.5 7.4 DEPTH OUT: .2832' Off Bottom Connection 2.1 0 o 0 2.1 0 TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: CONNECTION GAS: TRIP GAS: Average: I 6u Average: NA WIPER TRIP GAS: Current: I Current: I 3u NA NA Max: Max: 18@2809' NA NA GROSS LITHOLOGY: Trace of cement contamination 2796' to 2809'. Started seeing formation, mostly claystone, at 2809'. COAL: SANDSTONE: CONGLOMERATE: SilTSTONE: CLAYSTONE: o % 15 % o % 15 % 70 % COAL INTERVALS: NONE COAL ANTICIPATED: Correlating approximately (insufficient data)' high to type log. SHOW SUMMARY: NONE REMARKS: Epoch arrived on location 10:50 am on August 20,2001 and commenced with rig up. Epoch commenced logging on August 24,2001 at 10:30 am at top of window. Window milled from 2796 to 2812', increasing mud weight from 9.0 to 9.2, and milled ahead to 2832'. Pumped hi vis sweep, and circulated hole clean and conducted formation integrity test, 240 psi and 10.8 EMW. Tripped out of hole with drill pipe and tripping out with BHA. n EPOCH 18 . . . UNOCALe M14 RD EPOCH MORNING REPORT UNOCAl ALASKA RESOURCES, INC. M-14 RD, STEElHEAD PLATFORM DATE: August 26,2001 DAILY COST: $1710 CUM COST: $11935 12:01 AM DEPTH: 3180' ROP (FT/HR): 24 HR FTG: 348' 24 HR AVE: 80.9 YESTERDAY: 2832' PRESENT: 160 CURRENT BIT INFORMATION: NO.: 1 MAKE: SECURITY TYPE: FM2665 Footage 348 o 348 DEPTH IN: 2832' Hours On Bottom 10.9 4.3 o 0 10.9 4.3 DEPTH OUT: : Off Bottom Connection 6.6 1.1 o 0 6.6 1.1 TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: CONNECTION GAS: TRIP GAS: Max: I 480u@2966'. Max: Ou 5u@2832' Average: I 67u Average: Ou WIPER TRIP GAS: Current: I Current: I 14u Ou~3180' GROSS LITHOLOGY: COAL: SANDSTONE: CONGLOMERATE: 20 % 30 % 5 % 10 % 30 % 5 % SILTSTONE: CLAYSTONE: TUFF: COAL INTERVALS: 3008-18',3150-82' COAL ANTICIPATED: Correlating approximately 6' high to type log. SHOW SUMMARY: NONE REMARKS: Finished pulling out of hole with milling assembly and picked up and ran in hole with steerable BHA with LWD and side entry sub. Tripped in hole to 2717' and cut and slipped drill line. Ran in hole with gyro at 2777', and tripped to bottom and circulated, 5 units of trip gas. Drilled ahead, sliding, from 2832' to 2913' utilizing gyro steering tool for direction. Pulled out of hole above window to 2775' and laid down side entry sub. Ran to bottom and drilled ahead, rotating and sliding, from 2832 to 3180'. [:I EPOCH 19 . . . UNOCALe M14 RD EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M-14 RD, STEELHEAD PLATFORM DATE: August 27. 2001 DAILY COST: $1710 CUM COST: $13645 12:01 AM DEPTH: 4361' ROP (FT/HR): 24 HR FTG: 1181' 24 HR AVE: 128.4 YESTERDAY: 3180' PRESENT: 91 CURRENT BIT INFORMATION: NO.: 1 MAKE: SECURITY TYPE: FM2665 Footage 1529 348 1181 DEPTH IN: 2832' Hours On Bottom 34.9 13.5 10.9 4.3 24 9.2 DEPTH OUT: : Off Bottom Connection 21.4 2.7 6.6 1.1 14.8 1.6 TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: CONNECTION GAS: TRIP GAS: Max: I . 617u@3684' Max: Ou NA Average: I 124u Average: Ou WIPER TRIP GAS: Current: I 34u Current: Ou~4298' I 80u@3555' GROSS LITHOLOGY: COAL: SANDSTONE: CONGLOMERATE: SILTSTONE: CLAYSTONE: TUFF: 10 % 25 % 5 % 10 % 40 % 10 % COAL INTERVALS: 3625-80',3885-3900',4125-50',4360-80' COAL ANTICIPATED: Correlating approximately 30' high to type log. SHOW SUMMARY: NONE REMARKS: Drilled ahead, rotating and sliding, from 3180' to 3555'. Circulated out and pulled out of hole above window at 2717'. Worked on top drive and draw works. Tripped in and washed 90 feet to bottom. Drilled ahead, rotating and sliding, from 3555' to 4361'. fI EPOCH 20 . DATE: August 28. 2001 12:01 AM DEPTH: 4843' ROP (FT/HR): UNOCALe M14 RD EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M-14 RD, STEELHEAD PLATFORM DAILY COST: $1710 CUM COST: $15355 YESTERDAY: 4361' PRESENT: 12 24 HR FTG: 482' 24 HR AVE: 100.4 CURRENT BIT INFORMATION: NO.: 2 MAKE: SMITH TOTAL: YESTERDAY'S TC>TAL: PAST 24 HOURS: NO.: 1 MAKE: SECURITY TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: . GAS SUMMARY BACKGROUND GAS: CONNECTION GAS: TRIP GAS: GROSS LITHOLOGY: COAL: SANDSTONE: CONGLOMERATE: TYPE: MF10TODGPS DEPTH IN: 4843' Footage Hours On Bottom o 0 0 o 0 0 o 0 0 TYPE: FM2665 Footage 2011 1529 482 DEPTH IN: 2832' Hours On Bottom 46.2 18.3 34.9 13.5 11.3 4.8 Max: I 769u@4487' Max: Ou NA Average: I 149u Average: Ou WIPER TRIP GAS: 15 % . 15 % o % SILTSTONE: CLAYSTONE: TUFF: 10 % 60 % o % COAL INTERVALS: 4595-4645'. COAL ANTICIPATED: Correlating approximately 35' high to type log. SHOW SUMMARY: NONE DEPTH OUT: ~ Off Bottom Connection o 0 o 0 o 0 DEPTH OUT: 4843' Off Bottom Connection 27.9 3.1 21.4 2.7 6.5 0.4 Current: I Current: I 12u Ou~4 767' NA REMARKS: Drilled ahead, rotating from 4361' to 4836', and slide from 4836' to 4843', Difficulty sliding, and circulated bottoms up. Pulled out of hole and changed bít and BHA, including motor and MWD source, pumping out 4283' to 4210' and last four stands below window due tight spots. Preparing to run in with drill pipe. . U EPOCH 21 · · · UNOCALe M14 RD EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M-14 RD, STEELHEAD PLATFORM DATE: August 29. 2001 DAILY COST: $1710 CUM COST: 12:01 AM DEPTH: ~ ROP (FT/HR): YESTERDAY: 4843' PRESENT: 40.1 24 HR FTG: 24HRAVE: CURRENT BIT INFORMATION: NO.: 2 MAKE: SMITH TYPE: MF10TODGPS DEPTH IN: 4843' Footage Hours On Bottom 613 21.6 15.8 o 0 0 613 21.6 15.8 TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: $17065 613' 38.8 DEPTH OUT: ~ Off Bottom Connection 5.8 0.8 o 0 5.8 0.8 GAS SUMMARY Note: Connection gases lag to backreaming before connection. BACKGROUND GAS: Max: I 337u@5117' Average: I 57u Current: I CONNECTION GAS: Max: 140u@5009' Average: 95u Current: TRIP GAS: 827u@4843' WIPER TRIP GAS: I GROSS LITHOLOGY: COAL: SANDSTONE: CONGLOMERATE: SILTSTONE: CLAYSTONE: TUFF: 10 % 25 % 10 % 10 % 40 % 5 % 48u 120u@5385' NA COAL INTERVALS: 5095-5135',5160-90'. COAL ANTICIPATED: Correlating approximately 50' low to type log (no more coal on type log) SHOW SUMMARY: NONE REMARKS: Ran to bottom with drill pipe, reaming and working pipe last two stands in, 827 units of trip gas. Drilled ahead, rotating and sliding, from 4843' to 5456'. [:I EPOCH 22 · · · UNOCALe M14 RD EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M-14 RD, STEELHEAD PLATFORM DATE: August 30. 2001 DAILY COST: $1710 CUM COST: $18775 12:01 AM DEPTH: 5690' ROP (FT/HR): - YESTERDAY: 5456' PRESENT: 75 24 HR FTG: 234' 24 HRAVE: 37.7 CURRENT BIT INFORMATION: NO.: 2 MAKE: SMITH TYPE: MF10TODGPS DEPTH IN: 4843' Footage Hours On Bottom 847 33.3 . 22.0 613 21.6 15.8 234 11.7 6.2 TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: DEPTH OUT: 5690' Off Bottom Connection 11.3 1.0 5.8 0.8 5.5 0.2 GAS SUMMARY Note: Connection gases lag to backreaming before connection. BACKGROUND GAS: Max: I 117u@5512' Average: I 51 u Current: I 32u CONNECTION GAS: Max: 110u@5481' Average: 73u Current: 20u@5669' TRIP GAS: NA WIPER TRIP GAS: I 958u@5690' GROSS LITHOLOGY: COAL: SANDSTONE: CONGLOMERATE: SILTSTONE: CLAYSTONE: TUFF: o % 40 % o % 15 % 40 % 5 % COAL INTERVALS: NONE. COAL ANTICIPATED: Correlating approximately 90' low to type log. SHOW SUMMARY: NONE REMARKS: Drilled ahead, rotating and sliding, from 5456'to 5690', Circulate sweep and clean hole. Pump out of hole to 2820', tight from 4940' to 4824', and circulate and clean window and casing. Run in hole to bottom, and circulate and condition raising mud weight to 9.6, 958 units of trip gas. Pull out of hole with drill pipe, and begin laying down BHA. fI EPOCH 23 · · · UNOCALe M14 RD EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M-14 RD, STEELHEAD PLATFORM DATE: August 31. 2001 DAILY COST: $1710 CUM COST: $20485 12:01 AM DEPTH: 5690' ROP (FT/HR): - 24 HR FTG: 0' 24 HR AVE: NA YESTERDAY: 5690' PRESENT: NA CURRENT BIT INFORMATION: NO.: 2 MAKE: SMITH TYPE: MF10TODGPS DEPTH IN: 4843' Footage Hours On Bottom 847 33.3 22.0 847 33.3 22.0 o 0 0 DEPTH OUT: 5690' Off Bottom Connection 11.3 1.0 11.3 1.0 o 0 TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: CONNECTION GAS: TRIP GAS: Max: I 285u Max: NA 285u@5690' Average: I 125u Average: NA WIPER TRIP GAS: Current: I Current: I 16u NA NA GROSS LITHOLOGY: COAL: SANDSTONE: CONGLOMERATE: SILTSTONE: CLAYSTONE: TUFF: o % o % o % o % o % o % COAL INTERVALS: NONE. COAL ANTICIPATED: Correlating approximately 90' low to type log. SHOW SUMMARY: NONE REMARKS: Laid down BHA, including Anadril. Changed rams to 7" and rigged up and tested door seals. Stood back 6 joints of HWDP and rigged up and stood back cement head. Rigged up and ran in hole with 7" liner and packer, and circulated 15 minutes. Ran liner and packer to bottom with drill string, circulated and cleaned hole, 285 units of trip gas, and dropped ball. [:I EPOCH 24 · · · UNOCALe M14RD EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M-14 RD, STEELHEAD PLATFORM DATE: September 1. 2001 DAILY COST: $1710 CUM COST: $22195 12:01 AM DEPTH: 5690' ROP (FT/HR): YESTERDAY: 5690' PRESENT: NA 24 HR FTG: 0' 24 HR AVE: NA CURRENT BIT INFORMATION: NO.: 3 MAKE: HUGHES TYPE:ATJ-4 Footage o o o DEPTHIN:~ Hours On Bottom o 0 o 0 o 0 DEPTH OUT: : Off Bottom Connection o 0 o 0 o 0 TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: CONNECTION GAS: TRIP GAS: Average: I 85u Average: NA WIPER TRIP GAS: Current: I Current: I 10u NA NA Max: Max: 270u NA NA GROSS LITHOLOGY: COAL: SANDSTONE: CONGLOMERATE: o % o % o % SILTSTONE: CLAYSTONE: TUFF: o % o % o % COAL INTERVALS: NONE. COAL ANTICIPATED: Correlating approximately 90' low to type log. SHOW SUMMARY: NONE REMARKS: Dropped a second. ball and cemented liner. Set and tested packer at top of liner. Circulated 2000 strokes, maximum 270 units of gas, and finished circulating at 10 units of gas. Rigged down cement tools, pulled wear ring, ran in with test plug, and changed bottom rams to 3 %". Tested choke manifold and BOPE. Pulled test plug and installed wear ring. Picked up BHA with new bit for drilling cement, and began to pick up and run in with 3 %" drill pipe. U EPOCH 25 · · · UNOCALe M14 RD EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M-14 RD, STEELHEAD PLATFORM DATE: September 2. 2001 DAILY COST: $1710 CUM COST: $23905 12:01 AM DEPTH: 5690' ROP (FT/HR): YESTERDAY: 5690' PRESENT: NA 24 HR FTG: 0' 24HRAVE: NA CURRENT BIT INFORMATION: NO.: 4 MAKE: SMITH TYPE: XR20HTDGPS DEPTH IN: 5690' Footage Hours On Bottom o 0 0 o 0 0 o 0 0 DEPTH OUT: ~ Off Bottom Connection o 0 o 0 o 0 TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: CONNECTION GAS: TRIP GAS: Average: I 5u Average: NA WIPER TRIP GAS: Current: I Current: I 2u NA NA Max: Max: 7u NA NA GROSS LITHOLOGY: COAL: SANDSTONE: CONGLOMERATE: o % o % o % SILTSTONE: CLAYSTONE: TUFF: o % o % o % COAL INTERVALS: NONE. COAL ANTICIPATED: Correlating approximately 90' low to type log. SHOW SUMMARY: NONE REMARKS: Finished picking up and running in with 3 %" drill pipe, total 4814'. Ran in hole with 5" and drilled out float collar. Circulated, pumped dry job, and pulled out of hole. Laid down BHA #4 and picked up steerable BHA #5 with new bit, mud motor, and MWD. Ran in hole with 3 %" drill pipe. (:I EPOCH 26 · · · DATE: September 3. 2001 12:01 AM DEPTH: 5996' ROP (FT/HR): UNOCALe M14RD EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M-14 RD, STEELHEAD PLATFORM DAILY COST: $1710 CUM COST: $25615 YESTERDAY: 5690' PRESENT: 17.0 24 HR FTG: 306' 24 HR AVE: 20.3 CURRENT BIT INFORMATION: NO.: 4 MAKE: SMITH TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: CONNECTION GAS: TRIP GAS: GROSS LITHOLOGY: COAL: SANDSTONE: CONGLOMERATE: COAL INTERVALS: NONE. COAL ANTICIPATED: NONE. SHOW SUMMARY: NONE TYPE:XR20HTDGPS DEPTH IN: 5690' Footage Hours On Bottom 306 22.8 15.1 o 0 0 306 22.8 15.1 Max: I 27u@5918' Max: Ou 5u@5690' Average: I 8u Average: Ou WIPER TRIP GAS: DEPTH OUT: ~ Off Bottom Connection 7.7 0.7 o 0 1.2 0.7 Current: I Current: I 6u Ou@5996' NA o % 80 % 10 % SILTSTONE: CLAYSTONE: TUFF: o % o % 10 % REMARKS: Finished running in hole with 3 %" drill pipe, and ran to bottom with 5" drill pipe, washing down last stand. Drilled ahead, rotating and sliding, from 5690' to 5996'. ~ EPOCH 27 · · · DATE: September 4. 2001 12:01 AM DEPTH: 6575' ROP (FT/HR): UNOCALe M14 RD EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M-14 RD, STEELHEAD PLATFORM DAILY COST: $1710 CUM COST: $27325 YESTERDAY: 5996' PRESENT: 47.6 24 HR FTG: 579' 24 HR AVE: 27.7 CURRENT BIT INFORMATION: NO.: 4 MAKE: SMITH TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: CONNECTION GAS: TRIP GAS: GROSS LITHOLOGY: COAL: SANDSTONE: CONGLOMERATE: COAL INTERVALS: NONE. COAL ANTICIPATED: NONE. SHOW SUMMARY: NONE TYPE:XR20HTDGPS DEPTH IN: 5690' Footage 885 306 579 On Bottom 36.0 15.1 20.9 Off Bottom 10.8 7.7 3.1 DEPTH OUT: Connection 1.6 0.7 0.9 16u Ou@6556' NA REMARKS: Drilled ahead, rotating and sliding, from 5996' to 6310'. Drilled ahead, rotating, from 6310' to 6575'. Hours 46.8 22.8 24 Max: Max: Average: I 15u Average: Ou WIPER TRIP GAS: Current: I Current: I 25u@6203' Ou NA o % 70 % 5 % SILTSTONE: CLAYSTONE: TUFF: 5 % o % 20 % ~ EPOCH 28 . . . UNOCALe M14 RD EPOCH MORNING REPORT UNOCAL ALASKA RESOURCES, INC. M-14 RD, STEELHEAD PLATFORM DATE: September 5. 2001 DAILY COST: $1710 CUM COST: $29035 12:01 AM DEPTH: 6690' ROP (FT/HR): YESTERDAY: 6575' PRESENT: 38.8 24 HR FTG: 115' 24 HR AVE: 41.1 CURRENT BIT INFORMATION: NO.: 4 MAKE: SMITH TYPE: XR20HTDGPS DEPTH IN: 5690' Footage Hours On Bottom 1000 52.2 38.8 885 46.8 36.0 115 5.4 2.8 DEPTH OUT: 6690' Off Bottom Connection 13.4 1.7 10.8 1.6 2.6 0.1 TOTAL: YESTERDAY'S TOTAL: PAST 24 HOURS: GAS SUMMARY BACKGROUND GAS: CONNECTION GAS: TRIP GAS: Max: .1 Max: Average: I 14u Average: Ou WIPER TRIP GAS: Current: I Current: I 2u Ou@6647' NA 21 u@6595' Ou NA GROSS LITHOLOGY: COAL: SANDSTONE: CONGLOMERATE: o % 80 % o % SILTSTONE: CLAYSTONE: TUFF: o % o % 20 % COAL INTERVALS: NONE. COAL ANTICIPATED: NONE. SHOW SUMMARY: NONE REMARKS: Drilled ahead, rotating, from 6575' to 6690', total depth. Pulled off bottom, shut off pumps for 5 minutes, and pumped sweep while working and rotating pipe, maximum 3 units of gas at bottoms up. Pump pill and pulled out of hole wet to 7" casing shoe. Pumped slug and pulled out of hole, laying down BHA. Picked up and ran in hole with 25 joints 4 }'2" pipe and liner packer with setting tool. Ran in hole with 3 }'2" drill pipe. ~ EPOCH 29