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Home My WebLink About209-0931. 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 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 10,500 feet See schematic feet true vertical 6,346 feet N/A feet Effective Depth measured 6,715 feet See schematic feet true vertical 3,596 feet See schematic feet Perforation depth Measured depth 5,175 - 6,312 feet True Vertical depth 2,692 - 3,359 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 6,809 (MD) 3,651 (TVD) Packers 428 (MD) Packers and SSSV (type, measured and true vertical depth) See schematic TE-5 SSSV 428 (TVD) 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: 4,760psi 5,020psi 6,870psi 1,425 1,350 Burst Collapse 2,260psi Production Liner 8,223 2,476 Casing Structural 4,498 7" 8,223 10,498 6,328 1,425 Conductor Surface Intermediate 28" 7,420psi 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 209-093 50-733-20587-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018730 / ADL0017594 / ADL0018729 McArthur River / Middle Kenai Gas Trading Bay Unit M-20 Plugs Junk measured Length measured TVD 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 490 N/A 301 Size 490 0100 0 1450 13-3/8" Other: Patch / FCO w/N2 12 323-671 Sr Pet Eng: 5,410psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 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 490 measured 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 3:42 pm, Mar 07, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.03.07 10:37:40 - 09'00' Dan Marlowe (1267) RBDMS JSB 031324 Steelhead Platform Well M-20 Completed 11-30-2009 Revised By: JLL 02/09/24 SCHEMATIC MAX HOLE ANGLE = 78.2 Deg @ 2,301’ Casing Detail SIZE WT GRADE CONN ID in TOP(MD) BTM(MD) 28” Structural 27 Surface 490’ 13-3/8” 68 L-80 BTC 12.415 Surface 1,425’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 8,223’ 7” 26 L-80 DWCSR 6.276 8,022’ 10,498’ Tubing Detail 3-1/2” 9.3 L-80 H-503 2.992 Surface 6,809’ RKB to TBG Head = 78’.75 9 5/8” Casing in 12 ¼” Hole 13 3/8” in 17 ½” Hole 7” Liner in 8 1/2” Hole D-4 ECP Stage Collar 450-460 28” Conductor @ 480 9 5/8 Hydraulic Stage Collar @ 6,050’ B-6 C-3 & C-5 D-6 D-16A D-16C D-3A D-2 A-3 B-1 TOC 5,000’ MD CBL 11/11/21 TOC in Tbg 6,715’ CTMD 1 2 3 4 5 6 7 Tubing Patch 5,736 - 5,764 ELMD SZ-23 Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Notes SZ-23 5,175' 5,192' 2,692' 2,702' 17 6 1/25/24 Open A-3 5,746’ 5,766’ 3,027’ 3,038’ 20’ 5 1/18/22 Isolated 5,746-5,764 w/patch 1/20/24 A-3 5,764' 5,766' 3,037' 3,038' 2' 5 1/18/22 Open B-1 6,271' 6,292' 3,335' 3,347' 21' 6 1/24/24 Open B-1 6,272’ 6,312’ 3,336’ 3,359’ 40’ 5 11/15/21 & 1/17/22 Open B-6 6,916' 6,966' 3,713' 3,742' 50' 14 11/09/21 Isolated C-3 7,646' 7,660' 4,136' 4,144' 14' 14 11/09/21 Isolated 7,667' 7,678' 4,148' 4,155' 11' 11/09/21 Isolated C-5 7,812' 7,840' 4,235' 4,257' 28' 14 11/09/21 Isolated D-2 8,493' 8,509' 4,685' 4,697' 16' 0 11/09/21 Isolated D-3A 8,626' 8,630' 4,790' 4,793' 4' 4 11/09/21 Isolated D-3A 8,648' 8,659' 4,808' 4,817' 11' 4 11/09/21 Isolated D-4 8,816' 8,821' 4,950' 4,954' 5' 4 11/09/21 Isolated D-6 9,000' 9,054' 5,104' 5,148' 54' 12 Abandoned D-16A 10,214' 10,226' 6,095' 6,105' 12' 12 Abandoned D-16C 10,268' 10,300' 6,139' 6,165' 32' 12 Abandoned Jewelry Detail No Depth MD Depth TVD OD ID Item 1 428' 428’ 5.125 2.813 TE-5 SSSV 5,736' 3,021' Tubing Patch 5,736 - 5,764' ELMD 2 6,725’ 3,602’ Cement retainer w/10’ cement - TOC 6,715’ 3 6,775’ 3,631’ CIBP 4 6,809' 3,650’ 8.46 4.75 Upper SC-1 GP Packer 5 6,981' 3,751’ 8.46 4.75 Lower SC-1 GP Packer 6 7,854' 4,262’ 8.125 4.75 Model D Sump Packer 7 8,900' 5,020’ N/A N/A Model K-1 Cement Retainer Cement Retainer @ 8,900’ Fish/Other Detail Date Depth MD Description 1/22/22 2,222’ SLM Tagged fill (Sand) GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,638’ 1,499’ 2.992 SFO-1 GLM 12 Dome 905 2 3,103’ 1,946’ 2.992 SFO-1 GLM 12 Dome 895 3 4,662’ 2,397’ 2.992 SFO-1 GLM 12 Dome 885 4 5,690’ 2,994’ 2.992 SFO-1 GLM 12 Dummy 9/17/2021 6 6,749’ 3,615’ 2.992 SFO-1 GLM 20 Orifice Isolated Cement Details 13-3/8" 17-1/2” Hole: Pumped 164bbls of 13.0ppg lead Class G cement followed by 112bbls of 13.7ppg Class G tail cement. Pumped 2nd stage through DV collar at 450’. Pumped 255bbls 13.0ppg Class G with full returns ToC assumed at surface 9-5/8" 12-1/4” hole: Pumped 139bbls 13.2ppg class G lead cement followed by 47bbl 14.0ppg Class G tail cement. Pumped 2nd stage through DV collar at 6050’. Pumped 382bbls 13.2ppg Class G. Lost 72bbls during job. Saw cement back to surface ToC at surface 3-1/2”3-1/2” tubing cemented in place 11/10/21 with 111bbls 15.3ppg cement.CBL shows ToC at 5000’ MD Well Name:MRF M-20 API #:50733205870000 Field:McArthur River Field Start Date:1/17/2024 Permit #:209093 Sundry #:323-671 End Date:3/4/2024 1/17/2024 1/18/2024 1/19/2024 1/20/2024 1/21/2024 1/22/2024 Well Operations Summary Memory CCL/GAMMA for upcoming patch set Set straddle patch accross A-3 sands. Elements from 5742,-5769' (27') covering A-3 sand perfs 5746-5766' (20'). depths were CTMD corrected for RKB. See 1/24/24 for log results of ELMD placment. MIRU. BOP test from prior (M-16) well still valid. 2.80" Motor/Mill FCO with 6% KCL. Tag at 4278'. Wash tubing with mill from 4280'- 6100' encountering several small bridges. NPT: N2 pump & reel brake issues Daily Operations: FCO with 6%KCL and N2. 1.75" DJN. tag at 6013' MD and wash from 6013 - 6717' MD (PBTD). Switch to N2 only and blow well dry. All pumped fluid recovered. No gas production. Page 1 of 2 Well Name:MRF M-20 API #:50733205870000 Field:McArthur River Field Start Date:1/17/2024 Permit #:209093 Sundry #:323-671 End Date:3/4/2024 1/23/2024 1/24/2024 1/25/2024 2/20/2024 2/21/2024 3/4/2024 Well Operations Summary Daily Operations: AOGCC approves IA cement isolation still competent given no inflow, and holding gas pressure at 750psi. no MIT-IA required. Work complete Pressure up IA with GL. /ŶŝƟĂů͗ϭϴͬϳϲϯƉƐŝ 15 mins: 18 /759 psi (4psi loss) 30 mins: 18 / 758 psi (1 psi loss) IA is gas packed down to deepest GLM. Only Dome valves installed, and lowest one requires >800psi surface pressure to open BOPE test to 250 low / 3000 high. Pull test to 30k, MU Shorty MHA, ported sub. Secure equipment for night Static FL shots: Initial T/I pressures at 22/10 psi Repeat Tubing FL shots at 4262' / 4270' / 4252' Repeat IA FL shots at 4573' / 4662' / 4562' (Bottom live GLM at 4662' MD) Final T/I pressures at 22 / 10psi Run memory GR/CCL with P/T. Correct per Geo. Flag CT. PU 1.56" gun. Reperf 6271' - 6292' in the B-1. Pump N2 attempting to flow well. No fluid returns, no gas flow. Corrected GR/CCl show's patch actually set from 5736' - 5764' ELMD. Bottom 2' of perfs still exposed. Complete PTW & PJSM w/Production & Rig. M/U & RIH w/Tripoint 2.50" x 17' gun (6 spf, 60 degree phasing, 12g). Tagged 3-1/2" KB patch @ 5,734'. Correct counter to bottom shot = 5,733.27'. PUH to interval depth 5,175' - 5,192'. Bleed WHP to zero. Online w/N2 down coil 800 scf/min. At 3500 psi circ, good indication gun fired. PUH 100' and continue pumping N2 at 500 scf/min for 30 minutes. No fluid returns at surface. WHP falling. Discuss plan forward w/OE. Pooh w/gun BHA. On surface confirm all shots fired. Turn well over to production. Lay down risers and injector head. RDMO CTU #1. Page 2 of 2 1 Coldiron, Samantha J (OGC) From:Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent:Monday, March 4, 2024 9:39 AM To:McLellan, Bryan J (OGC) Cc:Dan Marlowe; Juanita Lovett; Ryan Rupert Subject:RE: [EXTERNAL] RE: Steelhead M-20 (PTD#209-093) Sundry #323-671 Attachments:10-403 Trading Bay Unit M-20 PTD 209-093_Sundry_323-671_Approved_122123.pdf No rush on this one, just checking in to see if you had time to review, or needed anything additionally from me? Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, February 21, 2024 4:54 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: RE: [EXTERNAL] RE: Steelhead M‐20 (PTD#209‐093) Sundry #323‐671 Updates diagnostics on M‐20 below. Given the fluid levels, I didn’t think a TIFL would be very valuable (reservoir pressure of open perfs is <<500psi). I was able to pressure up on the IA with Gas Lift today, and achieved the below stable results. Hilcorp requests that this work below satisfy the MIT requirements laid out in sundry #323‐671. The below information will be included in the well records and 404 for this job. The snapshot of the trend uses PT106 for the IAP and PT108 for the SITP on M‐20, FYI. 2/21/24: Pressure up IA with GL. Initial: 18 / 763 psi 15 mins: 18 /759 psi (4psi loss) 30 mins: 18 / 758 psi (1 psi loss) IA is gas packed down to deepest GLM. Only Dome valves installed, and lowest one requires >800psi surface pressure to open 2/20/24: Static FL shots: 2 Initial T/I pressures at 22/10 psi Repeat Tubing FL shots at 4262' / 4270' / 4252' Repeat IA FL shots at 4573' / 4662' / 4562' (Bottom live GLM at 4662' MD) Final T/I pressures at 22 / 10psi Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, February 14, 2024 10:44 AM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] RE: Steelhead M‐20 (PTD#209‐093) Sundry #323‐671 A TIFL could work Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 +1 (907) 250‐9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, February 14, 2024 10:43 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] RE: Steelhead M‐20 (PTD#209‐093) Sundry #323‐671 We'll shoot some fluid levels and get back to you with results Ryan Rupert 907‐301‐1736 ‐‐‐‐‐‐‐‐ Original message ‐‐‐‐‐‐‐‐ From: "McLellan, Bryan J (OGC)" <bryan.mclellan@alaska.gov> Date: 2/14/24 10:42 AM (GMT‐09:00) To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>, Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] RE: Steelhead M‐20 (PTD#209‐093) Sundry #323‐671 Ryan, That should be acceptable if you can confirm that there is some positive differential pressure down to the top of cement in the IA. If you have gas in the IA and liquid in the tubing, a 500 psi test might not be enough to overcome tubing pressure at the top of the cement packer. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 4 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, February 14, 2024 8:27 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] RE: Steelhead M‐20 (PTD#209‐093) Sundry #323‐671 Actually, since there’s only dome GLV’s installed and no orifice, we can pressure up the IA to 500psi with Gas lift and monitor pressures on T and IA for 30mins. IA should hold since we’ll be below the Psc pressure of those GLV’s. Is that acceptable? Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, February 14, 2024 8:00 AM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: [EXTERNAL] RE: Steelhead M‐20 (PTD#209‐093) Sundry #323‐671 Ryan, Is there another way to verify that the cement packer is isolating the IA from the tubing? Some kind of inflow test? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, February 14, 2024 7:51 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: Steelhead M‐20 (PTD#209‐093) Sundry #323‐671 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 5 Bryan‐ We have concluded our sundry work on M‐20. Please see below for activity summary. Unfortunately, we were unsuccessful at establishing any production, and the well remains dead / SI. We did add perfs shallower than existing perfs, which per the sundry would trigger an MIT‐IA. Given the well is SI and won’t flow, plus the presence of live GLV’s, Hilcorp asks the agency to forgo the MIT‐IA requirement. I wanted to confirm this with you before submitting the 404. Please advise. Thank you, Activity date Activity Summary 1/17/2024 MIRU. BOP test from prior (M‐16) well still valid. 1/18/2024 2.80" Motor/Mill FCO with 6% KCL. Tag at 4278'. Wash tubing with mill from 4280'‐ 6100' encountering several small bridges. 1/19/2024 Memory CCL/GAMMA for upcoming patch set 1/20/2024 Set straddle patch across A‐3 sands. Elements from 5742,‐5769' (27') covering A‐3 sand perfs 5746‐5766' (20') RKB depths. 1/21/2024 NPT: N2 pump & reel brake issues 1/22/2024 FCO with 6%KCL and N2. 1.75" DJN. tag at 6013' MD and wash from 6013 ‐ 6717' MD (PBTD). Switch to N2 only and blow well dry. All pumped fluid recovered. No gas production. 1/23/2024 BOPE test to 250 low / 3000 high. Pull test to 30k, MU Shorty MHA, ported sub. Secure equipment for night 1/24/2024 Run memory GR/CCL with P/T. Correct per Geo. Flag CT. PU 1.56" gun. Reperf 6271' ‐ 6292' in the B‐1. Pump N2 attempting to flow well. No fluid returns, no gas flow. 1/25/2024 Complete PTW & PJSM w/Production & Rig. M/U & RIH w/Tripoint 2.50" x 17' gun (6 spf, 60 degree phasing, 12g). Tagged 3‐1/2" KB patch @ 5,734'. Correct counter to bottom shot = 5,733.27'. PUH to interval depth 5,175' ‐ 5,192'. Bleed WHP to zero. Online w/N2 down coil 800 scf/min. At 3500 psi circ, good indication gun fired. PUH 100' and continue pumping N2 at 500 scf/min for 30 minutes. No fluid returns at surface. WHP falling. Discuss plan forward w/OE. Pooh w/gun BHA. On surface confirm all shots fired. Turn well over to production. Lay down risers and injector head. RDMO CTU #1. 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 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. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/28/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240228 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# AN-37 50733203940000 187109 11/8/2023 HALLIBURTON RBT KBU 31-18 50133206490000 215024 2/22/2024 HALLIBURTON PressTemp KBU 42-6 50133205460000 204209 2/23/2024 HALLIBURTON PPROF KU 31-07X 50133204950000 200148 2/2/2024 HALLIBURTON PressTemp MPU C-13 50029213280000 185067 2/23/2024 READ CaliperSurvey MPU C-14 50029213440000 185088 2/23/2024 READ CaliperSurve MPU L-43 50029231900000 203224 2/14/2024 READ CaliperSurvey MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON COILFLAG TBU M-20 50733205870000 209093 1/1/2024 HALLIBURTON COILFLAG Please include current contact information if different from above. T38535 T38536 T38537 T38538 T38539 T38540 T38541 T38542 T38543 2/29/2024 TBU M-20 50733205870000 209093 1/1/2024 HALLIBURTON COILFLAG Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 09:17:32 -09'00' 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:Daniel Scarpella To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Subject:SLB 1 BOPE testing on TBU M-20 Date:Tuesday, January 23, 2024 6:57:51 PM Attachments:SLB 1 1-24-2024 TBU M-20.xlsx Attached is the weekly BOPE testing. SLB 1 TBU M-20 Thank you, Daniel Scarpella Hilcorp North Slope LLC., Alaska | Sr. Well Site Supervisor | PBU Wells Team 907.230.2692 cell | 907.659.5580 office | H 2154 | alt. Anthony Knowles Well Interventions: daniel.scarpella@hilcorp.com RWO Operations: pbwellsrwowss@hilcorp.com P.O. Box 340067| DP PBOC 34 | PBOC 20| Prudhoe Bay, AK 99734 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. 7UDGLQJ%D\8QLW0 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:1 DATE: 1/23/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #22090930 Sundry #323671 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/2500 Annular:N/A Valves:250/2500 MASP:1189 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.NA Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75" Top Load P Trip Tank NA NA Annular Preventer 0NAPit Level Indicators NA NA #1 Rams 1 1.75" Blind/Shear P Flow Indicator NA NA #2 Rams 1 1.75" Pipe/Slip P Meth Gas Detector NA NA #3 Rams 0NAH2S Gas Detector NA NA #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 2 2" 2x2 FMC P Time/Pressure Test Result HCR Valves 0NASystem Pressure (psi)2900 P Kill Line Valves 2 2" 2x2 FMC P Pressure After Closure (psi)2225 P Check Valve 1 2" FMC P 200 psi Attained (sec)27 P BOP Misc 2 EQ Ports P Full Pressure Attained (sec)83 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA No. Valves 5P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer NA #1 Rams 22 P Coiled Tubing Only:#2 Rams 13 P Inside Reel valves 1P #3 Rams NA #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:0 Test Time:4.5 HCR Choke NA Repair or replacement of equipment will be made within days. HCR Kill NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/21/24 09:30 Waived By Test Start Date/Time:1/23/2024 9:00 (date) (time)Witness Test Finish Date/Time:1/23/2024 13:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg SLB Bryson Lowe Hilcorp Daniel Scarpella TBU M-20 Test Pressure (psi): Blowe2@slb.com daniel.scarpella@hilcorp.com Form 10-424 (Revised 08/2022)2024-0123_BOP_SLB1_TBU_M-20 9 9 9 99 9 9 9 9 9 MEU -5HJJ +LOFRUS$ODVND//&MEU 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Install Tubing Patch Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Fill Clean-out w/ Nitrogen 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,500 N/A Casing Collapse Structural Conductor Surface 2,260psi Intermediate Production 4,760psi Liner 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng McArthur River Middle Kenai Gas Same 6,346 6,715 3,596 1,189psi See schematic Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 7,420psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 / ADL0017594 / ADL0018729 209-093 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20587-00-00 Hilcorp Alaska, LLC Trading Bay Unit M-20 Length Size Proposed Pools: 490' 490' L-80 TVD Burst 6,809 6,870psi MD 5,020psi1,350'1,425' 490' 28" 13-3/8"1,425' 5,746 - 6,312 8,223' 7" 3,027 - 3,359 4,498'9-5/8" CO 228A 1/2/2024 10,498'2,476' 3-1/2" 6,328' See schematic / TE-5 SSSV See schematic / 428 (MD) 428 (TVD) 8,223' Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:54 pm, Dec 15, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.12.15 12:23:31 - 09'00' Dan Marlowe (1267) 323-671 Perforate SFD 12/20/2023 DSR-12/18/23 10-404 BJM 12/21/23 If perfs are added shallower than existing perfs, Perform MITIA to 1500 psi within 30 days of completing job. *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.21 11:07:32 -09'00'12/21/23 RBDMS JSB 122623 FCO + Patch Well: Steelhead M-20 Well Name:M-20 API Number:50-733-20587-00-00 Current Status:Offline Gas Producer Leg:Leg A1 (SW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:209-093 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:1,529 psi @ 3,396’ TVD 0.45psi/ft to deepest TVD Max. Potential Surface Pressure: 1189 psi Using 0.1 psi/ft Brief Well Summary Gas producer M-20 had it’s IA cemented for an uphole recomplete in late-2021. The well is highly deviated so EL tractor was brought out and shot B-1 perfs. The well briefly flowed 400mcfd before we shot the A-3, and came back with sand on the gun. This killed the well. We aim to cleanout any fill we encounter, patch off the A-3, and just produce the B-1. If unsuccessful, adperfs are also included in this procedure. The goal of this project is to return the well to production with only the B-1 perfs Pertinent wellbore information: - Tubing retrievable SSSV - Live GLV’s currently installed - Inclination: o Goes >60 degrees at 1900’ MD o 78 degree sail angle from 2200 – 4000’ MD o 54 degrees across open perfs - Pertinent events o 11/11/21: IA cement job for uphole recomplete o 11/15/21: Perforate B1 sands (6292’-6312’) – stuck EL tractor in well. Well did not flow. o 1/17/22: Perforate B1 sands (6272’-6292’) – all shots fired and gun was dry.Well was flowing at 400 MCFD post perforating. o 1/18/22: Perforate A3 sands (5746’-5766’) – all shots fired gun was wet and packed full of sand. Well sanded-up and would not flow post perforating A3 sands. o 1/22/22: SL tag w/2.5” DD bailer to 2222’ SLM/2257’ RKB (70 degrees at 2090’). If unsuccessful, adperfs are also included in this procedure. FCO + Patch Well: Steelhead M-20 Coiled Tubing Procedure 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. MU FCO BHA 4. RIH and cleanout to below A-3 perfs a. Working fluid will be water (8.33ppg or greater) b. Take returns to surface up the CT x tubing annulus c. Add foam and nitrogen as necessary to carry solids to surface d. Can use GL to assist with hole cleaning e. Keep fill top above B-1 perfs if practical 5. MU 3-1/2” patch 6. RIH and set patch to straddle off A-3 perfs (20’) 7. Continue FCO to PBTD, or as deep as practical 8. Lift fluid below deepest active GLM if needed with nitrogen down the CT 9. If unsuccessful in establishing flow from open perfs, PU guns and perforate / reperforate the sands within the Middle Kenai Gas Pool from ±5,138’ -- ±6,374’ MD (±2,670’ -- ±3,396’ TVD) 10. RDMO CT Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. CT BOP Drawing 4. Nitrogen procedure If unsuccessful perforate / reperforate the sands within the Middle Kenai Gas Pool from ±5,138’ -- ±6,374’ MD If perfs are added shallower than existing perfs, Perform MITIA to 1500 psi within 30 days of completing job. -bjm Steelhead Platform Well M-20 Completed 11-30-2009 Revised By: JLL 12/07/23 SCHEMATIC MAX HOLE ANGLE = 78.2 Deg @ 2,301’ Casing Detail SIZE WT GRADE CONN ID in TOP(MD) BTM(MD) 28” Structural 27 Surface 490’ 13-3/8” 68 L-80 BTC 12.415 Surface 1,425’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 8,223’ 7” 26 L-80 DWCSR 6.276 8,022’ 10,498’ Tubing Detail 3-1/2” 9.3 L-80 H-503 2.992 Surface 6,809’ RKB to TBG Head =78’.75 9 5/8” Casing in 12 ¼” Hole 13 3/8” in 17 ½” Hole 7” Liner in 8 1/2” Hole D-4 ECP Stage Collar 450-460 28” Conductor @ 480 9 5/8 Hydraulic Stage Collar @ 6,050’ B-6 C-3 & C-5 D-6 D-16A D-16C Tagged fill @ 8,857’ D-3A D-2 A-3 B-1 TOC 5,000’ MD CBL 11/11/21 TOC in Tbg 6,715’ CTMD 1 2 3 4 5 6 7 Tag Fill 2,222’SLM 1/22/22 Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Notes A-3 5,746’ 5,766’ 3,027’ 3,038’ 20’ 5 01/18/22 Open B-1 6,272’ 6,312’ 3,336’ 3,359’ 40’ 5 11/15/21 & 1/17/22 Open B-6 6,916' 6,966' 3,713' 3,742' 50' 14 11/09/21 Isolated C-3 7,646' 7,660' 4,136' 4,144' 14' 14 11/09/21 Isolated 7,667' 7,678' 4,148' 4,155' 11' 11/09/21 Isolated C-5 7,812' 7,840' 4,235' 4,257' 28' 14 11/09/21 Isolated D-2 8,493' 8,509' 4,685' 4,697' 16' 0 11/09/21 Isolated D-3A 8,626' 8,630' 4,790' 4,793' 4' 4 11/09/21 Isolated D-3A 8,648' 8,659' 4,808' 4,817' 11' 4 11/09/21 Isolated D-4 8,816' 8,821' 4,950' 4,954' 5' 4 11/09/21 Isolated D-6 9,000' 9,054' 5,104' 5,148' 54' 12 Abandoned D-16A 10,214' 10,226' 6,095' 6,105' 12' 12 Abandoned D-16C 10,268' 10,300' 6,139' 6,165' 32' 12 Abandoned Jewelry Detail No Depth MD Depth TVD OD ID Item 1 428' 428’ 5.125 2.813 TE-5 SSSV 2 6,725’ 3,602’ Cement retainer w/10’ cement -TOC 6,715’ 3 6,775’ 3,631’ CIBP 4 6,809' 3,650’ 8.46 4.75 Upper SC-1 GP Packer 5 6,981' 3,751’ 8.46 4.75 Lower SC-1 GP Packer 6 7,854' 4,262’ 8.125 4.75 Model D Sump Packer 7 8,900' 5,020’ N/A N/A Model K-1 Cement Retainer Cement Retainer @ 8,900’ Fish/Other Detail Date Depth MD Description 1/22/22 2,222’ SLM Tagged fill (Sand) GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,638’ 1,499’ 2.992 SFO-1 GLM 12 Dome 905 2 3,103’ 1,946’ 2.992 SFO-1 GLM 12 Dome 895 3 4,662’ 2,397’ 2.992 SFO-1 GLM 12 Dome 885 4 5,690’ 2,994’ 2.992 SFO-1 GLM 12 Dummy 9/17/2021 6 6,749’ 3,615’ 2.992 SFO-1 GLM 20 Orifice Isolated Cement Details 13-3/8" 17-1/2” Hole: Pumped 164bbls of 13.0ppg lead Class G cement followed by 112bbls of 13.7ppg Class G tail cement. Pumped 2nd stage through DV collar at 450’. Pumped 255bbls 13.0ppg Class G with full returns ToC assumed at surface 9-5/8" 12-1/4” hole: Pumped 139bbls 13.2ppg class G lead cement followed by 47bbl 14.0ppg Class G tail cement. Pumped 2nd stage through DV collar at 6050’. Pumped 382bbls 13.2ppg Class G. Lost 72bbls during job. Saw cement back to surface ToC at surface 3-1/2”3-1/2” tubing cemented in place 11/10/21 with 111bbls 15.3ppg cement.CBL shows ToC at 5000’ MD Steelhead Platform Well M-20 Completed 11-30-2009 Revised By: TDF 12/17/23 PROPOSED MAX HOLE ANGLE = 78.2 Deg @ 2,301’ Casing Detail SIZE WT GRADE CONN ID in TOP(MD) BTM(MD) 28” Structural 27 Surface 490’ 13-3/8” 68 L-80 BTC 12.415 Surface 1,425’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 8,223’ 7” 26 L-80 DWCSR 6.276 8,022’ 10,498’ Tubing Detail 3-1/2” 9.3 L-80 H-503 2.992 Surface 6,809’ RKB to TBG Head =78’.75 9 5/8” Casing in 12 ¼” Hole 13 3/8” in 17 ½” Hole 7” Liner in 8 1/2” Hole D-4 ECP Stage Collar 450-460 28” Conductor @ 480 9 5/8 Hydraulic Stage Collar @ 6,050’ B-6 C-3 & C-5 D-6 D-16A D-16C Tagged fill @ 8,857’ D-3A D-2 A-3 B-1 TOC 5,000’ MD CBL 11/11/21 TOC in Tbg 6,715’ CTMD 1 2 3 4 5 6 7 Patch for A-3 Perfs, ± 20’ Middle Kenai Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Notes Middle Kenai ±5,138’ ±6,374’ ±2,670’ ±3,396’ ±1,236’ - Future Future A-3 5,746’ 5,766’ 3,027’ 3,038’ 20’ 5 01/18/22 Isolated B-1 6,272’ 6,312’ 3,336’ 3,359’ 40’ 5 11/15/21 & 1/17/22 Open B-6 6,916' 6,966' 3,713' 3,742' 50' 14 11/09/21 Isolated C-3 7,646' 7,660' 4,136' 4,144' 14' 14 11/09/21 Isolated 7,667' 7,678' 4,148' 4,155' 11' 11/09/21 Isolated C-5 7,812' 7,840' 4,235' 4,257' 28' 14 11/09/21 Isolated D-2 8,493' 8,509' 4,685' 4,697' 16' 0 11/09/21 Isolated D-3A 8,626' 8,630' 4,790' 4,793' 4' 4 11/09/21 Isolated D-3A 8,648' 8,659' 4,808' 4,817' 11' 4 11/09/21 Isolated D-4 8,816' 8,821' 4,950' 4,954' 5' 4 11/09/21 Isolated D-6 9,000' 9,054' 5,104' 5,148' 54' 12 Abandoned D-16A 10,214' 10,226' 6,095' 6,105' 12' 12 Abandoned D-16C 10,268' 10,300' 6,139' 6,165' 32' 12 Abandoned Jewelry Detail No Depth MD Depth TVD OD ID Item 1 428' 428’ 5.125 2.813 TE-5 SSSV 2 6,725’ 3,602’ Cement retainer w/10’ cement -TOC 6,715’ 3 6,775’ 3,631’ CIBP 4 6,809' 3,650’ 8.46 4.75 Upper SC-1 GP Packer 5 6,981' 3,751’ 8.46 4.75 Lower SC-1 GP Packer 6 7,854' 4,262’ 8.125 4.75 Model D Sump Packer 7 8,900' 5,020’ N/A N/A Model K-1 Cement Retainer Cement Retainer @ 8,900’ Fish/Other Detail Date Depth MD Description 1/22/22 2,222’ SLM Tagged fill (Sand) GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,638’ 1,499’ 2.992 SFO-1 GLM 12 Dome 905 2 3,103’ 1,946’ 2.992 SFO-1 GLM 12 Dome 895 3 4,662’ 2,397’ 2.992 SFO-1 GLM 12 Dome 885 4 5,690’ 2,994’ 2.992 SFO-1 GLM 12 Dummy 9/17/2021 6 6,749’ 3,615’ 2.992 SFO-1 GLM 20 Orifice Isolated Cement Details 13-3/8" 17-1/2” Hole: Pumped 164bbls of 13.0ppg lead Class G cement followed by 112bbls of 13.7ppg Class G tail cement. Pumped 2nd stage through DV collar at 450’. Pumped 255bbls 13.0ppg Class G with full returns ToC assumed at surface 9-5/8" 12-1/4” hole: Pumped 139bbls 13.2ppg class G lead cement followed by 47bbl 14.0ppg Class G tail cement. Pumped 2nd stage through DV collar at 6050’. Pumped 382bbls 13.2ppg Class G. Lost 72bbls during job. Saw cement back to surface ToC at surface 3-1/2”3-1/2” tubing cemented in place 11/10/21 with 111bbls 15.3ppg cement.CBL shows ToC at 5000’ MD SLB Stack Drawing Not Drawn To Scale--- For Reference Only 2 1/16 10M Flanged Plug Valve (Manual) from KP Well Floor HR 580 Injector Head with 72" Gooseneck 4.06" 10K Conventional Stripper – 1.75" C062 Pin Connection Manual 2 1/16 10M Provided by client Blind/Shear Pipe/Slip 4 1/16 10M Combi BOP Lubricator to Injector Head STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 03/03/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL TBU M-20 (PTD 209-093) Perf 01/18/2022 Please include current contact information if different from above. 209-093 T36419 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.15 14:30:57 -08'00' 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: Cement / N2 Operations Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,500 feet See schematic feet true vertical 6,346 feet 6,278 feet Effective Depth measured 6,715 feet See schematic feet true vertical 3,596 feet See schematic feet Perforation depth Measured depth 5,746 - 6,312 feet True Vertical depth 3,027 - 3,359 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / L-80 6,809 MD 3,651 TVD 428 MD Packers and SSSV (type, measured and true vertical depth)See schematic TE-5 SSSV 428 TVD 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: Contact Email: Authorized Title:Contact Phone: 321-438 Sr Pet Eng: 5,410psi Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 130 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 711 7,420psi Katherine O'Connor Katherine.oconnor@hilcorp.com 907 777-8376Dan Marlowe, Operations Manager measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 8000 0 12 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 490' 1,425' N/A 53 Structural TVD 490' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 209-093 50-733-20587-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018730 / ADL0017594 / ADL0018729 McArthur River Field / Middle Kenai Gas Pool Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Trading Bay Unit M-20 measuredPlugs Junk measured N/A Length 490' 1,425' Size Conductor Surface Intermediate 28" 13-3/8" Production Liner 8,223' 2,476' Casing 1,350' 4,498' 7" 8,223' 10,498' 6,328' 9-5/8"4,760psi 5,020psi 6,870psi Burst Collapse 2,260psi L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 3:43 pm, Feb 03, 2022 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.02.03 15:34:08 -09'00' Dan Marlowe (1267) Steelhead Platform Well M-20 Completed 11-30-2009 Revised By: JLL 01/28/22 SCHEMATIC MAX HOLE ANGLE = 78.2 Deg @ 2,301’ Casing Detail SIZE WT GRADE CONN ID in TOP(MD) BTM(MD) 28” Structural 27 Surface 490’ 13-3/8” 68 L-80 BTC 12.415 Surface 1,425’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 8,223’ 7” 26 L-80 DWCSR 6.276 8,022’ 10,498’ Tubing Detail 3-1/2” 9.3 L-80 H-503 2.992 Surface 6,809’ RKB to TBG Head = 78’.75 9 5/8” Casing in 12 ¼” Hole 13 3/8” in 17 ½” Hole 7” Liner in 8 1/2” Hole D-4 ECP Stage Collar 450-460 28” Conductor @ 480 Cement to ML @ 345’ 9 5/8 Hydraulic Stage Collar @ 6,050’ B-6 C-3 & C-5 D-6 D-16A D-16C Tagged fill @ 8,857’ D-3A D-2 A-3 B-1 TOC 5,000’ MD CBL 11/11/21 TOC in Tbg 6,715’ CTMD 1 2 3 4 5 6 7 8 9 10 11 12 Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Notes A-3 5,746’ 5,766’ 3,027’ 3,038’ 20’ 5 01/19/21 Open B-1 6,272’ 6,312’ 3,336’ 3,359’ 40’ 5 11/15/21 & 1/18/22 Open B-6 6,916' 6,966' 3,713' 3,742' 50' 14 11/09/21 Isolated C-3 7,646' 7,660' 4,136' 4,144' 14' 14 11/09/21 Isolated 7,667' 7,678' 4,148' 4,155' 11' 11/09/21 Isolated C-5 7,812' 7,840' 4,235' 4,257' 28' 14 11/09/21 Isolated D-2 8,493' 8,509' 4,685' 4,697' 16' 0 11/09/21 Isolated D-3A 8,626' 8,630' 4,790' 4,793' 4' 4 11/09/21 Isolated D-3A 8,648' 8,659' 4,808' 4,817' 11' 4 11/09/21 Isolated D-4 8,816' 8,821' 4,950' 4,954' 5' 4 11/09/21 Isolated D-6 9,000' 9,054' 5,104' 5,148' 54' 12 Abandoned D-16A 10,214' 10,226' 6,095' 6,105' 12' 12 Abandoned D-16C 10,268' 10,300' 6,139' 6,165' 32' 12 Abandoned Jewelry Detail No Depth MD Depth TVD OD ID Item 1 428' 428’ 5.125 2.813 TE-5 SSSV 2 1,638’ 1,499’ 5.250 2.992 SFO-1 GLM #1 3 3,103’ 1,946’ 5.250 2.992 SFO-1 GLM #2 4 4,662’ 2,397’ 5.250 2.992 SFO-1 GLM #3 5 5,690’ 2,994’ 5.250 2.992 SFO-1 GLM #4 6 6,725’ 3,602’ Cement retainer w/10’ cement -TOC 6,715’ 7 6,749’ 3,615’ 5.250 2.992 SFO-1 GLM #5 8 6,775’ 3,631’ CIBP 9 6,809' 3,650’ 8.46 4.75 Upper SC-1 GP Packer 10 6,981' 3,751’ 8.46 4.75 Lower SC-1 GP Packer 11 7,854' 4,262’ 8.125 4.75 Model D Sump Packer 12 8,900' 5,020’ N/A N/A Model K-1 Cement Retainer Logging Detail Hole Section LWD/MWD Mud Logging Notes 17 ½” GR/Res Gas Detection, Mud Logging Consulting Geologist 12 ¼” GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist 8 ½” GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist Cement Retainer @ 8,900’ Fish Detail Date Depth MD Description 11/15/21 ~6,278’ Has small slickline fishing neck - 1" OAL of fish = 56.38' (31.82' welltrac tractor tools/xo's + 24.56' of AK EL gun, xo's Rig Start Date End Date CTU 9/17/21 1/19/22 11/08/21 - Monday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-20 50-733-20587-00-00 209-093 Conduct JSA and approve PTW. Move coil equipment to get spotted over SW leg. Move bridge and replace hatch on SE leg. RU Hardline. Stab coil through injector. Test BOPE. Witness waived by AOGCC (Jim Regg) at 09:22 on 10/30/2021. Function test BOP rams Test BOPE to 250 psi low / 1,500 psi high. Change pack-offs and RU hardline. Prep to backload choke manifold, iron basket and N2 tank to beach for job at Beaver Creek.;Demob SLB coil crew from Steelhead platform. 10/30/2021 - Saturday 09/17/2021 -Friday ATTEND MORNING MEETING. RIG UP W/L, PT 1500 PSI- GOOD. RIH W/ 2.76" GAUGE RING TO 6850'KB - TUBING CLEAR - POOH. RIH W/ 3 1/2 OK-5 W/ 1 1/4 JDS TO 6782' KB LOCATE MANDREL WT - POOH - OOH W/ NO VALVE. RIH W/ SAME TO 6782' KB WT LATCH - 1500 LBS OIL JAR LICK AND SPANG FREE - POOH. OOH W/ HIGH FLOW ORIFICE VALVE - DAMAGED CHECK VALVE. RIH W/ SAME TO 5732'KB WT LATCH VALVE 2 X 1500 OIL JAR LICKS - COME FREE - POOH. OOH W/ LIVE VALVE IN GOOD CONDITION. RIH W/ 3 1/2 OK-5 W/ JKRT W/ DUMMY VALVE TO 5732'KB WT SET VALVE - POOH. RIH W/ 3 1/2 OK-5 W/ 1.25" LIB TO 5732' KB WT - POOH. OOH W/ IMPRESSION OF VALVE IN POCKET. DISCUSS OPERATIONS W/ CO. REP. DECIDE TO NOT RISK PULLING MORE VALVES. RIG DOWN W/L - CLEAN AREA - PREPARE FOR FLIGHT. Depart OSK heliport. Arrive at Steelhead platform and have orientation. Conduct JSA with SLB coil crew, Quadco rep, & READ cased hole rep. Approve PTW. Spot equipment and RU hardline. Move bridge over well slot. Function test BOP rams. Pressure test BOPE to 250 psi low / 1500 psi high. Witness waived by AOGCC rep Jim Regg via e-mail on 11/5/21 at 15:47. NU Riser from swab flange in wellbay to drill deck. NU BOP's on riser. RU return line from IA in wellbay to tank on drill deck. Rig Start Date End Date CTU 9/17/21 1/19/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-20 50-733-20587-00-00 209-093 11/09/21 - Tuesday SLB coil, Quadco, and READ conduct JSA and approve PTW. Warm equipment and pick lubricator joints and injector w/ crane. MU CTC and pull test to 20k. MU READ memory GR/CCL logging BHA. 2.0" x 0.31' CTC, 2.12" x 1.70' DFCV, 2.12" x 1.75' Disco, 2.375" x 10.59' carrier, 2.75" x 1.16' fluted centralizer, 2.12" x 0.68' XO, 2.12" x 0.50' DJN. Max OD = 2.75". OAL = 16.67'. Hook up water supply hose to pump and PT lubricator to 1500 psi. PT hardline to 4500 psi. Shut in production. Open well and RIH w/ memory logging BHA. Swab open 20.5 turns. Tubing pressure = 45 psi. Log up from 6850' to 5500' at 50 ft/m. Stop at 6699.6' (electronic) and paint flag. READ memory logging depth = 6698.84'. Mechanical counter = 6699. POOH. Download data from memory tools and confirm good data. MU CIBP BHA: 2.0" x 0.31' CTC, 2.12" x 1.70' DFCV, 2.12" x 1.75' Disco, 2.12" x 0.79' XO, 1.70" x 6.36' setting tool, 2.63" x 0.71' setting sleeve, 2.63" x 1.25' CIBP. Correlate depth to tubing tally. Add +25' to log to get on depth. Corrected EOP at flag = 6712.01'. Corrected top of plug at flag = 6723.63'. RIH with CIBP BHA. Correct depth to 6723.6' at coil flag. RIH and pull into position at 6775' (top of CIBP). Drop 3/8" ball, ball on seat and shears at 2400 psi. Set down ~ 4k to ensure plug is set. POOH. Pump down backside of coil while taking returns up IA while POOH. Coil at surface. Shut in swab and laydown BHA. Ball recovered. Install night cap and laydown lubricator. Trouble shoot water supply from rig. Unable to get water to coil pump. Circulate water down tubing and up IA to return tank until fluid at surface. Shut in IA. PT tubing and IA to 1500 psi. Bleed down to 0 psi. Wrap coil with parachute and heater for the night. Blowdown lines with air. SDFN. Rig Start Date End Date CTU 9/17/21 1/19/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-20 50-733-20587-00-00 209-093 11/10/21 - Wednesday Conduct JSA with Halliburton cement, SLB coil, Quadco. Crane move Halliburton cement equipment on deck Offload cement from herc pods to silo. RU cement equipment. MU Quadco CTC, up jar & Disco. PT MU FH setting tool and one-trip cement retainer on 1.75"" coiled tubing. BHA: 2.0" x .33' CTC, 2.15" x 5.97' up jar, 2.12" x 1.58' Disco (9/16" ball), 2.13" x 6.99' FH setting tool and cement retainer (1/2" ball seat). OAL = 14.86'. Open well and RIH with cement retainer on coiled tubing. RIH to coil flag. Uncorrected depth = 6715.7'. Correct depth to 6725.8' which is mid element of retainer. RIH past set depth and pull into position. Stop coil with mid element of retainer at 6725'. Drop 1/2" ball and set retainer at 6725'. Ball on seat and sheared at 4150 psi. Confirm circulation from coiled tubing and up IA. PT backside of coil to 500 psi. Set down 9k lbs on retainer. Halliburton pump 5 bbls of freshwater down coil. Then PT to 5000 psi. Pump 10 bbls of surfactant wash and 2 bbls of freshwater. Confirm returns from IA to tank at surface. Cement is wet. Halliburton start pumping cement down coil. Cement at weight of 15.3 ppg. Returns up IA to tank at surface. Tubing pressure = 450 psi, CTP = 1430 psi, rate = 1.0 bpm. Cement at nozzle. Pumped 30 bbls of 15.3 ppg cement down coil, taking returns through open GLM and up IA. Tubing pressure = 490 psi, CTP = 3738 psi, rate = 1.0 bpm. Returns up IA to tank are 1:1 for volume pumped. Pump total of 111 bbls of 15.3 ppg cement down coil, taking returns up IA to surface. Pump 28.4 bbls of water displacement. Leave 1 bbl of cement in coil. Shut down pump. IA = 145 psi, WHP = 560 psi. Unsting coil from retainer and PUH. IA pressure stable at 149 psi. WHP stable at 330 psi. Reverse circulate cement at 0.8 bpm and RIH to 6715'. POOH reverse circulating, keeping hole full. Coil at surface. Shut in Swab. Blow down lines with air. Wrap reel with parachute and heat. SDFN. 11/11/21 - Thursday SLB coil, READ, and Quadco conduct JSA and approve PTW. PU another stick of lubricator. MU Quadco MHA and READ memory CBL toolstring. 2.0" x 0.31' CTC, 2.12" x 1.70" DFCV, 2.12" x 1.75' Disco, 2.20" x 0.5' ported xover, 1.69" x 24.11' memory CBL. PT lubricator and RIH. Have Ops normal up IA and prep for gas lift. Stop coil at 4700'. Log down from 4700' to 6700' at 30 ft/min while holding 500 psi WHP. Log up from 6700' to 4700' at 30 ft/min. Close choke and WHP go to 0 psi. Ops start gas lifting IA and flowing to test separator. Coil at surface. Laydown READ memory CBL. Download data and confirm data is good. Platform has shut down, so IA lift gas is shut off. Recover 35 of 286 bbls from IA. RD hose from IA to return tank. RD treating iron from pump truck to choke skid. Laydown lubricator. SDFN, Lift gas applied to IA during the night to unload IA/Tubing. Separator indicated that there was 245 bbls of fluid recovered, but operations says more was recovered just not captured on totalizer. Rig Start Date End Date CTU 9/17/21 1/19/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-20 50-733-20587-00-00 209-093 11/14/21 - Sunday MIRU AK E-line and Welltec tractor. Remove hatch and install bridge. Spot E-line unit, Welltec run cables and test power to panel. Build new cable head. Test Welltec tractor with AK E-line GR sub. SDFN. 11/15/21 - Monday Conduct JSA with AK E-line and Welltec. Approve PTW. Warm up equipment. Perform voltage checks through tractor with AK E-line. Check voltage in perforating mode and safe mode. Mu perf gun and tractor into lubricator/riser. MU riser section from lower wellbay to top deck. PT lubricator to 250 psi low / 2000 psi high. Open well and RIH with AK E-line and Welltec tractor. Run 1: RIH with 2-3/8" x 20' perf gun. 10.8 gram razor charges, 60 deg phasing, 5 spf. Tractor from 2150' to 4630'. GR/CCL to Top Shot = 13.3'. Stop depth = 6278.7'. Send correlation data to town. On depth. Perforate B1: 6292' - 6312'. Initial Tubing pressure = 120 psi,Lost ~ 1000# of weight when perforated. Tool shorted and is stuck downhole. No communication with tractor. Work wire starting at safe pull from weakpoint at 2100#. Work up to high end weak point of 2500#. Pulled free. POOH. Cable at surface. Pulled out of weak point. Damaged wire about 10' above weak point. Fish left in well at ~ 6278'. Has small slickline fishing neck - 1". OAL of fish = 56.38' (31.82' welltrac tractor tools/xo's + 24.56' of AK EL gun, xo's. 11/12/21 - Friday SLB coil conduct JSA and Ops approve PTW. Warm up equipment and run hose to unload return tank to Ops. MU nozzle with centralizer to blowdown tubing with N2. 2.0" x 0.31' CTC, 2.12" x 1.70" DFCV, 2.12" x 4.91' WT bar, 2.12" x 1.75' Disco, 2.75" x 1.16' centralizer, 2.12" x 0.66' XO, 2.12" x 0.5' DJ nozzle. Max OD = 2.75". OAL = 10.99'. Pump fluid from return tank to operations. RIH with nozzle to 2000' and wait for tank level to drop adequately. RIH and Tag at 6715' ctmd. Stop pumping from return tank to operations. Pump Nitrogen down coil taking returns to surface to blowdown coil and tubing. Recover 70 bbls of fluid and then all nitrogen. SD N2 pump. POOH with coiled tubing. Close swab and bleed down 70 psi of WHP. Laydown BHA. Start to RD Continue to pump fluid from return tank to production. Finish pumping return fluids to production. ND riser and BOPs from well. NU swab flange with tree cap. Remove bridge and install hatch cover. Prep to De-mob equipment from platform. Coil crew de-mob. 01/06/22 - Thursday AKEL crew arrives at facility and obtains permit, PJSM. Spot eline equipment and stab riser on tree. Eline unit has frozen air lines, tarp up unit and get heater on it. Rig up toolstring in lubricator on deck: head / 5' weight bar / 2.6" roller / knuckle / 7' weight bar / 2.6" roller / knuckle / gun-gamma / 2.6" roller / knuckle / firing head. Purge air lines and issue is resolved. Test fire through toolstring and check gun-gamma. Tools check out good. Prepare 10' 2-3/8" gun for morning. Secure riser with nightcap and SDFN. Rig Start Date End Date CTU 9/17/21 1/19/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-20 50-733-20587-00-00 209-093 01/17/22 - Monday 01/07/22 - Friday Crew assembles and obtains permit to work, PJSM. Warm up eline equipment. Pressure test lubrcator to 250 psi low / 2000 psi high. Arm 10' 2-3/8" gun. RIH with head / 5' weight bar / 2.3" roller bogey / knuckle / 7' weight bar / 2.3" roller bogey / knuckle / gun-gamma / 2.3" roller bogey / firing head / gun / SL roller. RIH at 250 fpm to 3800' and unable to fall deeper. Attempt to make it past deviation multiple times at speeds from 150 - 600 fpm. After initial run to 3800' unable to make it past 3300'. POOH and break off lubricator. Add knuckle joint between bottom 2.3" roller bogey and gun. Fill riser with diesel and drop into well for lubrication. RIH and attempt to make it past deviation multiple times with no success. 3300' is deepest depth achieved. Rig up diesel pump to well and trickle in diesel. RIH with no success. POOH and break off lubricator. Remove SL roller and add 2 x 5' SL weight stems and place SL roller on bottom. RIH, unable to pass 3300'. Get permission to jumper sales gas down tubing to help push tools. Come online with sales gas and deviate out in same spot. POOH. Break off lubricator and disarm gun. Lay down tools and rig down eline. AKEL and Welltec crews arrive at facility and obtain permits, PJSM. Rig up eline while Welltec assembles tools. Pressure test lubricator to 250 psi low and 2000 psi high. Break off riser from tree and lay down same on deck. Make up toolstring inside lubricator. Rope socket, 2-1/8" tractor with one motor section and four wheel sections (2 x 2.64" centralizers), gun-gamma. Perform hot checks and voltage safety circuit test through toolstring. Arm 20' 2-3/8" HC gun. Pick up toolstring (OAL: 56.8') in lubricator and stab on tree. RIH. Free fall down to 2150' and engage tractor. Tractor from 2150' to 4650' at 30-40 fpm, easy tractoring. Free fall down to 6400' and correlate to open hole log. Send log to town for correction and add 1 foot. Perforate B1 sand from 6272-6292' and begin to come uphole. Lose 600# of tension and get weight back. POOH. Break off riser from tree and lay down same on deck. Inspect gun, all shots fired and gun is dry. Wire severely kinked about 15' above rope socket. Secure well and SDFN. Rig Start Date End Date CTU 9/17/21 1/19/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Trading Bay Unit M-20 50-733-20587-00-00 209-093 01/18/22 - Tuesday AKEL and Welltec crews assemble and participate in morning safety meeting. Obtain permits and PJSM. Fire up eline equipment and build new rope socket while Welltec readies new tractor tools. Discover that second 20' gun is in a 6 SPF carrier, wrong gun system (2.5"). Make up 2 x 10' 2-3/8" guns loaded at 5 SPF into tandem 20' gun. Make up toolstring inside lubricator. Rope socket, 2-1/8" tractor with one motor section and four wheel sections (2 x 2.64" centralizers), gun-gamma. Perform hot checks and voltage safety circuit test through toolstring. Arm 2 x 10' 2-3/8" tandem HC guns. Pick up toolstring (OAL: 57') in lubricator and stab on tree. RIH. Free fall down to 2150' and engage tractor. Tractor from 2100' to 4655' at 20 fpm, easy tractoring. Free fall down to 5900' and Shut in well. Jumper gas lift pressure and increase WHP to 220 psi. Correlate to open hole log and send to town for correction. Add one foot per geologist and perforate A3 from 5746-5766'. Lost 50# but much less violent than last run. Pressure readings: 300 psi @ 5 minutes, 480 @ 10 minutes, 550 @ 15 minutes. POOH. Break off riser from tree and lay down same on deck. Inspect gun, all shots fired and gun was wet and packed full of a lot of sand. RDMO eline. 01/19/2022 - Wednesday Final set of perforations killed well. Well will not flow & is shut in. MITIA will not be conducted. TBG pressure 7 psi. 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: 11/29/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL TBU M-20 (PTD 209-093) Memory Radial CBL 11/11/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/29/2021 By Abby Bell at 4:24 pm, Nov 29, 2021 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: 11/29/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL TBU M-20 (PTD 209-093) Coil Flag 11/09/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/29/2021 By Abby Bell at 4:24 pm, Nov 29, 2021 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,500'N/A Casing Collapse Structural Conductor Surface 2,260 psi Intermediate Production 4,760 psi Liner 5,410 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6,329' 8,850' 4,979' 97 psi 2,476' 7" 4,498'9-5/8" 10,498' 6,328' 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. 9/12/2021 3-1/2" Taylor Wellman for Packers (x3) see schematic & TE-5 SSSV 6,916 - 8,821 1,425' 8,223' Perforation Depth MD (ft): 8,223' see schematic & 428 (MD) 428 (TVD) Tubing Grade:Tubing MD (ft): 3,713 - 4,954 Perforation Depth TVD (ft): 490' 1,425' 28" 13-3/8" 490' 490' CO 228A 9.3# / L-80 TVD Burst 6,809' 6,870 psi 7,420 psi Tubing Size: MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 / ADL0017594 / ADL0018729 209-093 50-733-20587-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit M-20 COMMISSION USE ONLY Authorized Name: 5,020 psi1,350' Other: Cement / N2 Operations Authorized Signature: Daniel E. Marlowe, Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 8,850' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:01 pm, Aug 31, 2021 321-438 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.08.31 11:13:46 -08'00' Taylor Wellman (2143) MITIA to 1500 psi 5-10 days after return to production, post perf. Provide 48 hrs notice for AOGCC witness. X DLB 08/31/2021 CT 10-404 XX BJM 9/8/21 Review CBL log with AOGCC before adding perfs. DSR-8/31/21 CT BOP test to 1500 psi dts 9/9 2021 JLC 9/10/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.10 15:22:56 -08'00' RBDMS HEW 9/13/2021 Well Work Prognosis Well: SHP M-20 Well Name: Trading Bay Unit M-20 API Number: 50-733-20587-00-00 Current Status: Gas Producer Leg: A-1 SW Corner Estimated Start Date: Sept 12, 2021 Rig: SL/EL/CTU Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 209-093 First Call Engineer: Katherine O’Connor 907-777-8376 214-684-7400 Second Call Engineer: Karson Kozub (907) 570-1801 Expected BHP: Current Bottom Hole Pressure: 272 psi @ 3,729 TVD Based on resent SITP from M-20 on 6/23/2021 Maximum Expected BHP: 373 psi @ 2,758’ TVD Based on offset M-22 RFT data in 2018 Maximum Potential Surface Pressure: 97 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) Brief Well Summary M-20 is a gas producer on the Steelhead platform producing ~150 mscfs/day from the B-6, & C-3/5, & D- 2/3A/4sands. The objective on this well is to isolate the well from the currently existing producing sands and recomplete into the A-2, A-3, and B-1 sands. This will be executed by setting a plug in the tubing above the packer at 6809’ MD, pumping a cement packer, and perforating the sands uphole. top bottom size ID bbls/ft ft volume 3-1/2" tubing 0 6809 3-1/2"2.992 0.009 6809 62 3-1/2" tbg x 9-5/8" casing 0 8223 3-1/2" 9.3# x 9-5/8" 47# 8.681 0.061 6749 414 GLM 5 Procedure: 1. RU SL pressure test lubricator to 250psi low/1500 psi high a. Pull lowest GLV & leave open b. Set DGLVs in GLMs #1-4 2. MIRU coil tubing 3. NU BOP and test to 250psi low/1500psi high. a. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Run tie in log & set CIBP at ±6775’ MD’ MD 5. Pump FIW into inner annulus and tubing, pumping down tubing taking returns up IA 6. Pressure test tubing & IA to 1500 psi (to ensure plug is holding) 7. Set one trip cement retainer @ ± 6735’ MD 8. PT coil tubing x 3-1/2” tubing backside to 1500 psi to ensure dummy GLVs are holding 9. establishing returns up the IA and pump the following schedule (target TOC in the IA is ±5000’ MD): a. 10 bbls surfactant wash b. 2 bbl fresh water (FW) spacer c. 105 bbls class G cement d. 2 bbl FW spacer Well Work Prognosis Well: SHP M-20 e. CT volume of cement displacement 10. With 1 bbl of cement remaining in the coil, unsting from retainer and lay the last 1 bbl of cement on the retainer. Note pressures after unstinging from retainer. Do not bleed any pressure. Ensure retainer is holding pressure, and then reverse circ cement and POOH maintaining full hole. 11. Wait for cement to reach 500 psi compressive strength and Log cement from ±6770’ MD to identify TOC. 12. Blow down well with N2 13. RDMO CTU 14. RU EL pressure test lubricator to 250 low/2000 psi high. a. Add perforations per procedure, utilize tractor as needed 15. MITIA to 1500 psi Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. Coil Tubing BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form Review CBL log with AOGCC before adding perfs. MITIA to be performed 5-10 days after returning well to production. Notify AOGCC for witness. Steelhead Platform Well M-20 Completed 11-30-2009 Revised By: JLL 01/08/2020 SCHEMATIC MAX HOLE ANGLE = 78.2 Deg @ 2,301’ Casing Detail SIZE WT GRADE CONN ID in TOP(MD) BTM(MD) 28” Structural 27 Surface 490’ 13-3/8” 68 L-80 BTC 12.415 Surface 1,425’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 8,223’ 7” 26 L-80 DWCSR 6.276 8,022’ 10,498’ Tubing Detail 3-1/2” 9.3 L-80 H-503 2.992 Surface 6,809’ RKB to TBG Head = 78’.75 9 5/8” Casing in 12 ¼” Hole 13 3/8” in 17 ½” Hole 7” Liner in 8 1/2” Hole D-4 ECP Stage Collar 450-460 28” Conductor @ 480 Cement to ML @ 345’ 9 5/8 Hydraulic Stage Collar @ 6,050’ B-6 C-3 & C-5 D-6 D-16A D-16C Tagged fill @ 8,857’ D-3A D-2 7 6 1 5 3 2 8 9 10 Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Notes B-6 6,916' 6,966' 3,713' 3,742' 50' 14 7” Big Hole Charge. 56.5 gm C-3 7,646' 7,660' 4,136' 4,144' 14'14 7” Big Hole Charge. 56.5 gm7,667' 7,678' 4,148' 4,155' 11' C-5 7,812' 7,840' 4,235' 4,257' 28' 14 7” Big Hole Charge. 56.5 gm D-2 8,493' 8,509' 4,685' 4,697' 16' 0 Open D-3A 8,626' 8,630' 4,790' 4,793' 4' 4 Open D-3A 8,648' 8,659' 4,808' 4,817' 11' 4 Open D-4 8,816' 8,821' 4,950' 4,954' 5' 4 Open D-6 9,000' 9,054' 5,104' 5,148' 54' 12 Abandoned D-16A 10,214' 10,226' 6,095' 6,105' 12' 12 Abandoned D-16C 10,268' 10,300' 6,139' 6,165' 32' 12 Abandoned Jewelry Detail No Depth MD Depth TVD OD ID Item 1 428' 428’ 5.125 2.813 TE-5 SSSV 2 1,638’ 1,499’ 5.250 2.992 SFO-1 GLM #1 3 3,103’ 1,946’ 5.250 2.992 SFO-1 GLM #2 4 4,662’ 2,397’ 5.250 2.992 SFO-1 GLM #3 5 5,690’ 2,994’ 5.250 2.992 SFO-1 GLM #4 6 6,749’ 3,615’ 5.250 2.992 SFO-1 GLM #5 7 6,809' 3,650’ 8.46 4.75 Upper SC-1 GP Packer 8 6,981' 3,751’ 8.46 4.75 Lower SC-1 GP Packer 9 7,854' 4,262’ 8.125 4.75 Model D Sump Packer 10 8,900' 5,020’ N/A N/A Model K-1 Cement Retainer Logging Detail Hole Section LWD/MWD Mud Logging Notes 17 ½” GR/Res Gas Detection, Mud Logging Consulting Geologist 12 ¼” GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist 8 ½” GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist Cement Retainer @ 8,900’ 4 Steelhead Platform Well M-20 Completed 11-30-2009 Revised By: JLL 08/27/21 PROPOSED MAX HOLE ANGLE = 78.2 Deg @ 2,301’ Casing Detail SIZE WT GRADE CONN ID in TOP(MD) BTM(MD) 28” Structural 27 Surface 490’ 13-3/8” 68 L-80 BTC 12.415 Surface 1,425’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 8,223’ 7” 26 L-80 DWCSR 6.276 8,022’ 10,498’ Tubing Detail 3-1/2” 9.3 L-80 H-503 2.992 Surface 6,809’ RKB to TBG Head = 78’.75 9 5/8” Casing in 12 ¼” Hole 13 3/8” in 17 ½” Hole 7” Liner in 8 1/2” Hole D-4 ECP Stage Collar 450-460 28” Conductor @ 480 Cement to ML @ 345’ 9 5/8 Hydraulic Stage Collar @ 6,050’ B-6 C-3 & C-5 D-6 D-16A D-16C Tagged fill @ 8,857’ D-3A D-2 A-2 A-3 B-1 TOC ±5000’ MD TOC in Tbg ±6700’ MD 1 2 3 4 5 6 7 8 9 10 11 12 Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Notes A-2 ±5,454’ ±5,534’ ±2,857’ ±2,904’ ±80’ Proposed A-3 ±5,746’ ±5,776’ ±3,027’ ±3,044’ ±30’ Proposed B-1 ±6,272’ ±6,322’ ±3,336’ ±3,365’ ±50’ Proposed B-6 6,916' 6,966' 3,713' 3,742' 50' 14 Isolated C-3 7,646' 7,660' 4,136' 4,144' 14'14 Isolated7,667' 7,678' 4,148' 4,155' 11' C-5 7,812' 7,840' 4,235' 4,257' 28' 14 Isolated D-2 8,493' 8,509' 4,685' 4,697' 16' 0 Isolated D-3A 8,626' 8,630' 4,790' 4,793' 4' 4 Isolated D-3A 8,648' 8,659' 4,808' 4,817' 11' 4 Isolated D-4 8,816' 8,821' 4,950' 4,954' 5' 4 Isolated D-6 9,000' 9,054' 5,104' 5,148' 54' 12 Abandoned D-16A 10,214' 10,226' 6,095' 6,105' 12' 12 Abandoned D-16C 10,268' 10,300' 6,139' 6,165' 32' 12 Abandoned Jewelry Detail No Depth MD Depth TVD OD ID Item 1 428' 428’ 5.125 2.813 TE-5 SSSV 2 1,638’ 1,499’ 5.250 2.992 SFO-1 GLM #1 3 3,103’ 1,946’ 5.250 2.992 SFO-1 GLM #2 4 4,662’ 2,397’ 5.250 2.992 SFO-1 GLM #3 5 5,690’ 2,994’ 5.250 2.992 SFO-1 GLM #4 6 ±6,735’ ±3,607’ Cement retainer 7 6,749’ 3,615’ 5.250 2.992 SFO-1 GLM #5 8 ±6,775’ ±3,631’ CIBP 9 6,809' 3,650’ 8.46 4.75 Upper SC-1 GP Packer 10 6,981' 3,751’ 8.46 4.75 Lower SC-1 GP Packer 11 7,854' 4,262’ 8.125 4.75 Model D Sump Packer 12 8,900' 5,020’ N/A N/A Model K-1 Cement Retainer Logging Detail Hole Section LWD/MWD Mud Logging Notes 17 ½” GR/Res Gas Detection, Mud Logging Consulting Geologist 12 ¼” GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist 8 ½” GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist Cement Retainer @ 8,900’ Steelhead Platform Well M-20 Completed 11-30-2009 Revised By: JLL 01/08/2020 SCHEMATIC MAX HOLE ANGLE = 78.2 Deg @ 2,301’ Casing Detail SIZE WT GRADE CONN ID in TOP(MD) BTM(MD) 28” Structural 27 Surface 490’ 13-3/8” 68 L-80 BTC 12.415 Surface 1,425’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 8,223’ 7” 26 L-80 DWCSR 6.276 8,022’ 10,498’ Tubing Detail 3-1/2” 9.3 L-80 H-503 2.992 Surface 6,809’ RKB to TBG Head = 78’.75 9 5/8” Casing in 12 ¼” Hole 13 3/8” in 17 ½” Hole 7” Liner in 8 1/2” Hole D-4 ECP Stage Collar 450-460 28” Conductor @ 480 Cement to ML @ 345’ 9 5/8 Hydraulic Stage Collar @ 6,050’ B-6 C-3 & C-5 D-6 D-16A D-16C Tagged fill @ 8,857’ D-3A D-2 Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Notes B-6 6,916' 6,966' 3,713' 3,742' 50' 14 7” Big Hole Charge. 56.5 gm C-3 7,646' 7,660' 4,136' 4,144' 14'14 7” Big Hole Charge. 56.5 gm7,667' 7,678' 4,148' 4,155' 11' C-5 7,812' 7,840' 4,235' 4,257' 28' 14 7” Big Hole Charge. 56.5 gm D-2 8,493' 8,509' 4,685' 4,697' 16' 0 Open D-3A 8,626' 8,630' 4,790' 4,793' 4' 4 Open D-3A 8,648' 8,659' 4,808' 4,817' 11' 4 Open D-4 8,816' 8,821' 4,950' 4,954' 5' 4 Open D-6 9,000' 9,054' 5,104' 5,148' 54' 12 Abandoned D-16A 10,214' 10,226' 6,095' 6,105' 12' 12 Abandoned D-16C 10,268' 10,300' 6,139' 6,165' 32' 12 Abandoned Jewelry Detail No Depth MD Depth TVD OD ID Item 1 428' 428’ 5.125 2.813 TE-5 SSSV 2 1,638’ 1,499’ 5.250 2.992 SFO-1 GLM #1 3 3,103’ 1,946’ 5.250 2.992 SFO-1 GLM #2 4 4,662’ 2,397’ 5.250 2.992 SFO-1 GLM #3 5 5,690’ 2,994’ 5.250 2.992 SFO-1 GLM #4 6 6,749’ 3,615’ 5.250 2.992 SFO-1 GLM #5 7 6,809' 3,650’ 8.46 4.75 Upper SC-1 GP Packer 8 6,981' 3,751’ 8.46 4.75 Lower SC-1 GP Packer 9 7,854' 4,262’ 8.125 4.75 Model D Sump Packer 10 8,900' 5,020’ N/A N/A Model K-1 Cement Retainer Logging Detail Hole Section LWD/MWD Mud Logging Notes 17 ½” GR/Res Gas Detection, Mud Logging Consulting Geologist 12 ¼” GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist 8 ½” GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist Cement Retainer @ 8,900’ Superseded Steelhead Platform Well M-20 Completed 11-30-2009 Revised By: JLL 08/27/21 PROPOSED MAX HOLE ANGLE = 78.2 Deg @ 2,301’ Casing Detail SIZE WT GRADE CONN ID in TOP(MD) BTM(MD) 28” Structural 27 Surface 490’ 13-3/8” 68 L-80 BTC 12.415 Surface 1,425’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 8,223’ 7” 26 L-80 DWCSR 6.276 8,022’ 10,498’ Tubing Detail 3-1/2” 9.3 L-80 H-503 2.992 Surface 6,809’ RKB to TBG Head = 78’.75 9 5/8” Casing in 12 ¼” Hole 13 3/8” in 17 ½” Hole 7” Liner in 8 1/2” Hole D-4 ECP Stage Collar 450-460 28” Conductor @ 480 Cement to ML @ 345’ 9 5/8 Hydraulic Stage Collar @ 6,050’ B-6 C-3 & C-5 D-6 D-16A D-16C Tagged fill @ 8,857’ D-3A D-2 A-2 A-3 B-1 TOC ±5000’ MD Perforation Data Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Notes A-2 ±5,454’ ±5,534’ ±2,857’ ±2,904’ ±80’ Proposed A-3 ±5,746’ ±5,776’ ±3,027’ ±3,044’ ±30’ Proposed B-1 ±6,272’ ±6,322’ ±3,336’ ±3,365’ ±50’ Proposed B-6 6,916' 6,966' 3,713' 3,742' 50' 14 Isolated C-3 7,646' 7,660' 4,136' 4,144' 14'14 Isolated7,667' 7,678' 4,148' 4,155' 11' C-5 7,812' 7,840' 4,235' 4,257' 28' 14 Isolated D-2 8,493' 8,509' 4,685' 4,697' 16' 0 Isolated D-3A 8,626' 8,630' 4,790' 4,793' 4' 4 Isolated D-3A 8,648' 8,659' 4,808' 4,817' 11' 4 Isolated D-4 8,816' 8,821' 4,950' 4,954' 5' 4 Isolated D-6 9,000' 9,054' 5,104' 5,148' 54' 12 Abandoned D-16A 10,214' 10,226' 6,095' 6,105' 12' 12 Abandoned D-16C 10,268' 10,300' 6,139' 6,165' 32' 12 Abandoned Jewelry Detail No Depth MD Depth TVD OD ID Item 1 428' 428’ 5.125 2.813 TE-5 SSSV 2 1,638’ 1,499’ 5.250 2.992 SFO-1 GLM #1 3 3,103’ 1,946’ 5.250 2.992 SFO-1 GLM #2 4 4,662’ 2,397’ 5.250 2.992 SFO-1 GLM #3 5 5,690’ 2,994’ 5.250 2.992 SFO-1 GLM #4 6 ±6,735’ ±3,607’ Cement retainer 7 6,749’ 3,615’ 5.250 2.992 SFO-1 GLM #5 8 ±6,775’ ±3,631’ CIBP 9 6,809' 3,650’ 8.46 4.75 Upper SC-1 GP Packer 10 6,981' 3,751’ 8.46 4.75 Lower SC-1 GP Packer 11 7,854' 4,262’ 8.125 4.75 Model D Sump Packer 12 8,900' 5,020’ N/A N/A Model K-1 Cement Retainer Logging Detail Hole Section LWD/MWD Mud Logging Notes 17 ½” GR/Res Gas Detection, Mud Logging Consulting Geologist 12 ¼” GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist 8 ½” GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist Cement Retainer @ 8,900’ Superseded Steelhead Platform M-20 Current 08/28/2021 Valve, Master, WKM-M, 3 1/8 5M FE, HWO, EE trim Valve, Upper master, SSV, WKM-M, 3 1/8 5M FE, HWO, w/ 15'’ operator, EE trim Valve, Swab, WKM-M 3 1/8 5M FE, HWO, EE trim BHTA, Otis, 3 1/8 5M FE x 3 1/2'’ Bowen quick union top Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'' operator 13 3/8'’ 9 5/8'’ 3 ½’’ Steelhead Platform M-20 28 x 13 3/8 x 9 5/8 x 3 1/2 Tubing hanger, Vetco-MB 242, 13 5/8 5M x 3 ½ 563 susp x 3.725 MCA lift, w/ 3'’ type H BPV profile, 2- ½ npt control line ports Starting head, Vetco MB-246, 20 ¾ 3M NT-2 top x 28'’ BW bottom, w/ 2- 3'’ LPO and 6'’ ANSI 600 outlets Multibowl system, Vetco MB-242, 13 5/8 5M Flanged top x 20 ¾ 3M NT-2 bottom, Coiled Tubing BOP SWAB VALVE MASTER VALVE HilcorpMonopod Rig 56Flow Diagram Fluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveAutomatic Choke Manual ChokePressure Gauge Knife ValveChoke LineP PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLDGAS BUSTER Panic LineC12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well: Trading Bay Unit M-20 (PTD 209-093) Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JAN 10 2010 1. Operations Abandon Ll Plug Perforations LJ Fracture Stimulate LJ Pull Tubing LJ Operations shutdown Li Performed: Suspend ❑ Perforate ❑� Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 2 Exploratory ❑ Stratigraphic ❑ Service ❑ 209-093 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20587-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 / ADL0017594 / ADL0018729 Trading Bay Unit M-20 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A McArthur River Field / Middle Kenai Gas Pool 11. Present Well Condition Summary: Total Depth measured 10,500 feet Plugs measured 8,850 feet true vertical 6,329 feet Junk measured N/A feet Effective Depth measured 8,850 feet Packer measured 6,809; 6,981; feet 7,854 true vertical 4,979 feet true vertical 3,650; 3,751; feet 4,262 Casing Length Size MD TVD Burst Collapse Structural Conductor 490' 28" 490' 490' Surface 1,425' 13-3/8" 1,425' 1,350' 5,020 psi 2,260 psi Intermediate Production 8,223' 9-5/8" 8,223' 4,498' 6,870 psi 4,760 psi Liner 2,476' 7" 10,498' 6,328' 7,420 psi 5,410 psi Perforation depth Measured depth 6,916 - 8,821 feet True Vertical depth 3,713 - 4,954 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3 / L-80 6,809 (MD) 3,650 (TVD) 428 (MD) Packers and SSSV (type, measured and true vertical depth) Packers (x3) See Schematic TE-5SSSV 428 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 153 0 150 12 Subsequent to operation: 0 187 0 80 12 14. Attachments (required per 20 arc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas Q WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 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: 319-531 Authorized Name: Dan Marlowe Contact Name: Dan Marlowe Authorized Title: Operations Mahiager Contact Email: dmarlowe(a?hilcoro.cora Authorized Signature: Date: 0I !f5 ZU2C7 Contact Phone: (907) 283-1329 Form 10-404 Revised 4/2017 E A 1,��,� !�/ /A cy BBDMS —25�JJAN 13 2020 Submit Original Only RKB to TBG Head = 78'.75 Cement to ML CP Stage :ollar45"60 " Conductor 480 (8" in 17 %' Hole SIB Hydraulic age Collar )50' ng in 12 YV fill @ 8,857' tainer Q 8,900' 1/2' Hole MAX HOLE ANGLE = 78.2 Deg @ 2,301' Steelhead Platform SCHEMATIC Well M-20 Completed 11-30-2009 Casing Detail SIZE WT GRADE CONN ID in TOP(MD) BTM(MD) 28" 428' Structural 27 Surface 490' 13-3/8" 68 L-80 BTC 12.415 Surface 1,425' 9-5/8"47 3,103' L-80 1 all8.681 Surface 8,223' 7" 26 L-80 DWCSR 6.276 8,022' 10,498' 5 5,690' 2,994' Tubing Detail 2.992 SFO -1 GLM #4 3-1/2" 9.3 L-80 H-503 2.992 Surface 6,809' Jewelry Detail No Depth MD Depth TVD OD ID Item 1 428' 428' 5.125 2.813 TE -S SSSV 2 1,638' 1,499' 5.250 2.992 SFO-1GLM#1 3 3,103' 1,946' 5.250 2.992 SFO -1 GLM#2 4 4,662' 2,397' 5.250 2.992 SFO -1 GLM#3 5 5,690' 2,994' 5.250 2.992 SFO -1 GLM #4 6 6,749' 3,615' 5.250 2.992 SFO -1 GLM#5 7 61809' 31650' 8.46 4.75 Upper SC -1 GP Packer 8 6,981' 3,751' 8.46 4.75 Lower SC -1 GP Packer 9 7,854' 4,262' 8.125 4.75 Model D Sump Packer 10 8,900' 5,020' N/A N/A Model K-1 Cement Retainer Logging Detail Hole Section LWD/MWD Mud Logging Perforation Data 17'x" GR/Res Zone Top (MD) (MD) Top (ND) ( NDfin) Amt SPF Notes B-6 6,916' 6,966' 3,713' 1 3,742' 50' 14 7" Big Hale Charge. 56.5 gm C-3 7,646' 7,fi67' 7,660' 7,678' 4,136' 4,14 8' 4,144' 4,155' 14'14 11 ' 7" Big Hole Charge. 56.5 gm C-5 7,812' 7,840' 4,235' 4,257' 28' 14 7" Big Hole Charge. 56.5 gm D-2 8,493 8,509 4,685' 4,697' 16 0 Open D -3A 8,626' 8,630' 4,790' 4,793' 4' 4 Open D -3A 8,648' 8,659' 4,808' 4,817' 11' 4 Open D-4 8,816' 8,821' 4,950' 4,954' 5' 4 Open D-6 9,000' 9,054' 5,104' 5,148' 54' 12 Abandoned D -16A 10,214' 10,226' 6,095' 6,105' 12' 12 Abandoned D -16C 1 10,268' 10,300' 6,139' 6,165' 32' 12 Abandoned Logging Detail Hole Section LWD/MWD Mud Logging Notes 17'x" GR/Res Gas Detection, Mud Logging Consulting Geologist 12 V GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist 8 34" GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist Revised By: JILL 01/08/2020 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Trading Bay Unit M-20 Eline 50-733-20587-00-00 1 209-093 12/13/19 12/16/19 Daily Operations: 12/13/19 - Friday ARRIVE ON PLATFORM. PRE JOB SAFEFY MEETING, PERMIT, -SA. GO OVER JOB SCOPE. MOVE EQUIPMENT, PULL HATCHES. PRESSURE TEST TO 250 LOW, 1500 HIGH, TEST GOOD. RIH W/ R5, RB, STEM, RB, KJ, RB, OJ, SSSJ. RB W/ 12' DUMMY GUNS W/ RB ON BOTTOM TO 2454'KB, STOPS, PULL UP TO SSSV 3 MORE TIMES STOPPING AT SAME SPOT. POOH TALK W/ PRODUCTION. RIH W/ 6' OF DUMMY GUNS TO 2406'KB, PULL UP TO 500'. RIH TO 2804'KB W/T 3084'KB CAN NOT PASS, PULL TO 500'4 MORE TIMES STOPPING AT 2430', 2390', 2375', 2666'KB. POOH TALK W/ PRODUCTION - ADD 5' STEM, CUT 5' WIRE RETIE ROPE SOCKET. RIH W/ 6' DUMMY GUNS 3 TIMES FROM 500' TO 2300', 2375', 2320'KB POOH. LAY DOWN LU B. SECURE WELL. CLEAN UP AREA. 12/14/19 -Saturday MORNING MEETING, JSA, PERMIT. GO OVER JOB. REHEAD, PICK UP LUB. FILL 30'x 41/2 RISER W/ DIESEL. SHUT IN WELL. RIH W/ 2.50" x 6' DD BAILER TO 8774'KB POOH - HAND FULL OF POSSIBLY SCALE OR COAL. RIH W/ 2.50" x 12' DUMMY GUNS W/ ROLLER BOG1E ON BOTTOM TO 856VK13 POOH. RIG DOWN, SECURE RISER, CLEAN UP AREA, STAND BY FOR FLIGHT. 12/15/19 - Sunday Steelhead Orientation / / Safety Meeting. Start Rig Up. PT L:250 H:1500. RIH Gun 1 Attempt 1 (RS, RB, 7' WB, RB, TITAN GAMMA, RB,, 10' G N, SL -RB), tagged/ multiple attempts made at various speeds up to 550 fpm. POOH. OOH / MU toolstring. RIH Gu ttempt 2 (RS, RB, 7'WB, RB, K, TITAN GAMMA, RB, 6' GUN, SL -RB), tagged / multiple attempts made at various speeds up to 550 fpm. POOH to dump diesel. OOH / Filling riser with diesel. RIH Gun 1 Attempt 3 (same toolstring as attempt 2), tagged / multiple attempts made at various see to 550 fpm. POOH. OOH / MU toolstring. RIH Gun 1 Attempt 4 (RS, 5'WB, RB, 7' , WB, RB, K, TITAN GAMMA, R 6' GUN SL -RB), tagged in multiple spots from 2300 to 2400 at various speed up to 550 fpm. POOH. OOH / Fill riser comp) ull of diesel and drop as we MU next toolstring. RIH Gun 1 Attempt 5 (RS, 7' WB, RB, K, 5'WB, 5'WB, RB, K, TITAN GAMMA, RB, 5' GUN, K, SL -RB), tagged in multiple spots from 2300 to 2400 at various speed up to 550 fpm. POOH. OOH / MU toolstring. RIH Gun 1 Attempt 6 (RS, 5'WB, RB, K, 5'WB, RB, K, TITAN GAMMA, RB, K, 6' GUN, SL -RB), tagged in multiple spots from 2300 to 3200 but kept attempting up to 575 fpm. Made it past 70 degree deviation. Main tight spots around 2300, 2900, 3200, worst at 3400. (600 fpm). Correlation Log from 8500 to 7800. Log sent to town. Shot / POOH. OOH/ Rig Down. 12/16/19 - Monday PTW / Safet `Uleeting. Start Rig Up / Drop Diesel. RIH Gun 2 Attempt 1 (RS, 5'WB, RB, K, 5'WB, RB, K, TITAN GAMMA, RB, K, 0' GU ; SL -RB), tagged in multiple places from 2500-3213 at speeds up to 600 fpm. POOH. OOH / Fill Riser with diesel, put on night cap and drop diesel. RIH Gun 2 Attempt 2 (same toolstring as attempt 1), made it through multiple tight spots, the worst at 3400', running at 630 fpm. Correlation Log from 8550 to 7800. Log sent to town. Pull into position, Shot / POOH. OOH / Rig Down. THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai Gas Pool, TBU M-20 Permit to Drill Number: 209-093 Sundry Number: 319-531 Dear Mr. Golis: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jerem . Price Chair DATED thisZ day of November, 2019. clBDMS—K7'j NOV 2 7 2019 RECEIVED NOV 2 0 2019 A®GCC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 95 Zan 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 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: Hilcorp Alaska, LLC Exploratory ❑ Development FZ] • Stratigraphic ❑ Service ❑ 209-093 . 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20587-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A Will planned perforations require a spacing exception? Yes ❑ No Q Trading Bay Unit M-20 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018736 / ADL0017594 / ADL0018729 McArthur River Field /Middle Kenai Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,500 6,329 8,850 4,979 109 psi 8,850 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 490' 28" 490' 490' Surface 1,425' 13-3/8" 1,425' 1,350' 5,020 psi 2,260 psi Intermediate Production 8,223' 9-5/8" 8,223' 4,498' 61870 psi 4,760 psi Liner 2,476' 7" 10,498' 6,328' 7,420 psi 5,410 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,916 - 8,821 3,713 - 4,954 3-1/2" 9.3 / L-80 6,809 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): SC -1 GP Packer (x2) Model D Sump Packer & TE-5SSSV 6,809 (MD) 3,650 (TVD) / 6,981 (MD) 3,751 (TVD) 7,854 (MD) 4,262 (TVD) & 428 (MD) 428 (TVD) 12. Attachments: Proposal Summary ❑' Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/15/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS Q • WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowf hllcor .Cam \ Contact Phone: (907) 283-1329 �cw- it 9 Authorized Signature: t/LJ Date: I t � 19 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1130IMSW-�J NOV 2 7 2019 Post Initial Injection MIT Req'd? Yes E]No ❑ Spacing Exception Required.? p g p q Yes No Subsequent Form Required: APPROVED BY Approved by. VV17FMI hl &JECOMMISSION Date: v4�r%J# L. A/1/ 7 i9 c9nn Submit Form and F 10-403 Revi ea 4/ 17 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate N Hik.p Alaelm, LLC Well Work Prognosis Well Name: Trading Bay Unit M-20 API Number: 50-733-20587-00 Current Status: Gas Well Leg: A-1 (SW corner) Estimated Start Date: 12/15/2019 Rig: E -Line Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 209-093 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Stan Golis Office: 907-777-8356 Current Bottom Hole Pressure: <480 psi @ 3,713' TVD 0.129 psi/ft (2.49 ppg) 2009 RFT Data Maximum Expected BHP: x480 psi @ 3,713' TVD 0.129 psi/ft (2.49 ppg) 2009 RFT Data Maximum Potential Surface Pressure: 109 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) "Well to be perforated while Flowing Brief Well Summary: Well M-20 is a gas well completed in the B, C, & D Sands. This project will add additional perforations in the D-2 Sand. E -line Procedure: 1. MIRU E -line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e -line guns and perforate with well flowing per program. 3. RD E -line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Steelhead Platform SCHEMATIC Well M-20 Hileo.p AloeL.. LLC Completed 11-30-2009 RKB to TBG Head = 78'.75 Cement to ML Q 345' CP Stage )ollar450460 ° Conductor 480 '8" in 17 Y2' Hole ./8 Hydraulic Ige Collar @ 5D' ng in 12 A' A] @ 8,857' amer @ 8,900' V2" Hole MAX HOLE ANGLE = 78.2 Deg @ 2,301' Casine Detail SIZE WT GRADEaDWCSR ID in TOP(MD) BTM(MD) 28" 428' Structural27 5.125 Surface 490' 133/8" 68 L-80 12.415 Surface 1,425' 9-5/8" 47 L-80 8.681 Surface 8,223' 7" 26 L-80 6.276 8,022' 10,498' 5 5,690' 2,994' Tubing Detail 2.992 SFO -1 GLM#4 3-1/2" 9.3 L-80 H-503 2ti Surface 6,809' Jewelry Detail No Depth MD Depth TVD OD ID Item 1 428' 428' 5.125 2.813 TE -5 SSSV 2 1,638' 1,499' 5.250 2.992 SFO -1 GLM#1 3 3,103' 1,946' 5.250 2.992 SFO -1 GLM#2 4 4,662' 2,397' 5.250 2.992 SFO -1 GLM #3 5 5,690' 2,994' 5.250 2.992 SFO -1 GLM#4 6 6,749' 3,615' 5.250 2.992 SFO -1 GLM #5 7 6,809' 3,650' 8.46 4.75 Lipper SC -1 GP Packer 8 6,981' 3,751' 8.46 4.75 Lower SC -1 GP Packer 9 7,854' 4,262' 8.125 4.75 Model D Sump Packer 10 8,900' 5,020' N/A N/A Model K-1 Cement Retainer Loagine Detail Hole Section LWD/MWD Mud Logging Perforation Data 17 Y:" GR/Res Zone ) (MD) (TVD) Btm (TVD) Amt SPF Notes B-6 Consulting Geologist 6,966' 3,713' 3,742' 50' 14 7" Big Hole Charge. 56.5 gm C3 M7,6671 7,660' 7,678' 4,136' 4,148' 4,144' 4,155' 14' 11'GS 14 7" Big Hole Charge. 56.5 gm 7,840' 4,235' 4,257' 28' 14 7" Big Hole ChargD-3A8,630' 4,790' 4,793' 4' 4D -3A8,659' 4,808' 817''Top D-4 8,821' 4,950'S4 Open D-6 9,054' 5,104' 5,148' 54' 12 Abandoned D -16A 10,214' 10,226' 6,095' 6,105' 12' 12 Abandoned D -16C 10,268' 10,300' 6,139' 6,165' 32' 12 Abandoned Loagine Detail Hole Section LWD/MWD Mud Logging Notes 17 Y:" GR/Res Gas Detection, Mud Logging Consulting Geologist 12 Y.." GR/Res/ Dens-Neut, PWDVib Gas Detection, Mud Logging Consulting Geologist 8'h" GR/Res/ Dens-Neut, PWD)/ib Gas Detection, Mud Logging Consulting Geologist Revised By: JLL 11/15/19 Stee PROPOSED Well eadPlatform Well M-20 ffik,.Ai-k. "` Completed 11-30-2009 RKB to TBG Head = 78'.75 Cement to ML 345' CP Stage ollar 450-460 ' Conductor 480 8' in 17 54 Hole 18 Hydraulic age Collar 50' ,g in 12'/,° ill @ 8,857' Rimer @ 8,900' 12" Hole MAX HOLE ANGLE = 78.2 Deg @ 2,301' Casine Detail SIZEJ26 Depth MD GRADE CONN ID in TOP(MD) BTM MID) 28"Structural 428' 428' 27 Surface 490' 13-3/8" 1,638' L-80 BTC 12.415 Surface 1,425' 9-5/8" 3,103' L-80 BTC -M 8.681 Surface 8,223' 7" 4,662' L-80 DWCSR 6.276 1 8,022' 10,498' 5 5,690' 2,994' Tubing Detail 2.992 SFO -1 GLM#4 3-1/2" 9.3 L-80 H-503 2.992 Surface 6,809' Jewelry Detail No Depth MD Depth TVD Do ID Item 1 428' 428' 5.125 2.813 TE -5 SSSV 2 1,638' 1,499' 5.250 2.992 SFO -1 GLM#1 3 3,103' 1,946' 5.250 2.992 SF0-1 GLM#2 4 4,662' 2,397' 5.250 2.992 SFO -1 GLM#3 5 5,690' 2,994' 5.250 2.992 SFO -1 GLM#4 6 6,749' 3,615' 5.250 2.992 SFO -1 GLM#5 7 6,809' 3,650' -8-4-61-4-7N Upper SC -1 GP Packer 8 6,981' 3,751' 8.46 4.75 Lower SC -1 GP Packer 9 7,854' 4,262' 8.125 4.75 Model D Sump Packer 10 8,900' 5,0217 N/A N/A Model K-1 Cement Retainer Loeeim Detail Hole Section LWD/MWD Mud Logging Perforation Data 17 %" GR/Res Zone Tap (MD) (MD) (TVD) (TVD) Amt SPF Notes B-6 6,916' 6,956' 3,713' 3,742' 50' 14 7" Big Hole Charge. 56.5 gm C-3 7.646' 7,667' 7,660' 7,678' 4,136' 4,148' 4,144' 4,155' 14' 11' 14 7" Big Hole Charge. 56.5 gm C-5 7,812' 7,840' 4,235' 4,257' 28' 14 7" Big Hole Charge. 56.5 gm D-2 --F--3A 4-8,493' ±8,509' ±4,685' ±4,697' 16' 0 PROPOSED 8,626' 8,630' 4,790' 4,793' 4' 4 Open D -3A 8,648' 8,659' 4,808' 4,817' 11' 4 Open D-4 8,816' 8,821' 4,950' 4,954' S' 4 Open D-6 9,000' 9,054' 5,104' 5,148' S4' 12 Abandoned D -16A 10,214' 10,226' 6,095- ,095' 6,105' 12' 12 Abandoned D D -16C 10,268' 10,300' 6,139' 6,165' 32' 12 Abandoned Loeeim Detail Hole Section LWD/MWD Mud Logging Notes 17 %" GR/Res Gas Detection, Mud Logging Consulting Geologist 12'/." GR/Res/ Dens-Neut, PWD Vila Gas Detection, Mud Logging Consulting Geologist 8 Y" GR/Res/ Dens-Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist Revised By: JLL 11/15/19 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate 0 Other ❑ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WOO 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development CI Exploratory ❑ 209 -093 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99516 50- 733 - 20587 -00 -r j ' ®� 7. Property Designation (Lease N Jmber): 8. Well Name and Number: 7r ADL0018730 / ADL0017594 / ADL0018729 ' Trading Bay Unit M -20 r DE (' 14 2012 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A McArthur River Field / Middle Kenai Gas AOGCC 11. Present Well Condition Summary: Total Depth measured 10,500 feet Plugs measured 8,850 (cement) feet true vertical 6,329 feet Junk measured N/A feet Effective Depth measured 8,850 feet Packer measured See Schematic feet true vertical 4,979 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 490' 28" 490' 490' Surface 1,425' 13 -3/8" 1,425' 1,350' 5,020 psi 2,260 psi Intermediate • •. »•. +. Production 8,223' 9 -5/8" 8,223' 4,498' 6,870 psi 4,760 psi Liner 2,476' 7" 10,498' 6,328' 7,240 psi 5,410 psi Perforation depth Measured depth See Schematic feet FEB 8 2013 True Vertical depth See Schematic feet SCANNED B 2 8 Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# / L -80 6,127' (MD) 3,249' (TVD) (2) SC -1 GP Packers 6,809'; 6,981'; 7,854' (MD) ' Packers and SSSV (type, measured and true vertical depth) Model D Sump Packer 3,650'; 3,751'; 4,262' (TVD) TE -5 SSSV 449' (MD) / 449' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 226 0 150 104 Subsequent to operation: 0 1,683 0 110 65 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 1151 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ . Gasp WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Ted Kramer Email tkramer @hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature Phone 907 777 -8420 Date 12/14/2012 Form 10-404 Revised 10/20 F m r�'h DEC 1 7 1x it Afig) CZ • /P •ili Submit Original Only 7;t4P4-.‘4"--. • • Hilcorp Alaska, LLC Hileorp Alaska, LLC Well Operations Summary Well Name API Number IWell Permit Number Start Date End Date M -20 50- 733 - 20587 -00 209 -093 11/30/2012 12/2/2012 1 30/1 - riday Rig up lubricator. Pressure test to 250 psi low and 2,500 psi high. RIH with 2- 1/2 "x5' DD bailer with roller boogies and tagged fill at 8,857' RKB . POOH. RIH with 2 -1/2 "x10' spent dummy guns and tag fill at 8,857' RKB. POOH. Rig down slick line. 12/01/12 - Saturday Rig up lubricator. Put new cable head on. Pressure test to 250 psi low and 2,500 psi high. RIH with 2- 1/2 "x5' HC, 4 spf, 60 deg phase, 1 wt bar, CCL /GR with 3 roller boogies spaced out along tool string. Work ed tools from 2,100' to 3,286' and could not go any deeper. From 2,089' to 4,107' it's 70 to 77 degree angle. POOH. Add another weight bar and roller boogie. RIH with 2- 1/2 "x5' HC, 4 spf, 60 deg phase and tie into composite log provided by Radu Girbacea. Spot perf gun from 8,816' to 8,821'. Tubing pressure 169 psi. Fired guns and didn't see any pressure increase. POOH. RIH with 2 -1/2 "x15' (11' loaded) HC, 4 spf, 60 deg phase, 2 wt bars, CCL /GR with 4 roller boogies spaced out along tool string and could not get tools to go past 3,235'. POOH and drop a wt bar and see if the 5' off the length helps. RIH with 2 -1/2 "x15' (11' loaded) HC, 4 spf, 60 deg phase, 1 wt bars, CCL /GR with 4 roller boogies spaced out thru tool string and couldn't get past 3,100'. Ordered out 5' guns. Tubing pressure has come up to 240 psi since first gun run. POOH. Rig for stand -by. Waiting on guns from Pollard. 1 'fit. _ : Ada :` V Unload 11' gun and load 5' perf gun. Pressure test to 250 psi low and 2,500 psi high. All perf zones were from Final Approved Perf Request Form by R.Girbacea. RIH with 2- 1/2 "x5' HC, 4 spf, 60 deg phase, CCL/GR, 1 wt. bar and tie into composite log provided by Radu Girbacea. Spot perf gun from 8,659' to 8,653.5'. Tubing pressure 204 psi. Fired guns and didn't see any pressure increase. POOH. All shots fired. Pressure starts to increase after 5 or 10 min after perf. Pressure went up to 240 psi. 5' perf gun can be loaded to perf approx 5.5'. (D3A Sand) RIH with 2- 1/2 "x5' HC, 4 spf, 60 deg phase, CCL /GR, 1 wt. bar and tie into composite log provided by Radu Girbacea. Spot perf gun from 8,653.5' to 8,648'. Tubing pressure 209 psi. Fired guns and didn't see any pressure increase. POOH. All shots fired. (D3A Sand). RIH with 2- 1/2 "x5' (4' loaded) HC, 4 spf, 60 deg phase, CCL /GR, 1 wt. bar and tie into composite log provided by Radu Girbacea. Spot perf gun from 8,626' to 8,630'. Tubing pressure 204 psi. Fired guns and didn't see any pressure increase. POOH. All shots fired. (D3A Sand) Rig lubricator off well. • Steelhead Platform SCHEMATIC Well M -20 Hilro,p Alaska, LU: Completed 11 -30 -2009 Casing Detail RKB to TBG Head = 78'.75 SIZE WT GRADE CONN ID in TOP(MD) TOP(TVD) BTM(MD) BTM(TVD) 28" Structural 27 Surface Surface 490' 490' . 13 -3/8" 68 L -80 BTC 12.415 Surface Surface 1,425' 1,352' CementtoML 9 -5/8" 47 L -80 BTC -M 8.681 Surface Surface 8,223' 4,498' .4--- @ 345' 7" 26 L -80 DWCSR 6.276 8,022' 4,368' 10,498' 6,328' Tubing Detail A ECP Stage Collar 450A60 1 3 1 9.3 1 L - 80 H - 503 1 2.992 1 Surface ( Surface 1 6127' 3,249' 28" Conductor @ 480 Jewelry Detail No Item Depth MD OD ID Notes 1 TE - 5SSV 449' 5.39 2.94 2 SFO -1 GLM 1,643' 5.31 2.87 3 SFO -1 GLM 3,109' 5.31 2.87 L 13 3/8 in 17 %" Hole 4 SFO -1 GLM 4,636' 5.31 2.87 5 SFO -1 GLM 5,664' 5.31 2.87 6 SFO -1 GLM 6,723' 5.31 2.87 7 Upper SC -1 GP Packer 6,809' 8.46 4.75 1 8 Lower SC -1 GP Packer 6,981' 8.46 4.75 Model D Sump 1 9 5/8 Hydraulic 9 7,854' 8.125 4.75 1 4 Stage Collar © Packer MMM 6050' Model K -1 Cement 10 Retainer 8,900' N/A N/A • Perforation Data ., Zone MD TVD SPF Notes B� B -6 6,916'-6,966' 3713' - 3742' 14 7" Big Hole Charge. 56.5 gm 7,646'- 7,660' 4136'- 4144' {stir 'r C -3 14 7" Big Hole Charge. 56.5 gm ',VN/ .,, . C - & C - 7,667- 7,678' 4148' - 4155' g C -5 7,812'- 7,840' 4235' - 4257 14 7" Big Hole Charge. 56.5 gm r t..,., . � 4tY a 1 It� D -3A 8,626' - 8,630' 4,790' - 4,793' 4 Open D -3A 8,648'- 8,659' 4,808'- 4,817' 4 Open D -4 8,816' - 8,821' 4,950' - 4,954' 4 Open D -6 9,000' - 9,054' 5,104' - 5,148' 12 Abandoned D -16A 10,214' - 10,226' 6,095' - 6,105' 12 Abandoned • ■ D -16C 10,268' - 10,300' 6,139'- 6,165' 12 Abandoned 9 5/8" Casing in 12 W Hole D -3A D-4 * '''' Tagged fill @ 8,857' Logging Detail Hole Section LWD /MWD Mud Logging Notes ■ - t Cement Retainer © 8,900' 17 'A" GR /Res Gas Detection, Mud Logging Consulting Geologist 1 t= 12''4" GR /Res/ Dens -Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist D 8' /" GR /Res/ Dens -Neut, PWD Vib Gas Detection, Mud Logging Consulting Geologist D -16A D -16C 7" Liner in 8 1/2" Hole MAX HOLE ANGLE = 78.2 Deg @ 2,301' Revised By: JLL 12/10/2012 DATA SUBMITTAL COMPLIANCE REPORT 4/27/2011 Permit to Drill 2090930 Well Name /No. TRADING BAY UNIT M -20 Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20587 -00 -00 MD 10500 TVD 6329 Completion Date 11/30/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION - ■ Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR, RES, DEN / NEU, MUD LOG (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type_ - Med /Frmt Number Name Scale Media No Start Stop CH Received Comments 13pt Report: Final Well R Open 1/26/2010 Final Well Report, Tab of Cont, Equip & Crew, Well Det, Geo Data, Drill Data, Daily Reps D C 19215c- Final Well R 480 10500 Open 1/26/2010 Final Well Report, Tab of Cont, Equip & Crew, Well Det, Geo Data, Drill Data, Daily Reps Log Mud Log 2 Col 480 10500 Open 1/26/2010 MD Formation L9g' Mud Log 2 Col 480 10500 Open 1/26/2010 TVD Formation 1 Log/ Mud Log 2 Col 480 10500 Open 1/26/2010 MD Combo Log Log,- Mud Log 2 Col 480 10500 Open 1/26/2010 TVD Combo Log Log Mud Log 2 Col 480 10500 Open 1/26/2010 MD Gas Ratio 1 Log 7 Mud Log 2 Col 480 10500 Open 1/26/2010 TVD Gas Ratio kog Mud Log 2 Col 480 10500 Open 1/26/2010 MD Drilling Dynamics • Lob Mud Log 2 Col 480 10500 Open 1/26/2010 TVD Drilling Dynamics Ra Analysis - Misc 0 0 Open 1/26/2010 DCS Anal Report Log Corr tion 5 Blu 8534 10377 Case 1/26/2010 Correlation Log, , GR, tffD C Pds 19216 orrelation 8534 10377 Case 1/26/2010 Correlation Log, GR, CCL j Induction /Resistivity 2 Col 380 10474 Open 1/26/2010 TVD Vision Service "'Log Induction /Resistivity 5 Col 380 10474 Open 1/26/2010 TVD Vision Service Log Induction /Resistivity 2 Col 380 10474 Open 1/26/2010 MD Vision Service J Log Induction /Resistivity 5 Col 380 10474 Open 1/26/2010 MD Vision Service DATA SUBMITTAL COMPLIANCE REPORT 4/27/2011 Permit to Drill 2090930 Well Name /No. TRADING BAY UNIT M -20 Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20587 -00 -00 MD 10500 TVD 6329 Completion Date 11/30/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N C Las 19813 Induction /Resistivity 378 10490 Open 6/29/2010 Final, Mud, Survey in DLIS, LAS and PDS graphics Log Porosity 5 Col 1400 7960 Open 9/13/2010 Accelorator Poro Sonde, GR, Tractor ,--.8b C Dls 20120 - orosity 1400 7960 Open 9/13/2010 Accelorator Poro Sonde, GR, Tractor Plus PDS graphics file Log Cement Evaluation 5 Col 140 7990 Case 9/13/2010 USIT, CCL, GR, CEL, ill Tractor D C Dls 2012ment Evaluation 140 7990 Case 9/13/2010 USIT, CCL, GR, CEL, Tractor plus PDS graphics '' file 4 E0 C Las 20938 nl duction /Resistivity 378 10499 Open OH LAS & DLIS data, OH Log Graphics data, Dir Survey data, (/kpt Directional Survey 0 10500 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y'A N } Daily History Received? N Chips Received? Y 141- -- L_ Formation Tops 1' N III Analysis 4 / N Received? Comments: Compliance Reviewed By: l'-'-ls Date: l? _(1 y %� !/w 1 1 • Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 "` Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcastro @chevron.com DATE September 9, 2010 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste #100 Anchorage, AK 99501 DATA TRANSMITTAL WELL LOG TYPE LOG DATE INTERVAL B- CD LOGGED LINE TBU M -20 USIT 2/19/2010 1400 -7990 X X TBU M -20 APS- GR- TRACTOR 2/19/2010 1400 -7960 X X 36 , 3 go` , E . , ff . _ i 7 -- - L2 r - ‘ Please acknowledge receipt by signing and returning one copy of this transtri tb 828. Received By: Date: `v „ -, - a..- ! Aleakz, Dii ..,,. 3,s3 . (;7:171,77,-),,sikin • . Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE June 28, 2010 To: AOGCC Mahnken, Christine R ;✓ _ '.' 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 Aaska 7 3 3 DATA TRANSMITTAL Transmitted herewith is one DVD containing the following data • D -48L1 �� • Formation evaluation logs - LAS f'j . 0 ? • Gamma ray logs - LAS �� • K -12RD2 oo - t ( ! • K- 12RD2Final_Survey.xls • K- 12RD2__Tops.xlsx Out _D • MPR -Gamma ray logs - LAS, CGM, PDF • K -18RD cg©! - /l /9t16 • K- 18RD_Final_Survey.doc • Density Neutron logs - LAS b _ / 9156 t • K- 18RDPB1 • UBI log - LAS, PDS, DLIS aD '5.- y Z5b, • survey.xls / 9 /� • K -24RD2 �a3` /tS0 • Density Neutron logs - LAS • Final Mudlog Report - LAS, DOC ODD '!c9 6 / 9 $/( • M -06 • Final Togs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS • M -10 c9011 a- /5 tya • M- 10Tops.xlsx • USIT log - PDS 069 -0 5' 3 /9 n3 • Final logs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS • M -10PB1 • Final logs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS • M -16RD /9'9 - b U / Zl • M- 16RD_Tops.xlsx • Final logs; Cement Bond Log, Completion Record -PDS • M -17 • M- 17_Tops.xlsx • M17_MWD_Survey.pdf • Final Mudlog Report - LAS, DOC, DBF, MDX, PDF, DAT • Final logs; Depth, Formation Evaluation, Cement Bond, Plug Setting, Perforation - LAS, PDS, DLIS, TIFF Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: / Date: ip STATE OF ALASKA ALASK L AND GAS CONSERVATION COMMISS .J GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. Test: 0 Initial ❑ Annual ❑ Special 1b. Type Test: ❑ Stabilized ❑ Non Stabilized 0 Multipoint ❑ Constant Time 0 Isochronal ❑ Other 2. Operator Name: 5. Date Completed: 11. Permit to Drill Number: Union Oil Company of California 3/26/2010 209 -0930 3. Address: 6. Date TD Reached: 12. API Number: PO Box 196247, Anchorage, AK 99519 March 4, 2010 50- 733 - 20587 -00 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): 13. Well Name and Number: Surface: 1,052'FNL. 464' FWL, Sec 33, T9N, R13W, S.M. 160' Steelhead M -20 Top of Productive Horizon: 8. Plug Back Depth(MD +TVD): 14. Field /Pool(s): 1097' FNL, 266'FEL, Sec 32, T9N, R13W, S.M. 10,415' MD (6,260' TVD) McArthur River Field Total Depth: 9. Total Depth (MD + TVD): Middle Kenia Gas Pool 994' FNL, 421'FEL, Sec 6, T8N, R13W, S.M. 10,500' MD (6,329' TVD) 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 214069.33 y- 2499459.80 Zone- 4 N/A ADL 18730 [Steelhead Platform] TPI: x- 213349.72 y- 2499424.17 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 211859.46 y- 2494282.34 Zone- 4 perforated casing 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 7" 26 6.276 10,498 6916 MD 6966 MD 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. 7646 MD 7660 MD 3.5" 9.3 2.992 6809 7812 MD 7840 MD 20. Packer set at ft: 21. GOR cf /bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): 6809 NA NA NA 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): 0 Tubing ❑ Casing 113 F° 734 psia @ Datum 4200 TVDSS 14.7 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO % N % H Prover: Meter Run: Taps: NA NA 0.56 0 0 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line )( Orifice psig Hw F psig F psig F Hr. Size (in.) Size (in.) 1. X 646 59 2. X 543 59 4 3. X 495 60 4 4. X 430 60 4 5. X 200 56 4 Basic Coefficient Flow Temp. Super Comp. ) Pressure Gravity Factor Rate of Flow (24-Hour) 24 -Hour hw m Pm Factor F Factor Q Mcfd Fb or Fp Ft 9 Fpv 1. 0 2. 4000 3, 5010 4. 5910 5. 7800 Temperature for Separator for Flowing No. Pr Tr z Gas Fluid T Gg G 1. 519 1.51312 0.918 2. 0.806835067 519 1.51312 0.929 3. 0.73551263 520 1.516035 0.934 Critical Pressure 673 4. 0.638930163 520 1.516035 0.941 Critical Temperature 345 5. 0.29717682 516 1.504373 0.97 ABDt S K T 11 Form 10 -421 Revised 1/2004 CONTINUED ON REVERSE SIDE Submit in Duplicate Pc 660.7 pc 436524.49 1 734 p 538756 No. Pt Pt Pc Pw Pw Pc Ps Ps Pf -Ps 1. 2. 557.7 311029.29 125495.2 113.3 12836.89 423687.6 671 450241 88515 3. 509.7 259794.09 176730.4 142.3 20249.29 416275.2 652 425104 113652 4. 444.7 197758.09 238766.4 179.3 32148.49 404376 624 389376 149380 5. 214.7 46096.09 390428.4 342.3 117169.29 319355.2 557 310249 228507 25. AOF (Mcfd) 13,594 n 0.663 Remarks: I hereby certi th ./h or= •/• ing is true and correct to the best of my knowledge. 5 Signed g _A(elm� Title Petroleum Engineer Date 5/6/2010 w / / DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd / -1 hwPm Fp Basic critical flow prover or positive choke factor Mcfd /psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= 1/Z dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air dimensionless Gg Specific gravity of separator gas (air= 1.00), dimensionless GOR Gas -oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back - pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut -in wellhead pressure, psia Pf Shut -in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells , Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10 -421 Revised 1/2004 Side 2 ilti►C1vCL AAA- } STATE OF ALASKA o f ofr f zoto APR 0 2 2010 ALASKA AND GAS CONSERVATION COMMISSI N AlaskaollaGascons.c OF SUNDRY WELL OPERATIONS 1. Operations Ab "IFS:: Repair Well 11 Plug Perforations U Stimulate [1 Other U Perform 3 Stage Gravel Pack Performed: Alter Casing ❑ Pull Tubing El Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program 1=1 Operat. Shutdown ❑ Perforate 1=1 Re -eKter Suspended Well ❑ 2. Operator Union Oil Company of Califomia 4. Well Class Before Work: ` 1. Permit to Drill Number: Name: Development El Exploratory ❑ 209 -0930 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ ', API Number: 50- 733 - 20587 -00 7. Property Designation (Lease Clumber): 8. Well Name AO Number: ADL017594, ADL018729, ADL018730 [Steelhead Platform] Trading Bay Unit M -20 9. Field /Pool(s): McArthur River Field / Middle Kenai Gas Pool 10. Present Well Condition Summary: Total Depth measured 10,500 feet Plugs (measured) 8,850 (cement) feet true vertical 6,329 feet Junk (measured) N/A feet Effective Depth measured 8,850 feet Packer (measured) 6,809', 6,981', 7,854' feet true vertical 4,979 feet (true vertical) 3,650', 3,751', 4,262' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 490' 2 - 3 2 " 490' 490' Surface 1,425' 13 -3/8" 1,425' 1,352' 5,020 psi 2,260 psi Intermediate Production 8,223' 9 -5/8" 8,223' 4,498' 6,870 psi 4,760 psi Liner 2,476' 7" 10,498' 6,328' 7,240 psi 5,410 psi Perforation depth: Measured depth: 6,916'- 6,966', 7,646'- 7,660', 7,667'- 7,678', 7,812'- 7,840' True Vertical depth: 3,71X-3,742', 4,136' - 4,144', 4,148' 4,155', 4,235' - 4,257' Tubing (size, grade, measured and true vertical depth): 3 1/2" 9.3#, L -80 6,127' MD 3,249' TVD (2) SC - 1 GP Packers & 6,809', 6,981', 7,854'MD / Packers and SSSV (ty pe, measured and true vert ical depth): Model D Sump Packer 3,650', 3,751', 4,262'ND TE -5 SSSV 449'MD / 449'TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 6,916' - 6,966' (B -6), 7,646'- 7,660'(C -3), 7,667'- 7,678' (C -3), 7,812'- 7,840'(C -5) Treatment descriptions including volumes used and final pressure: C -3 & C -5 Sands: Gravel Pack with 14,5601bs 20-40 sand at 7.9b m, 4,000psi max rate B -6 Sand: Gravel Pack with 7,2731bs 20 -40 sand at 7.1 bpm, 4,000psi max rate, Re- streessed with 7671bs 20-40 sand at 4.5bpm, 4,000psi max rate 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 360psi 52psi Subsequent to operation: 0 7850 0 480psi 230psi 13. Attachments: `. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development El Service ❑ Daily Report of Well Operations X `. Well Status after work: Oil ❑ Gas WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -033 Contact David Ross 263 -7696 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276 -7600 Date 4/1/2010 RBDMS APR 01 fi Form 10-404 Revised 7/2009 Submit Original Only Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -20 TRADING BAY UNIT M -20 5073320587 LV5861 160.00 185.00 Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Drill and Complete Drill and 10/12/2009 3/4/2010 Complete Primary Wellbore Affected Wellbore UWI Well Permit Number M -20 507332058700 2090930 Daily Operations 2/13/2010 00:00 - 2/14/2010 00:00 Operations Summary Skid rig to M -20. 2/14/2010 00:00 - 2/15/2010 00:00 Operations Summary Continue to skid rig over M -20. Rig up line to fill M -20 annulus 9 5/8" by 3 1/2 ". Fill annulus with FIW at 3.4 BPM with "0" PSI, after pumping 434 barrels, pressure started building to 45 psi, total FIW pumped 630 barrels. Rig up on tree to pump into tubing and pump FIW at 4.5 barrels with "0" PSI, after 90 barrels pumped with "0" psi, increase the pump rate to 7.7 BPM with 25 psi, total FIW pumped 120 barrels, shut down and tubing went on vacuum. Notified AOGCC of upcoming BOP test. 2/15/2010 00:00 - 2/16/2010 00:00 Operations Summary Nipple up BOP stack, install 5" pipe rams in the top, 3 1/2" rams in bottom, Pressure Test BOP Annular 200 / 1000 psi, Rams and choke manifold 200 / 3000 psi. AOGCC witness waived by Chuck Scheve @12:27 on 2/15/10. 211612010 00:00 - 2/17/2010 00:00 Operations Summary Tested stand pipe manifold 250/5000 psi, R/U wireline tested lubricator to 500 psi. RIH w/ 2.70" jet cutter, pumped tool in from 2140' -5800' corelated on depth and cut tubing @ 8939' WLM. POOH and R/D wireline. Pumped a 30 bbl salt pill for FLC well still on vacuum. Est. loss rate 200 BPH. Pumped 35 bbl salt/carbonate pill losses slowed to 4.8 BPH. POOH standing back tubing losses slowed to —4 BPH. 2/17/2010 00:00 - 2118/2010 00:00 Operations Summary Contiune POOH, stood back 65 stands of tubing and LD 84 jts, 4 GLMs and 1 SSSV. Recovered 8938.77' of tubing. P/U cement retainer and RIH to 8860' spaced out with 1 jt of DP and set retainer @ 8900'. Tested backside to 500 psi for 10 mins, OK, bled pressure. Performed injection test below retainer with 84 bbls of FIW. Shut in annular and applied 500 psi to annulus. Pumped 10 bbls of drill water ahead and began pumping 14.0 ppg cement at 2 BPM 180 psi 2/18/2010 00:00 - 2/19 /2010 00:00 Operations Summary Continued pumping 45 bbls of 14.0 ppg slurry followed by 15 bbls of 17.0 ppg slurry, diplaced cement with 76 bbls of drill water @ 2.1 BPM. Final pressure was 1800 psi, shut down and trapped 1400 psi below the retainer. POOH to 8845' and reverse circulated cement out at 4 BPM, 800 psi. 3bbls of good cement returned , 160 bbls reveresed (2 CBUs). POOH and P/U WBC tool assembly and TIH to 8726'. WOC. Tagged cement @ 8850' w/ 10k on bit. POOH to 8840' and performed a 1500 psi P/T on plug for 10 minutes, test witnessing waived by Jim Regg © 08:45. Begin rotating and reciprocating WBC tool assembly while circulating FIW. Increased rate to 8 BPM and pumped 40 bbls of caustic, 40 bbls of Baraklean and 35 bbls of N -vis, circulated pills to surface and caught sample of FIW (660 ppm and 175 NTUs). Tagged cement again @ 8850' 2/19/2010 00:00 - 2/20/2010 00:00 Operations Summary Continue TIH w/ WBCT assembly to PBTD @ 8850'. Circulated well with FIW displaced well with 6% KCI completion fluid seperated by a 30 bbl N -Vis pill. Circulated and filtered completion fluid until a NTU value of 88 and a trace of solids. Flow checked well and POOH with the WBCT assembly while drifting the DP. LD WBCT assembly. M/U logging tools and R/U Eline, begin to RIH with tractor, ASP and USIT tools. 2/20/2010 00:00.2/2112010 00:00 Operations Summary RIH with tractor, ASP and USIT tools logging fluid properties from 1400'- 2185'. Ran tractor from 2185-4600' and continued to RIH logging fluid properties to 7998' . POOH while logging w/ ASP and USIT up to 1350'. RIH to 4650' and logged w/ the USITand ASP out of hole to 1350'. Mixed and filtered 450 bbls of brine while R/U completion equipment. R/D a -line and P/U Model D sump packer and setting tool and TIH to place packer w/ DP in tension @ 7854' DPM. R/U a -line and test lubrictator to 500/1500 psi. RIH w/ GR tool to 2150' before attempting to pump down tool. No additional line tension observed, POOH w/ logging tools and re- arranged pump down cups. Run back in hole to 2150' and begin pumping GR tool down hole at 2.5 BPM and 300 psi. Notified AOGCC of upcoming BOP test. 2/21/2010 00:00 - 2/22/2010 00:00 Operations Summary Continue to pump GR tool to 4700', quit pumping and RIH to 7820'. Logged out of hole to 5000'. correlated sump packer on depth and set at 7854' POOH and LD running tool. Pulled wear bushing and installed test plug. Filled stack and performed BOP test as per AOGCC regs, Tested annular to 200/1000 psi and UPRs, LPRs, choke and kill valves, upper and lower TDVs to 200/3000 psi. AOGCC witness waived by Chuck Scheve @ 12.27 hrs. -- 2/22/2010 00:00.2/23/2010 00:00 Operations Summary P/U 196' of 7" perf guns and assembly and TIH w/ 3 1/2" x 5" tapered string. Latched into sump packer at 7854' , spaced out to position guns @ 7646' to 7660' , 7667' to 7678' (C -3 sands) and 7812' to 7840' (C -5 sand). Set and tested packer, opened by -pass displaced 62.8 bbls of completion brine in DP with N2, shut by pass and pressured DP to fire the guns. Guns fired at 5464 psi surface pressure and 6212 psi @ the firing head . Perforated for production 25 net feet in the C -3 and 28' in the C -5 with 7" Big Hole Charges. 56.5 gm, 14 spf, 45 deg. phased. Shut down monitored pressure decline. Bullheaded 77bbls of completion fluid down the DP © 2 BPM, shut down and monitored surface pressure. Pressure stabilized at 540 psi. Bullheaded an additional 97 bbls of completion fluid between 4 and 7 BPM max pressure 2040 psi. Chevron 1 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -20 TRADING BAY UNIT M -20 5073320587 LV5861 160.00 185.00 Daily Operations 2/23/2010 00:00 - 2/24/2010 00:00 Operations Summary Monitoring pressure decline after bullheading 97 bbls of brine. Pressure stabilized at 120 psi, bleed well down to 0 psi and monitored for 10 minutes with no pressure gain. Monitor trip tank for losses. No losses in 15 minutes. Unset Champ packer and R/D treating lines. CBU © 4 BPM noticed gassy return at bottoms up. Loss rate 1.8 BPH. POOH and UD guns, all shots fired. P/U MI SWACO WBCT assembly TIH to 7591'. Reamed from 7591'- 7695', 7780' -7854' working through section 3 times while circulating 8 BPM and rotating @ 60 RPM. Fluid loss @ 4 BPH while pumping. 2/24/2010 00:00 - 2/26/2010 00:00 Operations Summary Continue circulating out perf debris at 7.3 BPM , returns had 50 ppm solids at purpp shut down. Drop drifts and POOH with WBCT assembly and UD same. P/U and M/U lower GP assembly and concentric wash pipe. TIH with GP assembly to 7840' © 3 min /stand. Snap into sump packer at 7,854' and space out leaving 5k down on packer. Change out bails and R/U treating lines. 2125/2010 00:00 - 2/26/2010 00:00 Operations Summary Drop packer setting ball and pump to seat. Set top GP packer @ 6981', test annulus to 1000 psi. Release setting tool, locate reverse position and reverse ball back to surface. P/T hard line to 6000 psi, good test. Pump 10 bbls of pickle acid and reverse circulate until returns cleaned up to a trace of solids (478 bbls total). Pumped injection diagnostic tests. Pumped HRWP with 1 ppa gravel @ 7.9 BPM with 2.1 BPM returns. Induced sand out to 4000 psi by opening choke and slowing rate to 5 BPM. Placed 14,560 lbs of gravel behind pipe, equivelant to 157 lbs/ft of perforations (51'). Reversed out excess gravel, P/U and dumped seals, no losses observed. Established circulating position and retstressed pack. Calculations indicated 40' of blank covered. Changed out bails R/D surface lines and performed soft KOIV closure. KOIV closed no losses. POOH and UD service assembly. 2/26/2010 00:00 - 2/27/2010 00:00 Operations Summary TIH with TCP assembly to SC -1 packer @ 6981' latch packer plug, shear off and space out to perf B -6 sand. Set Champ packer and test backside to 500 psi. P/T hard lines to 5000 psi with brine and N2. Open bypass and displace 30 bbls in DP with N2. P/T hard lines to 5000 psi w/ brine and N2. Continued to displace a total of 57.4 bbls from DP. Shut bypass and pressured DP with N2 to 3757 psi when guns fired . Perfed for production the B -6 sand from 6916' - 6966' , Big Hole Chrg. 56.5 gm, 14 spf, 45° Phased Monitored pressure decline, bled to 700 psi in 60 mins. Bullhead 94 bbls of brine @ 8 BPM shut down, well blled to 0 psi in 3 mins. Well on vacuum, losses @ 16 BPH. Unset packer and CBU (400 bbls) R/D hard lines. losses @ 13 BPH. POOH from 6981 to 6356'. Notified AOGCC of upcoming BOP test. 2/2712010 00:00 - 2/28/2010 00:00 Operations Summary POOH from 6559' -245', average losses 11 BPH. POOH UD perf assembly all shots fired. P/U WBCT assembly with 3.66 grapple and TIH to 6886' avg losses 10 BPH. Wash and ream from 6900' -6966' while pumping 6 BPM made 3 passes. Circulated and condition hole to a trace of solids. Latch onto packer plug @ 6982' and with 15K dn. wt. attempt to work free - no go - working over pull up to max of 150K over in 5 K increments. Attempt release from fish and freed same. Static hole loss = 8.6 BPH. Dropped drift and POOH, UD WBCT assembly, recovered 35 lbs of debris from magnets and .5 lbs from ditch magnets. 2/28/2010 00:00 - 3/1/2010 00:00 Operations Summary Break out packer plug and UD cleanout assembly. Perform BOPE test to AOGCC regulations. 200 /3000psi on UPR & LPRs and choke manifold, 200 /1000psi on annular. Test waived by Jim Reggs w/ AOGCC. P/U upper GP assembly and TIH to 6982'. 3/1/2010 00:00 - 3/212010 00:00 Operations Summary R/U and test rig lines to 3500 psi. Drop packer setting ball, set packer @ 6809' and test backside to 1000 psi. Reverse ball back to surface. R/U GP hard lines and test same to 6000 psi. Pickle DP and reverse to pits until fluid cleaned up. Performed injection diagnostics tests and pumped HRWP on the B -6 sand at 7.1 BPM with 1 ppa sand and 2.1 BPM returns. Sanded out to 4000 psi with 7273 lbs of sand behind pipe. Reveresed out excess sand, dumped seals and restressed pack. Re- stress indicated open screen not covered by sand. Performed re -pack pumping 4.5 BPM with 1 ppa sand and 2.1 BPM returns. Sanded out to 4000 psi with and additional 767 lbs behind pipe for a total of 8040 lbs. Reversed out excess sand, dumped seals and re- stressed pack pumping 1.5 BPM @ 1490 psi indicating 10' of blank covered. Total sand in the formation equal to 110 lbs/ft of perforations. R/D hard lines and monitored losses 16.2 BPH. Successfully performed soft closure of KOIV. R/D pumping equipment and began POOH. 3/2/2010 00:00 - 3/3/2010 00:00 Operations Summary POOH with drill pipe and GR wash pipe, Lay down wash pipe, pull wear bushing,Run 3 -1/2" 9.2# L -80 completion tubing, make up SSSV, and Land tubing, Test seals, test hanger seals, install BPV, Nipple down BOP 3/3/2010 00:00 - 3/4/2010 00:00 Operations Summary Nipple Down Riser, Install and test Vetco production tree to 250 / 5000 psi, Prepare and skid drill package over M -17 unevrun • 1 •elhead Platform %. Well M -20 As Built 3 -29 -2010 Casing and Tubing Detail RKB to TBG Head = 78'.75 SIZE WT GRADE CONN MIN TOP TOP BTM BTM ID in MD TVD MD TVD Cement to ML rkb rkb rkb rkb 4-- @ 345' 28" Structural 27 Surface Surface 490' 490' 13 -3/8" 68 L -80 BTC 12.415 Surface Surface 1,425' 1,352' 9 -5/8" 47 L -80 BTC -M 8.681 Surface Surface 8,223' 4,498' _"' ECP Stage 7" 26 L -80 DWCSR 6.276 8,022' 4,368' 10,498' 6,328' Collar450 Tubing 3 - 1/2" 9.3 L - 80 H - 503 2.992 Surface Surface 6127' 3,249' 28" Conductor . @ 480 d Logging Detail ' - : Hole LWD /MWD Wire Line Mud Logging Notes S ection Gas Detection, , GR/Res Consulting Geologist J Mud Logging b F �° 13 3/8" in 17 %" Hole 12 %, GR/Res/ Dens- Gas Detection, Consulting Geologist Neut, PWD Vib Mud Logging GR/Res/ Dens- Gas Detection, d 8'�2 Neut, PWD Vib Mud Logging Consulting Geologist PI 9 5/8 Hydraulic Miscellaneous Equipment Informtion 0 1 A Stage Collar @ Item Depth OD ID Notes 6050' MD TE -5 SSSV 449 5.39 2.94 • ,5 SFO -1 GLM 1643 5.31 2.87 - B - 1Sand SFO -1 GLM 3109 5.31 2.87 -' = SFO -1 GLM 4636 5.31 2.87 M ►M SFO -1 GLM 5664 5.31 2.87 • ' ::*>:::::':: SFO -1 GLM 6723 5.31 2.87 Upper SC -1 GP Packer 6809 8.46 4.75 r' B & B - Sands Lower SC -1 GP Packer 6981 8.46 4.75 Model D Sump Packer 7854 8.125 4.75 �� / Cement tagged @ ii " •' +' +'• C - & C - Sands Model K -1 Cement Retainer 8900 N/A N/A 8850' Perforation Detail MD TVD Zone Density Notes • . (SPF) 6916' -6966' 3713' - 3742' B -6 14 7" Big Hole Charge. 56.5 gm 9 5/8" Casing in 12 7 646' -7660' 4136'- 4144' t g C -3 14 7" Big Hole Charge. 56.5 gm Hole 7667' -7678' 4148' - 4155' 7812' -7840' 4235' - 4257' C -5 14 7" Big Hole Charge. 56.5 gm Cement tagged @ 8850' 9000' - 9054' 5104' - 5148' D -6 12 Abandoned 10214' - 10226' 6095' 6105' D -16A 12 Abandoned 10268' 10300' 6139' - 6165' D -16C 12 Abandoned ' '0 Cement Retainer @ 8900' DF Sand D -16A Sand D -16C Sand alIMIN 7" Liner in 8 1/2" Hole 1AX HOLE ANGLE = 78.2 Deg @ 2301' 3/29/2010 DRAWN BY: DR • Oi l° /10 4 4 010 ` / JO ' STATEOFALASKA FEB 2 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska ON & 6113 Cons. Commission APPLICATION FOR SUNDRY APPROVALS Anchorage 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations 0 • Perforate El . Pull Tubing 0 . Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Perform 3 stage Gravel Pack 0 • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development El Exploratory ❑ 209 -0930 ' 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20587 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 Trading Bay Unit M -20 9. Property Designation (Lease Number): 10. Field / Pool(s): n,('� �� .et -/ v (7'4“ r n /p ADL,017594, ADL018729, ADL018730 [Steelhead Platform] McArthur River Field / Gr as Sand 9,-f- 11' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,500 6,329 10,415 6,260 N/A N/A Casing Length Size MD / TVD Burst Collapse Structural Conductor 490' 28 -32" 490' 490' Surface 1,425' 13 -3/8" 1,425' 1,352' 5,020 psi 2,260 psi Intermediate Production 8,223' 9 -5/8" 8,223' 4,498' 6,870 psi 4,760 psi Liner 2,476' 7" 10,498' 6,328' 7,240 psi 5,410 psi Perforatio •ep h MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,268'- ;# 41.4 10,214'- 6,139'- 6,165', 6,095'- 6,105', 10,226', 'i0 9,054' 5,104'- 5,148' 3 -1/2" 9.2 #, L -80 10,197' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): BakerModel S -3 Packer/ TE -5 SSSV 8,974'MD (5,082'TVD) / 432'MD (432'TVD) 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 . Exploratory ❑ Development 0 ' Service ❑ 14. Estimated Date for 63/2010 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas El . WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Ross 263 -7696 Printed Name /Timothy C. Brandenburg Title Drilling Manager Signature �.,_ 1� Phone 276 -7600 Date 2/2/2010 COMMISSION USE ONLY �j //� �j �j Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �./` " D Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: T$ S t a.4t. K L.Ci a. y go pc- to loco ec . - - r t s t reuv 150 P t o 3000 r - • eetr tv MC Zs. Zips- (h) Ai ftie Kak.. - L Po ?& G s a ffvogC.cl. Subsequent Form Required: [ 0 _ 4 4. ' APPROVED B l Approved by: , / COMMISSIONER THE COMMISSION Date: 1 t /6 0 Form 10 -403 Revised 12/2009 R 1 G i Ii A L RBDMS FEB 11 2010 �c?L a Submit in Duplicate I Z_ - .9 = %C% Chevron • • Trading Bay Unit Well # M -20 2/1/10 OBJECTIVE: • High Rate Water Pack (HRWP) B - 1, B - 5, B - 6, B - 8, C - 3, and C - 5 gas sands. ' PROCEDURE SUMMARY: 1 ND tree, NU BOP, & test same. 2 R/U Eline. 3 Pump down jet cutter & cut tubing +/- 8,940'MD. 4 R/D Eline. 5 POOH w/ +/- 8,940' of 3 1/2" completion. 6 Set 7" cement retainer at +/- 8,900'. 7 Squeeze +/ -60 bbl w/ + /- 15.8ppg class G cement below retainer. 8 Spot + / -2bbl cement on top of retainer & TOH. 9 Dress off TOC to +/- 8,850' w/ wellbore cleaning tool assembly and bit and circulate wellbore clean w/ FIW. 10 Pressure test casing /liner top /liner and cement plug to 1,500psi. 11 Displace well to 6% KCL and filter same. 12 R/U Eline. 13 Run USIT /ASP Logs from +/- 1,400' to +/- 8,022'. 14 R/D Eline. 15 Set Sump Packer at +/- 7,854'. 16 TCP perforate zone #1 C -3 from +/- 7,646' to +/- 7,660' & +1- 7,667' to +1- 7,678' and C -5 from +/- 7,812' to +/- 7,840' and TOH. 17 RIH & latch GP assembly #1 into Sump packer at +/- 7,854' and set lower GP packer at +/- 7,347'. 18 HRWP zone #1. 19 TOH w /GP service assembly. 20 TCP perforate zone #2 B -5 from +/- 6,766' to +/- 6,796', B -6 from +/- 6,908' to +/- 6,969', & B -8 from +/- 7,268' to +/- 7,272', +1- 7,292' to +/- 7,298', & +/- 7,322' to +1- 7,332' and TOH. 21 RIH & latch GP assembly #2 into lower GP packer at +/- 7,347' and set middle GP packer at +/- 6,309'. 22 HRWP zone #2. 23 TOH w/ GP service assembly. 24 TIH with TCP assembly #3. 25 TCP perforate zone #3 B -1 from +/- 6,267' to +1- 6,292' and TOH. • 26 RIH & latch GP assembly #3 into middle GP packer at +/- 6,309' and set upper GP packer at +/- 6,127'. 27 HRWP zone #3. 28 TOH w/ GP service assembly. 29 Run 3 -1/2" tubing gaslift completion and latch into upper GP packer at +/- 6,127'. 30 ND BOP, NU tree. Turn well over to production. • M -20 REVISED BY: CVK 2 -1 -10 Chevron • •teelhead Platform 1%0 Well M -20 ---%1110 As Built Well Sketch RKB to TBG Head = 78'.75 Casin and Tubing Detail SIZE WT GRADE CONN MIN TOP TOP BTM BTM ID in MD rkb TVD rkb MD rkb TVD rkb ' p , 28" Structural 27 Surface Surface 490' 490' , 13 -3/8" 68 L -80 BTC 12.415 Surface Surface 1,425' 1,352' 9 -5/8" 47 L -80 BTC -M 8.681 Surface Surface 8,223' 4,498' ECP Stage Collar 7" 26 L -80 DWCSR 6.276 8,022' 4,368' 10,498' 6,328' A r ' IL 433' -458' Tubing 3 -1/2" 9.2 L -80 2.992 Surface Surface 10,197' 28" Conductor @480 Miscellaneous Equipment Information Item Depth OD ID Notes Baker Flexlock Liner Hanger / 8,022'- 6.187 RS bushing is minimum , ZXP Packer Assy 8,053' minimum diameter @ 8040.6' � RA Tags 5851, 7288, 8759, 9950 TE -5 SSSV 432' 5.37" 2.81" C C. ' - ,' t3 3 /s" in 17 /" Hole SFO - GLM 1,641' 5.313" 2.867" TRO 923 psi / BK -2 latch SFO -1 GLM 4,827' 5.313" 2.867" TRO 898 psi / BK -2 latch ' 9 5/8 Hydraulic Stage SFO -1 GLM 6,481' 5.313" 2.867" TRO 887 psi / BK -2 latch Collar @bolo' SFO - GLM 7,915' 5.313" 2.867" TRO 880 psi / BK -2 latch SFO - GLM 8,944' 5.313" 2.867" Orifice / BK -2 latch Model S -3 Packer 8,974' 5.95" 2.96" X- Nipple 8,990' 4.5" 2.81" 0 XN nipple 10,187' 3.960" 2.75" W LEG / burst disc 10,197' 4.25" 3.125" Cementing Information Description Volume Density Yield Notes (bbls) (PM) (ft3 /sx) 13 3/8 Surface Casing 164 13.0 1.96 Stage 1 Lead 0 • 13 3/8 Surface Casing 112 13.6 -13.8 1.61 Bumped plug Stage 1 Tail 13 3/8 Surface Casing Stage 2 Lead 255 13.0 1.96 Landed Closing Plug w/ positive indication of closing 9 5/8 Intermediate 139 13.2 1.88 Casing Stage 1 Lead 9 sin Intermediate Ca 47 14.0 1.60 Bumped plug sing Stage 1 Tail 9 5/8" Casing in 12'/." Landed closing plug w/ positive Hole 9 5/8 Intermediate indication of closing. Lost then Casing Stage 2 Lead 382 13.2 1.88 regained returns. 72 bbls fluid lost. Cement seen at surface. Channeling likely. Rotated and reciprocated liner. 7 Liner 101 15.8 1.19 Started to pack off but resolved itself. Trace cement at surface. No losses reported Perforation Detail MD TVD Zone Density Notes (SPF) D -6 Sand 9,000 — 9,054' 5,104' - 5,148' D -6 12 4 -5/8" Millennium Charge 22.7 gm = 10,214' — 10,226' 6,095' - 6,105' D -16A 12 4 -5/8" Millennium Charge 22.7 gm 10,268' — 10,300' 6,139' - 6,165' D -16C 12 4 -5/8" Millennium Charge 22.7 gm D -16A Sand 11 Cann '216 " 7" Liner in 9" Hole TD = 10,500' MD MAX HOLE ANGLE = 78.2 Deg @ 2301' PBTD = 10,415' MD (10,408' correlated ELM) Well Detail Created By: JAR 12/9/09 Revised by CVK 12/15/09 %.f1evrtan ' 1 • Selhead Platform ' Well M -20 Proposed Re- Completion Casing and Tubing Detail RKB to TBG Head = 78'.75 SIZE WT GRADE CONN MIN TOP TOP BTM BTM ID in MD TVD MD TVD Cement to ML rkb rkb rkb rkb f-- @ 345' 28" Structural 27 Surface Surface 490' 490' 13 -3/8" 68 L -80 BTC 12.415 Surface Surface 1,425' 1,352' 9 -5/8" 47 L -80 BTC -M 8.681 Surface Surface 8,223' 4,498' ECP Stage 7" 26 L -80 DWCSR 6.276 8,022' 4,368' 10,498' 6,328' - t i Collar450 - 460 Tubing 3 - 1/2" 9.3 L - 80 H - 503 2.992 Surface Surface 6,127' 3,249' 28" Conductor @ 480 Logging Detail Hole LWD /MWD Wire Line Mud Logging Gas Detection, Notes G Section 17 +/_" GR/Res Consulting Geologist Mud Logging 13 3/8" in 17 %" Hole 12 Y;' GR/Res/ Dens- Gas Detection, Consulting Geologist Neut, PWD Vib Mud Logging GR/Res/ Dens- Gas Detection, 8 YZ' Neut, PWD Vib Mud Logging Consulting Geologist 1. I II 9 5/8 Hydraulic Miscellaneous Equipment Informtion A.- Stage Collar @ 6050' Item Depth OD ID Notes MD TE -5 SSSV 433' 5.38" 2.81" SFO -1 GLM 1,638' 5.31" 2.87" B - 1Sand SFO -1 GLM 4,822' 5.31" 2.87" SFO -1 GLM 6,000' 5.31" 2.87" Upper SC -1 GP Packer 6,127' ° 8.42" 6.00" Middle SC -1 GP Packer 6,309' 8.42" 6.00" ;:` Lower SC -1 GP Packer 7,347' 8.42" 6.00" B - 5, B & B - Sands Model D Sump Packer 7,854' 8.125" 4.75" C -3 & C -5 Sands Perforation Detail MD TVD Zone Density Notes (SPF) 6267' -6292' 3,332' - 3,347' B -1 14 7" Big Hole Charge. 56.5 gm, 6766' -6796' 3,625' - 3,643' B -5 14 7" Big Hole Charge. 56.5 gm 11 6908' -6969' 3,708' - 3,744' B -6 14 7" Big Hole Charge. 56.5 gm 7268' -7272' 3,917'- 3,919' 7292' -7298' 3,931'- 3,934' B -8 14 7" Big Hole Charge. 56.5 gm t , 9 S /8 Casing in 12 + /." 7322' -7332' 3,948'- 3,954' Hole 7646' -7660' 4,136' 4,144' C -3 14 7" Big Hole Charge. 56.5 gm 7667' -7678' 4,148' - 4,155' 7812' -7840' 4,235' - 4,257' C -5 14 7" Big Hole Charge. 56.5 gm 9000' - 9054' 5,104' - 5,148' D -6 12 Abandoned 10214' - 10226' 6,095' - 6,105' D -16A 12 Abandoned 10268' - 10300' 6,139' - 6,165' D -16C 12 Abandoned 8 z = D-6 Sand = D -16A Sand = D -16C Sand 7" Liner in 8 1/2" Hole MAX HOLE ANGLE = 78.2 Deg @ 2301' 2/2/2010 DRAWN BY: DR • • M -20 20 3/4" BOP Stack up r- 21 1/4" 2M Hydril Annular 4.22' 1 1 HUB CLAMP 20 3/4" 3 M Hydril DBL Gate Pipe Rams 4.71' 20 3/4" 3M Blind Rams 1 1 HUB CLAMP _ ♦ �_ 20 314" 3M Mud Cross ICE HUB CLAMP t I 20 314" 3M Single Gate 2.71' • HUB CLAMP 20 3/4 3M 2 NT2 Connector XO Blind Flanges on Diverter Lines Diverter Ir Spool AI ti 3.00' 20 3/4 3M NT2 Connector 20 3/4" 3M Riser 20 3/4" 3M Riser 20 3/4" 3M x 13 5/8" 5M DSA • • • f ' s SEAN PARNELL, GOVERNOR 1aT ALASKA OIL AND .AS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: McArthur River Field, Middle Kenai Gas Pool, Trading Bay Unit M -20 Sundry Number: 310 -033 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair 11 DATED this day of February, 2010. Encl. • • Page 1 of 1 2 o4 Aubert, Winton G (DOA) From: Ross, David A. [Petro Technical Resources of AN [rossda @chevron.com] Sent: Tuesday, February 16, 2010 9:03 AM To: Aubert, Winton G (DOA) Cc: Bonnett, Nigel (Nigel.Bonnett); Nienhaus, Doug R; Kanyer, Christopher V; Smith, David [ASRC]; Haynes, Daniel R. Subject: M -20 Abandonment Slurry Change Winton, As per our phone conversation this moming we are planning to substitute the 15.8 ppg slurry noted on the M-20 10-403 with a 14.0 ppg slurry due to logistical reasons. The 14.0 ppg slurry will develop — 1600 psi compressive strength at the BHST of 125 °F, and will be suitable to use as an abandonment slurry to be squeezed below the retainer. We will proceed with this change based on your verbal approval on the phone. Thank you for your time and consideration pertaining to this matter. Regards, David Ross Alaska Wellbore Maintenance Team Chevron North America Exploration & Production (MCA) Office: (907) 263 -7696 Cell: (907) 903 -9555 Fax: (866) 244 -1439 Email: rossda@chevron.com 2/16/2010 • ID Chevron Debra Oudean Chevron North America Exploration and Production *11. Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 1%0 Tele: 907 263 7889 Fax: 907 263 7828 E -mail: oudeand @chevron.com DATE January 22, 2009 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste #100 Anchorage, AK 99501 r DATA TRANSMITTAL o. Q' WELL LOG TY PE: SCAL ` LOG DATE INTERVAL RUN L INE CD LOGGED # LINE TBU M -06 CEMENT EVALUATION ULTRASONIC IMAGING TOOL 5" 9/10/2009 300 -12392 1 X GR/CCL • TBU M -06 CEMENT EVALUATION 5" 9/10/2009 400 -12392 1 X 0 ' ULTRASONIC IMAGING TOOL GR/CCL QJ TBU M -06 VISION SERVICE MEASURED DEPTH RECORDED 7/24/2009 0 -12502 X X MODE 1:600 / 1:240 TBU M -06 VISION SERVICE 7/24/2009 0 -12502 X X TRUE VERTICAL DEPTH RECORDED MODE 1:600 / 1:240 4 TBU M -06 PRODUCTION LOG 12/24/2009 11370 -12380 2 X W /GHOST /DEFT/TEMP /PRESS /DENS /GR/CCL N., TBU M -06 FINAL WELL REPORT - NOTEBOOK 9/1/2009 X X $ FORMATION LOG MD / FORMATION LOG TVD / LWD COMBO LOG MD / LWD COMBO LOG TVD / GAS VJ RATION LOG MD / GAS RATION LOG TVD / DRILLING DYMANICS MD / DRILLING DYNAMICS TVD ' TBU M -20 VISION SERVICE MEASURED DEPTH RECORDED 10/19/2009 380 -10474 1 -5 X X MODE Q \ y 1:600 / 1:240 (b TBU M -20 VISION SERVICE 10/19/2009 380 -10474 1 -5 X Q1' TRUE VERTICAL DEPTH RECORDED MODE 1:600 / 1:240 TBU M -20 FINAL WELL REPORT - NOTE BOOK 9/1/2009 X X FORMATION LOG MD / FORMATION LOG TVD / LWD COMBO LOG MD / LWD COMBO LOG TVD / GAS RATION LOG MD / GAS RATION LOG TVD / DRILLING DYMANICS MD / DRILLING DYNAMICS TVD g TBU M -32 RD PERFORATION RECORD 2.5 POWER SPIRALS 11/17/2009 9100 - 9520.5 2 X X o ii Q` TBU M -32 RD FLOWMETER LOG 11/16/2009 8700 -9522 1 X X (Iti `'=' p WELL DATA REPORT DATE TBU M -20 DCS ANALYSIS REPORT 12/9/2009 Please acknowledge receipt by signing and r rning one copy of this transmittal or FAX to 907 263 7828. Received BE "\ O Date: STATE OF ALASKA l g i at zso ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 1 7 2009 WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas El SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b. vAlaska3110 ei Lies Cons, uomm scion 20AAC 25.105 20AAC 25.110 Development 0 AntIffokliitttorY ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Union Oil Company of California Aband.: 11/30/2009 209 -0930 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 10/18/2009 50- 733 - 20587 -00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1044' FNL, 452'FWL, Sec 33, T9N, R13W, S.M. 11/18/2009 Trading Bay Unit M -20 Top of Productive Horizon: 8. KB (ft above MSL): 160 15. Field/Pool(s): 1097' FNL, 266'FEL, Sec 32, T9N, R13W, S.M. GL (ft above MSL): McArthur River Field Total Depth: 9. Plug Back Depth(MD +TVD): 994' FNL, 421'FEL, Sec 6, T8N, R13W, S.M. 10,415' MD (6,260' TVD) Grayling Gas Sand 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 214069.33 y- 2499459.8 Zone- 4 10,500' MD (6,329' TVD) ADL017594, ADL018729, ADL018730 TPI: x- 213349.72 y- 2499424.17 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 211859.46 y- 2494282.34 Zone- 4 432' MD (432' TVD) N/A 18. Directional Survey: Yes Ei No U 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 185 (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD: Gamma/Resistivity, Density/Neutron, Mud log N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 28 -32 1/2 -1 "WT X -56 Surface 490' Surface 490' Driven N/A 164bbl 13.0ppg lead / 112bb1 13 -3/8" 68# L -80 Surface 1,425' Surface 1,352' 17 -1/2" 13.6- 13.8ppg class G cement tail & 255bb1 13.0ppg class G / cement 139bb1 13.2ppg lead / 47bb1 14.0ppg class G cement tail & 9 -5/8" 47# L -80 Surface 8,223' Surface 4,498' 12-1/4" 382bb1 13.2ppg class G / cement 7" 26# L -80 8,022' 10,498' 4,368' 6,328' 8- 1/2 "x9„ 101bb1 15.8ppg class G cement 24. Open to production or injection? Yes Is No ❑ If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4 -5/8" guns 12spf D -16C 10,268'- 10,300'MD (6,139'- 6,165'TVD) 3 -1/2" 10,197' 8,974'MD (5,082'TVD) 4 -5/8" guns 12spf D -16A 10,214'- 10,226'MD (6,095'- 6,1051VD) 4 -5/8" guns 12spf D -6 9,000'- 9,054'MD (5,104'- 5,148'TVD) 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Currently attempting to flow well Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: N/A 24 Test Period —► N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. N/A N/A 24 -Hour Rate — N/A N/A N/A N/A 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ig Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. C t:Tio . I j J1 _.'7 ito f . t L i [9 Form 10 -407 Revised 7/2009 CONTINUED ON REVERSE Submit original only 28. GEOLOGIC MARKERS (List all formations an markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes el No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base See attached formation top information. Formation at total depth: 30. List of Attachments: Operations Summary, Directional Survey, Wellbore Schematic, Mud Weight Report, Formation Tops 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Rose 263 -7637 Printed Name: Timothy C. Brandenburg Title: Drilling Manager Signature: Phone: 907-276-7600 Date: 12/16/2009 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for 1 njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 7/2009 • • Steelhead M -20 Formation Tops Chevron API No: 50- 733 - 20587 -00 %O. APD: 209 -0930 %N. Well Surface ft MDbrf ft TVDbrf ft TVDss Well Surface ft MDbrf ft TVDbrf ft TVDss M -20 SZ1CT 865.2 861.4 -701.1 M -20 B5ST 6766.4 3625.8 - 3465.5 M -20 SZ2CT 955.5 947.2 -786.9 M -20 B4CT 6883.1 3693.7 - 3533.4 M -20 SZ3CT 1002.3 990.8 -830.6 M -20 B6ST 6907.8 3708.1 - 3547.9 M -20 SZ4CT 1059.2 1043.0 -882.8 M -20 B5CT 7042.4 3786.7 - 3626.5 M -20 SZ5ST 1110.8 1089.6 -929.4 M -20 B7STRT 7080.5 3808.9 - 3648.6 M -20 SZ5CT 1152.1 1126.3 -966.0 M -20 B8ST 7203.3 3879.9 - 3719.6 M -20 SZ6ST 1177.3 1148.4 -988.1 M -20 CCT 7342.4 3959.9 - 3799.6 M -20 SZ6CT 1267.0 1224.9 - 1064.7 M -20 C1ST 7385.5 3984.7 - 3824.4 M -20 SZ7CT 1322.6 1271.0 - 1110.7 M -20 C1CT 7546.9 4078.4 - 3918.1 M -20 SZ8CT 1396.9 1329.1 - 1168.8 M -20 C2CT 7597.9 4108.1 - 3947.8 M -20 SZ9CT 1483.4 1395.1 - 1234.8 M -20 C3ST 7633.2 4128.8 - 3968.6 M -20 -SZ10CT 1582.7 1463.6 - 1303.3 M -20 C4ST 7706.4 4172.1 - 4011.9 M -20 SZ11BST 1702.1 1538.6 - 1378.3 M -20 C3CT 7784.2 4219.2 - 4059.0 M -20 SZ11CT 1904.0 1643.4 - 1483.2 M -20 CSST 7811.4 4235.8 - 4075.5 M -20 SZ12ST 1950.5 1663.2 - 1502.9 M -20 DCT 7952.1 4324.0 - 4163.8 M -20 SZ12CT 2118.9 1725.4 - 1565.1 M -20 D1ST 8027.0 4371.8 - 4211.6 M -20 SZ13ST 2238.8 1756.2 - 1595.9 M -20 D1CT 8409.8 4624.0 - 4463.7 M -20 SZ13CT 2492.3 1810.5 - 1650.3 M -20 D2ST 8492.1 4684.4 - 4524.1 M -20 SZ14ST 2563.6 1826.1 - 1665.9 M -20 D2CT 8589.9 4760.9 - 4600.6 M -20 SZ14CT 2836.9 1887.3 - 1727.0 M -20 D3BST 8681.2 4836.3 - 4676.0 M -20 SZ15ST 3045.2 1934.1 - 1773.8 M -20 D3CT 8795.8 4933.1 - 4772.9 M -20 SZ16ST 3265.7 1980.0 - 1819.8 M -20 D4CT 8911.2 5030.1 - 4869.8 M -20 SZ16CT 4071.7 2161.2 - 2000.9 M -20 D5CT 8968.8 5077.9 - 4917.7 M -20 SZ17ST 4228.0 2209.6 - 2049.4 M -20 D6ST 8999.6 5103.4 - 4943.1 M -20 SZ17CT 4360.9 2258.6 - 2098.4 M -20 D6CT 9085.2 5173.9 - 5013.6 M -20 SZ18ST 4419.7 2282.7 - 2122.5 M -20 D7ST 9114.6 5198.0 - 5037.8 M -20 SZ18CT 4611.4 2371.5 - 2211.2 M -20 D7CT 9167.4 5241.3 - 5081.0 M -20 SZ19CT 4739.5 2439.9 - 2279.7 M -20 D8ST 9202.8 5270.4 - 5110.1 M -20 SZ2OST 4817.0 2484.0 - 2323.7 M -20 D8CT 9337.7 5380.7 - 5220.4 M -20 SZ2OCT 4879.9 2520.3 - 2360.0 M -20 D9ST 9399.0 5430.8 - 5270.6 M -20 SZ21ST 4916.7 2541.6 - 2381.3 M -20 D9CT 9488.3 5503.8 - 5343.6 M -20 SZ22CT 5111.8 2654.8 - 2494.5 M -20 D1OST 9503.9 5516.6 - 5356.3 M -20 SZ23CT 5148.3 2676.1 - 2515.8 M -20 D1OCT 9662.3 5646.2 - 5486.0 M -20 ACT 5332.0 2784.3 - 2624.1 M -20 D11ST 9695.0 5672.9 - 5512.6 M -20 A2ST 5447.0 2852.5 - 2692.2 M -20 D11CT 9743.6 5712.6 - 5552.3 M -20 A2CT 5549.8 2912.9 - 2752.6 M -20 D12ST 9768.4 5732.7 - 5572.5 M -20 A3ST 5627.1 2957.9 - 2797.7 M -20 D12CT 9849.1 5798.6 - 5638.3 M -20 A4ST 5680.8 2989.1 - 2828.8 M -20 D13AST 9938.0 5871.1 - 5710.9 M -20 A5ST 5746.5 3027.0 - 2866.8 M -20 D14ST 10032.5 5948.2 - 5787.9 M -20 A5CT 5975.3 3159.9 - 2999.6 M -20 D14CT 10130.5 6028.0 - 5867.7 M -20 - A6ST 6039.3 3197.5 - 3037.2 M -20 D15ST 10158.0 6050.4 - 5890.2 M -20 BCT 6211.8 3299.6 - 3139.4 M -20 D15CT 10197.5 6082.6 - 5922.3 M -20 B1ST 6266.8 3332.3 - 3172.0 M -20 D16AST 10217.9 6099.1 - 5938.9 M -20 B2ST 6372.8 3394.9 - 3234.6 M -20 D16CST 10266.4 6138.7 - 5978.4 M -20 B1CT 6440.4 3434.7 - 3274.5 M -20 D16CT 10375.6 6227.5 - 6067.3 M -20 B4ST 6474.4 3454.7 - 3294.4 M -20 D17ST 10396.1 6244.2 - 6084.0 M -20 B3ST 6474.6 3454.8 - 3294.6 M -20 D17CT 10451.7 6289.5 - 6129.2 M -20 B2CT 6678.4 3574.5 - 3414.2 M -20 TD 10500.0 6328.8 - 6168.5 M -20 -_' B3CT 6716.3 3596.6 - 3436.3 Page 1 of 1 Chevron • • 11%. Chevron - Alaska kl. Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -20 TRADING BAY UNIT M -20 5073320587 LV5861 160.00 185.00 *pw a Y N i ~ Primary Jo T ype Job Category Objective Actual Start Date Actual End Date Drill and Complete Drill and 10/12/2009 Complete Primary Wellbore Affected Wellbore UWI Well Permit Number M -20 507332058700 2090930 CO[i0ffi1.. s . .. „ 10/12/2009 00:00 - 10/13/2009 00:00 Operations Summary Skidding rig. 10113/2009 00:00 - 10/14/2009 00:00 Operations Summary Skidding rig & rig up. 10/14/2009 00:00 - 10/1812009 00:00 Operations Summary Rigging up. 10/15/2009 00 :00 - 10/1612009 00:00 Operations Summary Continue Rigging up. 10/1612009 00:00 - 10/17/2009 00:00 Operations Summary Continue Rigging up. Test Diverter per AOGCC requirements. Test witness waived by AOGCC Jim Regg on 10/15/09. 10/17/2009 00:00.10118/2009 00:00 Operations Summary Continue Rigging up. 10/18/2009 00:00 - 10/19/2009 00:00 Operations Summary Finish replacing new gasket ring in wellhead. MU cleanout BHA #1. Clean out conductor to 480'. POOH UD BHA #1. 10119/2009 00:00 - 10/20/2009 00:00 Operations Summary MU directional BHA #2. Drill directionally 17 -1/2" hole from 480' to 563' and loose partial returns. Pump LCM pill and continue directionally drilling to 1,220' with full returns. 10/20/2009 00:00.10/21/2009 00:00 Operations Summary Drill directionally to 17 -1/2" hole section TD @ 1,430'. POOH UD BHA #2. MU Wash Tool. RIH. Wash out conductor. 10/21/2009 00:00 - 1 0/22/2009 00:00 Operations Summary Finish washing out conducto .' R n 13 -3/8 ", 68 ppf, L -80, BTC casing to 1425'. Land hanger and test void. Cement 13 -3/8" w /'4sbbls 13.0 ppg lead class G cement followed by 1 bls 13.6 -13.8 ppg tail class G cement. Bumped plug and tested floats OK. CIP 23:07. 10/22/2009 00:00.10/23/200 00:00 Operations Summary Inflate ECP and open stage collar. Pump 13 -3/8" stage 2 cement job of 155 bls 13.0 ppg G blend w/ full returns. Land plug and close stage collar. CIP 03:40. Test casing to 1550 psi for 15 min OK. Pick up BOP stack and all 13 -5/8" multi bowl wellhead. Re- install BOPS and prep to test. 10/23/2009 00:00 - 10/24/2009 00:00 Operations Summary Test BOP's, annular 250psi low /1000psi high, rams 250psi low /3000psi high, witnessed by AOGCC Jeff Jones. Upper IBOP valve failed. Replace IBOP and finish BOP testing with some additional repairs necessary to secure good test. Install wear bushing. 10124/2009 00:00 - 10/2812009 00:00 Operations Summary Finish repairing accumulator 4 way valve. Drill out stage collar at 433'. TIH and tag cement at 1,328'. Test casing per AOGCC to 1500 psi for 30 min. Drill out shoe track and 20' of new hole. 10/26/2009 00:00 - 10/26/2009 00:00 . Operations Summary Condition mud for FIT test. Perform FIT to 13.2 ppg EMW. Directionally drill 12 -1/4" hole 1,450' to 2,205'. TOOH. Start PU DP. 10/28/2009 00:00 - 10/2712009 00:00 Operations Summary Continue picking up DP. MU 12 -1/4" rotary steerable BHA. 10/27/2009 00:00 - 10/28/2009 00:00 Operations Summary MU rotary steerable BHA and test. TIH. Change saver sub and repair top drive breakout cylinder. TIH. Directionally drill 2,205'- 2,945'. 10/28/2409 00:00 - 10129/2009 00:00 Operations Summary Directionally drill 2945- 5126'. 10129/2009 00:00 - 10/30/2009 00:00 • Operations Summary Directionally drill 5121'- 5787'. Pull wiper trip to 13 3/8" shoe. Prep to cut drilling line. Chevron • • IWO Chevron - Alaska %. Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -20 TRADING BAY UNIT M -20 5073320587 LV5861 160.00 185.00 10/3012009 00:00 - 10/31/2009 00:00 Operations Summary Cut drilling line. Repair top drive. TIH. Directionally drill 5787'- 6155'. 10/31/2009 00:00 - 1111/2009 00:00 Operations Summary Directionally drill 6155' - 7503' 11/1/2009 00:00 - 11/2/2009 00 :00 Operations Summary Directionally drill 12 1/4" hole 7503' - 8062'. SPP decrease. Check surface equipment for leak. TOOH for washout. 1112/2009 00:00 - 11/312009 00:00 Operations Summary Finish TOOH. Find 8" NMDC box broken and most of BHA missing. MU fishing BHA and start TOOH. SD to repair pumps and LEL sensor. 11/3/2009 00:00 - 11/4/2009 00:00 Operations Summary Continue to work on mud pumps. TIH to top of fish. Circulate hole clean and latch fish at 7903'. Fish moving but slipped from overshot several times. TOOH. 11/4/2009 00:00 - 11/5/2009 00:00 Operations Summary TOOH. No fish recovery. Re dress fishing tools and TIH. Latch fish at 7903. TOOH with fish and work into tight hole at 7120' and lose fish. 11/5/2009 00:00 - 11/5/2009 00:00 Operations Summary TIH looking for top of fish. Find TOF at 7903. Latch fish. Lose fish twice when pumps engaged. TOOH. Test BOPS 250psi low /3000psi high, annular 250psilow /1000psi hig, per AOGCC. Test witness waived by Jim Regg. Start making up clean out BHA. 1116/2009 00:00 - 11/712009 00:00 Operations Summary Finish making up clean out BHA and TIH. Tag top of fish at 7922. circulate and condition hole. TOOH for fishing assy. Start MU fishing BHA. 11/7/2009 00:00 - 11/8/2009 00:00 Operations Summary MU Fishing BHA and TIH. Latch fish © 7902'. Work fish free and TOOH. 11/8/2009 00:00 - 11/9/2009 00:00 Operations Summary Finish TOOH and recover 100% of fish. MU drilling BHA and TIH. 11/9/2009 00:00 - 11/10/2009 00:00 • Operations Summary TIH. Drill from 8062' to section TD @ 8240'. Condition mud and TOOH. 11/10/2009 00 :00 - 11/11/2009 00:00 Operations Summary Finish TOOH. LD drilling BHA. RU casing tools and prep to run 9 5/8, 47 ppf, L -80, BTC -M casing. 11/11/2009 00:00 - 11 /12/2009 00:00 Operations Summary Running 9 -5/8" 47 ppf, L -80 BTC -M casing. 11/12/2009 00:00 - 11/13/2009 00:00 • Operations Summary in sh running 9 5/8 casing to 8 2) Land hanger. Cement casing w/ 568 bbls class G cement slurry in 2 stages (stage one -(3_9bb1 13.2ppg lead w/ 7ISbl 14.0ppg tail; stage two - 82 113.2ppg). Approximately 72 bbls fluid lost on stage 2. Cement to surface on stage 2. 'Rail pack -off into wellhead nd test voids OK. Notice give upcoming BOP test. 11/13/2009 00:00.11114/2009 00:00 Operations Summary Install 7" casing rams. Test BOP's 200psi /1000psi /3000psi. AOGCC did not respond to advance notification of BOP test. No inspector was on board. / MU 8 1/2" clean out BHA. TIH to 585' 11/14/2009 00:00 - 11/15/2009 00:00 Operations Summary TIH installing SS500 NRP's on the DP. Test casing to 3,000 psi, ok. Drill out stage collar at 6,010' and chase junk to 6,945'. Test casing to 3,000 psi, per AOGCC, ok. TOOH. 11/1512009 00:00 - 11/16/2009 00:00 Operations Summary Finish TOOH. LD BHA. MU 8 -1/2" rotary steerable BHA. TIH. Tag cement at 8,127' start drilling out shoe track. Displace mud system. 1111812009 00:00 - 11/17/2009 00:00 Operations Summary Finish mud displacement and drilling out shoe track. Drill 20' new hole and conditionn mud for LOT test. Perform LOT at 8,260' MD/4,492' TVD to 13.8 ppg EMW. Drill 8 -1/2" x 9" underreamed hole with rotary steerable assy to 9,091'. 11117/2019 00:00 - 11/18/2009 00:00 Operations Summary Drill 8 1/2" x 9" underreamed hole with rotary steerable to 10,148'. Collect pore pressure at 9015'. Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -20 TRADING BAY UNIT M -20 5073320587 LV5861 160.00 185.00 [af1Y OtterailOnS.i. , . 11/18/2009 00:00 - 11/1912009 00:00 Operations Summary Drill 8 1/2 x 9" hole w/ rotary steerable from 10 148' to TD at 10 500'. Collect reservoir pressures at 10,217', and 10,362'. TOOH. ry p 11/19/2009 00:00 - 11/20/2009 00:00 Operations Summary TOOH. MAD pass logging 8,275-8,236' and 8,026- 7,956'. TOOH. Run 7" 26 ppf, L -80, DWCSR liner. 11/20/2009 00:00 - 11/21/2009 00:00 Operations Summary Finish running 7" 26 ppf liner to 10,498'. Cement liner with OLbbls 15.8 ppg class G slurry. Displace cement and bump plug. Rotated liner 15 -20 RPM with approximately 23 -24 M tq while reciprocating. Quit r 9,1„-bbls g w/ 48 bbls cement in annulus. Indications of packing off noted but losses not recorded. Release pressure and check floats OK. 11/21/2009 00:00 - 11/22/2009 00:00 Operations Summary Set liner hanger and liner top packer at 8,022'. Test annulus to 1500 psi for 10 min OK. Circulate out spacer w/ trace cement on BU. TOOH. Install 3,„-- 1/2 rams in lower ram cavity. Test same 200psi /3000psi and annular 200psi /1000psi per AOGCC.. MU 7" clean out assy and TIH to 124'. 11/22/2009 00:00 - 11/23/2009 00:00 Operations Summary TIH w/ 9 5/8 x 7" clean out assy. Tag landing collar @ 10,415' (PBTD). Displace well to FIW. TOOH. 11/23/2009 00:00 - 11/24/2009 00:00 Operations Summary Clean and filter surface lines and pits. RU E -line and correlate work string to formation. Landing collar corrected depth is 10,408'. Continue filtering fluid system and cleaning pit system. 11/2412009 00:00 - 11 /25/2009 00:00 Operations Summary Clean pits with caustic & BaraKleen pills. Filter fluid system and circulate the hole with filtered inlet water. Sample and circulate until <500ppm solids are achieved. Notified AOGCC of upcoming BOP test. • 11/2512009 00:00 - 11/28/2009 00:00 Operations Summary Mixed and filtered 450 bbls of 6% KCI , pumped viscous sweep and displaced well to brine. Circulated and filtered brine in the well until 96 NTU's and trace of solids. Circulated in Inflo -250 @ .05 %. POOH with cleanout assembly while drifting pipe and LD same. Magnets recovered 4 lbs of metal. Test BOPs : 200psi low /3000psi high, annular to 200/1000 psi. 11/28/2009 00:00 - 11/27/2009 00:00 Operations Summary Continue testing BOPs. Jug tested well to 3000 psi for 30 mins (good test). P/U and TIH with 4 5/8" TCP assembly, set Champ packer @ 8795' , begin surface line rig up to perforate. 11/27/2009 00:00 - 11128/2009 00:00 Operations Summary PT surface lines to 3000 psi, closed UPR's and tested packer to 1000 psi. Increased annular pressure to 1800 psi and guns fired. Perforated for production the D -16C (10268'- 10300'), D -16A (10214'- 10226') and D-6 (9000'- 9054'). Lost annulus pressure shortly after guns fired. Bullhead 165 bbls of completion brine down drill pipe catching pressure during the last 15 bbls. Open by -pass and annulus and monitored well — 12 BPH losses. Unset packer circulated and filtered well +/- 50 BPH losses. POOH w TCP assembly and LD same. P/U and TIH with post pert cleanout assembly to 3427' 11/28/2009 00:00 - 11/29/209 00:00 Operations Summary Continue to TIH w/ cleanout assembly to top of fill @ 10407' (8' of fill) POOH to 8996 circulate and filter 1 1/2" wellbore volumes. POOH w/ cleanout assembly and LD same 1/2 lb metal on magnets. Pull wear bushing. PU and TIH w/ 3 1/2" completion string to 3260' 11/29/2009 00:00 - 11/30/2009 00:00 Operations Summary Continue to TIH w/ 3 -1/2" 9.2 ppf L -80 completion string to 10123'. Space out and place packer on depth, land tubing hanger an PT same 250/5000 psi. Drop ball and pressure up to set packer 500 psi, 1000 psi, 1500, psi 2000 psi lost pressure @2150 psi. Packer set @ 8974'. Pumped down tubing w/ no communication to annulus. ND BOP equipment and prepare to NU tree. 11/3012009 00:00 - 12/1/2009 00:00 Operations Summary NU tree and test void 250/5000 , pull BPV and install 2 way check to test tree components 250/5000 psi -good test. Test TRSSSV connection at wellhead to 5000 psi -good test. Continue demob operations. 12/1/2009 00:00 - 12/2/2009 00 :00 Operations Summary Demobe equipment and perform rig maintenance. 12/2/2009 00:00 - 12/3/2009 00:00 Operations Summary Demobe equipment and perform rig maintenance. 12/312009 00:00.1214/209 00:00 Operations Summary Perform rig maintenance. Chevron NW %0 Schlumberger M -20 Survey Report Report Date: December 9, 2009 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: Chevron Vertical Section Azimuth: 201.250 Field: Trading Bay Unit Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: Steelhead / M-20 (leg Al slot 2) TVD Reference Datum: Rotary Table Well: M-20 TVD Reference Elevation: 160.25 ft relative to Mean Sea Level Borehole: M-20 Sea Bed 1 Ground Level Elevation: - 185.000 ft relative to Mean Sea Level UWIIAPI#: 507332058700 Magnetic Declination: 18.438° Survey Name l Date: M-20 / October 21, 2009 Total Field Strength: 55536.965 nT Tort I AHD I DD11 ERD ratio: 228.117° / 7543.06 ft / 6.456 / 1.192 Magnetic Dip: 73.635° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: October 21, 2009 Location LatlLong: N 60.83181315, W 151.60245944 Magnetic Declination Model: BGGM 2009 Location Grid NIE YIX: N 2499459.800 ftUS, E 214069.330 ftUS North Reference: True North • Grid Convergence Angle: - 1.39934316 Total Corr Mag North -, True North: +18.438 Grid Scale Factor. 0.99999303 Local Coordinates Referenced To: Well Head I Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub -Sea TVD TVD Closure DLS Northing Easting Longitude True Section Departure True North True North (ft ) (deg) (deg) (ft ) (ft) (ft ) (ft) (ft ) (ft) (ft) (deg1100ft) (ftUS) (ftUS) Latitude Long RTE 0.00 0.00 0.00 - 160.25 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2499459.80 214069.33 N 60.83181315 W 151.60245944 Gyro -MWD 347.15 0.12 168.38 186.90 347.15 0.31 0.36 0.36 -0.36 0.07 0.03 2499459.44 214069.39 N 60.83181218 W 151.60245903 434.01 0.32 11.92 273.76 434.01 0.14 0.58 0.25 -0.21 0.14 0.50 2499459.59 214069.47 N 60.83181258 W 151.60245864 465.23 0.43 340.37 304.98 465.23 -0.03 0.78 0.12 -0.01 0.12 0.74 2499459.78 214069.45 N 60.83181312 W 151.60245876 494.73 0.88 320.74 334.48 494.73 -0.23 1.11 0.27 0.27 -0.06 1.68 2499460.07 214069.28 N 60.83181388 W 151.60245978 525.78 1.51 318.85 365.52 525.77 -0.53 1.76 0.90 0.76 -0.48 2.03 2499460.57 214068.87 N 60.83181523 W 151.60246213 554.23 1.96 310.67 393.96 554.21 -0.87 2.62 1.75 1.36 -1.10 1.80 2499461.19 214068.27 N 60.83181687 W 151.60246558 584.38 2.81 302.61 424.08 584.33 -1.19 3.87 2.97 2.09 -2.11 3.02 2499461.94 214067.27 N 60.83181888 W 151.60247126 614.43 3.67 294.93 454.08 614.33 -1.39 5.57 4.62 2.90 -3.60 3.20 2499462.78 214065.80 N 60.83182107 W 151.60247962 644.21 4.83 288.51 483.78 644.03 -1.39 7.77 6.76 3.70 -5.66 4.20 2499463.63 214063.77 N 60.83182326 W 151.60249113 674.32 6.17 285.79 513.75 674.00 -1.18 10.66 9.56 4.54 -8.41 4.53 2499464.54 214061.03 N 60.83182556 W 151.60250659 704.13 7.67 283.87 543.34 703.59 -0.77 14.25 13.08 5.45 -11.89 5.09 2499465.54 214057.58 N 60.83182806 W 151.602526 734.61 9.27 281.86 573.49 733.74 -0.11 18.74 17.50 6.44 -16.27 5.34 2499466.64 214053.23 N 60.83183078 W 151.60255 765.70 10.85 280.37 604.10 764.35 0.85 24.17 22.86 7.49 -21.59 5.15 2499467.81 214047.92 N 60.83183362 W 151.602580 799.00 12.47 278.90 636.71 796.96 2.21 30.90 29.51 8.61 -28.23 4.95 2499469.09 214041.32 N 60.83183669 W 151.60261762 829.16 14.05 274.67 666.07 826.32 3.95 37.81 36.34 9.41 -35.10 6.14 2499470.06 214034.47 N 60.83183888 W 151.60265610 861.64 15.88 273.23 697.45 857.70 6.45 46.20 44.59 9.98 -43.46 5.75 2499470.84 214026.12 N 60.83184045 W 151.60270298 892.32 17.28 273.95 726.85 887.10 9.11 54.95 53.25 10.53 -52.20 4.61 2499471.60 214017.40 N 60.83184195 W 151.60275194 924.59 18.97 271.42 757.52 917.77 12.31 64.99 63.19 10.99 -62.23 5.78 2499472.31 214007.39 N 60.83184321 W 151.60280812 955.56 20.20 270.75 786.69 946.94 15.89 75.37 73.46 11.18 -72.61 4.04 2499472.75 213997.02 N 60.83184374 W 151.60286627 988.47 21.38 272.32 817.46 977.71 19.83 87.05 85.06 11.50 -84.28 3.96 2499473.36 213985.36 N 60.83184461 W 151.60293170 1019.00 22.71 270.84 845.76 1006.01 23.69 98.51 96.46 11.81 -95.73 4.72 2499473.95 213973.91 N 60.83184546 W 151.60299588 1050.65 24.09 269.55 874.81 1035.06 28.21 111.08 108.95 11.85 - 108.30 4.65 2499474.29 213961.35 N 60.83184557 W 151.60306630 1083.37 25.40 268.59 904.52 1064.77 33.38 124.77 122.55 11.63 - 122.00 4.19 2499474.40 213947.66 N 60.83184495 W 151.60314303 1114.16 26.73 268.53 932.18 1092.43 38.60 138.30 135.99 11.29 - 135.52 4.32 2499474.39 213934.13 N 60.83184402 W 151.60321882 1144.99 28.03 268.08 959.55 1119.80 44.13 152.48 150.09 10.87 - 149.69 4.27 2499474.32 213919.95 N 60.83184287 W 151.60329823 1177.76 29.58 269.25 988.27 1148.52 50.19 168.27 165.81 10.50 - 165.48 5.03 2499474.34 213904.16 N 60.83184187 W 151.60338667 SurveyEditor Ver SP 2.1 Bld( users) M -20 (leg Al slot 2) \M- 20 \M- 20 \M -20 Generated 12/15/2009 1:37 PM Page 1 of 4 Comments Measured Inclination Azimuth Sub -Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft ) (deg) (deg) (ft ) (ft) (ft) (ft) (ft ) (ft ) (ft ) (deg1100ft ) (ftUS) (ftUS) 1209.28 30.92 268.57 1015.50 1175.75 56.22 184.15 181.64 10.20 - 181.35 4.39 2499474.42 213888.28 N 60.83184104 W 151.60347563 1240.43 31.97 269.54 1042.07 1202.32 62.36 200.40 197.85 9.93 - 197.60 3.74 2499474.55 213872.03 N 60.83184031 W 151.60356667 1272.22 33.37 268.87 1068.83 1229.08 68.80 217.56 214.98 9.69 - 214.76 4.55 2499474.73 213854.88 N 60.83183966 W 151.60366281 MWD 1300.45 34.26 268.96 1092.29 1252.54 74.77 233.27 230.66 9.40 - 230.46 3.16 2499474.82 213839.17 N 60.83183884 W 151.60375083 1331.32 35.60 268.34 1117.59 1277.84 81.57 250.94 248.30 8.98 - 248.13 4.49 2499474.83 213821.49 N 60.83183770 W 151.60384984 1351.60 36.57 267.88 1133.98 1294.23 86.26 262.88 260.21 8.58 - 260.07 4.97 2499474.73 213809.55 N 60.83183662 W 151.60391673 13 -3/8" Csg 1425.00 40.48 267.27 1191.40 1351.65 104.62 308.59 305.81 6.64 - 305.74 5.35 2499473.90 213763.85 N 60.83183130 W 151.60417262 1487.69 43.82 266.83 1237.87 1398.12 121.87 350.66 347.77 4.47 - 347.75 5.35 2499472.76 213721.80 N 60.83182537 W 151.60440800 1519.88 45.46 266.19 1260.77 1421.02 131.34 373.27 370.33 3.09 - 370.32 5.28 2499471.94 213699.20 N 60.83182160 W 151.60453450 1614.41 49.87 263.99 1324.42 1484.67 162.17 443.13 439.92 -2.93 - 439.91 4.97 2499467.61 213629.48 N 60.83180511 W 151.60492446 1709.00 54.67 261.55 1382.29 1542.54 197.88 517.92 514.24 -12.39 - 514.09 5.47 2499459.96 213555.09 N 60.83177921 W 151.60534011 1805.57 58.80 259.27 1435.26 1595.51 239.29 598.64 594.24 -25.88 - 593.68 4.71 2499448.43 213475.20 N 60.83174232 W 151.60578 1899.30 62.89 257.22 1480.91 1641.16 283.89 680.48 675.13 -42.58 - 673.79 4.76 2499433.69 213394.71 N 60.83169662 W 151.60623 SZ12 ST Marker 1950.50 64.98 256.10 1503.41 1663.66 310.00 726.47 720.50 -53.20 - 718.54 4.54 2499424.17 213349.72 N 60.83166758 W 151.60648566 1992.66 66.71 255.20 1520.66 1680.91 332.40 764.93 758.40 -62.73 - 755.80 4.54 2499415.54 213312.23 N 60.83164148 W 151.60669448 2088.90 70.88 251.69 1555.47 1715.72 387.40 854.63 846.38 -88.33 - 841.76 5.51 2499392.06 213225.67 N 60.83157146 W 151.60717612 2122.71 72.54 250.43 1566.08 1726.33 408.12 886.74 877.69 -98.75 - 872.12 6.05 2499382.38 213195.07 N 60.83154295 W 151.60734624 2206.14 76.33 247.36 1588.47 1748.72 462.27 967.09 955.64 - 127.69 - 947.07 5.76 2499355.27 213119.43 N 60.83146375 W 151.60776619 2301.85 78.17 248.44 1609.59 1769.84 526.34 1060.44 1046.30 - 162.81 - 1033.56 2.22 2499322.28 213032.12 N 60.83136768 W 151.60825079 2396.99 77.77 248.20 1629.42 1789.67 589.72 1153.49 1137.25 - 197.18 - 1120.02 0.49 2499290.03 212944.84 N 60.83127363 W 151.60873528 2491.42 77.27 247.91 1649.83 1810.08 652.82 1245.68 1227.59 - 231.64 - 1205.54 0.61 2499257.67 212858.50 N 60.83117936 W 151.60921444 2585.96 77.48 248.37 1670.49 1830.74 715.87 1337.94 1318.28 - 265.99 - 1291.16 0.52 2499225.42 212772.07 N 60.83108537 W 151.60969418 2680.87 77.12 248.23 1691.36 1851.61 778.96 1430.53 1409.53 - 300.22 - 1377.19 0.41 2499193.30 212685.23 N 60.83099170 W 151.61017619 2774.73 76.77 248.47 1712.56 1872.81 841.20 1521.96 1499.83 - 333.96 - 1462.17 0.45 2499161.65 212599.45 N 60.83089940 W 151.61065235 2869.26 76.77 248.74 1734.20 1894.45 903.54 1613.98 1590.89 - 367.53 - 1547.85 0.28 2499130.19 212512.98 N 60.83080755 W 151.61113241 2964.99 76.97 248.56 1755.94 1916.19 966.64 1707.21 1683.26 - 401.47 - 1634.68 0.28 2499098.38 212425.35 N 60.83071467 W 151.61161891 3060.63 77.68 248.55 1776.93 1937.18 1029.91 1800.52 1775.78 - 435.58 - 1721.53 0.74 2499066.39 212337.69 N 60.83062132 W 151.61210551 3155.40 78.12 248.78 1796.79 1957.04 1092.62 1893.18 1867.76 - 469.29 - 1807.84 0.52 2499034.80 212250.58 N 60.83052907 W 151.61258911 3247.85 78.12 247.85 1815.82 1976.07 1154.24 1983.65 1957.56 - 502.72 - 1891.91 0.98 2499003.43 212165.72 N 60.83043759 W 151.61306012 3344.24 77.97 247.74 1835.79 1996.04 1219.10 2077.95 2051.13 - 538.36 - 1979.22 0.19 2498969.94 212077.57 N 60.83034007 W 151.613540 3438.88 77.91 247.74 1855.57 2015.82 1282.82 2170.50 2143.01 - 573.42 - 2064.87 0.06 2498936.98 211991.09 N 60.83024413 W 151.61402 3531.17 77.91 246.81 1874.90 2035.15 1345.48 2260.75 2232.57 - 608.28 - 2148.11 0.99 2498904.16 211907.03 N 60.83014873 W 151.61449552 3627.35 77.82 246.74 1895.11 2055.36 1411.36 2354.78 2325.85 - 645.36 - 2234.52 0.12 2498869.20 211819.74 N 60.83004726 W 151.61497965 3721.63 77.50 245.72 1915.26 2075.51 1476.50 2446.88 2417.16 - 682.48 - 2318.80 1.11 2498834.15 211734.57 N 60.82994567 W 151.61545188 3817.73 76.92 243.37 1936.54 2096.79 1544.71 2540.59 2509.74 - 722.76 - 2403.42 2.46 2498795.96 211649.00 N 60.82983546 W 151.61592592 3912.23 75.71 241.82 1958.90 2119.15 1613.63 2632.41 2600.02 - 765.01 - 2484.93 2.04 2498755.70 211566.48 N 60.82971983 W 151.61638258 4002.14 74.91 238.08 1981.71 2141.96 1681.49 2719.38 2684.84 - 808.55 - 2560.20 4.12 2498714.02 211490.18 N 60.82960069 W 151.61680426 4102.15 73.46 233.41 2008.98 2169.23 1760.76 2815.59 2777.10 - 862.68 - 2639.71 4.72 2498661.84 211409.36 N 60.82945257 W 151.61724970 4196.75 70.63 227.80 2038.16 2198.41 1839.13 2905.57 2861.10 - 919.74 - 2709.24 6.38 2498606.50 211338.46 N 60.82929646 W 151.61763919 4290.89 68.26 222.02 2071.23 2231.48 1919.81 2993.70 2940.32 - 982.10 - 2771.46 6.28 2498545.68 211274.74 N 60.82912583 W 151.61798772 4323.57 67.70 220.61 2083.48 2243.73 1948.27 3024.00 2966.81 - 1004.86 - 2791.46 4.35 2498523.42 211254.19 N 60.82906358 W 151.61809975 4385.58 66.24 218.02 2107.75 2268.00 2002.51 3081.06 3015.92 - 1049.00 - 2827.61 4.51 2498480.17 211216.97 N 60.82894281 W 151.61830228 4481.08 63.60 214.77 2148.23 2308.48 2085.97 3167.55 3088.62 - 1118.59 - 2878.94 4.14 2498411.86 211163.95 N 60.82875242 W 151.61858978 4577.01 60.39 211.12 2193.28 2353.53 2168.87 3252.23 3157.68 - 1189.62 - 2925.02 4.74 2498341.98 211116.16 N 60.82855810 W 151.61884785 SurveyEditor Ver SP 2.1 Bld( users) M -20 (leg Al slot 2) \M- 20 \M- 20 \M -20 Generated 12/15/2009 1:37 PM Page 2 of 4 Comments Measured Inclination Azimuth Vertical TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft ) (deg) (deg) (ft) (ft ) (ft ) (ft) (ft ) (ft ) (ft ) (deg/100ft ) (ftUS) (ftUS) 4671.91 57.65 210.01 2242.13 2402.38 2249.15 3333.58 3222.77 - 1259.66 - 2966.40 3.06 2498272.97 211073.08 N 60.82836647 W 151.61907959 4766.71 55.33 208.94 2294.46 2454.71 2327.37 3412.62 3285.82 - 1328.46 - 3005.30 2.62 2498205.14 211032.51 N 60.82817825 W 151.61929743 4860.70 54.28 205.82 2348.64 2508.89 2403.72 3489.42 3346.05 - 1396.65 - 3040.63 2.93 2498137.84 210995.53 N 60.82799172 W 151.61949526 4956.52 54.91 201.56 2404.17 2564.42 2481.72 3567.51 3404.78 - 1468.14 - 3071.98 3.68 2498067.13 210962.44 N 60.82779613 W 151.61967084 5052.48 54.48 197.56 2459.65 2619.90 2559.97 3645.81 3460.68 - 1541.91 - 3098.20 3.43 2497994.03 210934.43 N 60.82759433 W 151.61981761 5147.20 54.15 193.24 2514.92 2675.17 2636.48 3722.73 3512.47 - 1616.05 - 3118.63 3.72 2497920.41 210912.20 N 60.82739151 W 151.61993195 5240.81 53.86 187.88 2569.96 2730.21 2710.86 3798.45 3559.53 - 1690.45 - 3132.50 4.64 2497846.36 210896.51 N 60.82718797 W 151.62000960 5335.15 53.73 182.98 2625.70 2785.95 2784.06 3874.55 3602.39 - 1766.20 - 3139.71 4.19 2497770.82 210887.46 N 60.82698078 W 151.62004983 5430.34 53.58 178.93 2682.13 2842.38 2855.95 3951.22 3641.68 - 1842.83 - 3140.99 3.43 2497694.24 210884.30 N 60.82677116 W 151.62005689 5524.50 54.25 173.97 2737.62 2897.87 2924.98 4027.29 3676.64 - 1918.74 - 3136.26 4.32 2497618.24 210887.17 N 60.82656353 W 151.62003032 5620.69 54.40 170.21 2793.73 2953.98 2993.19 4105.42 3708.54 - 1996.11 - 3125.51 3.18 2497540.63 210896.03 N 60.82635189 W 151.61996996 5712.97 54.73 169.06 2847.23 3007.48 3057.22 4180.61 3737.60 - 2070.07 - 3111.98 1.08 2497466.36 210907.75 N 60.82614960 W 151.61989 5811.78 55.04 168.85 2904.07 3064.32 3125.54 4261.44 3769.38 - 2149.40 - 3096.50 0.36 2497386.68 210921.29 N 60.82593262 W 151.6198 5906.85 53.99 168.69 2959.25 3119.50 3190.85 4338.85 3800.95 - 2225.33 - 3081.42 1.11 2497310.41 210934.51 N 60.82572493 W 151.61972 6001.33 54.23 168.87 3014.64 3174.89 3255.42 4415.39 3833.47 - 2300.41 - 3066.53 0.30 2497234.99 210947.57 N 60.82551957 W 151.61963907 6098.79 53.71 170.05 3071.97 3232.22 3322.41 4494.20 3869.07 - 2377.89 - 3052.11 1.12 2497157.17 210960.09 N 60.82530764 W 151.61955818 6194.70 53.37 171.14 3128.96 3289.21 3388.77 4571.34 3906.49 - 2453.99 - 3039.50 0.98 2497080.79 210970.83 N 60.82509949 W 151.61948745 6287.87 53.80 170.77 3184.27 3344.52 3453.51 4646.32 3944.37 - 2528.03 - 3027.72 0.56 2497006.48 210980.81 N 60.82489695 W 151.61942130 6383.37 53.89 170.27 3240.61 3400.86 3519.79 4723.43 3983.92 - 2604.09 - 3015.02 0.43 2496930.14 210991.65 N 60.82468892 W 151.61935004 6478.20 54.00 169.82 3296.43 3456.68 3585.36 4800.09 4023.78 - 2679.60 - 3001.76 0.40 2496854.33 211003.05 N 60.82448238 W 151.61927569 6572.77 53.98 169.43 3352.03 3512.28 3650.50 4876.59 4064.14 - 2754.85 - 2987.99 0.33 2496778.77 211014.99 N 60.82427656 W 151.61919840 6668.28 54.13 169.28 3408.09 3568.34 3716.15 4953.91 4105.67 - 2830.84 - 2973.70 0.20 2496702.45 211027.41 N 60.82406870 W 151.61911828 6762.43 54.61 168.61 3462.94 3623.19 3780.83 5030.44 4147.33 - 2905.94 - 2959.03 0.77 2496627.01 211040.25 N 60.82386327 W 151.61903596 6858.64 54.32 169.80 3518.86 3679.11 3847.19 5108.73 4191.26 - 2982.85 - 2944.36 1.05 2496549.77 211053.03 N 60.82365292 W 151.61895370 6951.23 54.14 170.49 3572.98 3733.23 3911.51 5183.85 4235.34 - 3056.86 - 2931.50 0.64 2496475.47 211064.08 N 60.82345047 W 151.61888157 7046.85 54.40 170.18 3628.82 3789.07 3978.10 5261.48 4282.00 - 3133.38 - 2918.47 0.38 2496398.65 211075.24 N 60.82324117 W 151.61880846 7144.68 54.64 170.45 3685.60 3845.85 4046.44 5341.14 4330.80 - 3211.91 - 2905.07 0.33 2496319.82 211086.72 N 60.82302637 W 151.61873327 7239.80 54.99 170.03 3740.41 3900.66 4113.06 5418.88 4379.21 - 3288.53 - 2891.89 0.52 2496242.90 211098.02 N 60.82281681 W 151.61865934 7331.69 54.93 170.39 3793.17 3953.42 4177.53 5494.12 4426.82 - 3362.67 - 2879.10 0.33 2496168.48 211109.00 N 60.82261402 W 151.61858757 7425.99 54.66 169.66 3847.54 4007.79 4243.42 5571.17 4476.18 - 3438.55 - 2865.75 0.69 2496092.29 211120.49 N 60.82240645 W 151.61851 7522.99 54.32 169.18 3903.88 4064.13 4310.50 5650.13 4526.93 - 3516.17 - 2851.26 0.53 2496014.34 211133.08 N 60.82219415 W 151.61843 7617.57 54.25 168.42 3959.09 4119.34 4375.30 5726.92 4576.43 - 3591.50 - 2836.34 0.66 2495938.67 211146.15 N 60.82198810 W 151.61834775 7712.51 53.23 166.57 4015.24 4175.49 4438.95 5803.47 4625.19 - 3666.23 - 2819.77 1.90 2495863.55 211160.89 N 60.82178369 W 151.61825485 7805.48 52.15 164.36 4071.60 4231.85 4498.93 5877.41 4670.98 - 3737.80 - 2801.23 2.22 2495791.55 211177.68 N 60.82158792 W 151.61815086 7901.68 50.94 162.45 4131.43 4291.68 4558.42 5952.74 4716.24 - 3810.00 - 2779.72 2.00 2495718.86 211197.42 N 60.82139047 W 151.61803031 7988.29 50.02 160.21 4186.55 4346.80 4609.66 6019.55 4755.08 - 3873.29 - 2758.35 2.26 2495655.06 211217.24 N 60.82121736 W 151.61791049 8082.55 50.31 160.41 4246.93 4407.18 4664.34 6091.93 4796.82 - 3941.44 - 2733.96 0.35 2495586.34 211239.96 N 60.82103096 W 151.61777379 8175.70 49.73 159.86 4306.78 4467.03 4718.12 6163.31 4838.50 - 4008.57 - 2709.71 0.77 2495518.64 211262.56 N 60.82084735 W 151.61763786 9 -5/8" Csg 8223.00 49.58 159.91 4337.40 4497.65 4745.17 6199.36 4859.69 - 4042.42 - 2697.31 0.32 2495484.49 211274.13 N 60.82075475 W 151.61756836 8270.10 49.44 159.96 4367.98 4528.23 4772.08 6235.18 4880.95 - 4076.07 - 2685.02 0.32 2495450.56 211285.60 N 60.82066272 W 151.61749948 8363.91 46.64 159.82 4430.70 4590.95 4824.43 6304.93 4922.77 - 4141.57 - 2661.04 2.99 2495384.49 211307.97 N 60.82048357 W 151.61736507 8459.78 42.24 159.62 4499.13 4659.38 4874.67 6372.04 4963.45 - 4204.52 - 2637.78 4.59 2495320.99 211329.68 N 60.82031139 W 151.61723473 8553.24 37.95 159.67 4570.61 4730.86 4919.67 6432.22 5000.35 - 4260.94 - 2616.85 4.59 2495264.08 211349.23 N 60.82015707 W 151.61711740 8646.45 33.19 156.81 4646.41 4806.66 4959.35 6486.42 5032.97 - 4311.30 - 2596.83 5.41 2495213.25 211368.01 N 60.82001933 W 151.61700522 SurveyEditor Ver SP 2.1 BId( users) M -20 (leg Al slot 2) \M- 20 \M- 20 \M -20 Generated 12/15/2009 1:37 PM Page 3 of 4 Measured Azimuth Vertical Along Hole NS EW Comments Depth Inclination True Sub -Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft) _ (deg) (deg) (ft ) (ft) (ft ) (ft ) (ft) (ft) (ft ) (deg /100ft ) (ftUS) (ftUS) 8743.84 31.56 151.12 4728.68 4888.93 4994.73 6538.53 5061.51 - 4358.13 - 2574.02 3.55 2495165.87 211389.67 N 60.81989124 W 151.61687738 8838.52 32.90 144.41 4808.79 4969.04 5024.69 6588.98 5084.70 - 4400.75 - 2547.08 4.03 2495122.60 211415.57 N 60.81977467 W 151.61672642 8933.08 33.64 142.03 4887.86 5048.11 5052.14 6640.85 5105.31 - 4442.29 - 2516.02 1.59 2495080.32 211445.60 N 60.81966107 W 151.61655238 9027.96 34.80 140.96 4966.31 5126.56 5079.01 6694.21 5125.51 - 4484.03 - 2482.79 1.38 2495037.77 211477.80 N 60.81954690 W 151.61636623 9123.66 34.66 142.23 5044.96 5205.21 5106.56 6748.73 5146.72 - 4526.76 - 2448.92 0.77 2494994.24 211510.61 N 60.81943005 W 151.61617648 9218.56 35.25 145.29 5122.75 5283.00 5135.78 6803.09 5170.23 - 4570.60 - 2416.80 1.95 2494949.62 211541.66 N 60.81931013 W 151.61599649 9313.24 35.12 148.13 5200.13 5360.38 5167.42 6857.64 5196.76 - 4616.20 - 2386.86 1.73 2494903.31 211570.47 N 60.81918544 W 151.61582874 9408.00 35.12 150.17 5277.65 5437.90 5200.90 6912.15 5225.70 - 4662.99 - 2358.91 1.24 2494855.85 211597.27 N 60.81905745 W 151.61567213 9503.51 35.15 152.82 5355.76 5516.01 5236.41 6967.11 5257.15 - 4711.28 - 2332.68 1.60 2494806.93 211622.31 N 60.81892536 W 151.61552518 9598.35 34.91 153.81 5433.42 5593.67 5272.88 7021.55 5290.07 - 4759.92 - 2308.23 0.65 2494757.71 211645.57 N 60.81879233 W 151.61538819 9692.85 35.40 152.94 5510.68 5670.93 5309.37 7075.96 5323.37 - 4808.56 - 2283.85 0.74 2494708.49 211668.76 N 60.81865930 W 151.61525154 9787.91 35.39 151.72 5588.17 5748.42 5345.55 7131.02 5356.62 - 4857.32 - 2258.28 0.74 2494659.12 211693.13 N 60.81852593 W 151.61510 9882.96 35.24 152.03 5665.73 5825.98 5381.32 7185.96 5389.82 - 4905.78 - 2232.38 0.25 2494610.04 211717.84 N 60.81839339 W 151.6149 9977.62 35.44 153.76 5742.95 5903.20 5417.71 7240.71 5424.02 - 4954.52 - 2207.43 1.08 2494560.71 211741.58 N 60.81826009 W 151.61482 10073.03 35.59 154.71 5820.61 5980.86 5455.50 7296.14 5459.98 - 5004.43 - 2183.34 0.60 2494510.22 211764.45 N 60.81812357 W 151.61468842 10167.35 35.45 155.19 5897.38 6057.63 5493.36 7350.94 5496.35 - 5054.08 - 2160.14 0.33 2494460.03 211786.43 N 60.81798779 W 151.61455841 10262.15 35.58 156.08 5974.55 6134.80 5531.88 7406.01 5533.70 - 5104.24 - 2137.42 0.56 2494409.32 211807.92 N 60.81785058 W 151.61443111 10357.09 35.68 156.98 6051.71 6211.96 5571.17 7461.31 5572.13 - 5154.97 - 2115.40 0.56 2494358.07 211828.70 N 60.81771182 W 151.61430770 Last Survey 10435.99 34.59 156.30 6116.24 6276.49 5603.50 7506.72 5603.96 - 5196.66 - 2097.40 1.47 2494315.96 211845.67 N 60.81759780 W 151.61420684 7" Lnr 10498.00 34.59 156.30 6167.29 6327.54 5628.42 7541.92 5628.61 - 5228.89 - 2083.25 0.00 2494283.39 211859.03 N 60.81750964 W 151.61412755 TD (Projected) 10500.00 34.59 156.30 6168.93 6329.18 5629.22 7543.06 5629.40 - 5229.93 - 2082.79 0.00 2494282.34 211859.46 N 60.81750679 W 151.61412500 Survey Type: Definitive Survey NOTES: Gyro -MWD - ( GyroMWD system for use in low angle applications up to 20 degrees of inclination only. This is a preliminary error model pending further information from the gyro vendors. ) MWD - ( MWD - Standard -- Standard SLB MWD surveys which have fully met their FAC "field acceptance criteria" without any additional corrections. Survev Error Model: SLB ISCWSA version 24 * ** 3 -D 95.00% Confidence 2.7955 sigma Surveying Proq: MD From ( ft ) MD To (ft) EOU Freq Survey Tool Type Borehole -> Survey 0.00 345.25 Act -Stns SLB_GYRO -MWD -Depth Only M -20 -> M -20 • 345.25 1272.22 Act -Stns SLB_GYRO -MWD M -20 -> M -20 1272.22 1351.60 Act -Stns SLB_MWD- STD^ ^1 M -20 -> M -20 1351.60 8175.70 Act -Stns SLB_MWD- STD^ ^2 M -20 -> M -20 8175.70 10435.99 Act -Stns SLB_MWD- STD^ "3 M -20 -> M -20 10435.99 10500.00 Act -Stns SLB_BLINDAA3 M -20 -> M -20 Legal Description: Northing (Y) fftUS] Eastinq (X) (ftUS] Surface : 4236 FSL 4828 FEL S33 T9N R13W SM 2499459.80 214069.33 BHL : 4286 FSL 421 FEL S6 T8N R13W SM 2494282.34 211859.46 SurveyEditor Ver SP 2.1 Bld( users) M -20 (leg Al slot 2) \M- 20 \M- 20 \M -20 Generated 12/15/2009 1:37 PM Page 4 of 4 • • M -20 Mud Weight vs. Depth (MD & 0 1000 0 I 2000 3000 - 4000 5000 —4--Mud Weight Vs. MD —11I—Mud Weight Vs. ND 6000 7000 - 8000 9000 r dIS 10000 11000 I r 8.5 8.7 8.9 9.1 9.3 9.5 9.7 9.9 • Page 1 of 1 Aubert, Winton G (DOA) From: Barbee, Marcus [Consultant] [Marcus.Barbee @chevron.com] Sent: Tuesday, November 24, 2009 3:05 PM To: Aubert, Winton G (DOA) Cc: Nienhaus, Doug R; Bonnett, Nigel (Nigel.Bonnett); Tyler, Steve L; Brandenburg, Tim C; Kanyer, Christopher V; Rose, Jim [Contractor]; Ross, David A. [Petro Technical Resources of AK]; Flynn, Tim [ASRC] Subject: M -20 (PTD 2090930) API (50- 733 - 20587 -00) Attachments: M -20 Proposed Well Schematic VI 1.2.docx Mr. Aubert, Post log analysis of M -20 has caused Chevron to change completion plans. We will be perforating zones D -6, D -16A & D -16C and completing with 3-1/2" production tubing. Gravel pack operations in the B & C sands will not be pursued at this time. We are planning to complete over the Thanksgiving Holiday; please see the attached proposed schematic. Thank you, Wellbore Maintenance Team Chevron, Alaska 1- 907 - 263 -7605 Office 1- 907 -250 -1163 Cell 1- 907 -745 -2386 Home This transmission may contain information that is privileged, confidential and / or exempt from disclosure under applicable law. If you are not the intended recipient, you are hereby notified that any disclosure, copying, distribution, or use of the information contained herein (including any reliance therein) is STRICTLY PROHIBITED. If you received this transmission in error, please immediately contact the sender and destroy the material in its entirety, whether in electronic or hard copy format Thank You 11/24/2009 v ! Chevron • Set head Platform # Well M -20 OW Proposed 09/09 V11.2 Casing and Tubing Detail RKB to TBG Head = 78'.75 CONN MIN TOP TOP 3TM BTM 1D in MD TVD MD TVD Cement to ML rkb rkb -kb rkb f. @ 345 28" Structural 27 Surface Surface 480' 480' 13 -3/8" 68 L-80 BTC 12.415 Surface Surface 1430' 1355' 9-5/8" 47 L-80 BTC -M 8.681 Surface Surface 8230' 4489' ECP Stage 7" 26 L -80 DWCSR 6.276 8030' 4361' 10650' 6444' Collar 450-460 Tubing 3-1/2" 9.2 L-80 TCII 2.992 Surface Surface 6007' 3179' 28" Conductor @ 480 Hole Section! 17 y" GR /Res Gas Detection, Consulting Geologist Mud Logging L , 13318" in 17 f" Hole 12 ./." GR /Res/ Dens- Gas Detection, Mud Logging Neat, PVVD Vib Consulting Geologist 8 ,, /z " GR /ResJ Dens- Gas Detection, Consulting Geologist Neut, PWD Vib Mud Logging 9 5/8 Hydraulic A" Stage collar@ <«Ilaneous Eqr +ir- - t'^ - armtion I ,ih O`. Notes TE -5 SSSV 430 5.38 2.31 SFO-1 GLM -1638 5.31 2.87 SFO-1 GLM -482 5.31 2.87 SFO-1 GLM _6,,' 5.31 2.87 J SFO-1 GLM 5.31 2.87 SFO-1 GLM 5.31 2.87 Model S -3 Packer 8975 6.0 3.95 X- Nipple 8985 3.50 2.81 XN nipple 10,198 2.75 WLEG / burst disc 10,200 >9 J 4 9 518" Casing in 12'/." H o l e Pe Zoi +- 9,000 - 9,054' 5040' - 5072' D-6 12 4 -5/8" Millennium Charge 22.7 gm +- 10,214' - 10,226' 6118' - 6137' D-16A 12 4 -5/8" Millennium Charge 22.7 gm +- 10,268' - 10,300' 6156' - 6187' D -16C 12 4 -5/8" Millennium Charge 22.7 gm S D -6 Sand D -16A Sand D -16C Sand 7" Liner in 8 1/2" Hole MAX HOLE ANGLE = 77 Deg @ 2235' Well Detail DRAWN BY: DR 0 • -\ 1 L z t E S EAN PARNELL, GOVERNOR [.) / / ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 19647 Anchorage, SK 99519 Re: McArthur River Field, Graying Gas Sands, Trading Bay Unit M -20 Union Oil Company of California Permit No: 209 -093 Surface Location: 1044' FNL, 452 FWL, SEC. 33, T9N, R13W, SM Bottomhole Location: 996' FNL, 391 FEL, SEC. 6, T8N, R13W, SM Dear Mr. Brandenburg: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, mil' Daniel T. Seamount, Jr. Chair DATED this day of September, 2009 cc: Department of Fish 86 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • • Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, , AK AK 99519 -6247 Tel 907 263 7657 Fax 907 263 78888 4 Email brandenburgt @chevron.com 8/20/09 2, ",q0 :lQb nl `e! Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7` Avenue Anchorage, Alaska 99501 Re: Steelhead Platform, Trading Bay Unit M -20 Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the Trading Bay Unit M -20 well from the Steelhead Platform. Drilling operations are expected to commence approximately October 15, 2009 depending on the progress of other ongoing projects. Per Conservation Order 228, Trading Bay Unit requires 10 acre spacing. There are no wells producing or capable of production from the target strata of TBU M -20 within 745' of the planned wellpath of TBU M -20. Therefore, a spacing exemption is not required to drill or produce TBU M -20. — Due to the unstable nature of coals in Cook Inlet, Union Oil Company has planned alternate depths for the 9 5/8 casing shoe. Union Oil Company proposes the following alternate depths; the choice of which will be based on hole conditions encountered while drilling. 9 5/8 Casing Shoe Option 1 7200'MD, 3850' TVD 9 5/8 Casing Shoe Option 2 7840'MD, 4120' TVD In accordance with 20 AAC 25.005 (c)(4)(A -C)... (A) MASP calculations are attached for review. (B) The Grayling Gas Sands are potentially gas bearing throughout the section. Potential target reservoirs and their predicted pore pressures are indicated in the attached M -20 ' Well Design Summary. (C) Due to ongoing production operations in this field, sub - normally pressured sands occur in multiple places. Lost circulation and differential sticking are potential problems. Conventional solutions such as LCM and good drilling practice are intended to ameliorate the problems. An exception to 20 AAC 25.035 (c)(1)(B) is requested. The diverter system at Steelhead includes two 16" diameter diverter lines. The surface hole -_ section of M -20 is planned to be drilled with a 17 'h" bit. Union Oil Company of California / A Chevron Company Page 1 of 2 • • An exception to 20 AAC 25.035 (e)(3) is requested. The BOP stack for Steelhead includes 20 %" 3M ram preventers and a 21 1 /4" 2M annular preventer. The MASP for the subject well, when calculated in the most pessimistic manner, exceeds the rated working pressure of the annular preventer. The annular preventer will not be used in a secondary well control event in excess of its rated working pressure. Union Oil Company also requests that the test pressure for the annular be established at 1000 psi. The annular preventer has been previously tested to 2000 psi. Repeated testing to 2000 psi will degrade the annular element. In accordance with 20 AAC 25.050 (b)(2)(B)... Union Oil Company of California is the only operator of wells within 200' of the planned trajectory of M -20. Pursuant to 20 AAC 25.005 (c)(14)... Qualified drilling waste will be discharged in accordance with NPDES permit AKG -31 -5000 which became effective 7/2/2007 and expires 7/2/2012. At this time, Union Oil Company does not intend to apply for annular disposal approval. The remaining requirements of 20 AAC 25.005 are attached for review or currently on file with the Commission. If you have any questions, please don't hesitate to contact myself or Jim Rose at 907 - 263 -7637. Sincerely, Timothy C. Brandenburg Drilling Manager Attachments: Form 10-401 in Duplicate M -20 Cementing Calculations M -20 Well Design Summary M -20 Casing Design M -20 Summary Drilling Procedure M -20 MASP Calculations M -20 Summary Mud Program M -20 FIT / LOT Procedure M -20 Planned Well Sketch M -20 Spider Plots M -20 Planned Well Trajectory M -20 Combo BOP /Diverter Schematic M -20 Drilling Hazards Notice M -20 Choke Manifold Schematic M -20 Plat Cc: File Union Oil Company of California / A Chevron Company Page 2 of 2 vJ 4A- STATE OF ALASKA 4 (l l t0 t ALA OIL AND GAS CONSERVATION COMM ON PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development Oil ❑ 1 c. Specify if well is proposed for: Drill El ' Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas . 0 Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket el Single Well ❑ 11. Well Name and Number: Union Oil Company of California Bond No. 086S103515406BCM • Trading Bay Unit M -20 • 3. Address: 6. Proposed Depth: 12. Field /Pool(s): PO Box196247, Anchorage, AK 99519 MD: 10,600' ' TVD: 6,459' • McArthur River Field ' 4a. Location of Well (Governmental Section): 7. Property Designation: 2 Surface: 1044'FNL, 452'FWL, SEC 33, T9N, R13W, SM ADL017594, ADL018729 • ,4 L% «73.t' Grayling Gas Sands • Top of Productive Horizon: 8. Land Use Permit: /P JQ 13. Approximate Spud Date: 1209'FNL, 167'FEL, SEC 32, T9N, R13W, SM N/A 10/15/2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest 996'FNL, 391'FEL, SEC 6, T8N, R13W, SM 5116, 3085 Property: >6,000' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 160' AMSL 15. Distance to Nearest Well Open Surface: x- 214069 . y- 2499460 • Zone- 4 KB Elevation above GL: feet to Same Pool: N/A 16. Deviated wells: Kickoff depth: 525 feet 17. Maximum Anticipated Pressures in psig (see 20 5.035) Maximum Hole Angle: 82 degrees Downhole: 2,855 • Surface: ,209 • 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 28 -32 1/2 -1" WT X -56 Weld 401 0 0 480 480 Driven 17 -1/2" 13 -3/8" 68# L -80 BTC 1311 0 0 1390 1310 3,194 ft in 2 stages r 12 -1/4" 9 -5/8" 47# L -80 BTC -M 7121 0 0 7200 3918 2993 ft in 4- 6tage. / %t o 8 -1/2" 7" 26# L -80 DWCSR 3600 7000 3804 10600 6459 606 ft in 1 stage / C? 4 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural 401' 28 -32 Driven 480' 480' Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): N/A N/A 20. Attachments: Filing Fee ❑ BOP Sketch El Drilling Program El Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat El Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements el 21. Verbal Approval: Commission Representative: Date 8/20/2009 22. 1 hereby certify that the foregoing is true and correct. Contact Jim Rose 907 - 263 -7637 Printed Name # Timothy C Bran nburg Title Drilling Manager Signature K' 1 • Phone 907 - 276 -7600 Date '$/7-9 101 Commission Use Only Permit to Drill -,-,. API Number: Permit Appro I See cover letter for other Number: 2-C-- 50- '? 33- : j 8 7`C Date: q 3 / D f requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas h rates, or gas contained in shales: Other: Test 0.K. Yl.1.t -t a y BOP & f 1000 pr-t: , Samples req'd: Yes ❑ " No Mud log req'd: Yes ❑ o l2 Test raw. 3 0 P E j o S 000 e S i . H measures: Yes E No III Directional svy req'd: Yes Q No ❑ N r 20 A M . ZS. 0 3 5 C k) (t) , a, fee itod'e BO J) E h S a ft ro tie d 14„ Zo k A - C 2 5 . 0 SS a) ( z . ' v Vet f ii h.0 V ttri i t c -( { 5 ? Pr0 VC ci. `/—'yam) - APPROVED BY THE COMMISSION ,i/1/5/1" ® ®® DATE: ► r 9 , r , COMMISSIONER 1 9- /' ems Form 10 - 401 (Revised 1/2009) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit in Duplicate STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMON PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development Oil ❑ 1 c. Specify if well is proposed for: Drill 0 Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas 0 Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket El Single Well ❑ 11. Well Name and Number: Union Oil Company of California Bond No. 086S103515406BCM Trading Bay Unit M -20 3. Address: 6. Proposed Depth: 12. Field /Pool(s): PO Box196247, Anchorage, AK 99519 MD: 10,600' TVD: 6,459' McArthur River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1044'FNL, 452'FWL, SEC 33, T9N, R13W, SM ADL017594, ADL018729 Grayling Gas Sands Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1209'FNL, 167'FEL, SEC 32, T9N, R13W, SM N/A 10/15/2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest 996'FNL, 391'FEL, SEC 6, T8N, R13W, SM 5116, 3085 Property: >6,000' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 160' AMSL 15. Distance to Nearest Well Open Surface: x- 214069 y- 2499460 Zone- 4 KB Elevation above GL: feet to Same Pool: N/A 16. Deviated wells: Kickoff depth: 525 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 82 degrees Downhole: 2,855 Surface: 2,209 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 28 -32 1/2 -1" WT X -56 Weld 401 0 0 480 480 Driven 17 -1/2" 13 -3/8" 68# L -80 BTC 1311 0 0 1390 1310 3,194 ft in 2 stages 12 -1/4" 9 -5/8" 47# L -80 BTC -M 7121 0 0 7200 3918 2993 ft in 4 ,tege• 2 sf.a 8 -1/2" 7" 26# L -80 DWCSR 3600 7000 3804 10600 6459 606 ft in 1 stage W(,a. 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural 401' 28 -32 Driven 480' 480' Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): N/A N/A 20. Attachments: Filing Fee ❑ BOP Sketch El Drilling Program El Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat 0 Diverter Sketch El Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 8/20/2009 22. I hereby certify that the foregoing is true and correct. Contact Jim Rose 907 - 263 -7637 Printed Name f Timothy C Brandenburg Title Drilling Manager Signature JO. ` Phone 907 - 276 -7600 Date iSralhi Commission Use Only Permit to Drill API Number: (Permit Approval See cover letter for other Number: 50- Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ❑ Other: Samples req'd: Yes ❑ No El Mud log req'd: Yes ❑ No ❑ H measures: Yes ❑ No ❑ Directional svy req'd: Yes ❑ No ❑ APPROVED BY THE COMMISSION DATE: , COMMISSIONER Form 10-401 (Revised 1/2009) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit in Duplicate Steelhead M -20 Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE 17 -1 /2" Hole Section • Shallow gas sands will be encountered that have the potential to flow and cause a loss of well '/ control. All operations shall proceed with the necessary precautions to prevent a kick. Special attention is required in the following areas: 1. Monitor trip tank on each trip into and out of the hole. 2. Carefully monitor PVT for gain / loss. 3. Have LCM material onboard and ready for use in the event significant losses occur. 4. Minimize surge and swab pressures while tripping. 5. Review cement spacers and washes to ensure the well is not under balanced at any point during cementing operations. 6. Perform diverter drills until the crews are familiar with the procedure. • M -9, M -2, M -3, M -4 are all critical close approach wells. Record annulus pressures on these wells prior to spud and monitor during the drilling of the surface and 1st intermediate hole sections. 12 -1/4" Hole Sections • Shallow gas sands will be encountered that have the potential to flow and cause a loss of well control. All operations shall proceed with the necessary precautions to prevent a kick. Special attention is required in the following areas: 1. Monitor trip tank on each trip into and out of the hole. 2. Carefully monitor PVT for gain / loss. 3. Have LCM material onboard and ready for use in the event significant losses occur. 4. Minimize surge and swab pressures while tripping. 5. Review cement spacers and washes to ensure the well is not under balanced at any point during cementing operations. 8 -1 /2" Hole Section • Significantly under pressured reservoir sands will be encountered A heightened awareness of kick detection, pre -job planning and trip tank calibration will be essential while drilling /trip ping the intermediate interval. • Loss circulation is considered to be a major risk due to the depleted reservoir sands which will be encountered. Loss circulation materials will be readily available for adding to the mud system should significant losses be encountered. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures • Differential sticking is a considerable risk while drilling these depleted sands. Keep the drill string moving whenever possible. • Numerous coals will be drilled through. Unocal coal drilling strategy; limiting the amount of coal drilled ( <10') prior to back reaming should be followed. HYDROGEN SULFIDE - H2S • Steelhead designated as an H2S drill site. Standard Operating Procedures for H2S v precautions should be followed at all times. Version 1.0 Rigsite Hazards and Contingencies Chevron • Steelhead Platform Well M -20 %O. Well Design Summary M -20 Well Design Summary Steelhead M -20 is a development well drilled in a WSW direction from slot Al -2. The well penetrates multiple primary and secondary Grayling Gas Sand targets from the SZ12 at 1585' TVD through the D17 sand at 6269' TVD. M -20's trajectory builds to 82° inclination and then turns to the south while dropping back to 27° inclination near TD at 10600' MD, and - 6459' TVD. Basic Well Information Platform: Steelhead Well Name: Trading Bay Unit M -20 Estimated Spud Date: 10/15/09 Field: McArthur River Productive Horizon: Grayling Gas Sands PTD: TBD Total Depth: 10600' MD, 6459' TVD Slot: Slot Al -2, SW Leg Surface Location: 1044' FNL, 452' FWL, Sec 33, T9N, R13W, SM X= 214069, Y= 2499460, NAD27, ASP, Zone 4 Planned BHL: 996'FNL, 391' FEL, Sec 6, T8N, R13W, SM X=211889, Y=2494279 Original KB Elevation: 160' AMSL KB to THF: TBD Well Control Summary Hole Section Equipment Test Pressure (psi) 21 1 /4 2M Diverter c/w 2 ea 16" 600 psi Diverter 17'/2" Valves* Function 21 1 /4,1 ' Annular, 20 3/4 3M Double Gate, 12 '/4 " 20 3 /43 - M Mud Cross, 20 3/4 3M Single Gate ° 250/1000/3000 - 1 1 /8 5M Choke Manifold* 21 1/4 Annular, 20 3/4 3M Double Gate," 8 1 /2" 20 3/4 3M Mud Cross, 20 3/ 3M Single Gate / 250/1000/3000' 3 1/8 5M Choke Manifold* Schematics of the well control equipment are attached for reference 8/20/2009 Page 1 of 3 • • Chevron %110 Steelhead Platform Well M -20 Well Design Summary Anti - Collision Evaluation Summary There is only 1 close approach well and it is considered "minor risk ". Collision risk will be mitigated procedurally. Close Approach M -20 Path Ellipse Separation Diverging From Well (MD ft) (ft) (ft) D -18 8431 427.7 8431 Formation Integrity Testing Test Point, 20' Pr Depth d Test Type Projected Test Below... (TVD) (EMW ppg) 13 3/8" Csg Shoe 1400 FIT 12.4 min 9 5/8" Shoe 3922 LOT 11.6 min Mud Program Summary Depth Density Viscosity Section (MD ft) Mud Type (pp 9) (sec) PV YP API FL 17'/4" Surf. 0 -1390 Pre -Hyd Gel 9.0-x' 60 -85 10 -28 25 -35 <8 12 1/4" Interm. 1390 -7200 KCL /GEM /Pmr 9.2 -9.3 40 -53 6 -15 13 -20 <_6 8'/2" Prod. 7200 -10600 KCL /GEM /Pmr 9.2 -9.3 40 -53 6 -15 13 -20 <_5 Cementing Summary See Attachments 8/20/2009 Page 2 of 3 • • • Chevron %NO Steelhead Platform Well M -20 %.1 Well Design Summary Formation Markers Measured Forcasted Target Top TVDSS Depths Depth (RKB) V8 EMW Requirement (ppg RKB) C -1 3791 7256 1.2 C -3 3929 7497 2.1 -5.2 max D -2 4657 8476 1.6 -4.8 max D3B 4804 8694 2.3 D -6 5045 9009 1.2 -2.2 max D16 6155 10275 0.8 -3.0 max D -17 6269 10403 8.0 " 8/20/2009 Page 3 of 3 Chevron • IOW Steelhead Platform Well M -20 Basic Drilling Procedure M -20 Basic Drilling Procedure 1. RU Steelhead rig over slot B2 -12. 2. Install A section wellhead and test. 3. Install 21 1 /4 2M /20 3 /4 3M combo diverter /BOP stack and dual 16" diverter lines. Function test diverter per AOGCC requirements. / 4. MU 17 bit and clean out conductor to 480'. 5. MU 17 l /2" directional BHA and drill to 1390' taking gyro surveys as necessary. 6. MU jet wash tool and wash out conductor to 480'. 7. Run and cement 13 3/8" casing to surface in 2 stages utilizing an ECP stage collar. 8. Install 13 5/8 multi bowl wellhead system. NU BOP stack. Install blind flanges on diverter outlets. Install 9 5/8 rams. Test stack to 250/1000/3000. 9. MU 12 drill out BHA and drill out stage tool. Test casing to 1500 psi. 10. Drill out shoe track and perform FIT to 12.4 ppg EMW. r 11. Trip. MU directional BHA. 12. Directionally drill to 7200'. 13. Run and cement 9 5/8 cag to ML in 2 stages. 14. Redress BOP's w/ 7" rams and test 250/1000/3000 psi. Test 9 5/8" casing to 3000 psi 15. MU 8 directional BHA and drill out. Perform LOT to 11.6 ppg minimum. 16. Directionally drill to section TD at -10600' MD. 17. Pull wiper trip. 18. Run 7" Liner, hanger, and liner top packer. Set liner hanger and cement. Set packer. 19. Redress BOP's and test 250/1000/3000. Test 7" liner to 3000 psi. 20. PU clean out string and make bit and scraper runs to PBTD. Displace to completion fluid. 21. TIH with TCP guns and perforate lower GGS. 22. Observe well, and TOOH. 23. TIH with sump packer and test. 24. TIH with TCP guns and perforate for GP Stage 1. 25. Run GP stage 1 tools. 26. Perform GP stage 1. 27. TIH with TCP guns and perforate for GP Stage 2. 28. Run GP stage 2 tools. 29. Perform GP stage 2. 30. TIH with TCP guns and perforate for GP Stage 3. 31. Run GP stage 3 tools. 32. Perform GP stage 3. 33. Run 3 tubing. Space out and land tubing. Test hanger void. 34. Install BPV and ND BOP. 35. NU tree and test. 36. RDMO Steelhead rig. 8/20/2009 Page 1 of 1 BAROID FLU!, SERVICES • M -20 for CHEVRON - MID - CONTINENT EBIZ M -20 Cook Inlet Alaska United States of America Engineered Fluid Solutions Customized to Maximize Wellbore Value Submitted by: Megan Wesselman Halliburton Energy Services 6900 Arctic Blvd Anchorage, Alaska 99518 HALLIBURTON BARDID FLUID SERVICES • • CHEVRON - MID - CONTINENT Operator EBIZ Volume:Basic Mud Prog Well Name M -20 Objective and Methods Steelhead Producer Introduction: The following mud program was prepared for a deviated well on the Steelhead platform in Cook Inlet, Alaska. The well will be spudded with a pre- hydrated gel drilling fluid and the 17 %" interval will then be drilled to section TD at 1,390' MD where 13 3/8" casing will be run and cemented. The 12 %" hole will be drilled to section TD at 7,200' MD where 9 5/8" casing will be run and cemented. The 8 '/" production interval will be drilled to TD at 10,600' MD. The 7" production liner will then be run and cemented in place. 6% KCI brine and corrosion inhibitor will be required for completion. Spud the well with a FW AQUAGEL mud at 9.0 ppg. The mud weight will then be held in the 9.0 to 9.3 ppg mud weight range to the surface hole TD unless hole conditions dictate otherwise. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for efficient hole cleaning. Before cementing the surface casing, ensure the mud weight is 9.5 ppg. LCM will be added to help strengthen the wellbore. A 2% KCI /Clayseal /GEM mud will be maintained through the 12 -1/4" interval. This mud offers good LCM responses if losses are encountered. Special emphasis should be placed on maintaining low ECD's and surge /swab pressures to minimize the potential for lost circulation and disturbing the coal beds. This mud is formulated with three mechanisms to provide waste minimization and effective wellbore stabilization: glycol (GEM GP), ionic inhibition (KCI), and polymer encapsulation (Clayseal). Barotrol can be used to help stabilize the coal seams. The filtrate will be tightened in the lower section of the interval. Background LCM will be added to help seal and strengthen the wellbore. The production interval will use the existing 2% KCI /Clayseal /GEM system. Baracarbs 5/25/50 will be strung into the system while drilling to help prevent differential sticking and reduce formation damage. The mud weight will be held in the 9.2 ppg range or as required for hole stability. Primary Drilling Objectives: • Not exceeding the maximum allowable concentration of any product • Monitoring all discharges • Zero fluid related HSE incidents • Achieve wellbore stability • Achieve good hole cleaning considering hole angle, geometry and anticipated ROP rates • Lost circulation mitigation/control • Achieve good Zonal Isolation as per plan • Achieve minimal formation damage • Minimize fluids related NPT • Optimize LCM particulate to strengthen coal seams United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLIBURTON Page 2of15 BAROID FLUID SERVICES . CHEVRON - MID - CONTINENT Operator EBIZ Volume:Basic Mud Prog Well Name M -20 Critical Fluid Issues: • Eliminating /controlling losses in the under pressured zones. • Maintaining a low ECD in the production zone to reduce risk of lost returns. • Maintaining a stable wellbore through coal seams by reducing ECD's, surge, and swab. • Reducing drilling wastes with the inhibited drilling fluid system. • Follow new NPDES regulations Well Specifics: Casing Program MD Footage 17 -1/2" hole (13 -3/8" csg) 1390 920 12 -1/4" hole (9 -5/8" csg) 7200 5810 8 -1/2" Hole (7" liner) 10600 3400 United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLIBURTON Page 3of15 BAROID FLUID SERVICES • CHEVRON - MID - CONTINENT Operator EBIZ Volume:Basic Mud Prog Well Name M -20 Well Summary Well Data Estimated Days on Well 54 Maximum Density 9.50 ppg Total Measured Depth 10437 ft True Vertical Depth 6300 ft Maximum Deviation Max. Horz. Displacement Bottom Hole Temp Casing Design Description Top Top End End CSG ID CSG Bit Size Hole Hole MD (ft) TVD MD (ft) TVD (in) OD (in) (in) MD (ft) TVD (ft) (ft) (ft) 13 -3/8" Surface 0 0 1390 1307 12.415 13.375 17.500 1390 1307 9 5/8" Intermediate 0 0 7200 3918 8.681 9.625 12.250 7200 3918 7" Production 7200 3918 10437 6300 6.276 7.000 8.500 10437 6300 Fluid Program Int # Fluid Type Interval BHT Max Days (degF) Density (pp 17 -1/2" Surface AQUAGEL Spud Mud 14 5 12 -1/4" 2% Intermediate KCUCLAYSEAL /GEM 20 9.30 GP 2% 8 -1/2" KCUCLAYSEAL /GEM Production GP 20 9.30 United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 HALLIBURTON Page 4of15 BARDID FLUID SERVICES CHEVRON - MID - CONTINENT Operator EBIZ Volume:Basic Mud Prog Well Name M -20 Fluid Properties M -20 1 AQUAGEL Spud Mud Name Min Max Name Min Max Density ppg 9 9.50 Yield Point lbf/100_ft2 25 35 Funnel Viscosity sec /qt 60 85 API Filtrate mL /30min 8.00 Plastic Viscosity cp 10 28 pH 8.50 9.50 2% KCUCLAYSEAL /GEM GP / Name Min Max Name Min Max Density ppg 9.20 9.30 Yield Point lbf/100_ft2 13 20 Funnel Viscosity sec /qt 40 53 API Filtrate mL /30min 6 Plastic Viscosity cp 6 15 pH 8.50 9.50 United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- Page 5 of 15 HALLI B U RTO N • • BARDID FLUID SERVICES Operator CHEVRON - MID - CONTINENT EBIZ Volume:Basic Mud Prog Well Name M -20 Interval Summary 17 -1/2" Surface Hole Size 17.50 in Interval Top MD/TVD 0 / 0 ft Interval Bottom MD /TVD 1390 / 1307 ft Footage 1390 ft Casing ID /OD 12.415 / 13.375 in Casing Length 1390 ft Washout % 20 % Pit Volume 1000 bbl SCE 85 % Dilution Volume 1063.36 bbl % Solids Retained (LGS) 7 % Mud on Cuttings 0 % Start Mud Weight 9 ppg Maximum Deviation 0 DEG End Mud Weight 9.50 ppg Estimated BHT 0 degF Carry Over Volume 0 bbl Fluid Volume Required 2559.60 bbl Carry Over Weight 0 ppg Weight Up Material Required 97045.15 SAP Material Product Conc. (ppb) Units 201423 SODA ASH - 50 LB BAG 0.50 26 201060 AQUAGEL - 50 LB BAG 15.00 768 201068 CAUSTIC SODA - 50 LB BAG 0.10 6 201583 ALDACIDE G - 5 GAL CAN 0.10 6 478095 BAROID 41 1941 United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLIBURTON Page 6of15 • • BARDID FLUID SERVICES Operator CHEVRON - MID - CONTINENT EBIZ Volume:Basic Mud Prog Well Name M -20 Interval Discussion 17 -1/2" Surface Surface Hole Recommendations - (17 -1/2" hole, 13 -3/8" casing to 1390'l Properties: Densi Viscosi Plastic Viscosi Yield Point API FL • H 470' -1390' 9.0 -9.5 60 - 85 10 - 28 25 - 35 <8 8.5 -9.0 System Formulation: pre hydrated gel /produced water spud mud Product Concentration Water 0.905 bbl Soda Ash 0.5 ppb Aquagel 12 -15 ppb Caustic 0.1 ppb (9 pH) Barazan D as needed Baroid as required for weight PAC L /Dextrid if required for <8 FL Aldacide G 0.1 ppb Concerns and Contingencies Surface Interval - (1,390'MD - 17-1/2" hole, 13 -3/8" casing) Mud Type: Pre - hydrated gel /produced water spud mud 1. Mud weight: Maintain the 9.0 — 9.5 ppg density or as directed. At TD the MW will be increased to 9.5 ppg. 2. Rheology: Maintain a YP between 25 -35 or as needed to achieve adequate hole cleaning. 3. Filtrate control: Maintain the filtrate <8 using DEXTRID and /or PAC L. Additions of CONDET may be required to control screen blinding /BHA balling. Losses in this interval can be controlled with additions of 3 ppb BAROFIBRE and 3 ppb of Baracarb 50 or by dedicated LCM pills. Operations Summary: Mix a -50 bbl LCM pill prior to drilling out. The pill formulation will be: 45 bbls base mud, 15 ppb BAROFIBRE, and 15 ppb of BARACARB 50. Pre - hydrated AQUAGEL should be used to maintain rheological parameters. Maintain the mud as clean as possible while drilling. Should sweeps be required, a high viscosity sweep is recommended. Run DFG (Drilling Fluid Graphics) to confirm hole cleaning efficiency based on current rheology, flow rates, angle and cuttings size. Sweep Formulation: 65 bbl of mud with -1 ppb of BARAZAN D+ added. DEXTRID and /or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs /BAROFIBRE /STEELSEALs should be maintained in the system while drilling the surface interval to prevent losses and strengthen the wellbore. While drilling, monitor the torque and drag to determine if liquid lubricant is required. If so, approval from town will be required prior to additions of lubricants. STICKLESS 20 drilling beads could provide an alternative to lubricants. Additions of CONDET are recommended to reduce the incidence of bit balling and shaker blinding when penetrating high -clay content sections. Maintain the pH in the 8.5 - 9.0 range with caustic soda. Daily additions of ALDACIDE G / X -Cide 207 should be made to control bacterial action. United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLI B U RTO N Page 7 of 15 4 BARDID FLUID SERVICES Operator CHEVRON - MID - CONTINENT EBIZ Volume:Basic Mud Prog Well Name M -20 At TD, a Wallnut "flag" (30 bbl pill with 5 ppb of WALLNUT M) or carbide pill should be pumped to gauge hole washout and to calculate the required cement volume. The cement will then be pumped and drilling mud will be used to bump the plug. Pretreat this chase mud with 1 ppb Bicarb and 0.5 ppb citric acid. Losses have historically occurred in this interval. Ensure that the mud weight is maintained in the 9.0 -9.3 ppg range through this area. Maintaining background LCM concentrations at 10 ppb total ( BARACARBs /BAROFIBRE /STEELSEALs) has proven successful on both M -17, M -18, and M -06. Stress slow pipe movement to the drillers to reduce surge /swab on the zone. Stage pumps on slowly after connections and begin rotation prior to pumping (this will break the gels and reduce the pressure required to break the gels). Reduce system YP with BARATHIN as required for running casing (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what yp value they have targeted). Consider spotting a STEELSEAL 400 LCM pill prior to running the 13 -3/8" casing if losses have been seen in this interval. The plug will be bumped with mud on the well. This well is a large borehole. Modeling shows that it will become much more difficult to clean if flowrates drop below 800 gpm. Maintain a minimum 25 YP at all times. Be prepared to increase the YP if hole cleaning becomes an issue. Run DFG (Drilling Fluid Graphics) to confirm hole cleaning efficiency based on current rheology, flow rates and cuttings size. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 600 800 1000 80 rpm 56 86 124 100 rpm 58 89 125 Baroid recommends a flowrate in the 800 gpm range to maximize hole cleaning efficiencies at these higher penetration rates. However if losses occur, the flow rate can be reduced in conjunction with a slower penetration rate which would reduce the ECD /losses. Hazards / Concerns — Surface Interval: • Optimize solids control equipment to maintain density and sand content. • Maintain YP between 25 -35 to optimize hole cleaning and to control ECD. • Pump high viscosity sweeps to enhance hole - cleaning efforts. Monitor sweep effectiveness. • Successfully land and cement casing. United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLI B U RTO N Page 8 of 15 . . BAROID FLUID SERVICES Operator CHEVRON - MID - CONTINENT EBIZ Volume:Basic Mud Prog Well Name M -20 Interval Summary 12 -1/4" Intermediate Hole Size 12.25 in 1 Interval Top MD/TVD 1390 / 1307 ft Interval Bottom MD /TVD 7200 / 3918 ft Footage 5810 ft Casing ID /OD 12.415 / 13.375 in Casing Length 1390 ft Casing ID /OD 8.681 / 9.625 in Casing Length 7200 ft Washout % 15 % Pit Volume 1000 bbl SCE 80 % Dilution Volume 3246.69 bbl % Solids Retained (LGS) 6 % Mud on Cuttings 0 % Start Mud Weight 9.20 ppg Maximum Deviation 0 DEG End Mud Weight 9.20 ppg Estimated BHT 0 degF Carry Over Volume 0 bbl Fluid Volume Required 5428.82 bbl Carry Over Weight 0 ppg Weight Up Material Required 103680.021bm SAP Material Product Conc. (ppb) Units 201368 POTASSIUM CHLORIDE - 50 LB 7.00 761 BAG 201068 CAUSTIC SODA - 50 LB BAG 0.20 22 201681 BARAZAN D PLUS - 25 LB BAG 1.00 218 201126 DEXTRID LT - 50 LB BAG 2.00 218 201318 PAC -L - 50 LB BAG 1.00 109 201329 CLAYSEAL - 55 GAL DRUM 4.00 48 201583 ALDACIDE G - 5 GAL CAN 0.10 11 201627 GEM GP - 55 GAL DRUM 5.20 62 478095 BAROID 41 2074 United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLI B U RTO N Page 9 of 15 • BARDID FLUID SERVICES 111 Operator CHEVRON - MID - CONTINENT EBIZ Volume:Basic Mud Prog Well Name M -20 Interval Discussion 12 -1/4" Intermediate Intermediate Hole Section Recommendations (12 -1/4" Hole, 9 -5/8" casing to 7200') Mud Type: 2% KCI, CLAYSEAL, GEM GP Properties: Density Viscosity Plastic Viscosity Yield Point API FL QH 1390' -7200' 9.2 -9.3 40 -53 6 - 15 13 - 20 <6 8.5 -9.5 System Formulation: 2% KCI, CLAYSEAL, GEM GP Product Concentration Water 0.905 bbl KCI 7 ppb (7000 chlorides) Caustic 0.2 ppb (9 pH) Barazan D 1.0 ppb (as required 18 YP) Dextrid 1 -2 ppb PAC L 1 ppb Clayseal 4 ppb (initial 1 ppb) Aldacide G 0.1 ppb GEM GP 1.5% by volume Baroid as needed for 9.1 ppg Special Mixing Instructions: • Mix in order as listed • Add polymers slowly to minimize fisheyes. Intermediate Interval (12 -1/4" hole, 9 -5/8" casing to 7200' MD) Mud Type: 9.2 ppg KCl/ Clayseal /GEM System. 1. Mud weight: Maintain the density at 9.2 ppg or as needed; use solids control and whole mud dilution. Increase density as required for hole stability /coal sloughing. Maximize solids control usage. 2. Rheology: Maintain a YP between 13 and 20. Pump high viscosity sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation (ideally > 100 RPM). 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. LCM (BARACARBs 5/25/50, STEELSEAL 50/100/400, BAROFIBRE) should be maintained at elevated concentrations while drilling coals to help strengthen the wellbore. Operations Summary: Mix a -50 bbl LCM pill prior to drilling out. The pill formulation will be the 50 ppb pill from the LCM tree. Mix the recommended LCM material in thinned back base mud. Drill out the cement/casing with the existing mud system. Soda ash and citric acid should be used to pretreat for any negative effects of the cement. After obtaining a leak off, begin drilling ahead displacing to the KCI based fluid. BARACARB 5, 25 and /or 50 should United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLIBURTON Page 10 of 15 • BARDID FLUID SERVICES Operator CHEVRON - MID - CONTINENT EBIZ Volume:Basic Mud Prog Well Name M -20 be maintained at 5 ppb. BAROFIBRE \STEELSEAL 50/100/400 should be maintained at 5 ppb. The CLAYSEAL concentration should be 1 ppb in the initial mix. As the mud shears, slowly raise the CLAYSEAL concentration to its full 4 ppb concentration. GEM GP should be maintained at 1.5% v/v (5.2 ppb). BARAZAN- D+ should be used to maintain rheological parameters. Maintain the mud as clean as possible while drilling. Should sweeps be required, a high viscosity sweep is recommended. Sweep Formulation: 50 bbl of mud with -1 ppb of BARAZAN D+ added. DEXTRID and PAC L should be used for filtrate control (6cc range). 4 ppb BAROTROL should be added to help control coals and shales. While drilling, monitor the torque and drag to determine if liquid lubricant is required. If so, approval from town will be required prior to additions of lubricants. STICKLESS 20 drilling beads could provide an alternative to lubricants. Additions of CONDET are recommended to reduce the incidence of bit balling and shaker blinding when penetrating high -clay content sections. Maintain the pH in the 8.5 - 9.5 range with caustic soda. Daily additions of ALDACIDE G / X -Cide 207 should be made to control bacterial action. Maintain Cl- with 2% KCI for 7,000 chlorides. The GEM GP can be raised above the 1.5% level to help reduce torque. Do not exceed 3% v/v of GEM GP. Reduce system YP as required for running casing (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 15 (check with the cementers to see what yp value they have targeted). Consider spotting a STEELSEALs LCM pill (20 ppb of the different sizes) prior to running the casing if losses have been seen in this interval. Suggested Drilling Parameters Pump rate and drill string rotation should be optimized through the real -time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue in this interval. Maximum Acceptable ROP in f h at Specified GPM and RPM GPM— 600 700 800 60 rpm 52 55 62 80 rpm 86 97 106 100 rpm 123 133 149 Rotary speed is the most critical factor in cleaning this highly deviated wellbore. Maximize rpms at all times. ROPs above these levels or with no rotation (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: • extended periods of circulation (with maximum pipe rpm, targeting > 100 rpm) • hole cleaning sweeps (change flow regime of base mud by using fibers, density or rheology for carrying capacity) • connection practices - employing extended gpm, rpm and back reaming during the connection United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLI B U RTO N Page 11 of 15 • 0 BARDID FLUID SERVICES Operator CHEVRON - MID - CONTINENT EBIZ Volume:Basic Mud Prog Well Name M -20 Interval Summary 8 -1/2" Production Hole Size 8.50 in Interval Top MD/TVD 7200 / 3918 ft Interval Bottom MD /TVD 10437 / 6300 ft Footage 3237 ft Casing ID /OD 12.415 / 13.375 in Casing Length 1390 ft Casing ID /OD 8.681 / 9.625 in Casing Length 7200 ft Washout % 10 % Pit Volume 1000 bbl SCE 70 % Dilution Volume 1249.57 bbl % Solids Retained (LGS) 6 % Mud on Cuttings 0 % Start Mud Weight 9.20 ppg Maximum Deviation 0 DEG End Mud Weight 9.20 ppg Estimated BHT 0 degF Carry Over Volume 500 bbl Fluid Volume Required 2526.57 bbl Carry Over Weight 9.20 ppg Weight Up Material Required 60674.661bm SAP Material Product Conc. (ppb) Units 201368 POTASSIUM CHLORIDE - 50 LB 7.00 354 BAG 201068 CAUSTIC SODA - 50 LB BAG 0.20 11 201681 BARAZAN D PLUS - 25 LB BAG 1.00 102 201126 DEXTRID LT - 50 LB BAG 2.00 102 201318 PAC -L - 50 LB BAG 1.00 51 201329 CLAYSEAL - 55 GAL DRUM 4.00 22 201583 ALDACIDE G - 5 GAL CAN 0.10 6 201627 GEM GP - 55 GAL DRUM 5.20 29 478095 BAROID 41 1214 United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLI B U RTO N Page 12 of 15 0 BARDID FLUID SERVICES 41111 Operator CHEVRON - MID - CONTINENT EBIZ Volume:Basic Mud Prog Well Name M -20 Interval Discussion 8 -1/2" Production 8 -1/2" Hole Recommendations (7" liner) to 10,437' Mud Type: 2% KCI, CLAYSEAL, GEM GP Properties: Densi Viscosi Plastic Viscosi Yield Point API FL • H 7200'- 10600' 9.2 -9.3 40 -53 6 - 15 13 - 20 <5 8.5 -9.5 System Formulation: 2% KCI, CLAYSEAL, GEM GP Product Concentration Water 0.905 bbl KCI 7 ppb (7000 chlorides) Caustic 0.2 ppb (9 pH) Barazan D 1.0 ppb (as required 18 YP) Dextrid 1 -2 ppb Clayseal 4 ppb (Initial build 1 ppb) Aldacide G 0.1 ppb GEM GP 1.5% by volume Baracarb 50 10 ppb Baroid as needed Mud Type: 9.2 ppg KCI /CLAYSEAL /GEM System. 1. Mud weight: Maintain the density at 9.2 ppg or as directed; use solids control and whole mud dilution. Increase density as required for hole stability /coal sloughing. Maximize solids control usage. 2. Rheology: Maintain a YP between 13 and 20. Pump high viscosity sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation (ideally > 80 RPM). 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. LCM (BARACARBs 5/25/50, STEELSEAL 50/100/400) should be maintained at elevated concentrations while drilling coals to help strengthen the wellbore. Operations Summary: Mix a -50 bbl LCM pill prior to drilling out. The pill formulation will be the 50 ppb pill from the LCM tree. Mix the recommended LCM material in thinned back base mud. Drill out the cement/casing with the existing mud system. Soda ash and citric acid should be used to pretreat for any negative effects of the cement. BARAZAN -D+ should be used to maintain rheological parameters. Maintain the mud as clean as possible while drilling. The mud may need centrifuged prior to adding 10 ppb of BARACARBs (5,25, and /or 50) and 6 ppb total STEELSEALs (50,100, and /or 400) (bridging agent for the "weak" zones and coal stability). Should sweeps be required a high viscosity sweep is recommended. Sweep Formulation: 20 bbl of mud with -1 ppb of BARAZAN D+ added. Maintain CLAYSEAL concentrations at 4 ppb and GEM GP at 1.5% v/v (5.2 ppb). DEXTRID and /or PAC L should be used for filtrate control (5cc range) to TD. While drilling, monitor the torque and drag to determine if United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLI B U RTO N Page 13 of 15 • BARDID FLUID SERVICES Operator CHEVRON - MID - CONTINENT EBIZ Volume:Basic Mud Prog Well Name M -20 liquid lubricant is required. If so, approval from town will be required prior to additions of lubricants. STICKLESS 20 drilling beads could provide an alternative to lubricants. Additions of CONDET are recommended to reduce the incidence of bit balling and shaker blinding when penetrating high -clay content sections. Maintain the pH in the 8.5 – 9.5 range with caustic soda. Daily additions of ALDACIDE G / X -Cide 207 should be made to control bacterial action. The GEM GP can be raised above the 1.5% level to help reduce torque. Do not exceed 3% v/v of GEM GP. Reduce system YP with BARATHIN Plus as required for running casing (do not jeopardize hole conditions). Spot the above LCM pill in the bottom of the hole. If it has been used, mix a duplicate pill to spot on bottom. Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 15 (check with the cementers to see what yp value they have targeted). The plug will be bumped with 6% KCI brine. Suggested Drilling Parameters: Maximum Acceptable ROP in fph at Specified GPM and RPM GPM— 350 450 550 60 rpm 51 66 82 80 rpm 84 108 137 100 rpm 117 155 185 Rotary speed is the most critical factor in cleaning this highly deviated wellbore. Maximize rpms at all times. ROPs above these levels or with no rotation (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: • extended periods of circulation (with maximum pipe rpm, targeting > 100 rpm) • hole cleaning sweeps (change flow regime of base mud by using fibers, density or rheology for carrying capacity) • connection practices - employing extended gpm, rpm and back reaming during the connection Production Hole - Hazards / Concerns: • Optimize solids control equipment to minimize colloidal solids build up and dilution requirements. • Maintain flow profile based on PV, YP and tau flow parameters. • Pump sweeps as required to enhance hole - cleaning efforts. Follow the hole cleaning guidelines to assist in drilling parameter selection. Use connections for high RPM and pump rate support when these parameters are limited during drilling operations. • Follow the coal drilling guidelines. Coal Drilling The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The hole stability risks when drilling coal seams are often high, and the fluid design and drilling operations have been optimized to combine reduced risk with reduced costs. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt -type additives and LCM particulates to further stabilize coal seams. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLIBURTON Page 14 of 15 BAROID FLUID SERVICES . CHEVRON - MID - CONTINENT Operator EBIZ Volume:Basic Mud Prog Well Name M -20 In the event that sloughing coal is encountered, consider spotting a 30 ppb (15 ppb BAROTROL and 15 ppb LCM — 5 ppb total of BARACARBs (5, 25 and /or 50), 5 ppb total of STEELSEALs (50,100, and /or 400), 5 ppb BAROFIBRE) pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss (based on ECD values using the DFG software). Solids Control Equipment Maximize the use of all solids control equipment to ensure that the solids content of the system is kept to a minimum during this interval. 1. Run the shale shakers with as fine a screen size as possible. • Size shakers screens with coarse mesh initially • Adjust screen size as solids loading, mud rheology and flowrates allow • Inspect the shakers frequently, taking time to repair / replace damaged screens 2. Maximize the use of the centrifuge, keeping the fluid as clean as possible. Running Casing / Cementing Preparation Monitor hole fill /returns closely while running the liner to insure losses haven't occurred. Refer to Baroid's DFG+ program if calculated surge /swab values are needed. Condition the mud prior to the cement job. Completion The well will be completed with a 6% KCI brine. If rig ops allow, bump the plug with the brine, then finish displacing the casing after coming off the liner hanger. System Formulation: 6% KCI Product Concentration Water 0.976 bbl KCI 21.8 ppb ALDACIDE G 0.25 ppb United States of America Cook Inlet Baroid Fluid Services Kenai Offshore, Alaska 8 -16 -09 -- HALLIBURTON Page 15of15 Chevron • Illteelhead Platform %. Well M -20 %. Proposed 08/09 V7 CASING AND TUBING DETAIL RKB to TBG Head = 78'.75 ' SIZE WT GRADE CONN MIN TOP TOP BTM BTM ID in MD rkb TVD rkb MD rkb TVD rkb Cement to ML 28" Structural 27 Surface 480' 4-- @ 345' 13 - 3/8" 68 L -80 BTC 12.415 Surface 1390' 9 - 5/8" 47 L -80 BTC -M 8.681 Surface 7200' 28" Conductor 7" 26 L -80 DWCSR 6.276 7000' 10600' E I @ 480 Tubing 3 - 1/2" 9.2 L - TCII 2.992 Surface Surface TBD TBD I ECP Stage Collar Logging Detail Hole LWD /MWD Wire Line Mud Logging Notes Section 17 %z" GR/Res Gas Detection, Consulting Geologist Mud Logging L i. 13 3/8" in 17'/:" Hole 12 '/4 GR/Res/ Dens- Gas Detection, Consulting Geologist 9 5/8 Hydraulic Stage Neut, PWD Vib Mud Logging im / - Collar @ 5960' 8 'A" GR/Res/ Dens Gas Detection, Consulting Geologist Neut, PWD Vib Mud Logging Perforation Detail MD Zone Density (SPF) Notes =, Miscellaneous Equipment Informtion Item Depth OD ID Notes Gravel Pack, 3x 9 5/8" Casing in 12'/" �_'` Hole • g 0 Cementing Information 4 I C I Description Volume Density Yield Notes :::::::;,:.:.... I (bbls) (ppg) (ft3 /sx) TCP perforating 4 ■ . 7" Liner in 8 1/2" Hole Well Detail MAX HOLE ANGLE = 88° @ 2694' MD DRAWN BY: JAR Chevron • • %. $chlumberger WELL FIELD STRUCTURE (P7) I Trading Bay Unit Steelhead Mapnelk Rammelen Surface Lacation 744027 Mara Mate Planes, Zone 04, US Feat I Miscellaneous M 3 42 , BGG 2009 Dip: 73634• Dale: September 29, 2009 Let: 7460095/527 Northing: 249945980 PUS 003 Cane: - 1.39934318• Skl: leg /11 slot 2 WO Rat: RM9,4 Table (180251 above Mean Sea Level) Mao Des. +18.484 FS: 55535.5 nT Lon: W151388.854 EaMing: 21409953 SUS Scale Fact: 0.9999930318 Plan: M -20 (97) Sr, Date: August 20, 2009 0 1000 2000 3000 4000 5000 RTE 0 0 20" Conductor KOP Bld 51100 1000 1000 13318" Csg End Bld D ' Cry 3/100 Et7id Cry Cry 31100 2000 a 2000 • o o 3000 Endsty 3000 0 c n m 8 9.518" Csg (n ° ' D•.. 4000 4000 Cry 2/f00 5000 5000 End Cry • 6000 9 6000 TO 17" Lnr M -20 (P 7000 7000 0 1000 2000 3000 4000 5000 Vertical Section (ft) Azim = 201.23 °, Scale = 1(in):1000(ft) Origin = 0 N / -S, 0 E / -V Chevron • 0 %. Schlumberger %. WELL I FIELD I STRUCTURE M -20 (P7) Trading Bay Unit St eelhead MagnSio Parameters Sutlace Location NAD27 Alaska Stale Planes, Zone 04, US Feet Miscellaneous Motld'. 13GGM 2009 0'0'. 73634• Dale'. September 20, 2009 Lai: 1160 49 54 527 Northing: 2499459807U5 Grid Cony- 139934316• Slot: leg WO ska2 D Rey: Rotary Table (160.256 Mean ean Sea Level) Mag Dec'. +18464• FS: 555355 nT Lon: W151 36 0 054 Ewa , 214069.33 PUS Scala Fact: 09999930316 I Marc M-20 (R7) Srvy Date: August 20,2009 -3200 -2400 -1600 -800 0 20 Conductor 13418 "Cs• RTE • 0 0 . r KOP Bld 5100 Cry 3/100 End Bld End Cry Cry 31100 -800 -800 N -1600 A•/ 11041A - 1600 A A• • A Z End Cry o -2400 -2400 0 4b E- n a1 U CO co -3200 tores9•• ¢ -3200 v v v Cry 21100 -4000 -4000 End Cry -4800 -4800 TD l 7" Lnr -20 (P7) -5600 -5600 -3200 -2400 -1600 -800 0 «< W Scale = 1(in):800(ft) E »> • Planned Wellpath Geographic Report Report Generated 8/19/2009 at 4:17:16 PM Projection S stem T NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet . Operator Chevron North Reference True Area Cook Inlet, Alaska (Offshore) Scale 0.999993 Field McArthur River Field Horizontal Reference Point Slot Facility STEELHEAD Platform Vertical Reference Point Actual Datum (RKB) Slot slot #A1 -2 MD Reference Point Actual Datum (RKB) Well M -20 Field Vertical Reference IIIISMIMANNIr mean sea level Wellbore Plan M -20 Actual Datum (RKB) to Facility Vertical Datum 160.25 ft Wellpath Plan M- 20_Version#7 ext Actual Datum (RKB) to mean sea level 160.25 ft Wellbore Last Revised 03/05/2009 Facility Vertical Datum to Mud Line (Facility) 0.00 ft Sidetrack from (none) Section Origin X E 0.00 ft User Ulricard Section Origin Y N 0.00 ft Calculation method Minimum curvature Section Azimuth 201.23° Local North Local East Grid East Grid North Latitude Longitude [ft] [ft) [USft] [USft] Slot Location - 1043.49 454.28 214069.33 2499459.80 60 °49'54.527 "N 151 °36'08.854W Facility Reference Pt 213640.71 2500514.08 60 °50'04.803 "N 151 °3618.018'W Field Reference Pt 213640.71 2500514.08 60 °50'04.803 "N 151 °3618.018'W TVD from MD Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments -- [ft] [1 N [ft] [ft) [ft] [ft] [sry ft] [sry ft] [ °/100ft] [1 [ ° /100ft] [° /100ft] [ft] 0.00 0.00 255.00 0.00 - 160.25 0.00 0.00 214069.33 2499459.80 60 °49'54.527 "N 151 °36'08.854'W 0.00 0.00 0.00 0.00 0.00 100.00 0.00 255.00 100.00 -60.25 0.00 0.00 214069.33 2499459.80 60 °49'54.527 "N 151 °36'08.854'W 0.00 0.00 0.00 0.00 0.00 200.00 0.00 255.00 200.00 39.75 0.00 0.00 214069.33 2499459.80 60 °49'54.527 "N 151 °36'08.854'W 0.00 0.00 0.00 0.00 0.00 300.00 0.00 255.00 300.00 139.75 0.00 0.00 214069.33 2499459.80 60 °49'54.527"N 151°36'08.854'W 0.00 0.00 0.00 0.00 0.00 400.00 0.00 255.00 400.00 239.75 0.00 0.00 214069.33 2499459.80 60 °49'54.527 "N 151 °3608.854'W 0.00 0.00 0.00 0.00 0.00 500.00 0.00 255.00 500.00 339.75 0.00 0.00 214069.33 2499459.80 60 °49'54.527 "N 151 °36'08.854'W 0.00 0.00 0.00 0.00 0.00 525.00 0.00 255.00 525.00 364.75 0.00 0.00 214069.33 2499459.80 60 °49'54.527 "N 151 °36'08.854'W 0.00 - 105.00 0.00 0.00 0.00 600.00 3.75 255.00 599.95 439.70 -0.64 -2.37 214066.94 2499459.22 60 °49'54.521 "N 151 °36'08.902'W 5.00 0.00 5.00 0.00 1.45 700.00 8.75 255.00 699.32 539.07 -3.45 -12.88 214056.36 2499456.66 60 °49'54.493 "N 151 °36'09.114'W 5.00 0.00 5.00 0.00 7.88 800.00 13.75 255.00 797.37 637.12 -8.50 -31.72 214037.41 2499452.08 60 °49'54.444 "N 151 °36'09.494'W 5.00 ' 0.00 5.00 0.00 19.41 900.00 18.75 255.00 893.34 733.09 -15.74 -58.74 ' 214010.22 2499445.50 60 °49'54.372 "N 151 °36'10.039'W 5.00 0.00 5.00 0.00 35.95 1000.00 23.75 255.00 986.51 826.26 -25.12 -93.74 213975.00 2499436.98 60 °49'54.280 "N 151 5.00 0.00 5.00 0.00 57.36 1100.00 28.75 255.00 1076.17 915.92 -36.56 - 136.45 213932.03 2499426.58 60 °49'54.167 "N ,151°3611.606'W 5.00 0.00 MEM 0.00 83.50 1200.00 33.75 255.00 1161.64 1001.39 -49.98 - 186.54 213881.62 2499414.39 60 °49'54.035 "N 1151 °3612.617'W 5.00 0.00 MEM 0.00 114.15 1300.00 38.75 255.00 1242.26 1082.01 -65.28 - 243.64 213824.17 2499400.49 60 °49'53.884 "N 151 °3613.769'W 5.00 0.00 5.00 0.00 149.09 1390.00 43.25 255.00 1310.16 1149.91 -80.56 - 300.66 213766.79 2499386.61 60 °49'53.734 "N 151'36'14.919'W 5.00 0.00 5.00 0.00 183.98 13.375" Csg 1400.00 43.75 255.00 1317.42 1157.17 -82.34 - 307.31 213760.10 2499384.99 60 °49'53.716 "N 151 °3615.053'W 5.00 0.00 5.00 0.00 188.05 1500.00 48.75 255.00 1386.54 1226.29 - 101.03 - 377.06 213689.92 2499368.01 60 °49'53.532 "N 151 °36'16.460'W 5.00 0.00 5.00 0.00 230.73 1520.62 49.78 255.00 1400.00 1239.75 - 105.08 - 392.15 213674.73 2499364.33 60 °49'53.493 "N 151 °36'16.765'W 5.00 0.00 5.00 0.00 239.97 1600.00 49.78 255.00 1451.26 1291.01 - 120.76 -450.70 213615.82 2499350.08 60 °49'53.338 "N 151 °36'17.946'W 0.00 0.00 0.00 0.00 275.79 1620.62 49.78 255.00 1464.57 1304.32 - 124.84 - 465.91 213600.51 2499346.38 60 °49'53.298 "N 151 °36'18.252'W 0.00 0.00 0.00 0.00 285.10 1700.00 52.16 255.00 1514.55 1354.30 - 140.80 - 525.47 213540.58 2499331.88 60 °49'53.141 "N 151 °3619.454'W 3.00 0.00 3.00 0.00 321.55 1800.00 55.16 255.00 1573.80 1413.55 - 161.65 -603.27 213462.30 2499312.94 60 °49'52.935 "N 151 °36'21.023'W 3.00 0.00 3.00 0.00 369.16 1900.00 58.16 255.00 1628.75 1468.50 - 183.27 - 683.96 213381.10 2499293.29 60 °49'52.722"N 151 °3622.651'W 3.00 0.00 3.00 0.00 418.53 III 2000.00 61.16 255.00 1679.26 1519.01 - 205.60 - 767.31 213297.23 2499273.00 60 °49'52.502 "N 151 °36'24.332'W 3.00 0.00 3.00 0.00 469.54 2100.00 64.16 255.00 1725.17 1564.92 - 228.59 -853.11 213210.90 2499252.11 60 °49'52.276 "N 151 °36'26.063'W 3.00 0.00 3.00 0.00 522.04 2200.00 67.16 255.00 1766.38 1606.13 - 252.17 - 941.11 213122.35 2499230.69 60 °49'52.044 "N 151 °36'27.838'W 3.00 0.00 3.00 0.00 575.89 2300.00 70.16 255.00 1802.76 1642.51 - 276.27 - 1031.07 213031.83 2499208.79 60 °49'51.806 "N 151 °36'29.653'W 3.00 0.00 3.00 0.00 630.94 2400.00 73.16 255.00 1834.22 1673.97 -300.84 - 1122.74 212939.58 2499186.47 60 °49'51.564 "N 151 °36'31.502'W 3.00 0.00 3.00 0.00 687.04 2500.00 76.16 255.00 1860.67 1700.42 -325.80 - 1215.89 212845.86 2499163.80 60 °49'51.318 "N 151 °36'33.381'W 3.00 0.00 3.00 0.00 744.03 2600.00 79.16 255.00 1882.03 1721.78 -351.08 - 1310.24 212750.92 2499140.83 60 °49'51.069"N 151 °36'35.284'W 3.00 0.00 3.00 0.00 801.77 2694.59 82.00 255.00 1897.51 1737.26 - 375.23 - 1400.36 212660.23 2499118.89 60 °49'50.832 "N 151 °36'37.102'W 3.00 0.00 3.00 0.00 856.92 2700.00 82.00 255.00 1898.26 1738.01 -376.61 - 1405.54 212655.02 2499117.63 60 °49'50.818 "N 151°36'37.206'W 0.00 0.00 0.00 0.00 860.09 2800.00 82.00 255.00 1912.18 1751.93 - 402.24 - 1501.19 212558.77 2499094.34 60 °49'50.565 "N 151 °3639.135W 0.00 0.00 0.00 0.00 918.62 2900.00 82.00 255.00 1926.10 1765.85 - 427.87 - 1596.84 212462.52 2499071.05 60 °49'50.313 "N 151 °36'41.066W 0.00 0.00 0.00 0.00 977.15 3000.00 82.00 255.00 1940.02 1779.77 -453.50 - 1692.50 212366.28 2499047.77 60 °49'50.060 "N 151°36'42.994'W 0.00 0.00 0.00 0.00 1035.68 3100.00 82.00 255.00 1953.93 1793.68 - 479.13 - 1788.15 212270.03 2499024.48 60 °49'49.808 "N 151 °36'44.924'W 0.00 0.00 0.00 0.00 1094.21 3152.57 82.00 255.00 1961.25 1801.00 -492.61 - 1838.44 212219.42 2499012.24 60 °49'49.675 "N 151 °36'45.938'W 0.00 - 125.17 0.00 0.00 1124.99 3200.00 81.18 253.82 1968.19 1807.94 - 505.21 - 1883.63 212173.94 2499000.74 60 °49'49.551 "N 151 °36'46.849'W 3.00 - 124.99 -1.73 -2.48 1153.10 3300.00 79.47 251.32 1984.99 1824.74 - 534.73 - 1977.67 212079.21 2498973.53 60 °49'49.260 "N 151 °36'48.746'W 3.00 - 124.57 -1.71 -2.50 1214.68 3400.00 77.78 248.79 2004.72 1844.47 -568.16 - 2069.82 211986.27 2498942.36 60 °49'48.931 "N 151 °36'50.605'W 3.00 - 124.08 -1.69 -2.53 1279.21 3500.00 76.11 246.23 2027.32 1867.07 -605.40 - 2159.81 211895.39 2498907.32 60 °49'48.564 "N 151 °36'52.420'W 3.00 - 123.50 -1.67 -2.56 1346.52 3600.00 74.47 243.64 2052.72 1892.47 -646.37 - 2247.42 211806.81 2498868.51 60 °49'48.160"N 151 °36'54.187'W 3.00 - 122.84 -1.64 -2.60 1416.43 3700.00 72.85 241.00 2080.86 1920.61 -690.94 - 2332.39 211720.78 2498826.03 60 °49'47.721 "N 151 °36'55.901'W 3.00 - 122.09 -1.61 -2.64 1488.75 3800.00 71.28 238.31 2111.66 1951.41 - 738.99 - 2414.48 211637.54 2498780_.00 60 °49'47.248 "N 151 °36'57.557'W 3.00 - 121.27 -1.58 -2.68 1563.27 3900.00 69.74 235.58 2145.03 1984.78 - 790.39 - 2493.49 211557.30 249873054 60 °49'46.741 "N 151 °36'59.150'W 3.00 - 120.35 -1.54 -2.73 1639.80 4000.00 68.25 232.79 2180.89 2020.64 - 845.01 - 2569.18 211480.30 2498677.79 60 °49'46.203 "N 151 °37'00.676'W 3.00 - 119.35 -1.49 -2.79 1718.12 Page 1 of 2 TVD from Inclination Azimuth TVD Fld Ref North East Grid East Grid North Latitude Longitude DLS Toolface Build Rate Turn Rate Vert Sect Comments [ft] [1 [1 [ft] [ft] [ft] [ft] [sry ft] [sry ft] [°1100ft] [°] [°/100ft] [° /100ft] [ft] 4100.00 66.80 229.94 2219.13 2058.88 - 902.68 - 2641.36 211406.74 2498621.90 60 °49'45.635 "N 151 °37'02.132' W 3.00 - 118.27 -1.45 -2.85 1798.01 4200.00 65.40 227.03 2259.65 2099.40 - 963.26 - 2709.81 211336.82 2498563.01 60 °49'45.039 "N 151°37'03.513'W 3.00 - 117.09 -1.39 -2.91 1879.27 4300.00 64.07 224.06 2302.33 2142.08 - 1026.57 - 2774.37 211270.74 2498501.30 60 °49'44.415 "N 151°37'04.814'W 3.00 - 115.82 -1.34 -2.97 1961.66 4400.00 62.79 221.03 2347.07 2186.82 - 1092.44 - 2834.84 211208.68 2498436.92 60 °49'43.766N 151 °37'06.034'W 3.00 - 114.46 -1.28 -3.04 2044.96 4500.00 61.58 217.92 2393.74 2233.49 - 1160.69 - 2891.07 211150.80 2498370.06 60 °49'43.094 "N 151 °37'07.168' W 3.00 - 113.01 -1.21 -3.11 2128.95 4600.00 60.45 214.74 2442.21 2281.96 - 1231.14 - 2942.89 211097.28 2498300.90 60 °49'42.400 "N 151 °37'08.212'W 3.00 - 111.47 -1.14 -3.18 2213.38 4700.00 59.39 211.50 2492.34 2332.09 - 130159 - 2990.17 211048.24 249822163 60 °49'41.687"N 151 °37'09.166'W 100 - 10184 -1.06 -3.25 2298.03 4800.00 58.41 208.18 2544.01 2383.76 - 1377.84 -3032.77 211003.84 2498156.44 60 °49'40.955 "N 151 °37'10.025'W 3.00 - 108.13 -0.98 -3.31 2382.67 4900.00 57.52 204.80 2597.06 2436.81 - 1453.69 -3070.59 210964.18 2498081.54 60 °49'40.208 N 151 °3710.787'W 3.00 - 106.34 -0.89 -3.38 2467.07 5000.00 56.72 201.35 2651.36 2491.11 - 1530.93 -3103.51 210929.39 2498005.13 60 °49'39.448 "N 151°37'11.451'W 3.00 - 104.46 -0.80 -3.45 2550.99 5100.00 56.02 197.85 2706.75 2546.50 - 1609.35 -3131.44 210899.54 2497927.42 60 °49'38.675 "N 151 °3712.014W 3.00 - 102.52 -0.70 -3.51 2634.20 5200.00 55.42 194.29 2763.08 2602.83 - 1688.73 4154.32 210874.74 2497848.62 60 °49'37.894 "N 151 °37'12.475'W 3.00 - 100.52 -0.60 -3.56 2716.47 5300.00 54.93 190.68 2820.20 2659.95 - 1768.85 -3172.07 210855.04 2497768.96 60 °49'37.105 "N 151 °3712.832'W 3.00 -98.46 -0.49 -3.61 2797.59 5400.00 54.54 187.04 2877.95 2717.70 - 1849.50 -3184.64 210840.49 2497688.64 60 °49'36.310 "N 151 °37'13.085W 3.00 -96.35 -0.39 -3.65 2877.32 5500.00 54.26 183.36 2936.17 2775.92 - 1930.46 -3192.01 210831.15 2497607.89 60 °49'35.513 "N 151 °37'13.234'W 3.00 -94.21 -0.28 -3.68 2955.45 5600.00 54.10 179.67 2994.71 2834.46 - 2011.49 -3194.16 210827.03 2497526.93 60 °49'34.715 "N 151 °37'13.276'W 3.00 -92.05 -0.16 -3.70 3031.76 5700.00 54.05 175.96 3053.39 2893.14 - 2092.39 -3191.07 210828.14 2497445.98 60 °4133.919 "N 151 °3713.214'W 3.00 -89.87 -0.05 -3.71 3106.04 5800.00 54.11 172.25 3112.07 2951.82 - 2172.92 -3182.75 210834.49 2497365.27 60 °49'33.126 "N 151 °37'13.045W 3.00 -87.70 0.06 -3.71 3178.10 5900.00 54.29 168.56 3170.58 3010.33 - 2252.87 -3169.23 210846.05 2497285.01 60 °49'32.338 "N 151 °3712.772'W 3.00 -85.54 0.18 -3.69 3247.72 6000.00 54.58 164.89 3228.75 3068.50 - 2332.02 - 3150.55 210862.79 2497205.44 60 °49'31.559 "N 151 °37'12.395'W 3.00 -83.40 0.29 -3.67 3314.73 6002.59 54.59 164.79 3230.25 3070.00 - 2334.05 -3150.00 210863.30 2497203.39 60 °49'31.539 "N 151 °37'12.384'W 3.00 45.71 0.35 -3.66 3316.43 6018.39 54.92 165.21 3239.37 3079.12 - 2346.52 -3146.66 210866.33 2497190.85 60 °49'31.416 "N 151 °37'12.317'W 3.00 0.00 2.10 2.62 3326.84 6100.00 54.92 165.21 3286.27 3126.02 - 2411.09 3129.60 210881.80 2497125.87 60 °49'30.780 "N 151 °3711.972'W 0.00 0.00 0.00 0.00 3380.85 6200.00 54.92 165.21 3343.74 3183.49 - 2490.22 -3108.71 210900.76 2497046.27 60 °4130.001 "N 151 °37'11.550'W 0.00 0.00 0.00 0.00 3447.03 6300.00 54.92 165.21 3401.21 3240.96 - 2569.34 - 3087.81 210919.72 2496966.66 60 °4929.222 "N 151 °37'11.129'W 0.00 0.00 0.00 0.00 3513.22 6400.00 54.92 165.21 3458.68 3298.43 - 2648.46 - 3066.91 210938.68 2496887.05 60 °49'28.443 "N 151 °3710.707'W 0.00 0.00 0.00 0.00 3579.40 6500.00 54.92 165.21 3516.15 3355.90 - 2727.58 - 3046.02 210957.64 2496807.44 60 °49'27.664 "N 151 °37'10.285'1N 0.00 0.00 0.00 0.00 3645.58 6600.00 54.92 165.21 3573.63 3413.38 - 2806.71 - 3025.12 210976.60 _ 2496727.83 60 °4926.885 "N 151 °37'09.863'W 0.00 0.00 0.00 0.00 3711.77 6700.00 54.92 165.21 3631.10 3470.85 - 2885.83 - 3004.22 210995.55 2496648.22 60 °49'26.106 "N 151 °37'09.441'W 0.00 0.00 0.00 0.00 3777.95 6800.00 54.92 165.21 3688.57 3528.32 - 2964.95 - 2983.32 211014.51 2496568.61 60 °49'25.327 "N 151 °37'09.019'W 0.00 0.00 0.00 0.00 3844.13 6900.00 54.92 165.21 3746.04 3585.79 - 3044.08 - 2962.43 211033.47 2496489.00 60 °49'24.548 "N 151 °37'08.597'W 0.00 0.00 0.00 0.00 3910.32 7000.00 54.92 165.21 3803.51 3643.26 - 3123.20 - 2941.53 211052.43 2496409.39 60 °49'23.768 "N 151 °37'08.176'W 0.00 0.00 0.00 0.00 3976.50 7100.00 54.92 165.21 3860.98 3700.73 - 3202.32 - 2920.63 211071.39 2496329.79 60 °49'22.989 "N 151 °37'07.754W 0.00 0.00 0.00 0.00 4042.68 7200.00 54.92 186.21 3918.45 3758.20 -3281.44 - 2899.74 211090.35 2496250.18 60•4922.210"N 151 °3T07.332"W 0.00 0.00 0.00 0.00 4108.87 95/8" Csg 7300.00 54.92 165.21 3975.92 3815.67 - 3360.57 - 2878.84 211109.30 2496170.57 60 °4921.431 "N 151 °3706.910'W 0.00 0.00 0.00 0.00 4175.05 7400.00 54.92 165.21 4033.39 3873.14 - 3439.69 - 2857.94 211128.26 2496090.96 60 °49'20.652 "N 151 °37'06.488'W 0.00 0.00 0.00 0.00 4241.23 7500.00 54.92 165.21 4090.86 3930.61 -3518.81 - 2837.05 _ 211147.22 2496011.35 60 °49'19.873 "N 151 °37'06.067'W 0.00 0.00 0.00 0.00 4307.42 7600.00 54.92 165.21 4148.33 3988.08 -3597.94 - 2816.15 211166.18 2495931.74 60 °49'19.094 "N 151 °37'05.645'W 0.00 0.00 0.00 0.00 4373.60 7700.00 54.92 165.21 4205.80 4045.55 - 3677.06 - 2795.25 211185.14 2495852.13 60 °49'18.315 "N 151 °37'05.223'W 0.00 0.00 0.00 0.00 4439.78 7800.00 54.92 165.21 4263.27 4103.02 -3756.18 - 2774.35 211204.10 2495772.52 60 °49'17.536 "N 151 °37'04.801'W 0.00 0.00 0.00 0.00 4505.97 7900.00 54.92 165.21 4320.74 4160.49 -3835.30 - 2753.46 211223.06 2495692.91 60 °49'16.756 "N 151 °37'04.379'W 0.00 0.00 0.00 0.00 4572.15 7916.54 54.92 165.21 4330.25 4170.00 - 3848.39 - 2750.00 211226.19 2495679.75 60 °49'16.628 "N 151 °37'04.310'W 0.00 - 159.54 0.00 0.00 4583.10 8000.00 53.36 164.48 4379.14 4218.89 -3913.68 - 2732.32 211242.27 2495614.05 60 °49'15.985 "N 151 °37'03.953'W 2.00 - 159.12 -1.87 -0.87 4637.55 8100.00 51.49 163.57 4440.12 4279.87 -3989.87 _ - 2710.51 211262.21 2495537.35 60 °4915.235 "N 151 °37'03.513'W 2.00 - 168.56 -1.87 -0.91 4700.67 8200.00 49.64 162.61 4503.63 4343.38 - 4063.76 - 2688.05 211282.86 2495462.93 60 °49'14.507 "N 151 °37'03.059'W 2.00 - 157.95 -1.86 -0.96 4761.41 8300.00 47.79 161.60 4569.62 4409.37 - 4135.26 - 2664.97 211304.19 2495390.89 60 °49'13.803 "N 151 °37'02.594'W 2.00 - 157.28 -1.85 - 1.01 4819.70 8400.00 45.95 160.52 4637.99 4477.74 - 4204.29 - 2641.29 211326.17 2495321.31 ' 60 °49'13.123 "N 151 °37'02.116'W 2.00 - 156.55 -1.84 -1.07 4875.46 8500.00 44.12 159.38 4708.65 4548.40 - 4270.75 - 2617.05 211348.79 2495254.27 60 °4112.469 "N 151 °37'01.627'W 2.00 - 155.74 -1.83 -1.14 4928.63 8600.00 42.30 158.16 4781.54 4621.29 -4334.56 - 2592.27 211372.00 2495189.87 60 °49'11.840"N 151 °37'01.127'W 2.00 - 154.85 -1.82 -1.22 4979.14 al 8700.00 40.50 156.85 4856.55 4696.30 - 4395.66 - 2566.98 211395.79 2495128.18 60 °49'11.239 "N 151 °37'00.616'W 2.00 - 153.87 -1.80 - 1.31 5026.93 8800.00 38.71 155.44 4933.59 4773.34. - 4453.96 - 2541.21 211420.13 2495069.26 60 °49'10.665 "N 151 °3700.097'W 2.00 - 152.78 -1.79 - 1.41 5071.94 8900.00 36.94 153.92 5012.58 4852.33 -4509.40 - 2515.00 211444.98 2495013.20 60 °49'10.119 "N 151 °36'59.568'W 2.00 - 151.58 -1.77 -1.52 5114.12 9000.00 35.19 152.27 5093.41 4933.16 -4561.90 - 2488.37 211470.31 2494960.07 60 °49'09.602 "N 151 °3659.031'W 2.00 - 150.25 -1.75 -1.65 5153.41 9100.00 33.47 150.47 5175.99 5015.74 - 4611.40 - 2461.37 211496.10 2494909.92 60 °49'09.115 "N 151 °36'58.486'W 2.00 - 148.76 -1.72 -1.80 5189.78 9200.00 31.78 148.50 5260.21 5099.96 -4657.85 - 2434.01 211522.31 2494862.82 60 °49'08.657 "N 151 °36'57.934'W 2.00 - 147.10 -1.70 -1.97 5223.16 9241.68 31.08 147.62 5295.78 5135.53 - 4676.29 - 2422.52 211533.35 2494844.11 60 °49'08.476 "N 151 °36'57.702'W 2.00 0.00 -1.67 -2.10 5236.19 9300.00 31.08 147.62 5345.73 5185.48 -4701.71 - 2406.40 211548.85 2494818.30 60 °49'08.225 "N 151 °36'57.377'W 0.00 0.00 0.00 0.00 5254.05 9400.00 31.08 147.62 5431.38 5271.13 -4745.31 - 2378.75 211575.42 2494774.04 60 °49'07.796 "N 151 °36'56.820'W 0.00 0.00 0.00 0.00 5284.67 9500.00 31.08 147.62 5517.02 5356.77 - 4788.90 - 2351.11 211601.99 2494729.79 60 °49'07.367 "N 151 °36'56.262'W 0.00 0.00 0.00 0.00 5315.29 9600.00 31.08 147.62 5602.67 5442.42 - 4832.49 - 2323.46 211628.57 2494685.53 60 °49'06.938 "N 151 °36'55.704'W 0.00 0.00 0.00 0.00 5345.91 9700.00 31.08 147.62 5688.32 5528.07 -4876.09 - 2295.82 211655.14 2494641.27 60 °49'06.508 "N 151 °36 0.00 0.00 0.00 0.00 5376.54 _ 9800.00 31.08 147.62 5773.96 5613.71 - 4919.68 - 2268.17 211681.71 2494597.02 60 °49'06.079 "N 151 °36'54.589 "V / 0.00 0.00 0.00 0.00 5407.16 9900.00 31.08 147.62 5859.61 5699.36 - 4963.28 - 2240.53 211708.28 2494552.76 60 °49'05.650 "N 151 °36'54.032'W 0.00 0.00 0.00 0.00 5437.78 10000.00 31.08 147.62 5945.26 5785.01 - 5006.87 - 2212.88 211734.85 _ 2494508.51 60 °49'05.221 "N 151 °36'53.474'W 0.00 0.00 0.00 0.00 5468.40 10100.00 31.08 147.62 6030.90 5870.65 -5050.46 - 2185.24 211761.42 2494464.25 60 °49'04.792 "N 151 °36'52.916'W 0.00 0.00 0.00 0.00 5499.03 10200.00 31.08 147.62 6116.55 5956.30 -5094.06 - 2157.60 211787.99 2494420.00 60 °49'04.362 "N 151 °36'52.359'W 0.00 0.00 0.00 0.00 5529.65 10245.19 31.08 147.62 6155.25 5995.00 -5113.76 - 2145.10 211800.00 2494400.00 60 °49'04.168 "N 151 °36'52.107'W 0.00 0.00 0.00 0.00 5543.48 10300.00 31.08 147.62 6202.20 6041.95 -5137.65 - 2129.95 211814.57 2494375.74 60 °49'03.933 "N 151 °36'51.801'W 0.00 0.00 0.00 0.00 5560.27 10400.00 31.08 147.62 6287.84 6127.59 - 5181.24 - 2102.31 211841.14 2494331.49 60 °49'03.504 "N 151 °36'51.244'W 0.00 0.00 0.00 0.00 5590.89 10414.19 31.08 147.62 6300.00 6139.75 - 5187.43 - 2098.38 211844.91 2494325.20 60 °49'03.443 "N 151 °36'51.165'W 0.00 0.00 0.00 0.00 5595.24 10500.00 31.08 147.62 6373.49 621324 - 5224.84 - 2074.66 211867.71 2494287.23 60 °49'03.075 "N 151 °36'50.686 "W 0.00 0.00 0.00 0.00 5621.52 • 10600.00 31.08 147.62 • 6459.14 6298.89 -5268.43 - 2047.02 211894.28 2494242.97 60 °49'02.645 "N 151°36'50.129'W 0.00 0.00 0.00 0.00 5652.14 TD Page 2 of 2 McArthur River Field Steelhead Platform M -20 Proposed SZ12ST X: 213446 Y: 2499309 Steelhead Platform, Leg A -1, Slot 2 X: 214069 Y: 2499460 ADL017594 ADL018730 T9N - R1; TD T8N - R13 X: 211889 Y: 2494279 ADL018729 N A Chevron ID X Y Location 0 500 1,000 Union Oil Company Leg A -1, Slot 2 214069.30 2499459.80 1044' FNL, 452' FWL, Sec 33, T9N, R13W, S Fee of California SZ12ST 213446.32 2499309.07 1209' FNL, 167' FEL, Sec 32, T9N, R13W, S State Plane Alaska TD 211888.98 2494279.25 996' FNL, 391' FEL, Sec 6, T8N, R13W, S Zone 4 NAD 27 August 19, 2009 Chevron Steelhead Platform Well M -20 Drilling Program 2009 M -20 Cement Calculations Surface Casing • 13 3/8 ", 68 ppf, Surface Casing in 17'/2" Hole, Stage 1 Cement from section TD at 1400' to the ECP stage tool at 470' OH Volume w/ 100% excess = (1390 -470) *0 237 *2 =228 bbls Shoe Track Volume = 80 *0.149 = 12.0 bbls Stage 1 Total Volume = 228 +12.0 = 240 bbls of slurry 13 3/8 ", 68 ppf, Surface Casing in 34 OD x Various ID Structural Pile Conductor, Stage 2 Cement from 470' to surface 1111 Annular Volume' = 470 *0.7005 = 329 bbls Stage 2 Total Volume = 329 bbls of slurry Notes: i I Used 30" average ID of conductor for volumetric calculations. Chevron , IOW Steelhead Platform 111110 z Well M -20 Drilling Program 2009 Intermediate Casing 9 5/8 ", 47 ppf, Intermediate Casing in 12'/" Hole, Stage 1 • Cement from TD @ 7200' to Stage Collar @ 5960' MD. OH Volume w /30% excess = (7200- 5960) *0.4558* 1.3 = 90 bbls Shoe Track Volume = 80 *0.0732 = 5.9 bbls Total Volume Stage 1 = 96 bbls slurry V 9 5/8 ", 47 ppf, Intermediate Casing in 12 V Hole, Stage 2 Cement from Stage Collar @ 5960' MD to ML @ 345' MD. OH Volume w/45% excess = (5960 - 1394) *0.0558 *1.45 = 369 bbls Cased Hole Volume = (1390 -345) *.0597 = 62 bbls Ilk f Shoe Track Volume = 80 *0.0732 = 5.9 bbls Total Volume Stage 2 = 437 bbls slurry v Chevron 1 Steelhead Platform Well M -20 Drilling Program 2009 Production Liner 7 ", 26 ppf, Production Liner in 8'/2" Hole Cement from section TD at 10,600' to 7000' (200' lap inside the 9 5/8" casing) • OH Volume w /30% excess = (10600 - 7200)*0.0226 *13 = 100 bbls Cased Hole Annular Volume = 200 *0.0256 = 5.1 bbls Shoe Track Volume = 80 *0.0383 = 3.1 bbls Total Cement Volume = 108 bbls slurry / Calculation & Casing Design Factors tgo. Chevron Steelhead Platform Cook Inlet, Alaska WELL: TBU M - FIELD: Trading Bay DATE: 18 - Aug - DESIGN BY: Jim Rose Sect. 1 12 1/4" hole MUD WT. 9.30 .PPG MASP= 1340 psi Sect. 2 8 1/2" hole MUD WT. 9.30 PPG MASP= 2180 psi Production Mode TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH / PRESS @ RESIST. / MINIMUM O • DESCRIPTION W/O BF SECTION TENSION WORST CASE BOTTOM w/o TENSION WORST CASE MASP YIELD WORST CASE SECTION CASING BOTTOM TOP LENGTH WT. GRADE THREAD LBS LBS 1000 LBS SF TENSION PSI* PSI SF COLL. PSI ** PSI SF BURST 1 13 3/8 1,390 0 1390 68 L -80 Butt 94,520 94,520 1478 15.64 440 2,270 5.16 1,340 5,020 3.76 TVD 1,310 0 2 9 5/8" 7,200 0 7200 47.5 L -80 Butt 342,000 342,000 905 2.65 1,316 4,760 3.62 2,180 6,870 3.15 TVD 3,918 0 3 7" 10,600 7000 3600 26 L -80 DWC SR 93,600 93,600 519 5.54 2,170 5,410 2.49 2,180 7,240 3.32 TVD 6,459 3803 * Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.436 psi/ft) and the casing evacuated for the internal stress (.1 psi/ft) **See attached sheet for calculation of MASP. 7" is a liner therefore production mode MASP is used on 9 5/8 burst SF calculation S Chevron 100 Steelhead Platform Well M-20 11 11011 Drilling Program 2009 M-20 Maximum Anticipated Surface Pressure Calculations 17 V2" Surface Hole, 13 318 Casing The 17 Y2" surface hole will be drilled to approximately 1390' MD / 1310' TVD under an existing structural pile • conductor and will use a diverter system for well control. The diverter system is not designed to shut the well in and contain pressure. Therefore, MASP is 0 psig for this hole section. 12 'A" Intermediate Hole Section, 9 5/8" Casing The 12 1 /4 " intermediate hole section will be drilled from 1310' TVD to 3918' TVD. MASP will be bottom hole pore pressure less a gas gradient to surface BHP MASP The maximum predicted pore pressure at section TD = 8.5 ppg. Pore pressure = 3918 x 8.5 x 0.052 =1732 psig • Correcting for an evacuated wellbore = 1732 - (3918*0.1) = 1340 psig MASP = 1340 psig Chevron %11. Steelhead Platform Well M -20 410 Drilling Program 2009 8 1 /2" Hole Section, 7" Liner The 8 1 /2" production hole section will be drilled from 3918' TVD to 6459' TVD. MASP will be bottom hole pore pressure less a gas gradient to surface BHP MASP The maximum predicted pore pressure at TD = 8.5 ppg. Pore pressure = 6459 x 8.5 x 0.052 = 2855 psig Correcting for an evacuated wellbore = 2855 - (6459 *0.1) = 2209 psig MASP = 2209 psig i • • Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT /LOT results are defined as follows: • Formation Integrity Test (FIT) - Formation is tested to a pre- determined equivalent mud weight. • Leak -Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the leak -off point. • LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak -offs. • Open Hole LOTs (OH LOTs)- Leak -off tests performed with open hole from the casing shoe to some point above the target reservoir. Generally done when leak -off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is required of being able to achieve estimated mud weight. Procedure for FIT: i 1. Drill 20' of new hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1- minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre- determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular pumping will be done on a well, the formation below the surface shoe is taken to leak -off. This ensures that future disposal fluids can pumped away without risk of damage to the surface shoe. If two attempts at establishing leak -off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per definition above), then an open -hole LOT is performed. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre- determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. . • Chevron %. Schlumberger 1 ,-- M -20 (P7) I FIE`° Trading Bay Unit I STRUCTURE Steelhead M SGGM elna : location NRD25 Slale Me Coro01, 39 1 1 MICNYnee MoBN: k P 2009 Dip: 1183 SSSSS FS:e'. . 20091 Lai n W1 89 Eo 2/3 980 SUS S 023 Gan: •1 3993043 I Sio M - (87) N w 0O Dal: b0620 20.25flabove Mean level) Map Dec: +18.IW' FS: 555 %.S nT Lon W15138 36 8.851 EaMi 21405900fi933 flUS Scale FM:09999930318 man A420 (Vn Soy Dale Saple Sapta mbn 20, 2009 -4000 -3000 -2000 -1000 0 1000 ■ 9R B ■ ; . tM -03 � r; Sri '' 'Ill o �., ; e 2 - 0 i 4' .rye -05 L� ! -1000 - • —"wil _ -1000 o Er ,, O li 3 000 TVD A 11 2) n -2000 •' - — -2000 ' Z i • _"' � 'id °1J • 4000 TV 1 � 6 - 30 • o ' O c . '4 '� - 4 a � .5000 , -3000 * i.; •� .11 a — -3000 � • • • / f , ' D 8 J � /' •.... 8 N—. '�,,� �. ,,,D 8,�a ..',,'3pRD . -17RD2 _� -4000 � i r: -4000 V r r e �, /• -2 � • D i fil • , ' ' � - II s8 \ ` 9 1a ;; O A ' -26 -5000 8 ■ ` wry , „$ WPMEMIIIIII " -5000 ir ii. -20 (P7 ' B -32 ',6 . % D -1 1 =130 s000 r, � �.,� _ �j� ` 4 1i713RD � ;I - � • -- N f A . •,, . a Ae • ...... _..... /II iee 71•DEN , ,3 el) .41:: , caa D -4 D -19 D -012'0 -4000 -3000 -2000 -1000 0 1000 «< W Scale = 1(in):1000(ft) E »> Chevron Schlumberger 1 WELL M-20 (P7) I FIELD Trading Bay Unit I STRUCTURE Steelhead MapnMr PammMen L SuOaw Loratnn NAD27 Alaska State Mance Zone 54. US Feet 33+41eneoua Mo. : BCC. 2009 Op 73.634' Data September 20.20091 Let: N60 4954.522 Northing: 2465459.80 8US OS Cow : - 1.39434316' I Slot'. leg 31 &012 Tu. Ref: Rotary Tebb (160.255 above Mwn Sea Leval) M84 Dec +16.404' FS 55535.5 nT Lon: W151368.854 Ewtnp: 214069.33(WS Scale Fact: 0.9999930316 Pbn'. M -20 (P7) S.y Date: September 20. 2009 -3000 -2500 -2000 -1500 -1000 -500 0 V00 A /vf i� ` 1 03 m 0'0 0 Tf b M- • A -500 eC b Z -500 A ' • ]6 . 20 ,, • r'' • 2g00 n'D • • � �Qi % • 250013'0 o Ln • < 1 � • • . • yam •$ % • 2 ,` -1000 1 S '2 O ° " . 28 oo 7VD ,1600-1,000 3 S � 1 o I • f!1 i Ada a WS � s' ° ° • 3000 -02 U co • (/1 • 2.1 • 1 V -1500 • ,,, , •1 4D V V • 2857 a 34 ,0 TV D DD 3, D8 L -2000 • 3000 , v 9 0 -41 - LE/0 T D -2000 6� ?8 ' 1- 4. -14RD 9 °b .1 -28 2 L O 380 7 • • s ' + &P7) D-42 M -15 M -14RD 300 -2500 -2000 -1500 -1000 -500 0 500 «< W Scale = 1(in):500(ft) E »> Chevron %. Schlumberger %. WELL M -20 (P7) I FlELD Trading Bay Unit I STRUCTURE Steelhead I M.Onet'r Parameters I Swine Locatbn 53027 A4vka State Ranee Zane 04. US Feet I Miaeelaneoua MetAl SCAM 2009 Dip: ]3.631' Date: September 20, 2000 Lat: 560 48 54.527 Northing 2499459.80 PUS Gee Com: - 1.39934318 Slot : lee Al slot 2 ND Ref Rotary Table (180.254 above Mean Sea Leve6 Meg Dee: 418.4W FS: 55535.5 nT Lon: W151 36 8.854 E445114 214069.33 PUS Scab Fap'. 0.9999930316 Plan' 543.20 (P7) Srvy Date: September 20, 2009 -120 -100 -80 -60 -40 -20 M -12PB1 0 M -16 20 40 M -12 , °° ° .\ M-19R1 - 8il, -14 20 .\-I N • 20 N ' • , 4 I , ' S;,1* 1..°° _ \ s'� � ' f 9 •�. tea • 0 • _ 5 0 : .. e ,,• \VI 0 9RD A 6t0 % a 1 � t call ,Y *`- :l O -20 - -20 N a - Q _ � �µ. • 800 ,Ia 11 - 19RD To M-20 (P7) •erg •M -1 • � P fr , - 40 a -40 • cn $� 3 �� V V • ioo°v D -60 'a -60 • ,IPo ppa -80 M 15 • l'D,.t -80 M -1 ST M -14RD -120 -100 -80 -60 -40 0 20 40 «< W Scale = 1(in):20(ft) E »> Chevron %. Schlumberger %. WELL M -20 (P7) I MELD STRUCTU0.E Trading Bay Unit Steelhead Sea Lev Table Mag+611 Pare eV I Sprbm L°' 1•76749 '279°924'59.80 Naeaa State Pbnea, one 01, US 6,M I Miece60 +++ g *1 12 M*I. BOOM 2009 Dip +3.63.' Deb'. September e, 20. 2009 Lan 58.52+ N+PS,+g'. 8US Sc a Z DPnv'. - ..39931318 Sbl + : b 4)12 71/D EM Rot . Table (160.35 0 a6pve Mean u Ma9 D +18.161' FS: 55535.5 nT Lon: W151 38 8.651 Eatlin9: 211U89.336US Scab P.01 0.9999930316 Pbn'. M-3D (P+) SOy Date: September 20.2009 -120 -100 -80 -60 -40 _20 M -12PB1 0 M -16 20 40 I •• M -12 90 • • M -19RD se,, -14 '�� 'la 20 ,r • 20 lls4� • � eg8o- ' 1S \ - s,„ 1 , Ik*.r Uat ' M -19RD 1 y _ A6 A c �;' n:, ,•-, . r Vi;µ <'° w G O _20 °°o 4' -20 • 0 II $ . 8 Po , e • • -19RD M -20 (P7) erg ' • M -19 u) 900 1 • -40 -4o • • V - • V • 1p0 0T`` o ° -6o -, 3 . -60 • / .' ''o 30° _ ■ M 15 • - Prz e -80 M -1 ST M -14RD -120 -100 -80 -60 -40 0 20 40 «< W Scale = 1(in):20(ft) E »> . • Chevron %. % Schlumberger 1 — M -20 (P7) I FIELD Trading Bay Unit I STRUCTURE Steelhead I 'gk P' 1 r'met&. Sutlan Lo Mb' NA02T bs6' SINS planes, Zell' s US "1 Mis»Ilansous MMotley. 6669 2009 Dip: 13 531' DNS: 5 5535S 'r 20, 20091 Lon N50 4.954.627 Melting: 2099159 US GM D O 1.399 I Pla 6g Al +67 2 Sfey Rat: September Table , 2009 7 above Mean S.. Level) WO.: •18.46' FS: 635355nT Lon: W151388.854 Ewalt, 214069330US Scale F' %'n: M -20 (P7) Srvy Date: Seplember20,2009 -3500 -3000 -2500 -2000 -1500 I I ',, -20 P7) , 41, Zo - 2000 -2000 , , l • . D • ' p .. N. 9800 • " -28 , �� 'la • , • Pl■ -2500 tyA • -2500 a � r • 1 1 -30 3000 I ; � r .•J5 -30RD $ " • ♦ • • D r8 4 � • vooT,m • A A .•8�3 �`� l i wool` ° o �° " �� -07RD •i j • • • • 8 tl; • IV e� � 4 -35l�0 '''' ♦,. � ". 4 3500 6 ° n oo B -07RD2 "E '0,0 • _ ________ t o J8 r ,. ' 5.0,0 , J To -4000 9 2°6 -4000 i6ao U) 417 U) BOO • •q6W o • ,'. • .7 X4 ee$ S 40p rUD ✓ R o � V ��% • Oat S .,.. •'' 11CA 4500°R8 5.._ ': . :. T-4500 s �r•2 d. ' � � 6 • 3, D $ 1 : : li -5000 -5000 30RDvJ �b k � e� •. , -20 (P TR � ' • 9 -03RD2 1 ,„•,•i 5500 D- TWORD2 D -1: D -2169$ : RD2 D -29RD -3500 -3000 -2500 -2000 -1500 «< W Scale = 1(in):500(ft) E »> • • (i 6 i i I ( I 1 2-1 000p HYDR IL 2 ANNUL AR I I I I STACK LEVEL II O b ( t i INSPECTION O LIFTING DEVICE M 1 ' _ (ROTATED FOR CLARDY) 11 R I II '.L -, I u l l - ` 7II.71,_ I IC� I' 711' DOUBLE /MAIL DOUBLE GATE RAMS PICKING POINT II ��NNiIU _11!'■ I. Ill I MIIMII— RAMS & — III!'�M_ l! )IiI = J1 RUBBERS O CENTER OF GRAVITY moll_ HYD KILL UNE CHOKE � UN � E O3 MUD CROSS /I, i'■ _ _ • 'I l'i'c'�\ Ci�� I I I I�Ci�� X203 p HUBHUB 203 /P3�DOOPA HYDRIL • _ I � I III 1 _ SINGLE GATE RAM 6' I t 04 16" DIVERTER LINE — IMI�MI■I1i Mil ��E31 16" DIVERTER LINE O4 F 203 /4. 3.000p6 i i-. DNER ER SPOOL w/ IIlia 1\ Il i ' i AI _ _I ff ElI t.Ab (2) NT2 CONNECTOR %O - - - -- --- ..,,, f I ' 4 ,•r DIVERTER VALVES a� j 203/Y 3,000pA f i - 14T2 CONNECTOR G O STACK LEVEL II INSPECTION O RAMS & RUBBERS O MUD CROSS O 5 RISER & NT2 CONNECTIONS O DIVERTER SPOOLS 0 RISER & NT2 CONNECTIONS 41 -5' I 06 LIFTING DEVICE 203/0 3,OODPI I RISER I AIM 1111.1 ` 2P3 E,R00ps1 6 RISER I I VETCO 20A/Y BMW NT2 CONNECTOR B ■ VETCO NT2 HEAD . I I 1 hevron E rEELIFAD PLAWFOfII 6' ANSI 600 RT 1111011 COX NA MINA 3M BOP STACK -UP NOVEMBER 2000 JON MRS NIA !IMMO . CHOKE MANIFOLD • • TO GAS BLISTER TO DERRICK VENT TO SHALE SHAKERS A • I I. u a ""1 it ..i, ) ..a • j V 1>i , I,' . ,. ., .. ,....., , .4it.., , , ...,„, .,.... , • \ Ir_d__,V . , 1111_16k lam 1 ................... 1 1 .....__._.4 . 1 1 1 _u_ 1 + 1 _ (... maw ( • �. _- ,... • Ow r =an: g .... . )11 eisi:',1111.... i n ,...., ,‘ , ,c,...„..i . . ... , II . (4 ,,,,:i l , t w.,-.4--;sz: -- D / . . 1.-. „iik.,45, • -?,*--) ots4 1 t 7r, j moms Ilki.., l ihrlifir - �. �� rte. el & I../ - 411 ilitAli) • SWACO i i � � CHOKE LINE I . NB 0111111111 A....I SECTION AA * ALL VALVES IN FLOW PATH ARE 3 -1 /16' $000 PSI CAMERON GATE TYPE TBU M -20 Index Map TBU M-1310. . Vv r. (Tyonek �� B 33 5 Perf 6, 4 0.. p .. 0 TBU M • ' a RD • ,� WTBU M -02 P �TBI. D -18 s hut — Y BU M -17 !/, _ ^ • (Tyonek (Tyonek D6 Perfs) C3 Perfs) k �i (Tyonek (Tyonek D16 Perfs) C1 Perfs) o` BU M -15 ..„/ (Active Gas TB \\ Producer) • 10 -acre spacing radius Wellbore annotations are presented in true vertical depth subsea CO 228 Rule 1 specifies 10 -acre spacing at the point of penetration of the D -1 sand. Depending on the final well course, a spacing exception may be needed if TBU M -20 is completed in SFD reservoir sands below 5600' TVD subsea (about 9800' measured depth) that are open to TBU M -15. 9/1/09 Page 1 of 2 Davies, Stephen F (DOA) From: Rose, Jim [Contractor] [RoseJi @chevron.com] Sent: Monday, August 31, 2009 2:33 PM To: Davies, Stephen F (DOA) Cc: Bonnett, Nigel (Nigel.Bonnett) Subject: RE: M -20 Question Steve, The closest point within the "GGS" above our primary target interval is: D -18 vs M20v7 - 6200'md on M -20, 3344'md on D -18, center to center distance of 2285' M -15 vs M20v7 - 1820'md on M -20, 1585'md on M -15, center to center distance of 540' and within our primary target interval (6200'md- 10600'md M -20 V7) is: D -18 vs M20v7 - 8431'md on M -20, 4660'md on D -18, center to center distance of 428' M -15 vs M20v7 - 10560'md on M -20, 6429'md on M -15, center to center distance of 467'. D -18 is incapable of production M -15 produces from the B -5 and D -6 which are primary target reservoirs in the M -20 well. Both the B5 and D6 fall outside the 745' spacing that would require a spacing exception. more specifically to the point B -5 zone, M -15 MD - 4450 (-3605' tvd) Horizontal distance (same TVD) is —2515' (M -20v7 depth is — 6660'md) 3D distance relative to 4450'md (different TVD on plan) is —2650' (M -20v7 depth is — 5360'md / 2855'tvd) D -6 zone, M -15 MD - 6915 (-5120' tvd) Horizontal distance (same TVD) is —1450' (M -20v7 depth is — 9030'md) 3D distance relative to 6915'md (different TVD on plan) is —1639' (M -20v7 depth is —8100'md / 4440'tvd) Based on my understanding, a spacing exception should not be required. Let me know if you need any more information. Jim From: Davies, Stephen F (DOA) [ mailto:steve.davies ©alaska.gov] Sent: Friday, August 28, 2009 4:56 PM To: Rose, Jim [Contractor] Subject: M -20 Question Jim, How close will M -20 approach D -18 and M -15 within the Grayling Gas Sands? 8/31/2009 • • Page 2 of 2 Thanks, Steve Davies AOGCC 8/31/2009 • • TRANSMITTAL LETTER CHECKLIST WELL NAME 14 /-'(- Zr PTD# 2q O? 3I /Development Service Exploratory Stratigraphic Test Non - Conventional Well /� FIELD: / 4r-/X t� / iL) 1� POOL: 4i (U /L- / it4 61 l Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTIOJ. L- 25.055: ._ • _ ..._._ — - -= = -= eatesztir • � t� !III JI •: --. -. • • . . . • _ 41[111:11i 11iSiSi'•1t1 1i1 moo griwu._ •—assuaies=t4e,-- J " 1 1 -, -.. . -- n_ -xcep ion • . t • I *, l r at/ (eA. All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool MCARTHUR RIVER, MIDKENAI GAS - 520550 Well Name: TRADING BAY UNIT M -20 Program DEV Well bore seg ❑ PTD #: 2090930 Company UNION OIL CO OF CALIFORNIA Initial Class/Type DEV / PEND GeoArea 820 Unit On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee_attached NA 2 .Lease number appropriate Yes Corrected 10- 401:Surfacelocin ADL 18730 top Prod Jnt inADL 17594;TD in ADL 18729 3 .Unique well name and number Yes 4 Well _located in a dolled pool Yes Middle Kenai_ Gas Pool,_governed by CO 225 and amended by.QQ 228,02 5 Well Jocated proper distance from drilling unit boundary Yes Rule 1 of CO 220 established 10 -acre drilling units for the pool at the DA sand, which Uee at 6 Well Jocated proper distance from other Wells Yes the vertical _mid -point of the_pool becauseof the Lenttcular_nature of the reservoir sands. 7 Sufficient acreage avaUable in drilling unit Yes Nearby_ Well_TQU_ 0-18 has been shut M. since 12/2003; other nearby well :MUM-15 is an 8 if deviated, is wellbore plat included Yes active gas producerJrt the Ty_onek B5, D5 and D16 sands. Spacing exception may be 9 .Operator only affected party Yes needed if TBU M -2Q is completed in sands_beiow 5600' TVD subsea that are open to 10 .0peratot has appropriate bond in _force Yes TBU M -15._ Thepermit approv_al_letter will reflect this._ SFD 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be leaned without adminlstratN_e approval Yes SFD 9/1/2009 13 Can permit be approved before 15- day_walt Yes 14 Well located within area and strata autharized_by injection Order # (put 10# in_comments) .(For NA 15 All welts within 1/4 mile area of review identified_(For only) NA 16 _Pre- produoed_Injector:. duration of pre:produation less than 3months (For service welt only)_ NA 17 _l&onconven..gas conforms to AS31,05.0300,1_.A).(j.2.A -D)_ NA 18 .Conductor string provided Yes Driven to 480. Engineering 19 Surface casing protects all known USDW$ Yes Set at 1310 TVO. 20 _CMT_vol_adequate toclrculate on conductor& surf csg Yes Adequate excess. 21 CMT_vpladequate to tie- Jn_long string to surf cog Yes 22 CMT_wilt cover all known productive horizons Yes 23 CasIng deaigns_adequate for 0, T, B_& permafr_oet Yes Adequate satety_factors, 24 Adequate tankage or_reserve pit Yes Steelhead rig. 25 lfa_re- drill, has al Q-403. forabandonment been approved NA New well. 26 Adequate wellbore eeparationproposed Yes 27 if.diverter requir_ed,_does_itmeet regulations No Vent line varianceraquested, Appr Date 28 _Drilling flutd_program_sehematic& equip_list_adequate Yes MaxMW 9,5_ppg. WGA 9/1/2009 29 BOPEs, dothey meet regulation No 2M pal rated annular. 30 _BOPEpress rating_appropriate;_testt to.(put prig In comments) Yes MASP 2209 ps1;.test ann to 1000 psl;.test rams to_3000 psi. • 31 _Choke_manifoJdccmplles w /API RP -53 (May 94) Yes _ _ _ _ _ _ _ 5M psi rated 32 Work will occurwithout operationshutdown Yes 33 is presence of H2S gas probable Yes H2S measures required. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Steelhead Platform is a designated H25 site. Geology 36 _Data presented on potential overpressure zones Yes Maximum anticipated pressure is 6.5 ppg. EMW;. will be_driUed using 9.2 -9.3 ppg mud, Appr Date 37 Seismic analysis of shallow gas zones NA Development weJl,_but Summary_of Drilling Hazards_discusses shallow gas sands_and mitigation. SFD 8/28/2009 38 Seabed conditionswvey_(if off-shore) NA 39 Contact name /phone_for.weekly_progress reports .texploratcry only NA Geologic Date: Engineering Date Public Date Approval recommended subject to full compliance with 20 AAC 25.055. Depending on the final well course, a spacing exception Commissioner: Commission Commissioner may be needed if TBU M -20 is completed in sands below 5600' TVD subsea that are open to TBU M -15. The permit approval 012 5_Z _,09 letter will reflect this. SFD • • 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. Company Chevron I Schlumberger Well M -20 t Chevron ' Field Trading Bay Unit %.1 %. Rig Nabors 51 State Alaska c70-69 3 Report by R. Heath Logging Date 17 Nov 2009 ' Report Date 09 Dec 2009 API Number 50- 733 - 20587 -00 Recorded By B.Warta /N.Goura Steth!jppe 675 .._ ...,.. as Final Report Innovations in Formation Testing DCS Analysis Report PD Plot 7 Ver 7.1.56 1 1 Page FT FPWD StethoSco a WorkArea M 20 Report Cover 1 Written Comments 3 Formation Tops Table 4 Pressure Gradients 5 1 Test Point Table 6 Test Point Summary Table 8 M_20__Header 9 M_20jool,String 10 M 20` Hookload Plo# 11 Gauge Comparison Table 12 1 Inclinometry Tables 13 Well Path Plots 16 Pressure Vs Depth Plot 17 Pressure Vs Depth. Plot Test2 Detail 18° Pressure Vs Depth Plot Tes3t Test4 Detail 19 1 Pressure Vs Time Plot 20 1 XY MUD Before vs MUD After 21 Polaris Interpretation 22 1 1 1 1 ' Written Comments Schlumberger 1 Objective: Compile a StethoScope evaluation report that includes plots of formation pressures versus depth, a table of test point data, and individual plots of each test draw - down /build -up sequence. Comments: 1 Run 5 was conducted with the StethoScope 675 tool between 17- Nov -2009 and 18- Nov -2009 in the 8.5" hole, from approximately 9015 ft to 10,286 ft (Measured Depth). 1 A total of 4 tests were attempted. Of those attempts, data was acquired for the final 3 tests, all completed with normal results, while the first attempted test ( #1) was a 'Lost Seal'. Overall, the quality of the tests ' was good; The test quality is graded by color, with Green being the highest (see the table below for grading explanation). ' All of the tests were acquired using the Time Optimized Pretest (TOP) 2 -C sequence, as noted in the Test Point Table. The data used to generate this report was the Recorded Mode FPWD675 StethoScope data, processed using PD -Plot software (Vers 7.1.56). TVD depths were calculated using the survey data supplied by the field engineer, in a file named Surveys.txt. The GR, TNPH and ROBB curves shown for correlation were obtained from the EcoScope675 survey on Run 5. Formation Pressure Quality Grading Description Color Quality# Description Examples No Seal,Tight, Buildin. -- Not Red 0 throw h 3 No Formation Pressure Close To Being Stabilized Yellow 3 through 7 Questionable /Fair Formation Pressure Close To Being Stabilized Green 8 through 10 Good Formation Pressure Build U. Stabilized 1 1 M -20 3 Schlumberger Formation Tops Table Formation Tops Table Source :Estimate I Formation Tops MD (FT) TVD (FT) 1 Sub Sea (FT)_ Color D6S 8986.37 5092.17 - 4931.92 D16AS 10208.01 6090.73 - 5930.48 ' D16CS 10261.99 6134.67 1- 5974A2 1 1 1 1 1 1 M -20 4 1 Sehlumberger Pressure Gradients Mud Column Gradients Formation Gradient Gauges Gradie Density Gradient Top FT Base or RI STD Commen Error % nt lb/gal Caption Contact Asia; t ' — — M Fl. ud After Lines psitft 1.8% AQAP 0.541 10.405 10.405 5116.03 6154.64 0.9935 31.2500 (10.219 to lb/gal 10.591 lb/gal) ' Mud Column Gradients 1 1 1 1 M -20 5 1 �2J Schlumberger I Test Point Table Last-Read DrawdoWn Test Test Test Test ° Formation Test Type Remarks Buildup Last -Rea ;NM) Drawd vn Mud No. TVD Bubsea.. Pressure; invest Buildup Irtuest. Mc aiiI.y Before F r FT FT psis psis ' p'sia� and /c md/cp psis , 1 9015.15 5116.03 -4955.78 Type 2 - C No Seal 2767.59 2769.12 692.22 2767.131 2 9015.67 5116.46 - 4956.21 479.24 Type 2 - C Good Test 479.17 t 479.26 157.56 1 197.57 2789.94 3 10221.52 6101.76 - 5941.51 463.12 Type 2 - C Good Test 462.18 462.68 21.66 11.72 3274.84 4 10286.55 6154.64 - 5994.39 342.33 Type 2 - C Good Test 342.33 342.32 55.51 56.01 3364.221 1 M -20 6 Schlumberger Test Point Table FPW Eg uiv. Mud:: H*0* Spheri9al 60 s . Pressure Mud Time & ' Prates; Pretest' Prete0 , ' err K?; ire Alter Mabmty: -Moojifty Slope Data. Volume, ,7,110,10 ' Flovimate : Rate. , Var�nce Density psis ld.fticFi' md lcp ps ps bfgai F Opn1 i .CAE is a�tmin I ca s G 2769.361 1.1 -.41 10.365 17- Nov -2009 16.09 , 15.5 1.04 115.0 580 01:16:20 s 2 789.83 l 177.45 47.23 0.05 ^ 0.02 10.441 17-Nov-20015 7 .19 15 7 0.99 r 113.5 580 1 i 01:43:23 3278.15 , 0.93 0.04 0.58 10.296 18-Nov -2009 14.311 14.44 0.99 129.5 589 04:52:35 i 3364.92 22.11 0.06 0.09 10.479 , 18-Nov -2009 6.98 7.06 0.99 131.3 580 f 1 08:03:53 a 1 1 1 1 1 1 1 1 1 1 1 1 1 M -20 7 Schlumberger Test Point Summary Table Test Types Quantity Type 2 - C 4 TOTAL 4 Gau0es AQAP 4 Runs Color 5 _ 4 Formation Pressure Quality: Color 0_(no pressure) -10 (best) 10 3 Drawdown Mobility Quality: Color 0 (no pressure) -10 (best) 10 M -20 8 I I I I Schlumberger Company: Chevron I Well: M -20 Field: Trading Bay Unit I Rig: Nabors 51 State: Alaska StethoScope675 I $ Formation Pressure While Drilling Recorded Mode Lo • I C } Total depth: 10500 ft o K.B. N/A Top Drive m Spud date: 19-Oct-09 G.L. N/A 0 o Runs: 5 To 5 w D.F. 160.25 ft = Q Permanent datum: Mean Sea Level Elev.: 0 ft co I z H x 2 0 - Log measured from: Drill Floor 160.25 ft above Perm. datum E c Depth reference: Driller's Pi•eTall I o i3 a = E API serial no. 1044' FNL, 452' FWL Longitude Latitude iii) U tc � _ 0 ..4 SEC 33, T9N, R13W, SM W 151.60245944 N 60.83181315 I Depth logged: 8240 ft To 10474 ft Mag decl: 18.38 deg. Other services: Date logged: 15- Nov -09 To 18- Nov -09 Mag dip: 73.62 deg. VISION Service, APWD Bore hole record Casing record I Hole size from to Size Density from to • l •r. ' •&F]G7• • u fT .t"� •i ii • i c.• i t AIMS • • u I �11i�T.riLIii • c.• .• � • v • Ei7 . ilTa6�iWiM111i M11111111111111■MININIMI �, . • • Borehole deviation record . - X17.7.1.111111111111M111111111 ■AFZ!a i • u �t1 S•udMud Surface ft 1430ft 0.12 de.. 36.57d - •. Oft 1430ft 1 _ 1430 ft 2205 ft 43.82 d - • 72.54 d - • . 1430 ft 2205 ft KCl/ • o mer 2205 ft 10500 ft 49.73 d 78.17 d 2205 ft 8240 ft 31.56 d - • 49.44 d -• . 8240 ft 10500 ft I Mud Information Dens' I Software record 9.25 IDEAL Wis 14_0C_25 25 Recorded B N. Goura Viscosi cP 43 @ 84 degF HSPM 14_1c_03 B. Warta I Fluid Loss cc /30min N/A StethoSco • - 7.8b14 Witnessed B Mike Leslie Sam •le Source Mud Pits TeleSco • - 9.5b11 Shane Hauck I 1 9 I I I DOWNHOLE EQUIPMENT StethoScope675 108.6 I TSTDC SN #AE -90 TSTEC SN #127 TSTHM SN #53 's`ti-tiy, ACQG SN #1776 ``" I Strain SN #232366 ACQG , y':#= 88.5 Cal Date: 16 - Mar - R -O Port :- ;; >- 87.8 Annular =. ; +;; Paine ; ".. 87.3 OD 6.75 Probe 1'<w 1 _ 80.7 BladeOD 8.25 ' rr'h: 1 TeleScope675 ; r . 74.2 MDC SN #45893 PMEA SN #1065 ` °,' ''' I OD 6.89' D &I ' i,y:wV _ 60.0 GAMMA '>': -" '& _ 57.8 ROP TF400r'- _ 44.7 PNG Monit 38.4 Neutron N ' n7~ 37.8 „_ . Spectrosc 37.8 EcoScope675 Neutron on y 36.8 46.4 DC SN #985 Receiver 35.9 EC SN #YW92 Ultrasoni 31.3 GSR -Z SN #A2648 Density S / 230.3 I PNG SN #8004 -4013 Density L 9.9 Continuou ';.:1' 27.7 OD 6.89 R-0 Port ('- ; <;'; 3 26.9 Pressure -, °;<;> 26.5 BladeOD 8.25 Gamma Ray a''':. ,' 26.0 I XO SN #60475 20.0 I OD 8.13 PowerDrive675 14.3 SN #52818 I OD 6.75 BIT -PDC SN #JD1265 wrialffiess - 0 ' 0 0.8 t OD 8.50 Maximum string diameter 8.50 in. I All lengths in Feet I 10 I I I Hookload Plot It has been learned on previous jobs to reduce Lost Seals and packer damage, before every I depth set to observe the up weight and down weight and set the tool in the mid - range, known as the rotating weight, irrespective of rig type. I Here below we see for this job all the sets had a test weight between the up and down weights. I 0 50 100 150 Hookload , Klbs 200 250 300 350 400 8000 1 .42 .... _ _ _ _ 1 8500 1 9000 I 1 0 1 2 9500 I 10000 - - I _ 1 10500 I 1 o3 I ill, DN Weight 3(1 2 XI 600 90 % I UP Weight 1 11 Schlumberger Pressure Gauge Comparison Table File Test Test Test Formation Mud Mud No. No. TVD Subsea , Pressure Before After Test Type (AQAP) (AQAP) (AQAP) 0 "1 9015: 4955,78 2767.13 2769.36 Type 2 - C 01 ` r 9018 4956,21 479.24 2789.94 2789.83 Type 2 - C ' 0 3 10222 . -5941.51 463.12 3274.84 3278.15 Type 2 - C 0 . 4 ° 10287 »5994.39 342.33 3364.22 3364.92 Type 2 - C Gauge Specifications ' Pressure Gauge Name Range A ura Repeatability Resolution Module Symbol, (p (P (1 >) (p AQAP (Quartz) 0 - 15000 +1- 5.0000 +1- 0.5000 0.0400 FPWD I I 1 M -20 12 ' 1 Schlumberger Inclinometry Tables I M -20 Source :Supplied Survey table I I MD TVD Devi ' Azimuth North - I East Departur Departur Dogleg e . e Severity Azimuth -T FT Deg. Deg FT FT FT Deg Deg /1QOf - I 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 347.15 347.15 0.12 168.38 -0.36 0.07 0.37 169.00 434.01 434.01 0.32 1192 -0.21 0.14 0.25 146.31 ' 465.23 465.23 0.43 340.37 -0.01 0.12 0.12 94.76 0.35 494.73 494.73 0.88 320.74 0.27 -0.06 0.28 347.47 1.53 525.78 525.77 1.51 318.85 0.76 -0.48 0.90 327.72 2.03 554.23 554.21 1.96 310.67 1.36 -1.10 1.75 321.03 1.58 I 308. 2.86 584.38 584.33 2.81 302.61 2.09 -2.11 2.97 314.73 2.82 614.43 614.33 3.67 294.93 2.90 -3.60 4.62 644.21 644.03 4.83 288.51 3.70 -5.66 6.76 303.17 3.90 674.32 674.00 6.17 285.79 4.54 _ -8.41 9.56 298.36 4.45 I 704.13 1703.59 7.67 283.87 5.45 -11.89 13.08 294.63 5.03 734.61 733.74 9.27 281.86 6.44 -16.27 17.50 291.59 5.25 765.70 764.35 10.85 280.37 7.49 -21.59 22.85 289.13 5.08 I 799.00 796.96 12.47 278.90 8.61 -28.23 29.51 286.96 4.86 829.16 826.32 14.05 274.67 9.41 -35.10 36.34 285.01 5.24 861.64 857.70 15.88 273.23 9.98 -43.46 44.59 282.93 5.63 892.32 887.10 17.28 273.95 10.53 -52.20 53.25 281.40 4.56 I 955.56 917.77 18.97 271.42 10.99 -62.23 63.19 280.02 5.24 946.94 20.20 270.75 11.18 - 72.61 73.47 278.75 3.97 988.47 977.71 21.38 272.32 11.50 -84.28 85.06 277.77 3.59 1019.27 1006.26 22.71 270.84 11.82 -95.84 96.57 277.03 4.32 I - 1050.65 1035.06 24.09 269.55 11.85 - 108.30 108.95 276.24 4.40 1083.37 1064.77 25.40 268.59 11.63 - 121.99 122.54 275.45 4.00 1114.16 1092.43 26.73 268.52 11.29 - 135.51 135.98 274.76 4.32 1144.99 1119.81 28.03 268.08 10.87 - 149.69 150.08 274.15 4.22 I 1177.66 1148.43 29.58 269.25 10.50 - 165.42 165.75 273.63 4.74 1209.28 1175.75 30.92 268.57 10.20 , - 181.35 181.64 273.22 4.24 1240.43 1202.32 31.97 269.54 9.93 - 197.60 197.85 272.88 3.37 ■ I 1272.22 1229.08 33.37 1300.45 1252.54 34.26 268.87 9.69 - 214.75 214.97 272.58 4.40 268.96 9.40 - 230.46 230.65 272.34 3.15 1331.32 1277.85 35.60 268.34 8.98 - 248.13 248.29 272.07 4.34 1351.60 1294.23 36.57 267.88 1 8.58 - 260.07 260.21 271.89 4/8 I 1487.69 1398.12 43.82 1519.88 1421.02 45.46 266.83 4.47 266.19 - 347.74 347.77 270.74 5.33 - 3.09 370.32 370.33 270.48 5.09 1614.41 1484.67 49.87 263.99 -2.93 - 439.91 439.92 269.62 4.67 1709.00 1542.55 54.67 261.55 -12.39 - 514.09 514.24 268.62 5.07 I 5 1805.57 1595.51 58.80 259.27 -25.88 - 593.67 594.23 267.50 4.28 ~ 1899.30 1641.17 62.89 257.22 -42.58 - 673.78 675.12 266.38 4.36 1992.66 1680.91 66.71 255.20 -62.73 - 755.80 758.40 265.26 4.09 I 2088.90 1715.73 70.88 2122.71 1726.34 72.54 251.69 -88.32 - 841.75 846.37 264.01 4.33 250.43 , -98.75 - 872.12 877.69 263.54 4.91 2206.14 1748.72 76.33 247.36 - 127.69 - 947.06 955.63 262.32 4.54 2301.85 1769.85 78.17 248.44 - 162.81 � - 1033.55 10 261.05 1.92 I 2396.99 1789.68 77.77 2491.42 1810.08 77.27 248.20 - 197.18 - 1120.02 1137.24 260.02 0.42 247.91 - 231.64 - 1205.54 1227.59 259.12 0.53 2585.96 1830.75 77.48 248.37 - 265.99 - 1291.16 1318.27 258.36 0.22 2680.87 1851.61 77.12 248.23 - 300.22 - 1377.18 1409.52 257.70 0.38 I 2774.73 1872.81 76.77 248.47 - 333.96 - 1462.17 1499.82 257.13 0.37 2869.26 1894.45 76.77 248.74 - 367.53 - 1547.85 1590.89 256.64 0.00 2964.99 1916.19 76.97 248.56 - 401.47 - 1634.68 1683.26 256.20 0.21 I 3060.63 1937.18 77.68 3155.40 1957.04 78.12 248.55 - 435.58 - 1721.53 1775.78 255.80 0.74 248.78 - 469.29 - 1807.84 1867.76 255.45 0.46 3247.85 1976.08 78.12 247.85 - 502.72 - 1891.91 1957.56 255.12 0.00 M -20 13 Schlumberger Inclinometry Tables 2051.12 254.78 0.16 I 3344.24 1996.04 77.97 ' 247.74 - 538.36 - 1979.21 3438.88 2015.82 77.91 247.74 ', - 573.42 - 2064.87 + 2143.01 254.48 0.06 3531.17 2035.15 77.91 246.81 - 608.28 - 2148.10 2232.56 1 254.19 0.00 3627.35 2055.37 77.82 1246.74 - 645.36 - 2234.51 2325.84 253.89 0.09 3721.63 2075.51 77.50 245.72 - 682.48 - 2318.80 2417.15 253.60 0.34 3817.73 2096.79 76.92 243.37 - 722.76 - 2403.41 2509.73 253.26 0.60 3912.23 2119.15 75.71 241.82 - 765.01 -2484.92 2600.01 252.89 1.28 4002.14 2141.96 74.91 238.08 - 808.55 - 2560.19 ' 2684.83 252.47 0.89 4102.15 2169.23 73.46 233.41 - 862.68 - 2639.71 2777.10 251.90 1.45 4196.75 2198.41 70.63 227.80 - 919.74 - 2709.23 - 2861.09 251.25 2.99 4290.89 2231.48 68.26 I 222.02 -982.10 - 2771.45 2940.32 1 250.49 2.52 4323.57 2243.74 67.70 220.61 1 -1004.86 -2791.45 2966.81 250.20 1.71 4385.58 2268.00 66.24 218.03 - 1049.00 - 2827.61 3015.92 249.65 2.35 4481.08 2308.48 63.60 214.77 - 1118.58 - 2878.95 3088.62 1248.77 2.76 4577.01 2353.53 I 60.39 211.12 - 1189.61 - 2925.03 3157.68 1247.87 3.35 I 4671.91 12402.38 57.65 210.01 - 1259.65 - 2966.41 3222.78 246.99 2.89 14766.71 1 2454.71 55.33 208.94 - 1328.45 - 3005.30 3285.82 246.15 I 2.45 4860.70 2508.89 54.28 205.82 - 1396.64 - 3040.63 3346.05 i 245.33 1.12 4956.52 , 2564.42 54.91 1 201.56 - 1468.13 - 3071.99 3404.78 1 244.46 0.66 5052.48 2619.90 54.48 197.56 - 1541.90 - 3098.21 3460.69 243.54 0.45 5147.20 2675.17 5 193.24 - 1616.04 - 3118.6 3 242.61 0.35 5240.81 2730.21 53.86 1187.88 - 1690.45 - 3132.51 3559.53 241.65 0.31 I 5335.15 2785.96 53.73 182.98 - 1766.19 -3139.71 3602.39 240.64 0.14 5430.34 2842.39 53.58 178.93 - 1842.82 - 3140.99 3641.68 x 239.60 0.16 5524.50 2897.87 54.25 173.97 - 1918.73 - 3136.27 3676.64 1 2 3 8.54 0.71 5620.69 2953.98 54.40 170.21 - 1996.10 - 3125.52 3708.54 237.44 0.16 5712.97 3007.48 54.73 169.06 - 2070.06 - 3111.99 3737.60 236.37 0.36 5811.78 3064.32 55.04 168.85 - 2149.39 - 3096.50 3769.38 235.23 0.31 5906.85 3119.50 53.99 168.69 - 2225.32 T - 3081.43 3800.96 1 234.16 1.10 6001.33 3174.89 54.23 ; 168.87 -2300.40 - 3066.54 3833.47 233.12 0.25 6098.79 3232.22 53.71 170.05 - 2377.88 - 3052.12 3869.08 232.08 0.53 6194.70 3289.21 53.37 171.14 - 2453.98 - 3039.51 3906.49 231.08 0.35 6287.87 3344.52 53.80 170.77 - 2528.02 - 3027.72 3944.36 230.14 0.46 I 6383.37 3400.87 53.89 170.27 - 2604.08 - 3015.02 3983.91 229.18 0.09 6478.20 3456.68 54.00 1 169.82 - 2679.59 - 3001.77 ' 4023.78 228.25 0.12 6572.77 3512.28 53.98 169.43 - 2754.84 - 2987.99 4064.14 227.32 0.02 6762.43 3623.19 54.61 ; 168.61 - 2905.94 �297371 4105.67 226.41 0.16 � �I - 2959.03 4147.33 225.52 0.51 I 6668.28 3568.34 54.13 169.28 -2830.83 -2973.71 6858.64 3679.11 54.32 169.80 -2982.84 -2944.37 4191.26 224.63 0.30 6951.23 3733.23 1 54.14 170.49 - 3056.85 - 2931.51 4235.34 223.80 0.19 - - 7046.85 3789.07 54.40 ' 170.18 - 3133.37 - 2918.48 4282.00 222.97 0.27 7144.68 3845.85 54.64 170.45 - 3211.90 - 2905.08 4330.80 222.13 ' 0.25 7239.80 3900.66 54.99 170.03 - 3288.52 - 2891.90 4379.21 221.33 0.37 7331.69 3953.42 54.93 170.39 - 3362.66 - 2879.10 4426.82 220.57 0.07 7425.99 4007.79 54.66 169.66 -3438.54 - 2865.76 4476.17 219.81 0.29 , 7522.99 4064.13 54.32 169.18 - 3516.16 - 2851.26 4526.93 219.04 0.35 7617.57 4119.34 54.25 168.42 I - 3591.49 - 2836.35 I 4576.43 218.30 0.07 7712.51 4175.50 53.23 166.57 - 3666.22 I -2819.78 I 4625.18 217.56 1.07 I 7805.48 4231.85 52.15 164.36 - 3737.80 ' - 2801.23 4670.98 216.85 1.16 7901.68 4291.68 50.94 162.45 - 3809.99 - 2779.73 4716.24 216.11 1.26 7988.29 4346.80 50.02 160.21 - 3873.28 - 2758.35 14755.08 215.46 1.06 8082.55 4407.18 50.31 160.41 - 3941.43 - 2733.97 4796.82 214.75 0.31 I 8175.70 4467.03 49.73 159.86 - 4008.56 - 2709.71 4838.50 214.06 0.62 8270.10 4528.23 49.44 159.96 - 4076.06 - 2685.03 14880.95 213.37 0.31 8363.91 4590.95 46.64 159.82 - 4141.56 - 2661.05 4922.77 212.72 2.98 8459.78 4659.38 42.24 ' 159.62 - 4204.51 -2637.79 4963.45 212.10 4.59 8553.24 4730.86 37.95 159.67 -4260.93 - 2616.86 5000.35 211.56 4.59 8646.45 4806.66 33.19 156.81 - 4311.29 i - 2596.84 5032.97 211.06 5.11 8743.84 4888.93 31.56 151.12 - 4358.12 I - 2574.03 5061.51 210.57 1.67 1 8838.52 4969.04 32.90 144.41 - 4400.74 - 2547.08 5084.70 210.06 1.42 8933.08 5048.11 , 33.64 142.03 - 4442.28 , - 2516.02 5105.31 209.53 0.78 M -20 14 I Schlumberger Inclinometry Tables 9027.96 5126.56 34.80 9123.66 5205.21 34.66 140.96 - 4484.03 - 2482.80 5125.51 208.97 1.22 142.23 - 4526.75 - 2448.93 5146.72 208.41 0.15 9218.56 5283.00 35.25 145.29 - 4570.60 - 2416.80 5170.23 207.87 0.62 ' 9313.24 5360.39 1 35.12 _ 9408.00 5437.90 35.12 148.13 - 4616.19 X2386.87 5196.76 207.34 0.14 150.17 - 4662.98 - 2358.91 I 5225.69 206.83 0.00 9503.51 5516.01 35.15 152.82 - 4711.28 - 2332.69 5257.15 206.34 0.03 9598.35 5593.67 34.91 I 153.81 - 4759.91 - 2308.24 5290.06 205 .87 0.25 I 151.72 -4857.31 9692.8 5748.43 35.39 -2283.85 5323.36 205.41 0.52 9692.85 5670.93 35.40 152.94 - 4808.55 83.85 - - 2258.29 5356.62 204.93 0.01 9882.96 15825.98 35.24 1 152.03 - 4905.77 - 2232.38 5389.81 1 204.47 0.16 ' 9977.63 5903.21 35.44 10073.03 5980.86 35.59 153.76 - 4954.51 - 2207.44 5424.02 204.01 0.21 154.71 - 5004.42 - 2183.35 5459.97 203.57 0.16 10167.35 6057.63 35.45 155.19 - 5054.07 - 2160.15 5496.35 203.14 0.15 10262.15 6134.80 35.58 156.08 - 5104.23 - 2137.43 5533.69 202.72 0.14 10357.09 6211.96 35.68 10435.99 6276.49 34.59 156.98 - 5154.96 - 2115.40 5572.12 202.31 0.11 - -- ---- - -- -- 156.30 - 5196.65 - 2097.40 5603.95 201.98 1.38 10500.00 6329.18 134.59 156.30 - 5229.92 - 2082.80 5629.40 201.71 r0.00 1 I 1 1 1 1 M -20 15 Schlumberger Well Path Plots 1 Ma • View 5629.40 North - ' South (FT) - 5629.40 - 5629.40 West - East (FT) 5629.40 Cross Section View 347.15 TVD (FT) 1 6329.18 , - 5629.40 Departure (FT) Plane = 201.7 - 21.7DEG) 5629.40 M -20 16 I I Schlumberger Pressure Depth Plot I FORMATION (AQAP psis) MUD BEFORE (AQAP psia) 1:1652 FT DRAWDOWN MOBILITY ROBE (g /c3) (AQAP and /cp) 250 500 <1 TVD MD 0 1.65 2.65 P 2500 3500 0.1 1000 TNPH (pu) - MUD AFTER (AQAP psia) 60 0 1 4 8 I> 1 4 ..8 Gas TIME VS DEPTH 2500 3500 A34H_UNC (ohmm) I 17- Nov -2009 00:00:01 18- Nov -2009 12:00:00 GRMA (gapi) 0.1 1000 0 150 P34H_UNC (ohmm) 0.1 1000 1 8951 111 __ • <1 , ' r -Al 5100 9001 9051 I 5150 -I�I Ill lilt 9101 I 5200 MPS e�s�mme- 9150- — = ■E ! I �� 5250 9200 " —_� C' ''ii 1 I tIll HI! _ 5300 2 _1 I 9 50- ��EE3 5 350 9301 I _ ■ ■ ■� U... _____N I �� 5400 9350- 11 IMII-11111-31 a��= �s= 9400 II 5450 � �� 9450 ■II- 4 Ilii11111131111111- W I 111111 5500 - -- 9500- ' � - 5550 9551 L I ' II s E _ - �w 5600 9601 I L u � ill l o- 10.405 a � I alismorl - 9 E 9700- 9750- �a.rPi 5 700 ®__�' { �. ��M� I II- — 5750 9800- I ' 5800 9851 __ m ,- ° . omma ' 5850 9900 ! U l il ______All I 9950- 1 •• • - 5900 1 �•�.. E 10000- I �� =I F �lt I IN � 595010050- J 600010101 ; —r�— 605010150- < dl1 � _ �1� = D1 , Islip _a� 10201 ire►- __�� I 3 SM • 3 6100 ��n,.�_o._ ." • �Ci. -. 10250- ‚II 1 . 1 ��r • 4 - 1 X150 4 L ■ ■ ®; � 10300 i EM �` I � 6200 'i 1 0350- >,� N - i ___ ■a - 1QAQQ,_ - ' M -20 17 Schlumberger Pressure Depth Plot FORMATION (AQAP psia) MUD BEFORE (AQAP psia) 1:317 FT DRAW DOWN MOBILITY ROBB (g /c3) (AQAP and /cp) 250 500 Q TVD MD 0 1.65 2.65 2500 3500 0.1 1000 TNPH (pu) MUD AFTER (AQAP psia) 60 0 1 4 8 1 4 On TIME VS DEPTH 2500 3500 A34H_UNC (ohmm) I 17-Nov-2009 00:00:01 18-Nov-2009 12:00:00 GRMA(gapi) 0.1 1000 0 150 P34H_UNC (ohmm) - 0.1 1000 Po i II 5050 — I 8950- Illr • 11 _ III r D•S .Ail • • 5100 9000- 1 1 I a 2a t s-- 4l . F ■ FINN /I , IN 9050- I ' 1 5150 WI' 9100- pr 5200 I "' , ' iii i 9150- ' Ira i ...... t , ..• /■ 5250 — I II 9200- In I M -20 18 I 1 Schlumberger Pressure Depth Plot I rr -- � FORMATION (AQAP psia) MUD BEFORE (AQAP psia) 1:317 FT DRAWDOWN MOBILITY ROBB (g /c3) 1 (AQAP and /cp) 250 500 [J TVD MD 0 1.65 2.65 I 2500 0.1 1000 TNPH (pu) MUD AFTER (AQAP psia) 3500 60 0 1 4 8 [] 1 4� Oas I TIME VS DEPTH 2500 3500 A34H_UNC (ohm) 17- Nov - 200900:00:01 18- Nov - 200912:00:00 GRMA (gapi) 0.1 1000 0 150 P34H_UNC (ohmm) 0.1 1000 <____ lir 11111111 10150 ,�' - 1111111it < ,r 6 050 Illr i ` I f1 1 I i I � I O H II I F C 10201 „ :■.,i 1 I'll it 1 1 1 11111 6100 ili 3 $ � 3 s. III — II 1025 Li 1111 0011 I s 6150 1 . 4 {} 4 1030' i J i 4 Al . ....1 I 6200 • 1 1035$ ! l 1 E IP $111 i .... 1oao, I"i `t i M -20 19 Schlumberger I Pressure Depth Plot 1:1625 FT TIME VS DEPTH r#QEASURED DEPTH (ft) FORMATION MUD BEFORE (AQAP psia) DRAW DOWN MOBILITY GRMA (gapi) �J (AQAP psia) TVD 17- Nov -2009 18 -Nov -2009 8000 12000 0 0 150 (MD) 00:00:01 11:59:00 250 500 2500 3500 0.1 1000 ROP5_RM ROBB (g /c3) 500 0 1.65 2.65 1 4 ...a 111 1 4 -8 TNPH (pu) A34H (ohmm) 60 0 0.1 1000 MUD AFTER (AQAP psia) P34H_UNC (ohmm) 0.1 1000 I 2500 3500 D6s IIIIII _ 5100 i� �� ma a�� ' (8995.8) f vi P ¶ • ® iP •'llllll 111111 11111111111111 I (9056.5) ®_ 'llllll 1 "� I �IIII'l �i l l , 5200 ' (9117.3) ( i® lull) l� I 5250 (9178.3) 1 p Ns I 5300 1 (9239 4) !� Ill I _M= C 5350 - - - -F- — — �F I (9300.5) 5400 -...ft � V III i v (9361.7) I )- i r 5450 — � = ili. _Ai 5500 ' + NI . / (9483.9) � -- — - 11 l ii i ' (9606.1) I —� m h 10.405 lb/gall 1 rig I f (9667.2) <il �` I 5700 i! ` hill r." II (9728.5) ¢ ,...rill I ' 5750 i ! � l il 5800 _ I� IIIE �r_ (9851.1) �� 5850 1 II Ii I (9912.4) i. ai� :— 5900 IIL (9973.7) �`� Ill li. ANN — ' 5950 - i I 11 (10035.1) - IT - - -- 1 — 1 Iil F r (1009 It wroLIMIIII 111 ' —1 6050 r i l (10158.0) la D16AS 6100 mil `� (10219.4 �� F D16CS ��:� �- 6150 I11I�11lllll112IF 1 (10280.9) ' i1iI M -20 20 I Schlumberger XY MUD Before vs MUD After 1 I 3380.00 t 0 1 ' Mud Pressure I After (psia) i 1 ' 0- 2 2760.00 ♦ 1 ' 2760.00 Mud Pressure Before (psia) 3380.00 I M -20 21 Pressure Vs Time Plot : Test #1 Run 5 9015.15 FT (MD) 5116.03 FT (TVD) Schlumberger M -20 Ihvestigatioh I Final 8 8 80 8 O M O O N 10 N ' LL a 0 m a 0 n .a co LL • ¢ O a Q U 0 Q wI - yai a 1- • CO w § w CC Ey N Ai _ , CL ■ K - ce w ill D a 1 m Se- e. I iLL1 w ef • a -' 0 F �0 Z j - 0 O a U , lli d' N < w O a w O F 4 Z O O 0 • 0 O 0- a O a LL LL LL V N / \ O O O N 00 0 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 2772.12 Ir li�� I , � � '111j1,, f " l III Mud Before Start Invest. No Seal 2770.12Packer Type TST675 Probe IIIIIIIPTIMPIRMINIRVIrlirlirrilr ri l+'j I t �� I ! � Gauge AQAP I �� ' �� 1111 Buildup Start Inv est Formation Pressure ps ia -' ail i ili VLI�1II1i111J111iiii �iiivii,LiIL..a, AiVlillitlill. dli� 11 JIiti ll hi II End Buildup Invest Last Read (Invest) 2767.59 psia .92768.12 Last Read (Final) 2769.12 psia w2766.12 ■ 11111111111111111ii Buildup St rttart Mud Pressure Before 692.225 2767.13 psia iiiimmiummilmi 2 I♦ End Buildup Mud Pressure After 2769.36 psia a Temperature Before /After 115.27 DEGF / 115.03 DEGF 2764.12 In Mud After Pretest Rate/Volume 1.04 c3 /s / 16.09 cc IIIIIII 60s Slope (Final) -.41 psia/m Pressure Variance (Final) 1.1 psia 2762.12 225.19 270.15 315.11 360.08 405.04 450 Time (sec) Quality: bad test,no seal 22 .... N m — — — MO MO — MO — — — NM — — ON MN • • I • MO MN MN MN 111.1 ININ MIN NM iliII Mlle • NM Pressure Vs Time Plot : Test #2 Run 5 9015.67 FT (MD) 5116.46 FT (TVD) Schlumber er M -20 9 i Investigation 1 I Final I o 0 0 o w o 0 0 @ LL w 0 a o gt a g LL Q a 0 U w Q Q J W w ■ 2 7 Q d J = W J r o> v - 7 a N Z 7 0 w a 0 Z N 0 0 a w 0 < Z U 0 • Q .II • o a LL - • a • LL u re V V M 0 o m o i / 100 200 300 400 479.46 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 II Mud Before Test Type Type 2 - C Packer TST675 Probe 479.26 1 Drawdown Start Invest. Gauge AQAP rlll i hln i l '" t Buildup Start Invest Formation Pressure 479.24 psis il► � ui V V n479.06 End Buildup Invest Last Read (Invest) 479.17 psia Last Read (Final) 479.26 psia D rawdown Start V Drawdown Mobility (Invest) 157.564 md/cp y A Buildup Start Drawdown Mobility (Final) 197.575 md/cp gn478.86 2 End Buildup Mud Pressure Before 2789.94 psia a Mud Pressure After 2789.83 psia 478.66 • Mud After Temperature Before /After 113.56 DEGF / 113.52 DEGF Pretest RateNolume 0.99 c3 /s / 7.15 cc 478.46 60s Slope (Final) 0.02 psia /m 245 275 305 335 365 395 Pressure Variance (Final) 0.05 psia Time (sec) Quality: Good Test 23 Flow Regime Identification Plot : Test #2 Run 5 9015.67 FT (MD) 5116.46 FT (TVD) (Final) Schlumberger ,e +o M -20 Spherical Time Function Plot : �_■ ■■ 490 ■ Sph erical Derivative - . ■ O Radial Derivative =MM. - ■��■■ =■■■p =MOM =MO __M■■■ ; ■•1 0 u'l 480 / ' - c - ii V �� hi .r 1 ill 1111 111 Q 1e +0- .1111 ■■uuI MIIIIIIIIM•■i■ui1MIIIIM=••u■uiI =M■■■ 2 111111111111111111 ( co 2> CL 1 e + ..i...■iiiii..■■iiiii..■■ r ■M=MIN Is .�� ∎M=M11•..• ∎ ∎�1M■■��E ∎��■■M•11 454 n c0 3.6 2.000 0 .c �„ Spherical Time, 1 /sqrt(sec) ❑ Last Buildup Pressure : 479.26 psia y �' Extrapolated Pressure : 479.21 psia ��11��'I� Buildup Mobility 47.23 md/cp 1e +r r ■ ■1!liil I ! . ' .. ' . ■1Spherical SIOPe -116 ■■■■I ∎ ∎ ■■■MI___ ■■ ■■ ■I ■iu ..■■■u Radial Time Function Piot ( IIIIilll i11 ■■ ■u11 600 ■■ ■1 f . 1111111 ■■IIIIP ■ 1e0 ■11 I ■••• ii r1 ______. __...• _____...• t_ ■_ ►..rtl�t�M ■ ■ ■N - ta■ ■MEN ∎ ∎ ∎ ■ ■.IN.I (D ■IIII.■■..I•1•111111■■•11= ■i1111 ■■ ■ii1111 M.■ ■■■nom =.1111■■ _ IM.. ■■■■I ■MIN■■■■■ Q co u) CL li 1e -0 1e 00 1e 01 1e+02 _� �`��' + + Delta -Time (sec) Slope on Spherical 0.006 O Slope on Radial -0.410 Slope on Spherical 0.416 Slope on Radial -0.020 440 2.12 0 Radial Time Last Buildup Pressure : 479.26 psia Extrapolated Pressure : 479.24 psia Horiz. Mobility Thickness : 177.454 md.FT /Cp Radial Slope : -.49 24 ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ NM MN r M 111111 NM MS MI 111. 111116 1111. 11.11 1111= Pressure Vs Time Plot : Test #2 Run 5 9015.67 FT (MD) 5116.46 FT (TVD) Schlumberger M -20 • o O LL C7 W N d < a - o a < N w w W 2 a Cr 2 a - W - o r < r- 0 CO < I-- < 0 a o < a 3 a � LL a LL NJ O M V 250 260 270 Time (sec) Tool Type FPWD675 ▪ Mud Before Test Type Type 2 - C Packer 5 Probe V Drawdown Start Invest. Gauge AQAP A Buildup Start Invest Formation Pressure 479.24 psia III End Buildup Invest Last Read (Invest) 479.17 psia Drawdown Start Last Read (Final) 479.26 psia Drawdown Mobility (Invest) 157.564 md/cp 0 Buildup Start Drawdown Mobility (Final) 197.575 md/cp • End Buildup Mud Pressure Before 2786.77 psia Mud Pressure After 2786.65 psia Mud After Temperature Before /After 113.56 DEGF / 113.52 DEGF Pretest RateNolume 0.99 c3 /s / 7.15 cc 60s Slope (Final) 0.02 psia /m Pressure Variance (Final) 0.05 psia Quality: Good Test 25 Pressure Vs Time Plot : Test #3 Run 5 10221.52 FT (MD) 6101.76 FT (TVD) Schlumber er M -20 Irivestigatici Final I 0 0 0 o o o o - o I N t a W m O m ,■r b ■ O < ° a W a J W N D K I W - 7 , ' C ' 2 2 UJ w - w w 0 • J LL 0 ii - 7 W J > 0 - 7 r 0 j i to z CL o 0 J a 3 z 3 LL Z LL Q LL O N O O <1 O 100 200 300 400 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 462.88 T est Type Type Before YP YP e 2- C Packer TST675 Probe 462.68 Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 463.12 psia : n462.48 II End Buildup Invest Last Read (Invest) 462.18 psia Last Read (Final) 462.68 psia D rawdown Start V Drawdown Mobility (Invest) 21.661 md/cp 2462.28 A Buildup Start Drawdown Mobility (Final) 11.724 md/cp 2 End Buildup Mud Pressure Before 3274.84 psia d Mud Pressure After 3278.15 psia 462.08 1 • Mud After Temperature Before /After 129.49 DEGF / 129.54 DEGF Pretest RateNolume 0.99 c3 /s / 14.31 cc 461.88 ' L I . 60s Slope (Final) 0.58 psia /m 310 330 350 370 390 410 Pressure Variance (Final) 0.04 psis Time (sec) Quality: Good Test 26 NM 10111 11.1 OM IMIn 1111. OM IIIIIII IIIII • 1.0 MIN MI NM • IIMI OM OM OM IIIII .I... r imlimimlimlimimllmimIMIMIMIMMMMIIIIIIIIIIIIIIIIIIIIIIIMIIIIIIIIIIIMII.MIMIMII.IMIMIMIIIII.M.M IIIIIII MO NM • • NM On MN • MI INN NE 111111 IIIIII MI MO NW 1111. Flow Regime Identification Plot : Test #3 Run 5 10221.52 FT (MD) 6101.76 FT (TVD) (Final) Schlumberger 1e +044._ 600 M -20 Spherical Time Function Plot : - - 0 - Spherical Derivative - - _ O Radial Derivative - _ - - -- i r— to 1 e+0;... ..:., . CD Nom immimmimmomom . /// LP 03 1111111 __1 EL' :11111 MI II \ t� ∎;;, d: . ( D400 M Lr. co al rn IN 1e +01 0_ 1e +00 1e +01 le +02 Delta -Time (sec) Slope on Spherical -0.010 r Slope on Radial -0.456 w NI N H ti ti 191 /'1 3.7 2.000 0 Spherical Time, 1 /sgrt(sec) Last Buildup Pressure : 462.68 psia Extrapolated Pressure : 463.12 psia Buildup Mobility : 0.93 and /cp Spherical Slope : -420.09 27 Pressure Vs Time Plot : Test #3 Run 5 10221.52 FT (MD) 6101.76 FT (TVD) Schlumberger M -20 Q o Q N � N nI g N LL i TO w p d n U j < d re Q re w ~ a w q ij i . a w w A N N N � O Q (h Q 160 170 180 190 200 210 220 230 240 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 463.12 psia ▪ End Buildup Invest Last Read (Invest) 462.18 psia Last Read (Final) 462.68 psia Drawdown Start 0 Drawdown Mobility (Invest) 21.661 md/cp 0 Buildup Start Drawdown Mobility (Final) 11.724 md/cp End Buildup Mud Pressure Before 3274.84 psia Mud Pressure After 3278.15 psia Mud After Temperature Before /After 129.49 DEGF / 129.54 DEGF Pretest Rate/Volume 0.99 c3 /s / 14.31 cc 60s Slope (Final) 0.58 psia /m Pressure Variance (Final) 0.04 psia Quality: Good Test 28 IIIIIIII • • • N • IIIIIII • • • • • • NM NM MO NM — EN NM — NM MI NM IIIN — N I• II 1111111 MI Pressure Vs Time Plot : Test #4 Run 5 10286.55 FT (MD) 6154.64 FT (TVD) Schlumber er M -20 9 I Investigation i i Final I 0 0 0 0 0 0 ,n o o o o N In N m LL i a. n W m a 4 0 a M�.�— • N a; '� a o ( 9 w w Q 4 / J g 0 w 1 • N w > w D CC I 1 �' rf § v rn i i w a . w w 2 _1 a n: 4 a t 1- 4 4 4 12 r" 1 - Z U 8 w 1 F 4 0 H a cn ( 0 o ..J 71 4 z' 3 O a /' Z 9 a 4 ',i LL LL El% 0 0 0 _1 0 _ ___, I( 0 100 200 300 400 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 342.52 Mud Before Test Type Type 2 - C IIII Packer TST675 Probe Drawdown Start Invest. Gauge AQAP 342.32 , ��t�� )pl,r�rp�n Buildup Start Invest Formation Pressure 342.33 psis m v' Il llil llv .ill llulhil ilrliilll . End Buildup Invest Last Read (Invest) 342.33 psia 8342.12 ., � .111111" ,I, Last Read (Final) 342.32 psia ; L � Drawdown Start Drawdown Mobility (Invest) 55.509 md/cp a 341.92 I Buildup Start Drawdown Mobility (Final) 56.01 md/cp ;12 r - EL I, End Buildu Mud Pressure Before 3364.22 psia Mud Pressure After 3364.92 psia 341.72 - Mud After Temperature Before /After 131.43 DEGF / 131.34 DEGF Pretest RateNolume 0.99 c3 /s / 6.98 cc 341.52 60s Slope (Final) 0.09 psia /m 290 313 336 359 382 405 Pressure Variance (Final) 0.06 psia Time (sec) Quality: Good Test 29 Flow Regime Identification Plot : Test #4 Run 5 10286.55 FT (MD) 6154.64 FT (TVD) (Final) Schlumberger ,e +0z M-20 - Radial Time Function Plot LL E , 1 �.. �_ . f 400 si Spherical Derivative 0 Radial Derivative _ _.� 1II , 1e +02 I . 1 - l i cu r, 1 0 1e +01 • , '� Ea 12 d V7 CL 11 ,.- 300 _ 111 v 1e +OC . _. 4 - - d ,, 0 1e -01 1e +00 1e +01 1e+02 Delta -Time (sec) Slope on Spherical 0.470 Slope on Radial 0.027 200 2.12 0 Radial Time Last Buildup Pressure : 342.32 psia Extrapolated Pressure : 342.33 psia Horiz. Mobility Thickness :22.111 md.FT /Cp Radial Slope : -3.94 30 m MN — — — — r — — • — • • • — ON MI — MI — MO I_ II• ON I_ NM I— MB I— I— (— Pressure Vs Time Plot : Test #4 Run 5 10286.55 FT (MD) 6154.64 FT (TVD) Sehiumberger M -20 I o o 0 N Y,) N Q Q Q N LL a w m ❑ - n R < 0 o U w Q Q J LL W LL V--- a w , N 2 a a CC i r ❑ a 2 a o a a I- w z r a 1- goo a to o 0 3 U ❑ J 0 C, Z ❑ a Z 3 LL Z Q LL O M C.? cn 0 Z m 290 300 310 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 342.33 psia • End Buildup Invest Last Read (Invest) 342.33 psia Last Read (Final) 342.32 psia V Drawdown Start Drawdown Mobility (Invest) 55.509 md/cp A Buildup Start Drawdown Mobility (Final) 56.01 md/cp II End Buildup Mud Pressure Before 3364.33 psia Mud Pressure After 3364.92 psia In Mud After Temperature Before /After 131.43 DEGF / 131.34 DEGF Pretest RateNolume 0.99 c3 /s / 6.98 cc 60s Slope (Final) 0.09 psia /m Pressure Variance (Final) 0.06 psia Quality: Good Test 31 I I StethoScope* 675 DRILLING & MEASUREMENTS Formation Pressure I StethoScope*, 6 -3/4 IN. OD Mechanical Specifications I StethoScope* 675 GENERAL DRILL CO NOMINAL OD 6-3/4" API Tolerances r MAXIM DIAMETER 8 -' /a" (9-Ys" optional) I MAKE UP LENGTH 31.0 ft (w /o saver subs) TOTAL TOOL WEIGHT 2,800 lbs I 6.906 TOP THREAD CONNECTION 5 1/2 FH Box (6.906" OD) I BOTTOM THREAD CONNECTION 5-1/2 FH Box (6.906" OD) MAX OPERATING TEMPERATURE 300 °F / 150 °C I 6250 - BENDING MAX TOOL CURVATURE Rotating: 8 deg /100 ft I (higher dogleg rates are possible provided RPM is controlled 221.3 below 60 RPM, contact your service representative) Sliding: 16 deg /100 ft I 150.0 1 MAX SHOCK COUNTS 30 min at shock level 3 (509 294.2 MAX CUMULATIVE SHOCK DURATION 200,000 shocks above 50g, I 372.0 AXIAL MAXIMUM JARRING LOAD 330,000 lbs MAXIMUM WEIGHT ON BIT 74,000,000 / L lbf I a (L= distance between stabilizers in ft) Wear band 1 6.906 HYDRAULICS MAX OPERATING PRESSURE 25,000 psi (27,000 psi on request) 6.250 30 0 MAX DIFFERENTIAL PRESSURE (IP / AP) 6,000 psi FLOW RANGE 0 — 800 gpm (1000 gpm Optional) I 8.25in MAXIMUM SAND CONTENT 2% Stabilizer OD = LCM tolerance No limit ,1 PRESSURE DROP 58,620 I r Press.Drop (psi) = Mud Weight (ppg) x Flowrate 2 (gpmI 2 /C 6.906 4, TORQUE MAXIMUM ROTARY 12,000 ft Ibf MAXIMUM TORQUE 40,000 ft-Ibf CONNECTION MAKE -UP TORQUE 5 -1/2 FH Pin - 22,000 ft-lbf (+/- 1,000 ft -lb) I 6 -3/4 IN. OD I An asterisk (*) is used to denote a mark of Schlumberger Schlumberger I I 1 1 StethoScope* 675 DRILLING & MEASUREMENTS Formation Pressure 1 StethoScope *, 6 -3/4 IN. OD Measurement Specifications StethoScope* 675 GENERAL I — TYPE Probe / Pretest GAUGES Advanced CQG - High Precision Crystal (primary) Strain gauge (secondary) I POWER SUPPLY Batteries MWD Turbine Power TOOL ACTIVATION PROTOCOL Downlink (Mud flow) ` PROBE 1 2.25 in. OD x 0.56 in. ID x 3A in. stroke 1 DIAMETER REACH 10 -1z" max(11 -%z "max with 9 -1a" Stabilizer) CONTACT FORCE 2,500 Ibs max PRETEST 1 VOLUME 0 to 25 cc fully adjustable DRAWDOWN RATE 0.1 to 2.0 cc /s 1 DELTA PRESSURE 6,000 psi max ROP + RANGE 0 to 20,000 psi with ACQG (25,000 psi optional) 1 ACCURACY (psi) ± [2.2 + 0.01 % of reading] RESOLUTION MEMORY 0.01 psi resolution at 1 s sample rate RESOLUTION REAL -TIME 0.1 psi 1 REPEATABILITY 0.1 psi following a 5,000 psi negative step MEMORY ACQUISITION RATE 16 Hz MEMORY CAPACITY 50 pretests of 5 mins. duration ' r BATTERY CAPACITY 150 pretests —1 cc /s Q 3200 psi & 125 °C Probe Setting piston C t 1 APWD measurement capability RANGE 0 to 25,000 psi ACCURACY (Between tests) ± [2.2psi + 0.01% of reading] - ACQG 1 ACCURACY (During Pretest) ± 0.1 % of full scale - Strain Gauge Downhole 1 6 -3/4 IN. OD 1 An asterisk (l is used to denote a mark of Schlumberger Schlumberger 1 1 DISCLAIMER THE USE OF AND RELIANCE UPON THIS RECORDED -DATA BY THE HEREIN NAMED ' COMPANY (AND ANY OF ITS AFFILIATES, PARTNERS, REPRESENTATIVES, AGENTS, CONSULTANTS AND EMPLOYEES) IS SUBJECT TO THE TERMS AND CONDITIONS AGREED UPON BETWEEN SCHLUMBERGER AND THE COMPANY, INCLUDING: (A) RESTRICTIONS ' ON USE OF THE RECORDED -DATA; (B) DISCLAIMERS AND WAIVERS OF WARRANTIES AND REPRESENTATIONS REGARDING COMPANY'S USE OF AND RELIANCE UPON THE RECORDED -DATA; AND (C) CUSTOMER'S FULL AND SOLE RESPONSIBILITY FOR ANY INFERENCE DRAWN OR DECISION MADE IN CONNECTION WITH THE USE OF THIS RECORDED -DATA. 1 I I 1 110 'Chevron Union Oil Company of California M -20 TRADING BAY UNIT Section 33 - T9N - R13W, SM Cook Inlet, Alaska • October 17, 2009 to November 18, 2009 FINAL WELL REPORT Lees F. Browne Jr. - Sr. Logging Geologist Peter Dykema - Logging Geologist Craig Silva - Sr. Logging Geologist Joshua Dubowski - Logging Geologist pt‘NR19 • ocp tcp-ic aoci Chevron • Chevron - Trading Bay Unit M -20 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW 3 1.1. EQUIPMENT SUMMARY 3 1.2. PERSONNEL 3 2. GENERAL WELL DETAILS 4 2.1. OBJECTIVES 4 2.2. WELL RESUME 4 2.3. HOLE DATA 4 3. GEOLOGICAL DATA 5 3.1. WELL LITHOLOGY 5 3.2. FORMATION / ZONE MARKER TOPS 20 3.3. ZONE SUMMARIES 25 3.4. SAMPLING PROGRAM AND DISTRIBUTION 58 4. DRILLING DATA 59 4.1. DAILY ACTIVITY SUMMARY 59 III 4.2. SURVEY DATA 67 4.3. MUD RECORD 73 4.4. DAYS VS. DEPTH 76 5. DAILY REPORTS 77 Enclosures 2 1100' Formation Log (MD/TVD) 2 1100' Drilling Dynamics Log (MD/TVD) 2 "/100' LWD Combo Lithology Log (MD/TVD) 2 "/100' Gas Ratio Log (M D/TVD) III 2 CANRIG 1 MUDLOGGING EQUIPMENT AND CREW 1.1. EQUIPMENT SU MMARY Parameter Equipment Type And Position Total Comments Downtime Electric Driven QGM Gas Trap Ditch Gas Mounted In Possum Belly; FID Total 2 5 Repair and replace Hydrocarbon Analyzer And QGM gas trap motor Chromatograph Rate of Penetration (ROP) Primary Drawworks Belt Driven 0 Encoder On Drum Shaft (Canrig) Pump stroke counter Externally Mounted Magnetic 0 Proximity Sensor (Canrig) Hookload / Weight on bit (WOB) Hydraulic Pressure Transducer 0 (Canrig) Drill string torque Varco Analog Feed 0 Top drive rotary (RPM) Varco Analog Feed 0 Standpipe Pressure Solid State Pressure Transducer 0 Casing Pressure Solid State Pressure Transducer 0 Mud flow in / out (MFI / MFO) MFI Derived From SPM / MFO From 0 Flow Paddle (Canrig) Pit volumes Radar Pit Probes 0 .111) Explosion Proof Touch Screen Driller's work station (Canrig) 0 Company man's work station Rigwatch (Canrig) 0 Toolpusher's work station Rigwatch (Canrig) 0 Geologist's work station Chevron 0 Pit's work station Rigwatch (Canrig) 0 1.2. PERSONNEL Unit Number: ML04 Mudloggers Years Days Technician Days Sample Catchers Days Lees F. Browne Jr. 29 28 Howard Lamp 3 James Foradas 23 Peter Dykema 6 24 Joshua Dubowski 23 Craig Silva 31 16 Jeff McBeth 10 Joshua Dubowski 1 3 Chevron 1111 111 0 Chevron - Trading Bay Unit M -20 • 2. GENERAL WELL DETAILS 2.1. OBJECTIVES Trading Bay Unit M -20 is a grassroots multi -zone Development Gas well from Chevron's Steelhead Platform. Production targets are the Grayling Gas Sands from the B -1 extending through the D -17, with the Primary objective being the C3 Sand. 2.2. WELL RESUME Operator: UNION / CHEVRON Well Name: Trading Bay Unit M -06 Field and Pool: Steelhead Platform Trading Bay Unit State: County Alaska Kenai Borough Company Representatives: Mike Leslie David Smith Roger Moore Lindsay Hubbard Location: SEC 33, T 9N, R13W, SM Elevation: — MSL RT: 160.2' MSL Classification: Development Gas API #: 50- 733 - 20587 -00 Permit #: 209 -0930 AFE #: UWADAK -D -9002 Rig Name / Type: Steelhead Rig #51 Primary Target: Depth: Tyonek C3 Sand Depth: 7630' MD, 4126.33' TVD Secondary Targets: Depths: Grayling Gas Sands: B -1 through D -17 Depths: Spud Date : -> Finish Date : -> 10/17/2009 to 11/18/2009 Total Depth: 10,500' MD (6329.18' TVD) Total Depth Formation: Tyonek Mudlogging Company EPOCH /CANRIG DRILLING TECHNOLOGIES MWD Company: SCHLUMBERGER Tools Run: MWD: Survey, Gyro (Surface), Gamma, Resis, Neu Por Bulk Den, Sigma Directional Drilling: SCHLUMBERGER Drilling Fluids Company: BAROID 2.3. HOLE DATA Maximum Depth Mud Deviation Deo iation Shoe Depth F.I.T. Hole T.D. Wei Section MD TVD Formation Weight (inc) Casing MD TVDSS 17.5" 1430' 1193.86' Sterling SZ9 9.5 40.75 13.375" 1425' 1191.24' 13.2 12.25" 8240' 4508' D1 9.3+ 49.73 9.625" 8222' 4496' 12.8 9.0" 10500' 6329.18' Tyonek 9.2+ 34.59 7" (Liner) 4 CANRIG Chevron Chevron - Trading Bay Unit M -20 3. GEOLOGICAL DATA 3.1. WELL LITHOLOGY Coal /Carbonaceous Shale (1315' to 1330) = interbedded, interlaminated low grade lignite, carbonaceous shale and "woody" organic material; black- brownish black to brown; note larger coal pieces have floating fragments of lower grade material. Tuffaceous Claystone/Tuffaceous Siltstone (1330' to 1430') = light brownish gray and various gray hues from light gray to medium gray with strong light brownish gray to pale brown secondary hues; most is hydrophilic, soft and clayey but continued minor fraction ranges from slightly brittle to marginally hard; clayey to silty to ashy to various matte textures; earthy lusters. Coal (1390' to 1405') = better developed than above; black, brittle, smooth to dense matte text; dull to sub vitreous luster; irregular to sub planar fracture; massive; visible alternating micro laminations of different coal grades. Sand (1400' to 1510') = medium light gray to medium gray with strong light olive gray secondary hues; rough salt and pepper appearance; fine lower to coarse upper; mostly medium; no dominant size fraction; subangular to subrounded; moderate developed sphericity; moderate sorting; submature; non to very weak siliceous cement; dominant grain support; composed of 85% quartz, 15% various lithic fragments; probable good porosity and permeability. Tuffaceous Siltstone (1490' to 1630') = very light gray to pinkish gray; poorly indurated; clustered to • clotted becoming mushy to pasty; slightly tacky to slimy; moderate hydrophilic; slightly cohesive; moderately adhesive; massive habit; earthy luster; silty to clayey texture; massive gradational beds of silt, clay and minor carbonaceous shale. Carbonaceous Shale (1570' to 1680') = dark brown to light brown to brownish black and various hues of all; brittle; resinous to earthy lusters; matte to smooth textures; platy to flaky habit; micro planar to planar fractures; thinly bedded; trace grading to Iignitic coal. Tuffaceous Claystone/Tuffaceous Siltstone (1630' to 1700') = light brownish gray and various gray hues from light gray to medium gray with strong light brownish gray to pale brown secondary hues; hydrophilic, soft and clayey; spotty to minor fraction of slightly to moderately brittle; clayey to silty to ashy to various matte textures; earthy lusters; displays localized carbonaceous laminations and particles. Sand /Sandstone/Tuffaceous Sandstone (1690' to 1880') = medium light gray to medium with gray with generally faint to locally strong light olive gray secondary hues; also locally common tuffaceous sandstone with higher lightness values to very light gray when ash content increases; dominant fine upper to medium upper, but overall range from very fine lower to granule (conglomerate); evident fining upward in more massive sections; consistent moderate sorting with gradually shifting dominant size mode; angular to sub angular, with consistent very minor fraction of sub rounded to rounded grains; mostly equant, sub spherical shape; pervasive tuffaceous clay (volcanic ash) matrix supported sandstone; inter -grain clays are variably soluble, and a major amount of the cuttings is disaggregated and loose; spotty sandstone is grain supported, and there is a trace of harder, firmer sandstone that displays some calcite cementation; clayey (ashy) sub lithic to lithic arenite; estimate 60 -80% quartz (plus minor percentage of volcanic glass), trace feldspar, 5 -15% chert, chalcedony and other minor crypto silica, 15- 25% lithics and mafic minerals; lithics dominated by low grade metamorphic greenstone and medium grade metamorphic medium gray to grayish black phyllite - argillite rock fragments; some discernible augite and biotite, but very abundant non - differentiated black, brownish black and other "blackish" mafic minerals; distinctive trace epidote. • 5 CANRIG Chevron hevron - Trading Bay Unit M -20 • Coal /Carbonaceous Shale (1875' to 1910') = mostly low to medium grade lignite, but some higher grade pieces to sub- bituminous; black to brownish black; adjacent carbonaceous shale is often dusky brown; associated carbonaceous claystone is pale brown; brittle and mostly fragile, but spotty tough fragments; smooth to dense matte textures; dull to sub vitreous luster; mostly irregular to sub planar to planar fracture; minor blocky sub conchoidal pieces. Sand / Sandstone/Tuffaceous Sandstone (1880' to 2110') = no significant change in characteristics; dominant primary color now light olive gray; localized zones transition to light medium and medium gray; overall size range fine lower to coarse upper; continued dominant fine upper to medium lower, but overall better sorting, with less discernible fining upward; same distribution of angular and rounded grains, but increasing grains have equant dimensions and overall better sphericity; supporting tuffaceous clay matrix is still derived from reworked volcanic ash but shards are becoming less prominent; more apparent devitrification of ashy sediment; estimate 65 -80% quartz and volcanic glass, trace feldspar, 5 -10% chalcedony, chert and other crypto silica, 15 -25% lithics and mafic minerals; continued sub lithic to lithic arenite; approximately 75 -80% of quartz is colorless to very pale gray, very pale brown or other colors and translucent, 20 -25% of quartz and nearly 100% of sand -sized grains of volcanic glass is colorless and transparent; 90% of the lithics fraction are greenstone or phyllite- argillite rock fragments and the remaining 10% are very diverse rock fragments from multiple sources; continued distinctive trace of epidote. Coal /Carbonaceous Shale /Carbonaceous Claystone (2110' to 2300') = low grade lignite and carbonaceous shale; trace higher grade lignite; visible interbedding with very abundant very carbonaceous dark brown tuffaceous claystone; note that the carbonaceous claystone ranges from somewhat silty, ashy and organic looking to a finer clay rich variation that has discernible fissility, a darker dusky brown color, a more organic overall appearance and is clearly gradational to the darker colored carbonaceous shale; both the coal and carbonaceous shale are interbedded with the dusky brown organic rich claystone; lignite coal: black to brownish black; brittle; planar fracture; thin platy to elongated irregular habit; mostly dense matte to clayey textures and earthy lusters. Tuffaceous Claystone/Tuffaceous Siltstone (2040' to 2400) = light brownish gray to pale brown with many close variations of gray and brown primary colors and secondary hues; also note abundant variation of brown to dusky brown carbonaceous tuffaceous mudstone that is adjacent and very thinly interbedded with carbonaceous shale and coal; mostly soft to very slightly firm and clayey, becoming slightly brittle as silt content increases; most is hydrophilic, easily hydrated and soluble; most cuttings appear as small sub spherical clumps; clayey to silty to ashy to various soft matte textures; earthy lusters; commonly has laminations, particles or dark patches of brown to brownish black organic /carbonaceous materials; also note some clumps have floating blebs of a lighter gray colored sandy siltstone to very fine ashy sandstone. Sand /Sandstone/Tuffaceous Sandstone (2110' to 2370') = significant matrix clay; very closely gradational to very sandy claystone; medium gray with light brownish gray to pale brown secondary hues; brownish colorations increase when adjacent to organic mudstones described above; very fine upper to medium upper; moderately sorted; angular to sub angular; very clayey sub lithic arenite to lithic arenite. Tuffaceous Siltstone (2380' to 2430') = very light gray to pinkish gray; very poor to poorly indurated; clustered to clotted; overall mushy to pasty; tacky to slimy; very slightly cohesive; moderately adhesive; amorphous to earthy fracture; massive habit; moderate earthy luster; silty to ashy texture; massive gradational beds of tuffaceous silt and clay with thin beds of very fine grained sand and flaky to thinly bedded carbonaceous shales. Sand (2440' to 2480') = medium light gray; clast size ranges from very fine upper to very fine lower grading to silt; sub rounded to rounded; well developed sphericity; poor sorting; sub mature nature; no visible cementation; unconsolidated; abundant hydrophilic silt/clay matrix; loosely attached; dominant 6 • CANRIG Chevron • C hevron - Trading Bay Unit M -20 matrix support; composed of > 85% quartz; poor porosity and permeability; sands becoming interbedded down section. Sand (2550' to 2630') = medium light gray; clast size ranges from fine upper to very fine upper; some grading to silt; sub angular to sub rounded; moderate developed sphericity; poor to moderate sorting; no abundant size factions; impacted to pitted textures; sub mature nature; non to very slight siliceous cement; disaggregated with local very weakly cemented consolidated sandstone; clay /silt hydrophilic matrix; both grain and matrix support; composed of > 80% quartz with various minor lithic fragments; sandstone appearing cleaner down section; note after 2600' that there is an increase in medium gains. Sand (2640' to 2670') = medium light gray; clast size ranges from medium upper to fine upper; distinct grain size change; sub rounded; moderate developed sphericity moderate sorting; sub mature; non to very weak siliceous cementation; slight hydrophilic clay /silt matrix loosely attached; dominant grain support with secondary local grain support in silt sections; composed of 85% quartz, 20% crypto silica (chert, chalcedony), meta lithics (greenstones, argillites), various other lithic rock fragments and mostly non differentiated mafic minerals; fair visible porosity and estimated permeability. Sand (2680' to 2760') = medium light gray; clast size ranges from medium upper to fine upper; becoming coarse lower to medium lower at 2760'; sub round to sub angular; moderate developed sphericity; moderate sorting; impacted to pitted textures; sub mature; non to very slightly siliceous cementation; disaggregated; slight hydrophilic clay /silt matrix; loosely attached; dominant grain support; composed of 90% quartz, 10% chert, argillite, greenstone, siliceous coal fragments and trace lithics; fair to good visible porosity and fair estimated permeability. Sand (2770' to 2830') = medium light gray to Tight gray; coarse lower to fine upper; dominantly medium; moderately sorted; sub rounded to sub angular; moderate developed sphericity; sub mature; non to very weak siliceous cementation; disaggregated; hydrophilic clay and ash matrix; note rare sandstone with remnant vitric tuff matrix; generally grain supported; composed of 90% quartz, 10% crypto silica (chert, chalcedony), meta lithics (greenstones, argillites), various other lithic rock fragments and mostly non - differentiated mafic minerals; fair to good visible porosity and probable fair to good permeability. Carbonaceous Shale /Carbonaceous Claystone /Coal (2840' to 2890') = composed of very carbonaceous shale and clay to lignitic coal; brownish gray to mottled brownish black; firm; earthy luster; some localized resinous luster; smooth texture; sub planar to sub blocky fracture habit; visible bleeding gas from coal fragments. tuffaceous siltstone (2900' to 2940') = pinkish gray to grayish orange pink; poor induration; clustered to clotted; mushy to pasty; some gelatinous; non to very weak cohesiveness; slight to moderate adhesive; amorphous fracture; massive to sub nodular habit; dull to moderate earthy luster; silty texture; composed of 40% silt, 40% clay, 20% very fine grain sand and various carbon and detrital material. Tuffaceous Siltstone (2950' to 3000') = light brownish gray to pinkish gray to grayish orange pink; poor induration; mushy to pasty; forms clustered and clotted blebs when hydrated; poor cohesiveness; poor to moderate adhesiveness; amorphous and massive, but also very common discernible thin interbedding; dull to moderately earthy luster; silty texture; mean composition of 40% silt, 40% clay, 20% very fine sand and spotty fractions of various carbonaceous material; note increasing amount of fine to medium floating sand grains down section. Sand (3010' to 3250') = medium light gray; medium upper to fine upper; sub rounded; moderately developed sphericity; moderate sorting with no predominant mean grain size; sub mature; disaggregated; slightly hydrophilic clay matrix; dominantly grain supported; composed of 90% quartz, 10% chert, argillite, greenstone and traces of other lithic rock fragments; fair to good visible porosity and estimated permeability. 7 CANRIG Chevron • hevron - Trading Bay Unit M -20 Sand (3250' to 3410') = medium light gray; coarse lower to fine upper range; dominantly medium; sub rounded; coarse grains decreasing with depth; moderately to poorly sorted; moderately developed sphericity; sub mature; non to very weak siliceous cementation; pervasive disaggregated grains, but note tight dense consolidated sandstone at 3280' to 3290' and some sparsely distributed weakly consolidated clusters; slightly hydrophilic clay matrix; dominantly grain supported; composed of 90% quartz, 10% chert, argillite, greenstone and traces of other lithic rock fragments; fair to good visible porosity and estimated permeability. Sand /Sandstone (3410' to 3800') = light olive gray to olive gray transitioning to medium light gray to medium gray with very olive gray secondary hue; greenish coloration derived from greenstone rock fragments; as both grain size and percentage of lithic fragments increase the sand has dark greenish pepper and salt appearance; evident massive repeat sections with discernible fining upward; moderate to moderately well sorted with transitioning mean size from fine lower to coarse lower; total range is very fine lower to very coarse lower; spotty very fine lower fraction nearly all glass shards winnowed from volcanic ash; trace very coarse grains often appear to be second mode; very angular to sub angular; despite the apparent sharpness of many grains, the dominant shape is equant and sub spherical; note consistent trace fraction of moderately well rounded grains. Sand /Sandstone (3410' to 3800') = very abundantly, pervasively disaggregated, but note sparsely distributed consolidated blebs of ashy - clayey sandstone with an easily separated, fragile and largely soluble matrix; note some very fragile sandstone with weak calcite cementation; fairly homogeneous lithic arenite composition overall, but the uppermost zones of each discreet sand section are repeatedly borderline sub lithic arenite and the basal zones often transition to compositional graywacke; estimate 50- 80% quartz (and volcanic glass), trace feldspar, 10 -20% various crypto silica (chalcedony, chert, agate) and other non differentiated silica, 15 -40% lithics and mafic minerals. • Sand /Sandstone (3410' to 3800') = pervasive black, vitreous, opaque to slightly translucent non - differentiated mafic minerals; occasionally augite, some hornblende and rare biotite are discernible; some apparent magnetite attracted to probe; note various other blackish dark colored minerals present; two very abundant dominant groups of lithic fragments include: pale medium green to grayish green to variegated green low grade metamorphic greenstone rock fragments (which are responsible for the overall olive - greenish gray sample coloration) and black to grayish black to dark gray medium grade metamorphic argillite - phyllite rock fragments; last 5 -10% of lithics are a moderately diverse group of rock fragments from multiple sources. Sand /Sandstone (3410' to 3800') = note that greenish coloration of sandstone is contrasted by distinctive traces of orange - red to red volcanic rock fragments and low grade jasper; other notable traces of rock fragments and minerals include: greenish yellow epidote, flakes of chlorite (associated with the greenstones), rose quartz, muscovite, yellow citrine, a golden - yellowish brown mica (either a yellow variation of biotite or possibly phlogopite), pinkish quartzite, silvery gray schist, yellowish brown lithic calcareous tuff and rare clastic coal fragments; note 70 -80% of the quartz is colorless to very pale gray to other very pale colors and translucent, 20 -30% of the quartz and nearly all of the volcanic glass is colorless and transparent. Sand /Sandstone /Conglomeratic Sand /Conglomerate (3800' to 4070') = light olive gray to olive gray; locally shifts to either greenish gray or a medium gray with olive gray and greenish gray secondary hues; greenish coloration from greenstone fragments and grains; in part displays dark greenish salt and pepper appearance; note that when conglomeratic the larger quartz grains contrast against greenish gray background coloration; repeat fining upward sections; moderately well sorted in uppermost zones to poorly sorted in basal zones; fine lower to granule (conglomerate); mostly shifting mean size from fine upper to very coarse lower; note rare pebbles in finer sand that appears to be second mode; angular to sub angular; mostly equant, sub spherical shape; many of the larger conglomerate clasts are well rounded; pervasively disaggregated with sparsely distributed small pieces of consolidated sandstone; 8 '� CANRIG Chevron Chevron - Trading Bay Unit M -20 • sandstone is mostly matrix supported with spotty grain supported; inter -grain support is mostly soluble tuffaceous clay with minor weak calcite cementation. Sand /Sandstone /Conglomeratic Sand /Conglomerate (3800' to 4070') = lithic arenite to compositional graywacke; estimate 50 -70% quartz (and volcanic glass), trace feldspar, 10 -20% various crypto silica (chalcedony, chert, agate) and other non - differentiated silica, 20 -40% lithics and mafic minerals; lithics and mafic minerals; lithics are dominated by green to grayish green to variegated green low grade meta greenstone rock fragments and black to grayish black to dark gray medium grade meta argillite- phyllite rock fragments; remaining lithics are diverse multiple sources; note that conglomerate zones have greater diversity of lithics than the finer sands; note distinctive traces of orange - red to red volcanic rock fragments and low grade jasper, greenish yellow epidote and flakes of chlorite; note that the conglomerate has a significant fraction of dense medium to dark gray slightly translucent chert not observed in the finer sands. Coal /Carbonaceous Shale /Carbonaceous Claystone (4070' to 4200') = medium grade lignite with interbedded carbonaceous shale, very carbonaceous mudstone and carbonaceous tuffaceous claystone; note tuffaceous carbonaceous claystone ranges from somewhat silty, ashy and organic looking to a finer clay rich variation that has some fissility, is pale brown to dusky brown and discernibly gradational to carbonaceous shale; both coal and carbonaceous shale are interbedded with the carbonaceous claystone; lignite is black to brownish black; brittle; mostly fragile; has a thin platy to thin hackly or irregular fracture habit; dense matte to smooth texture; dense earthy to dull lusters. Sand /Sandstone (4200' to 4360') = dominant light olive gray to olive gray or localized medium light gray to medium gray with strong light olive gray secondary hues; also note some very faint light brownish gray secondary hues as adjacent clays become more prominent; overall greenish hues derived from greenstone rock fragments; note that the greenish salt and pepper appearance observed in the major sand interval from 3800' to 4070' is less prominent; this interval is a stack of repeat sand sections, each of which displaying subtle but discernible fining upward; moderate to moderately well sorted with shifting mean size from fine lower to medium upper; total range is very fine lower to coarse lower; minor very fine lower fraction is nearly all glass shards that have been winnowed from volcanic ash; angular to sub angular; dominant equant, sub spherical shape; consistent very minor fraction of the sand grains has improved sphericity; nearly all disaggregated; trace consolidated mix of clay matrix support and very weak calc cementation; lithic arenite that transitions to compositional graywacke; estimated 60 -80% quartz (and volcanic glass), trace feldspar 10 -15% various crypto silica (chalcedony, chert, agate) and various non - differentiated silica, 15 -35% lithics and mafic minerals. Coal /Carbonaceous Shale (4360' to 4380') = black to brownish black, lignite and carbonaceous shale; brittle; fragile; thin platy and thin irregular fracture habit; many fragments display micro thin alternating laminations of different grades of lignite. Sand /Sandstone (4390' to 4460') = very light gray to light gray; clast size ranges from medium lower to fine lower; sub round; moderate some well developed sphericity; moderate some poor sorting; sub mature; non to very slightly calcareous; also some weak siliceous cementation; initially sparse silt and ash increases in silt/ash matrix increasing with depth; hydrophilic matrix; loosely attached; grain and matrix support becoming all matrix support after 4440'; fair to poor porosity and permeability. Sand (4500 - 4560') = very light gray to pinkish gray; clast size ranges from fine upper to very fine upper grading to silt; well developed sphericity; fine grains abundant; poor sorting; polished texture; no visible cement; moderate to abundant clay /ash matrix; hydrophilic and loosely attached; matrix supported; composed of >90% quartz, minor chert, greenstone and various detrital material; poor porosity and permeability. Sand (4570' to 4590') = very light gray; clast size fine upper to very fine upper grading to silt; sub angular to sub round; moderate developed sphericity; poor to moderate sorting; abundant grain size is fine; CANRIG 9 Ch ■1111/"C - Trading Bay Unit M -20 • impacted texture; sub mature nature; non to very weak siliceous cement; unconsolidated; moderate clay /ash matrix; grain supported to matrix support with depth; composed of >90% quartz; fair to poor porosity and permeability; no show of oil. carbonaceous clay /shale /coal (4600 -4620 brownish black mottled brown; firm; earthy luster; matte to mottled texture; hackly to sub planar fracture; composed of very carbonaceous clay and shale grading to lignitic coal; trace visible bleeding gas from coal cuttings. Tuffaceous Siltstone (4630' to 4680') = pinkish gray; very poor to poorly indurated; clustered to clotted; gelatinous; mushy to pasty; slimy; non to slight cohesiveness; slight to moderate adhesive; amorphous fracture; massive habit; hydrophilic; earthy luster; silty to ashy texture. Tuffaceous Siltstone (4690' to 4740') = pinkish gray; very poor to poorly indurated; clustered to clotted; gelatinous; mushy to pasty; slimy; non to slight cohesiveness; slight to moderate adhesive; amorphous fracture; massive habit; hydrophilic; earthy luster; silty to ashy texture; massive gradational tuffaceous silts and clays with interbedded very fine grained sand. Sand (4750' to 4800') = very light gray; clast size ranges from fine lower to very fine lower grading to silt; sub round to rounded; well developed sphericity; poor sorting; polished to pitted textures; sub mature nature; unconsolidated; moderate to abundant clay /ash matrix; very hydrophilic and loosely attached; composed of >90% quartz with minor lithic fragments; poor to local fair porosity and permeability; sand interbedded with silts. Sand (4810' to 4830') = very Tight gray; clast size ranges from fine lower to very fine lower grading to silt; sub round to rounded; well developed sphericity; poor sorting; polished to pitted textures; sub mature nature; unconsolidated; moderate to abundant clay /ash matrix; very hydrophilic and loosely attached; composed of >90% quartz with minor lithic fragments; poor porosity and permeability. 11° Carbonaceous Claystone /Carbonaceous Shale (4840' to 4890') = grayish black mottled brownish black; firm; earthy luster; matte to mottled texture; sub planar to sub blocky fracture; composed of very carbon clay and carbon shale grading to sub lignitic coal. Sand (4900' to 4950') = very light gray; clast size ranges from fine lower to very fine lower grading to silt; sub round; moderate to well developed sphericity; poor sorting; polish texture sub mature nature; unconsolidated and mostly interbedded; poor porosity and permeability. Sand 4960' to 5000') = very light gray; clast size ranges from fine lower to very fine lower grading to silt; sub round to rounded; well developed sphericity; poor sorting; polished to pitted textures; sub mature nature; unconsolidated; moderate to abundant clay /ash matrix; very hydrophilic and loosely attached; composed of >90% quartz with minor lithic fragments; poor porosity and permeability. Tuffaceous Siltstone (5010' to 5090') = pinkish gray; very poor to poorly indurated; clustered to clotted; gelatinous; mushy to pasty; slimy; non to slight cohesiveness; slight to moderate adhesive; amorphous fracture; massive habit; hydrophilic; earthy luster; silty to ashy texture; massive gradational tuffaceous silts and clays with interbedded very fine grained sand. Carbonaceous Shale /Carbonaceous Claystone /Coal (5095' to 5115') = brownish black mottled brownish gray to moderate brown; firm; earthy luster mottled with sub resinous lusters; matte texture; hackly to sub planar fracture along carbon shale partings; composed of very carbonaceous clay /shale and sub lignitic coals; trace out gas noted from larger lignitic coal fragments. Coal /Carbonaceous Claystone /Carbonaceous Shale (5120' to 5160') = brownish black; firm; earthy to sub resinous luster; matte texture; sub hackly fracture; composed of lignite coal grading to very carbonaceous clay and shale; better grade than the 5100' coal above. 10 CANRIG Chevron C hevron - Trading Bay Unit M -20 Sand /Sandstone (5170' to 5220') = very light gray to off white; clast size range medium upper to fine upper; sub round; moderate developed sphericity; moderate sorting; impacted to pitted textures; sub mature nature; non to very slight siliceous cement; generally unconsolidated with secondary consolidated clusters; moderate clay /ash matrix; both grain and matrix support; composed of >90% quartz; poor to fair porosity and permeability. Tuffaceous Siltstone (5230' to 5320') = pinkish gray; very poor to poorly indurated; brittle; clustered to clotted gelatinous; mushy to pasty; slimy; non to slightly cohesive; slight to moderate adhesive; amorphous fracture; massive habit; very hydrophilic with silts and clays going into solution; moderate earthy luster; silty to ashy texture; massive gradational tuffaceous silt and clay and very fine sands. Coal /Carbonaceous Shale (5325' to 5335') = brownish black; brittle to firm; earthy luster; matte texture; planar to flaky fracture along shale partings; composed of very carbonaceous shale and lignitic coal. Tuffaceous Claystone (5340' to 5410') = pinkish gray; very soft to soft; sectile to malleable; flexible; mushy to pasty; tacky to slimy; slightly cohesive; moderate adhesive; amorphous fracture; massive habit; moderate earthy luster; clayey to silty texture; massive beds of gradational tuffaceous silts and clays; composed of 50% silt, 50% clay. Sand (5420' to 5450') = light medium gray; some tiny spots of very light gray to off white; clast size ranges from medium upper to fine upper; sub round to round; moderate to well developed sphericity; moderate to poor sorting; polished to pitted texture; sub mature nature; non to very weak siliceous cement; dominant unconsolidated; moderate ash/ silt matrix; very hydrophilic; matrix and grain supported in parts; composed of >90% quartz, poor to fair porosity and permeability. Sand (5460' to 5540') = very light gray to off white; clast size ranges from coarse lower to fine lower; sub round to round; moderate to well developed sphericity; moderate to poor sorting; polished to pitted • texture; sub mature nature; non to very weak siliceous cement; dominant unconsolidated; moderate ash /silt matrix; very hydrophilic; matrix and grain supported in parts; composed of >90% quartz, poor to fair porosity and permeability; grading to siltstone with depth. Coal /Carbonaceous Shale /Carbonaceous Claystone (5540' to 5580') = black mottled brownish black; firm some hard; earthy to sub resinous luster; matte texture; sub planar fracture along shale partings to hackly fracture in lignitic coal; composed of very carbonaceous shale and clay to sub lignite to lignitic coal; trace visible bleeding gas from lignitic coals. Tuffaceous Claystone (5410' to 5700') = light brownish gray to medium light gray with other very faint brownish, yellowish, pinkish and bluish hues; soft to very slightly firm; hydrophilic; loses structure and becomes mushy and "runny" after hydration; moderate to poor cohesiveness and adhesiveness; forms tiny clumps when vibrated over shakers; spotty blebs of cleaner - looking lighter colored volcanic ash; clayey to silty to ashy to various soft matte textures; earthy to spotty micro sparkly lusters. Sand /Sandstone/Tuffaceous Sandstone (5630' to 5600') = light olive gray to medium light gray to medium gray with strong light olive gray secondary hues; increases in lightness value to light gray as matrix ash content increases; very fine lower to coarse lower; apparent fining upward; moderate to poorly sorted around transitioning mean size from fine lower to medium lower; note consistent very minor fraction of very fine lower grains are nearly all glass shards winnowed from volcanic ash; finest quartz begins at very fine upper; angular to sub angular; mostly equant, sub spherical shape; prominent tuffaceous clay and volcanic ash matrix support; trace of support from calcite mineralization; abundant loose disaggregated grains resulting from matrix clays going into solution; Note that ashiest sandstone has abundant discernible micro shards in matrix; lithic arenite to marginal compositional graywacke. Carbonaceous Clay and Shale (5810' to 5820') = brownish black mottled brownish gray; brittle to firm; earthy luster with mottled sub resinous lusters; matte texture; micro planar fractures along carbon shale 11 CANRIG Chevron • hevron - Trading Bay Unit M -20 partings to sub hackly in lignitic coal; composed of very carbonaceous clay /shale grading to carbonaceous mudstone to sub lignitic coals; no visible bleeding gas noted. Sand/Tuffaceous Sandstone (5830' to 5900') = very light gray; clast size medium to fine lower; increase in clast size with decrease in tuffaceous sand; sub round; moderately developed sphericity; poor to becoming fair sorting with depth; impact to pitted texture; sub mature nature; becoming grain supported with depth; composed of 90% quartz, 10% various lithic fragments; increased porosity and permeability with depth; samples becoming arenaceous with depth; grading away from tuffaceous sands. Sand (5910' to 5970') = very light gray; clast size ranges from medium upper to fine lower; sub round; moderately developed sphericity; moderate some local poor sorting; impacted texture; sub mature to mature nature; non to weak siliceous cement; dominant grain support; arenaceous; composed of 90% quartz, 10% chert and trace greenstone and argillite; good porosity and permeability; no show of oil fluorescence or oil cuts. Carbonaceous Shale /Clay and Coal (5980' to 5995') = brownish black mottled black; firm; earthy mottled resinous luster; matte texture; hackly to sub planar fractures along carbon shale partings; composed of very carbonaceous clay and shale mottled with sub lignitic coals; no visible bleeding gas from coal cuttings. Sand /Conglomerate Sand (6010' to 6090') = very light gray to pinkish gray; clast size range from coarse lower to fine upper; sub round to sub angular; moderately developed sphericity; poor sorting; mean size clasts are medium grains; impacted text; sub mature nature; non to very weak siliceous cement; unconsolidated with secondary weak consolidation locally; slight hydrophilic clay matrix; dominant grain support with possible local matrix support; composed of 80% quartz, 10% chert, 10% various lithic fragments; fair porosity and permeability; no oil indicators. Tuffaceous Sand (6100' to 6180') = pinkish gray; clast size range medium lower to very fine grading to silt; sub round; moderate to well developed sphericity; poor sorting; polished text; sub mature to immature nature; moderate silt/ash hydrophilic matrix; visible pyroclastic relic shard matrix ash; dominant matrix support; composed of quartz with chert and volcanic glass shards and various detrital material; poor visible porosity and permeability; no show of oil fluorescence or cuts; gradual decrease in coarse grain to tuffaceous very fines with depth after 6130'. Carbonaceous Clay / Mudstone and Coal (6200' to 6245') = brownish black mottled black; firm; overall earthy luster mottled resinous in lignitic coal; matte to smooth textures; sub hackly fracture; composed of various grades of very carbonaceous clay /mudstone to lignitic coals; no visible bleeding gas noted in any coal fragments. Sand (6250' to 6300') = very light gray to pinkish gray; clast size range from coarse lower to fine lower; abundant fraction of medium grain; sub round; moderately developed sphericity; poor sorting; impacted texture; sub mature nature; non to very weak siliceous cement; slight hydrophilic clay /silt matrix; dominant grain support; some interbedded coal; composed of 90% quartz, 10% chert and various lithic fragments; fair to some good porosity; fair permeability; no show of oil fluorescence or oil cuts. Sand (6310' to 6390') = very light gray; clast size range from coarse lower to fine lower; sub round; moderate developed sphericity; poor sorting; mean size medium to fine grains; impacted texture; sub mature nature; non to very weak siliceous cement; slight hydrophilic clay matrix; dominant grain support; composed of 90% quartz, 10% chert with minor meta greenstone; fair to good porosity and permeability; no oil indicators. Sand (6400' to 6440') = very light gray; clast size range from coarse lower to fine upper; sub round; moderate developed sphericity; poor sorting; mean size medium to fine grains; impacted texture; sub 12 CANRIG Chevron C hevron - Trading Bay Unit M -20 • mature nature; non to very weak siliceous cement; slight hydrophilic clay matrix; dominant grain support; composed of 90% quartz, 10% chert with minor meta. Carbonaceous Clay /Shale and Coal = (6440' to 6460') = brownish black mottled black; firm; overall earthy luster mottled resinous in lignitic coal; matte to smooth textures; sub hackly fracture; composed of various grades of very carbonaceous clay /mudstone to lignitic coals; no visible bleeding gas noted in any coal fragments. Sand (6460' to 6540') = very light gray; clast size range from coarse lower to fine upper; sub round; moderately developed sphericity; poor sorting; mean size medium to fine grains; impacted texture; sub mature nature; non to very weak siliceous cement; slight hydrophilic clay matrix; dominant grain support; composed of 90% quartz, 10% chert with minor meta; fair to good estimated porosity and permeability; no show of oil indicators. Sand (6540' to 6640') = very light gray; coarse upper to fine upper; sub angular to sub round; moderate sphericity; poor sorting; mean size medium to fine grains; bit impact texture; very light gray to white hydrophilic clay cement/matrix mostly washed out of sample; quartzose > 90% clear to light gray translucent, medium gray sub nodular chert, and traces of glauconite, citrine, argillite phyllite, feldspar and carbonaceous fragments; fair to good estimated porosity and permeability; no oil indicators Sand /Conglomerate Sand (6570' to 6660') = medium light gray to light gray with light olive gray secondary hue; visible coarsening overall at 6630' from predominantly fine /medium to predominantly medium /coarse; also increase in chert and feldspar; angular to sub rounded, minor sub nodular; moderate sphericity; nearly all disaggregated; trace consolidated w/ clay matrix support; lithic arenite transitions to graywacke; estimated 80% quartz (and volcanic glass), traces glauconite, feldspar, citrine, argillite phyllite and carbonaceous fragments; calc content if any masked by mud add; no fluorescence or other oil indicators. Carbonaceous Clay /Coal (6675' to 6745') = brownish black to black with grayish black secondary hues; firm; dull earthy to traces thin bedded vitreous luster from vitrain stringers; matte smooth texture; sub hackly fracture, minor sub conchodial fracture; composed of various grades of carbonaceous mudstone /shale to lignite with traces of vitrain; scattered visible outgassing noted in coal fragments. Sand (6760' to 6850') = very light gray to pinkish gray; medium upper to fine lower; mostly fine upper; angular to sub round; poor to moderate sphericity poor to fair sorting; polished to bit impacted texture; sub mature nature; scattered very Tight gray predominantly matrix supported sandstone with white hydrophilic clay /silt matrix/cement; dominant disaggregated sand grains composed of approx 90% quartz, with chert, argillite - phyllite and traces of various other lithic fragments; apparent fair to good porosity and permeability; no oil fluorescence or oil cuts. Carbonaceous Clay /Coal (6685' to 6900') = brownish black to black with grayish black secondary hues; firm; dull earthy luster; matte to gritty texture; sub hackly, splintery to earthy fracture; moderately fissile in part; trace visible outgassing. Sand (6895' to 6970') = light gray with pinkish gray and light greenish gray secondary hues; medium upper to fine lower, mostly medium lower; angular to sub rounded; low to moderate sphericity; fair sorting; bit impacted, chipped and crystalline textures; sub mature nature; predominantly disaggregated samples; scattered traces very light gray to white soluble and hydrophilic clay matrix; quartzose - composed of clear to Tight to medium translucent (smokey) gray quartz grains ( >90 %), chert, argillite - phyllite, feldspar, citrine and glauconite; apparent fair to good porosity /permeability; no oil indicators Sand /Conglomeratic Sand (6970' to 7060') = medium light gray to light gray; lithic arenite to compositional graywacke; estimate 80 -90% quartz (and volcanic glass), trace feldspar, 5 -7% various crypto silica (chalcedony, chert, agate) and other non - differentiated silica, trace lithics mostly translucent 13 CANRIG C • " - Trading Bay Unit M -20 to opaque greenstone fragments and grayish black to dark gray argillite - phyllite lithics; moderately well sorted; medium upper to fine lower; note rare coarse and very coarse nodular quartz and chert grains; angular to sub rounded, rare well rounded; moderate to well developed sphericity; essentially all disaggregate in sample; occasional trace of very light gray sandstone with white ashy clay matrix support, matrix is soluble and mod hydrophilic; calc content masked by mud additives; no fluorescence or other oil indicators. Sand (7055' to 7180') = medium light gray to light gray with light brownish gray to light greenish gray secondary hues; quartzose (85 -95 %); upper part of unit is fine lower to medium lower; angular to sub rounded, fair to well sorted; unit coarsens downward to medium upper to fine upper; angular to sub rounded; poor to fair sorting; more very Tight gray ashy clay matrix sandstone with depth; becoming mildly conglomeratic at 7140' w/ rare scattered coarse quartz and chert angular and nodular clasts; apparent poor to fair porosity /perm; no oil indicators. Sand /Sandstone (7180' to 7300') = medium light gray with pinkish gray and light brownish gray secondary hues; predominantly disaggregated sand interbedded with very light gray matrix supported sandstone w/ light gray to white soluble slightly hydrophilic ashy clay matrix/cement; slightly to mod calcareous; sand grains overall hi quartz ( >80 %); medium upper to fine lower; angular to sub rounded; chipped, bit broken texture; also signs of abundant re- working; sub mature to mature nature; matrix where present is ashy clay, lithifying agent; porosity and permeability vary with clay content; up to 10% medium to dark gray nodular chert, traces greenstone, feldspar, citrine, muscovite, argillite - phyllite and carbonaceous fragments; no oil indicators. Carbonaceous Clay /Shale and Coal (7310' to 7360') = brownish black mottled dark brown to black; brittle in smaller clay /shale fragments to firm in coals; earthy lusters in carbon clays to sub resinous to resinous luster in lignitic coal; matte texture; sub planar fracture in carbon shale to hackly in coal; • composed of very carbonaceous clay to carbon mudstone grading to sub lignitic to lignitic coal; very slight bleeding gas from mature lignitic coals. Tuffaceous Silt and Tuffaceous Claystone (7370' to 7410') = pinkish gray; very soft; lumpy to clumpy; clustered to clotted; gelatinous; amorphous fracture; massive habit; dull earthy luster; ashy to sub clayey texture; massive gradation of very hydrophilic tuffaceous silt and tuffaceous clay; interbedded very fine grain sands. Sand /Sandstone (7420' to 7520') = very Tight gray to salt and pepper appearance; clast size ranges from coarse lower to fine grains; sub round to sub angular; moderate developed sphericity; generally equant; some discoidal and triaxial; moderate sorting with some local poor sorting; chipped siliceous grains to impact quartz grains; sub mature to mature nature; arenaceous; non to local strong siliceous cement; slight hydrophilic clay matrix; local consolidated clusters with matrix residue; dominant clean grain support; composed of 80 -90% quartz; 20 -10% chert, dark argillite, siliceous coal grains and trace of greenstone; fair to good porosity and permeability; no show of oil fluorescence or oil cuts. Coal /Carbon Clay /Shale (7530' to 7560') = brown to black; brittle in smaller clay /shale fragments to firm in coals; earthy lusters in carbon clays to sub resinous to resinous luster in lignitic coal; matte texture; sub planar fracture in carbon shale to hackly in coal; composed of very carbonaceous clay to carbon mudstone grading to sub lignitic to lignitic coal; very slight bleeding gas from mature lignitic coals. Tuffaceous Claystone (7570' to 7595') = pinkish gray; very soft to soft; lumpy to clumpy; clustered to clotted; gelatin amorphous fracture; massive habit; earth luster; ashy to silty texture; massive gradational beds of hydrophilic clay and silts with detrital material. Carbonaceous Clay /Coal (7600' to 7615') = brownish black to black with grayish black secondary hues; firm; dull earthy luster; matte to gritty texture; sub hackly, splintery to earthy fracture; composed of very carbonaceous clay and lignitic coal; slight visible bleeding gas from lignite cuttings. 14 CANRIG Chevron • Chevron - Trading Bay Unit M -20 Sand /Sandstone (7635' to 7690') = very light gray; clast size coarse lower to fine upper; sub round; moderate developed sphericity; poor sorting; chip to impact to polish textures; sub mature nature; composed of medium to some coarse sand with fine grain matrix sands with slight hydrophilic clay /ash matrix; grain support; fair porosity and permeability; no show of oil indicators. Tuffaceous Claystone (7700' to 7750') = pinkish gray; very soft to soft; lumpy to clumpy; clustered to clotted; gelatin amorphous fracture; massive habit; earth luster; ashy to silty texture; massive gradational beds of silt and clay. Tuffaceous Siltstone (7750- 7790') = light to light olive gray; soft; lumpy to clumpy; hydrophilic nature masks fracture and other physical prop; dull earthy luster; matte to gritty texture. Carbonaceous Clay /Coal (7790- 7805') = black to grayish black with reddish brown hues; firm; dull, earthy to resinous lust; blocky to sub conchodial to irregular fracture; equant, planar habit; common fine light gray micro laminae in carbonaceous clay; coal is lignitic and thinly interbedded with carbonaceous clay. No visible outgas. Sand /Sandstone (7810' to 7850') = light gray with light brownish gray and pinkish gray secondary hues; very fine upper to medium upper, mostly fine upper quartzose ( >90 %), poor to fair sorting; angular to sub rounded; moderate sphericity; chipped, bit broken to crystalline text; sub mature nature; disaggregated in sample; scattered traces grading to coarse upper; largely re- worked; clasts include scattered traces of feldspar, greenstone, citrine, argillite - phyllite and occasional thin carbonaceous zones; apparent fair estimated porosity and permeability; no fluorescence or other oil indicators. Tuffaceous Claystone (7850' to 8000') = light gray with light brownish gray and pinkish gray secondary hues; clumpy to pasty; crumbly; soluble and slightly hydrophilic nature mask fracture, cuttings habit, • luster; dull waxy luster; smooth to gritty texture; massive bedding with locally silty zones and sandstone partings; slightly to mod calcareous. Coal (7900' to 7915') = grayish black to black; dull to waxy minor resinous luster; stiff to brittle; irregular, blocky conchodial fracture; massive, equant platy cuttings; smooth to matte texture; fissile with shale partings at base; grading to and with lenses of dark gray carbonaceous shale scattered visible outgassing. Sand /Sandstone (8050' to 8175') = light gray to Tight yellowish gray with occasional light greenish gray; fine upper to coarse lower, mostly medium lower; quartzose ( >90 %); poor to fair sorting; angular to sub rounded; moderate sphericity; chipped, bit broken to crystalline texture; re- worked with predominantly grain support; disaggregated w/ traces siliceous cement; local trace sandstone w/ highly calcareous cement; discernible clear glass micro shards (ranging to very fine upper) are spotty to abundant in finest fraction; also scattered to trace amounts of medium gray - gray blue chert, greenish -black glauconite, yellow citrine, brownish feldspar, orange -red jasper, dark gray mafics; repeat fining upward sections; scattered dull yellow mineral fluorescence; no visible oil, odor or other oil indicators. Sand (8260' to 8340') = medium light gray w/ light olive gray and light greenish gray hues; very fine upper to medium lower, mostly medium lower; poor to fair sorting; angular to sub angular; low to moderate sphericity; chipped, bit impacted to crystalline text; quartzose (90 %) w/ scattered chert, argillite- phyllite, and traces of greenstone, citrine and feldspar; very fine fraction includes common clear glass shards representing volcanic ash; distinctive fining upwards w/ predominantly medium upper to coarse lower at 8310; also addition of up to very coarse conglomerate clasts and nodules, and grain supported sandstone w/ very light gray to white clay ash matrix/cement material; essentially non calcareous; no oil indicators. 15 • CANRIG Chevron t 10 "•111/Chevron • 411°. - Trading Bay Unit M -20 Sandstone /Conglomerate (8340' to 8410') = medium light gray w/ light olive gray hues; medium upper to very coarse lower w/ coarsest fraction predominantly quartz, chert and siliceous siltstone; re- worked; very poor sorting; angular to sub angular; low sphericity; chipped, broken, mashed; re- lithified w/ silica and clay /ash matrix; locally scattered calc cement. Coal /Carbonaceous Shale (8410' to 8457') = brownish black to brownish gray; crunchy, brittle; irregular to sub conchoidal fracture; tab, elongated cuttings; waxy minor vitreous luster; smooth to silty texture; thick bedded with carbonaceous shale and silt partings; traces visible outgas mostly lignite, scattered sub bituminous Tuffaceous Claystone (8460' to 8530') = light gray to very light gray w/ light greenish gray hues; tacky; crumbly; earthy fracture; matte text; thin inter w/ siltstone and conglomerate; no calc; ashy. Conglomerate Sand (8480' to 8515') = mod brown to pale yellow brown; quartz and crypto - crystalline silica; clasts up to 2mm; nodular and reworked; thin interbeds. Siltstone (8460' to 8530') = brownish gray to medium dark gray; moderately hard; silica cement; carbonaceous, in part. Tuffaceous Claystone (8530' to 8580') = medium light gray to light brownish gray; curdy; crumbly; earthy fracture; smooth to matte texture; commonly silty; non to slightly calcareous; thick beds with siltstone and sandstone lenses and partings. Coal /Carbonaceous Shale (8581' to 8615') = brownish black to grayish black, some black; friable to firm friable; very thin bedded 60% fusain, 40% vitrain, also common thin arenaceous partings; carbonaceous shale is dusky brown, hard; irregular to splintery to sub conchoidal fracture; tabular to bladed cuttings; scattered visible outgassing; Tuffaceous Claystone (8625' to 8645') = medium light gray curdy, tacky; soluble and mod hydrophilic nature mask fracture, cuttings habit, luster; smooth to gritty texture; ashy with abundant clear glass shards; thick beds with common silty and sandy lenses and partings. Coal /Carbonaceous Shale (8665' to 8675') = brownish gray to grayish black; firm friable; irregular, earthy fracture; tabular bladed cuttings; dull, waxy minor greasy Tuffaceous Siltstone (8680' to 8740') = pinkish gray; moderate induration; stiff moderate cohesive; non adhesive; sub planar fracture; sub tabular habit; moderate to sub resinous luster; silty to gritty texture; slightly calcareous; gradational stiff siltstones with local very soft clay. Tuffaceous Claystone (8750' to 8790') = very light gray to pinkish gray; very soft; lumpy to clumpy; clustered to clotted; mushy to pasty; tacky; slimy; non to slight cohesiveness; moderate to very adhesive; earthy to amorphous fracture; massive pillow habit; moderate earthy luster; clayey to ashy texture; massive gradation of tuffaceous clay and tuffaceous silt. Coal (8795' to 8825') = black mottled brownish black; firm to hard; resinous to sub metallic in parts; matte to smooth texture along fracture points; blocky to sub conchoidal fractures; composed of sub lignitic coal to bituminous coal; visible bleeding gas from most cuttings. Tuffaceous Silt (8830' to 8890') = pinkish gray; poor induration; lumpy to clumpy; clustered to clotted; gelatin; mushy to pasty; tacky to slimy; slightly cohesive; moderate to very adhesive; amorphous fracture; pillow to massive habit; moderate earthy luster; silty to clayey to ashy texture; massive grading of tuffaceous silt and tuffaceous clay with various detrital material. 16 CANRIG Chevron C hevron - Trading Bay Unit M -20 Coal (8895' to 8930') = black some mottled brownish black; firm some hard; resinous luster; matte texture; hackly to sub conchoidal fractures; composed of lignitic to bituminous coal; visible bleeding gas from coal cuttings. Tuffaceous Silt (8940' to 8960') = pinkish gray; poor induration; lumpy to clumpy; clustered to clotted; gelatin; mushy to pasty; tacky to slimy; slightly cohesive; moderate to very adhesive; amorphous fracture; pillow to massive habit; moderate earthy luster; silty to clayey to ashy texture; massive grading of tuffaceous silt and tuffaceous clay with various carbon material. Coal (8970' to 8990') = black some mottled brownish black; firm some hard; resinous luster; matte texture; hackly to sub conchoidal fractures; composed of lignitic to bituminous coal; visible bleeding gas from coal cuttings. Conglomerate Sand (9035' to 9150') = very light gray; -clast size ranges from very coarse lower to medium lower; sub round to sub angular; poor to moderate sorting with abundant faction medium grains to coarse lower; poor sorting; chip to impacted texture; sub mature nature; non to very slight siliceous cement; clay structured matrix loosely attached; some hydrophilic clays; dominant matrix support @ 9040' with some local grain support; sample clast size becoming medium to fine grains after 9090' with a distinct clast size change; moderate sorting with impacted texture; sub mature to some mature nature; sub arenaceous; slight clay matrix; dominant grain support; composed of 90% quartz, 10% chert and trace lithics; fair to good porosity and permeability; no oil. Tuffaceous Claystone /Devitrified Ash (9130' to 9210') = pinkish gray becoming white in thin ash beds; very soft; lumpy to clumpy; clustered to clotted; gelatin slightly mushy to pasty; moderately hydrophilic; non to slight cohes9veness; moderate adhesive; amorphous fracture; pillow to massive habit; moderate earthy luster; silty to ashy texture; massive gradational silts and clay; scattered white devitrified ash; • visible pyroclastic relic shards inter bedded; minor very fine to fine grained sand. Sand (9220' to 9270') = very light gray; clast size medium upper to fine lower; sub round; moderate sphericity; moderate sorting; impact texture; sub mature nature; non to very slight siliceous cement; hydrophilic clay matrix; both grain and becoming matrix support with depth; composed of 90% quartz, 10% chert with various lithic fragments; arenaceous in parts; no oil indicators. Coal (9280' to 9290') = grayish black to black with brownish black carbonaceous silt/shale; crunchy; brittle; irregular to conchoidal fracture; tabular, bladed curved cuttings; waxy to vitreous luster smooth to matte texture; thick bedded with 80% fusain, 40% vitrain. sub bituminous to bituminous; scattered outgassing. Tuffaceous Claystone (9290' to 9370') = light gray to light bluish gray, occasionally white in thin ashy beds; curdy to gelatinous; soluble and hydrophilic; slightly cohesive; moderately cohesive; massive gradational to silts and conglomerate sandstone partings; locally very ashy with lighter color and abundant clear glass micro shards; essentially non calcareous. Coal (9365' to 9375') = black w/ minor mottled brownish black; firm to mod hard; resinous to waxy luster; smooth to matte texture; hackly to conchoidal fractures; sub bituminous; trace gassing Sandstone (9385' to 9480') = light gray w/ yellowish gray and greenish gray hues; fine lower to coarse upper; angular to sub round; moderate sphericity; poor sorting; impact texture; sub mature nature; slight hydrophilic ash /clay matrix predominantly grain supported, some matrix support; numerous very coarse to 2mm quartz and chert clasts; also thin white ash lenses quartzose ( >80 %) w/ abundant clay /ash, med gray chert, dark gray to black mafics; common greenstone, feldspar and orange red volcanics; moderate calcareous cement; common secondary silica matrix; no oil indicators. Tuffaceous Siltstone (9460' to 9530') = various hues, mostly medium gray, also 17 CANRIG Chevron • ""mor - Chevron - Trading Bay Unit M -20 yellowish brown, blue and greenish gray; firm friable to moderately hard; earthy texture; blocky to irregular fracture; generally non calcareous; commonly carbonaceous w/ scattered very fine black fragments and micro thin black stringers. Sandstone /Conglomerate (9505' to 9620') = medium to light gray with yellowish gray and pinkish gray secondary hues; fine lower to coarse upper, with abundant very coarse up to 2mm clasts of predominantly quartz and crypto crystalline silica; angular to sub rounded; bimodal sorting; fair sorting within the medium to fine range; overall sand color is influenced by interbedded tuff claystone /siltstone and by sedimentary lithics (especially tiny sand sized rip ups) with faintly greenish gray color greenstones contribute to the olive hues, but are less than 2% of sands in the interval. Conglomerate Sandstone (9620' to 9745') = medium to light gray to Tight olive gray fine lower to very coarse upper, with scattered up to 2mm clasts; predominantly medium upper to coarse lower in finer range; angular to sub angular, coarse grains especially common nodular (many fine grains are sub rounded) poor sorting, fair sorting in fine to medium range; chip to bit broken to polished textures heavily re- worked sediments; sequences continuously fining upwards; estimate fair to good porosity and permeability; scattered traces mineral flour; no oil indicators. Tuffaceous Siltstone (9670' to 9780') = med gray to yellowish brown, also bluish and greenish gray; friable to firm; earthy texture; irregular fracture; commonly carbonaceous w/ scattered disseminated black fragments and black micro thin stringers; non calcareous. becoming very carbonaceous at 9725' - grayish black to brownish black; slight micro sparkly luster; sucrosic texture; moderately hard. Coal (9745' to 9755') = black with minor grayish black; firm to mod hard, brittle resinous to vitreous luster; smooth to matte text; hackly to conchoidal fracture; sub bituminous; thin bedded. Sandstone (9765' to 9850') = medium light gray with pinkish gray and greenish gray secondary hues; fine upper to coarse lower with scattered very coarse, mostly coarse lower; angular to sub round; moderate sphericity; poor sorting; impact texture; sub mature nature; quartzose ( >90 %) with abundant chert, and common argillite- phyllite, greenstone, jasper and feldspar; note essentially all sandstone is easily pulverized at bit and disaggregated in cuttings; tiny sandstone pieces and individual grains have attached cementation material. Coal (9850' to 9870') = black to brownish black at contacts; firm; resinous luster matte texture; blocky fracture; composed of Iignitic to bituminous coal; visible bleeding gas from cuttings. Conglomerate Sand (9880' to 9920') = light gray; clast size very coarse upper to medium lower some pebble; angular coarse grain bit impact fragments to sub round medium grain matrix sands; moderate sphericity medium grains to poor in coarse grains; poor sorting; chip coarse grain to impacted medium grain; sub mature nature; no visible cement; very slight clay matrix; dominant grain support; composed of 85% quartz, 15% chert, feldspar, argillite, greenstone and various lithics; fair to good porosity and permeability; tight tuffaceous siltstone @ 9943'; no oil indicators. Sand (9930' to 10,030') = very light gray clast size rang coarse lower to fine upper; sub round with slight angular bit impact coarse grains; moderate developed sphericity; poor sorting; impacted texture; sub mature nature; slight siliceous cement; thin beds of tuffaceous sandstone; slight ash /silt matrix; both matrix and grain support; composed of >90% quartz with trace lithics; arenaceous in grain supported; gradational beds of conglomerate sand, sandstone, sand and tuffaceous sand resulting in various porosity and permeability; no oil indicators. Sand (10,040' to 10,130') = very light gray; clast size range medium upper to fine lower; scattered coarse grains; moderate to some well developed 18 CANRIG Chevron Chevron - Trading Bay Unit M -20 sphericity; moderate sorting; impacted texture; sub mature to scattered mature nature; non to very weak siliceous cement; non to slight ash /silt hydrophilic matrix; dominant grain support; composed of >90% quartz, with minor lithics; appears arenaceous; good porosity and permeability; no show of oil indicators. Coal (10,140' to 10,150') = black mottled grayish black; brittle to firm; resinous to dull luster; grading to very carbon shale at contacts; smooth to matte texture; hackly to planar fracture along carbon shale partings; bleeding gas. Tuffaceous Silt and Clay (10,160' to 10,190') = pinkish gray to grayish orange pink; very poor to poorly indurated; lumpy to clumpy; clustered to clotted; gelatinous slightly mushy to pasty; non to very slight cohesiveness; moderate adhesive; amorphous habit; massive to slightly pillow habit; moderate earthy luster; ashy to colloidal texture; massive silts and clay with thin coal stringers. Sand (Tuffaceous) (10,215' to 10,245') = very light gray to white (ash); clast size fine upper to very fine lower to silt and relic shards; sub round - round; moderate to well developed sphericity; poor sorting; polish to pitted texture; immature to sub mature nature; abundant ash and clay matrix; dominant matrix support; loosely attached, hydrophilic; composed of 90% quartz, 10% chert and various trace lithics; poor porosity and permeability; no show of oil indicators. Conglomerate Sand (10,270- 10,300') = light gray to very light gray; clast pebble to fine upper; angular bit impacted coarse grains to sub round medium matrix sands; poor to moderate sphericity; chip coarse to impacted medium grains; sub mature; no visible cement; unconsolidated; slight clay matrix hydrophilic; dominant grain support; sub graywacke to sub arenaceous; fair to good porosity and permeability; no oil indicators. Tuffaceous Siltstone (10,300' to 10,380') = pale yellowish brown to grayish orange; soft, easily friable; blocky fracture; earthy texture; non calc. Coal (10,380' to 10,390') = black; brittle; hackly to conchoidal fracture; smooth to matte texture; sub bituminous. Sandstone (10,400' to 10,450') = medium light gray w/ minor light brownish gray; clasts are fine lower to medium lower; fair to well sorted, especially at top of unit; angular to sub rounded; low to moderate sphericity; chipped, impact abrasion; totally disaggregated in sample; note that abundant grains have roughly equal dimensions which produces the effect of well developed roundness, but most are still in the angular to sub angular range; very light gray ashy clay matrix/cement is soluble and slightly hydrophilic - washes almost entirely out of samples. no oil indicators. 19 CANRIG • hevron - Trading Bay Unit M -20 3.2. FORMATION / ZONE MARKER TOPS Note: CT: Coal Top CB: Coal Base ST: Sand Top SB: Sand Base. FORMATION ACTUAL SSTVD (ft) SZ1CT 865 -701 SZ1CB 877 -712 SZ2CT 956 -787 SZ2CB 961 -792 SZ3CT 1002 -830 SZ3CB 1011 -839 SZ4CT 1059 -883 SZ4CB 1088 -908 SZ5ST 1111 -929 SZ5CT 1152 -966 SZ5CB 1162 -974 SZ6ST 1177 -988 SZ6CT 1267 -1064 SZ6CB 1284 -1079 SZ7CT 1323 -1111 • SZ9CT 1483 -1235 SZ9CB 1498 -1245 SZ1OCT 1583 -1303 SZ1OCB 1596 -1312 SZ11CT 1904 -1483 SZ11CB 1940 -1498 SZ12CT 2119 -1565 SZ12CB 2179 -1581 SZ13CT 2492 -1650 SZ13CB 2513 -1655 SZ14ST 2564 -1666 SZ14CT 2837 -1727 SZ14CB 2885 -1738 SZ15ST 3045 -1774 SZ16ST 3266 -1820 SZ16CT 4072 -2001 SZ16CB 4146 -2022 SZ17ST 4228 -2049 SZ17CT 4361 -2098 SZ17CB 4380 -2106 SZ18CT MD (ft) 4611 -2211 SZ18CB 4631 -2221 • 20 CANRIG Chevron hevron - Trading Bay Unit M -20 SZ20CT 4880 -2360 SZ2OCB 4892 -2367 SZ21CT 5113 -2495 SZ21CB 5166 -2526 SZ22CT 5202 -2547 SZ22CB 5233 -2566 SZ23BCT 5311 -2612 ACT 5319 -2616 ACT 5334 -2625 ACB 5346 -2632 A2ST 5447 -2692 A2SB 5544 -2749 A2CT 5550 -2752 A2CB 5577 -2768 A3ST 5627 -2797 A4ST 5681 -2829 A4SB 5708 -2845 A5ST 5747 -2867 A5BST 5875 -2941 A5CT 5975 -2999 A5CB 5992 -3009 • A6ST 6039 -3037 A6SB 6078 -3060 BCT 6212 -3139 BCB 6246 -3160 B1ST 6267 -3172 B1SB 6368 -3232 B2ST 6373 -3234 B2CT 6678 -3414 B1CT 6440 -3274 B1CB 6460 -3286 B3ST 6475 -3294 B3SB 6583 -3358 B4ST 6587 -3360 B4SB 6608 -3373 B3CB 6743 -3451 B5ST 6766 -3465 A2ACT 5608 -2787 A3SB 5673 -2824 B4CB 6896 -3541 B6ST 6908 -3548 B4CT 6883 -3534 B6AST 6978 -3589 • 21 CANRIG Chevron • hevron - Trading Bay Unit M -20 B5CB 7056 -3634 116111) B5CT 7042 -3626 B7STRT 7081 -3648 B7STRB 7172 -3701 B6SB 6969 -3583 B8ST 7203 -3719 B8SB 7335 -3795 CCT 7342 -3799 CCB 7360 -3809 C1ST 7386 -3824 C1SB 7508 -3895 C1CT 7547 -3918 C1CB 7561 -3926 C2CT 7598 -3948 C2CB 7615 -3958 C3ST 7632 -3968 C3SB 7683 -3998 C3AST 7632 -3968 C3ASB 7663 -3986 C3BST 7668 -3989 C3BSB 7682 -3997 C3CT 7784 -4059 C3CB 7800 -4068 C4ST 7707 -4012 C4SB 7766 -4048 C3CT 7784 -4059 C3CB 7806 -4072 C5ST 8711 -4076 C5SB 7841 -4094 C4CT 7865 -4109 C4CB 7867 -4110 DCT 7952 -4164 DCB 7974 -4178 D1ST 8027 -4212 D1STRAYB 8060 -4233 BJVTLD1NP 8209 -4329 9.625 CSG 8213 -4331 D1CT 8410 -4464 D1CB 8457 -4497 D2ST 8492 -4524 D2SB 8512 -4539 D2CT 8589 -4600 D2CB 8620 -4625 22 CANRIG • Chevron - Trading Bay Unit M -20 D2ACT D2ACB 8666 -4663 8674 -4670 D3BST 8681 -4676 D3BSB 8704 -4695 D3CT D3CB D4CT 8796 -4773 8814 -4788 8911 -4870 D4CB 8928 -4884 D5CT D5CB 8969 -4918 8987 -4933 D6ST 9000 -4943 D6SB 9056 -4989 D6CT 9085 -5013 D6CB 9105 -5030 D7ST 9115 -5038 D7SB D7CT 9161 -5076 9167 -5080 D7CB 9172 -5085 D8ST 9202 -5109 D8SB 9274 -5168 D8CT D8CB 9337 -5220 9342 -5224 D9ST D9SB D9CT D9CB D1OST 9399 -5271 9456 -5317 9488 -5343 9493 -5347 9504 -5356 D1OSB 9553 -5396 D1OAST 9586 -5424 D1OASB 9659 -5483 D1OCT D1OCB 9662 -5486 9671 -5493 D11ST D11SB D11CT D11CB D12ST D12SB D12CT D12CB D13ST 9695 -5513 9703 -5519 9743 -5552 9751 -5558 9768 -5572 9844 -5634 9849 -5638 9866 -5652 9871 -5656 D13SB 9923 -5698 D13AST 9938 -5711 23 CANRIG Chevron hevron - Trading Bay Unit M -20 • D13ASB 9989 -5752 D14ST 10033 -5788 D14CT 10130 -5867 D14CB 10141 -5876 D15ST 10158 -5890 D15SB 10164 -5895 D15CT 10198 -5923 D15CB 10208 -5931 D16AST 10217 -5938 D16ASB 10227 -5946 D16CST 10266 -5978 D16CSB 10304 -6009 D16CT 10375 -6067 D16CB 10390 -6079 D17ST 10396 -6084 D17SB 10446 -6125 D17CT 10451 -6129 D17CB 10466 -6141 D18ST 10490 -6161 TD 10500 -6169 °al 24 CANRIG cn� SZ7CT: 1323' MD, -111' SSTVD • � hevron - Trading Bay Unit M -20 3.3. ZONE SUMMARIES Drill Rate (ft/hr) Minimum Total Gas (units Maximum Average Maximum Minimum Average 62 35 62 77 43 67 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 1324' 77 15554 - - - - - - Coal /Carbonaceous Shale = interbedded, interlaminated low grade lignite, carbonaceous shale and "woody" organic material; black- brownish black to brown; note larger coal pieces have floating fragments of lower grade material. SZ8CT: 1397' MD, -1169' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Maximum Minimum Average 125 34 61 104 69 92 Peaks Depth TG C1 C2 Average C3 C41 C4N C51 C5 1410 104 20787 2 - - - - - Coal = better developed than above; black, brittle, smooth to dense matte texture; dull to sub vitreous luster; irregular to sub planar fracture; massive; visible alternating micro laminations of vitrain and fusain. SZ9ST: 1430' MD, -1194' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 295 55 175 453 72 258 C5N Peaks Depth TG C1 C2 C3 C4I C4N C51 1467 453 86456 - - - - - - Sand = medium Tight gray to medium gray with strong Tight olive gray secondary hues; rough salt and pepper appearance; fine lower to coarse upper; mostly medium; no dominant size fraction; sub angular to sub rounded; moderately developed sphericity; moderate sorting; submature; non to very weak siliceous cement; dominant grain support; composed of 85% quartz, 15% various lithic fragments; estimated good porosity and permeability. • 25 CANRIG Chevron h hevron - Trading Bay Unit M -20 III SZ9CT 1483' MD, -1235' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 147 40 99 265 54 158 Peaks Depth TG 01 C2 C3 C4I C4N C5I C5N 1503 265 52334 - - - - - - Coal/Carbonaceous Shale = black, brittle, firm friable; smooth to matte texture; waxy to vitreous luster; irregular to sub conchoidal fracture; massive; no visible cleat; thin bedding plans. SZ10ST: 1518' MD, -1260' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 155 74 133 139 54 116 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 1530 139 25479 - - - - - - Sand = medium light gray to medium gray with strong Tight olive gray secondary hues; rough salt and pepper appearance; fine lower to coarse upper; mostly medium; no dominant size fraction; sub angular to sub rounded; moderately developed sphericity; moderate sorting; submature; non to very • weak siliceous cement; dominant grain support; composed of 85% quartz, 15% various Iithic fragments; estimated good porosity and permeability. SZ10CT: 1583' MD, -1304' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 167 53 93 196 148 185 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 1593 196 36850 Carbonaceous Shale = dark brown to Tight brown to brownish black and various hues of all; brittle; resinous to earthy lusters; matte to smooth textures; platy to flaky habit; micro planar to planar fractures; thinly bedded; trace grading to lignite. III 26 CANRIG t • �hevron - Trading Bay Unit M -20 SZ11 ST: 1597' MD, -1313' SSTVD Drill Rate (ft/hr Minimum Average Total Gas (units Maximum Maximum Minimum Average 204 54 98 291 43 130 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 1668 291 58246 - SZ11 BST: 1702' MD, -1378' SSTVD - - - - - Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 284 58 142 2 30 189 C5N Peaks Depth TG C1 C2 C3 C4I C4N C51 1720 298 59764 - - - - - - Sand /Sandstone/Tuffaceous Sandstone = medium light gray to medium with gray with generally faint to locally strong light olive gray secondary hues; also locally common tuffaceous sandstone with higher lightness values to very light gray when ash content increases; dominant fine upper to medium upper, but overall range from very fine lower to granule (conglomerate); evident fining upward in more massive sections; consistent moderate sorting with gradually shifting dominant size mode; angular to sub angular, with consistent very minor fraction of sub rounded to rounded grains; mostly equant, sub spherical shape; pervasive tuffaceous clay (volcanic ash) matrix supported sandstone; inter -grain clays are variably soluble, and a major amount of the cuttings is disaggregated and loose; spotty sandstone is grain supported, and there is a trace of harder, firmer sandstone that displays some calcite cementation; clayey (ashy) sub lithic to lithic arenite; estimate 60 -80% quartz (plus minor percentage of volcanic glass), trace feldspar, 5 -15% chert, chalcedony and other minor crypto silica, 15 -25% lithics and mafic minerals; lithics dominated by low grade metamorphic greenstone and medium grade metamorphic medium gray to grayish black phyllite- argillite rock fragments; some discernible augite and biotite, but very abundant non - differentiated black, brownish black and other dark mafic minerals; distinctive trace epidote. SZ11CT: 1901' MD, -1482' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 200 42 95 197 74 137 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 1919 197 39493 - - - - - - Coal /Carbonaceous Shale = mostly low to medium grade lignite, but some higher grade pieces to sub bituminous; black to brownish black; adjacent carbonaceous shale is often dusky brown; associated carbonaceous claystone is pale brown; brittle and mostly fragile, but spotty tough fragments; smooth to dense matte textures; dull to sub vitreous luster; mostly irregular to sub planar to planar fracture; minor blocky sub conchoidal pieces. 27 CANRIG Chevron hevron - Trading Bay Unit M -20 • SZ12ST 1950' MD, -1503' SSTVD 6 Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 238 43 136 325 21 130 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 2011 325 64872 - - - - - - Sand /Sandstone/Tuffaceous Sandstone = no significant change in characteristics; dominant primary color now light olive gray; localized zones transition to light medium and medium gray; overall size range fine lower to coarse upper; continued dominant fine upper to medium lower, but overall better sorting, with less discernible fining upward; same distribution of angular and rounded grains, but increasing grains have equant dimensions and overall better sphericity; supporting tuffaceous clay matrix is still derived from reworked volcanic ash but shards are becoming less prominent; more apparent devitrification of ashy sediment; estimate 65 -80% quartz and volcanic glass, trace feldspar, 5 -10% chalcedony, chert and other crypto silica, 15 -25% lithics and mafic minerals; continued sub lithic to lithic arenite; approximately 75 -80% of quartz is colorless to very pale gray, very pale brown or other colors and translucent, 20 -25% of quartz and nearly 100% of sand -sized grains of volcanic glass is colorless and transparent; 90% of the lithics fraction are greenstone or phyllite- argillite rock fragments and the remaining 10% are very diverse rock fragments from multiple sources; continued distinctive trace of epidote. • SZ12CT: 2119' MD, -1565' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 238 51 119 264 83 154 C5N Peaks Depth TG C1 C2 C3 C4I C4N C51 2134 264 52917 - - - - - - Coal /Carbonaceous Shale /Carbonaceous Claystone = low grade lignite and carbonaceous shale; trace higher grade lignite; visible interbedding with very abundant very carbonaceous dark brown tuffaceous claystone; note that the carbonaceous claystone ranges from somewhat silty, ashy and organic looking to a finer clay rich variation that has discernible fissility, a darker dusky brown color, a more organic overall appearance and is clearly gradational to the darker colored carbonaceous shale; both the coal and carbonaceous shale are interbedded with the dusky brown organic rich claystone; lignite coal: black to brownish black; brittle; planar fracture; thin platy to elongated irregular habit; mostly dense matte to clayey textures and earthy lusters. 28 CANRIG Chevron NINO ` Chevron - Trading Bay Unit M -20 • SZ13ST: 2239 MD, - 15961' SSTV Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 257 10 173 318 39 140 C5N Peaks Depth TG C1 C2 C3 C4I C4N C51 2466 318 62237 - - - - - - Sand /Sandstone/Tuffaceous Sandstone = significant matrix clay; very closely gradational to very sandy claystone; medium gray with light brownish gray to pale brown secondary hues; brownish colorations increase when adjacent to organic mudstones described above; very fine upper to medium upper; moderately sorted; angular to sub angular; very clayey sub lithic arenite to lithic arenite. SZ13CT: 2492' MD, -1650' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 192 58 177 201 100 154 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 2506 201 38880 - - - - - - Coal = low grade lignite and trace sub bituminous; visible interbedding with very abundant very carbonaceous dark brownish black siltstone which is ashy and organic looking grading to variation that has discernible fissility, a darker dusky brown color black to brownish black; brittle; planar fracture; thin platy to elongated irregular habit; mostly dense matte to clayey textures and earthy lusters. SZ14ST: 2564' MD, -1666' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 211 6 165 551 29 176 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 2578 551 106016 - - - - - - Sand = medium light gray; clast size ranges from fine upper to very fine upper; some grading to silt; sub angular to sub rounded; moderately developed sphericity; poor to moderate sorting; no abundant size factions; impacted to pitted textures; sub mature nature; non to very slight siliceous cement; disaggregated with local very weakly cemented consolidated sandstone; clay /silt hydrophilic matrix; both grain and matrix support; composed of > 80% quartz with various minor lithic fragments; sandstone appearing cleaner down section; note after 2600' that there is an increase in medium grains. • 29 CANRIG Chevron r Chevron - Trading Bay Unit M -20 SZ14CT: 2837' MD, -1727' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 213 115 174 453 64 282 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 2861 453 89760 - - - - - Carbonaceous Shale /Carbonaceous Claystone /Coal = composed of very carbonaceous shale and clay to lignite; brownish gray to mottled brownish black; firm; earthy luster; some localized resinous luster; smooth texture; sub planar to sub blocky fracture; visible bleeding gas from coal fragments. SZ15ST: 3045' MD, -1774' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 201 44 179 80 28 62 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 3059 80 15158 - - - - - - Sand = medium Tight gray; medium upper to fine upper; sub rounded; moderately developed III sphericity; moderate sorting with no predominant mean grain size; sub mature; disaggregated; slightly hydrophilic clay matrix; dominantly grain supported; composed of 90% quartz, 10% chert, argillite, greenstone and traces of other lithic rock fragments; fair to good visible porosity and estimated permeability. SZ16ST: 3266' MD, -1820' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 204 6 174 85 0 34 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 3436 85 17055 - - - - - - Sand = medium Tight gray; coarse lower to fine upper range; dominantly medium; sub rounded; coarse grains decreasing with depth; moderately to poorly sorted; moderately developed sphericity; sub mature; non to very weak siliceous cementation; pervasive disaggregated grains, but note tight dense consolidated sandstone at 3280' to 3290' and some sparsely distributed weakly consolidated clusters; slightly hydrophilic clay matrix; dominantly grain supported; composed of 90% quartz, 10% chert, argillite, greenstone and traces of other lithic rock fragments; fair to good visible porosity and estimated permeability. • 30 CANRIG Ch_ evron � hevron - Trading Bay Unit M -20 SZ16CT: 4072' MD, -2001' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 204 132 185 90 18 73 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 4072 90 15978 - - - - - - Coal /Carbonaceous Shale /Carbonaceous Claystone = medium grade lignite with interbedded carbonaceous shale, very carbonaceous mudstone and carbonaceous tuffaceous claystone; note tuffaceous carbonaceous claystone ranges from somewhat silty, ashy and organic looking to a finer clay rich variation that has some fissility, is pale brown to dusky brown and discernibly gradational to carbonaceous shale; both coal and carbonaceous shale are interbedded with the carbonaceous claystone; lignite is black to brownish black; brittle; mostly fragile; has a thin platy to thin hackly or irregular fracture habit; dense matte to smooth texture; dense earthy to dull lusters. SZ17ST: 4228' MD, -2049' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 200 149 180 202 27 149 Peaks Depth TG 01 C2 C3 C4I C4N C5I C5N • 4249 202 40403 - - - - - - Sand /Sandstone = dominant light olive gray to olive gray or localized medium light gray to medium gray with strong light olive gray secondary hues; also note some very faint Tight brownish gray secondary hues as adjacent clays become more prominent; overall greenish hues derived from greenstone rock fragments; note that the greenish salt and pepper appearance observed in the major sand interval from 3800' to 4070' is Tess prominent; this interval is a stack of repeat sand sections, each of which displaying subtle but discernible fining upward; moderate to moderately well sorted with shifting mean size from fine lower to medium upper; total range is very fine lower to coarse lower; minor very fine lower fraction is nearly all glass shards that have been winnowed from volcanic ash; angular to sub angular; dominant equant, sub spherical shape; consistent very minor fraction of the sand grains has improved sphericity; nearly all disaggregated; trace consolidated mix of clay matrix support and very weak calc cementation; lithic arenite that transitions to compositional graywacke; estimated 60 -80% quartz (and volcanic glass), trace feldspar 10 -15% various crypto silica (chalcedony, chert, agate) and various non - differentiated silica, 15 -35% lithics and mafic minerals. 31 • CANRIG Chevron hevron - Trading Bay Unit M - 20 ibbigi Nftil l III SZ17CT: 4361' MD, -2098' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 199 135 187 178 40 129 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 4371 35477 35477 - - - - - - Coal /Carbonaceous Shale = black to brownish black, lignite and carbonaceous shale; brittle; fragile; thin platy and thin irregular fracture habit; many fragments display micro thin alternating laminations of different grades of lignite. SZ18ST: 4420' MD, -2123' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 212 34 170 337 15 116 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 4564 65213 71295 - - - - - - Sand /Sandstone = very light gray to light gray; clast size ranges from medium lower to fine lower; 411 sub round; moderate some well developed sphericity; moderate some poor sorting; sub mature; non to very slightly calcareous; also some weak siliceous cementation; initially sparse silt and ash increases in silt/ash matrix increasing with depth; hydrophilic matrix; loosely attached; grain and matrix support becoming all matrix support after 4440'; fair to poor porosity and permeability. SZ19CT: 4739' MD, -2279' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 202 63 172 243 23 129 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 4753 46772 46772 - - - - - - Carbonaceous Claystone /Carbonaceous Shale = grayish black mottled brownish black; firm; earthy luster; matte to mottled texture; sub planar to sub blocky fracture; composed of very carbonaceous claystone and carbonaceous shale grading to sub Iignitic coal. 32 • CANRIG �hevr - Trading Bay Unit M -20 I WO • ° Chevron SZ19STRY: 4755' MD, -2288' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 193 103 183 284 73 166 Peaks Depth TG 4816 C1 C2 C3 C41 C4N C51 C5N 284 55467 - - - - - - Sand = very light gray; clast size ranges from fine lower to very fine lower grading to silt; sub round to rounded; well developed sphericity; poor sorting; polished to pitted textures; sub mature nature; unconsolidated; moderate to abundant clay /ash matrix; very hydrophilic and loosely attached; composed of >90% quartz with minor lithic fragments; poor to local fair porosity and permeability; sand interbedded with siltstone. SZ2OST: 4817' MD, -2324' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 236 55 179 300 41 142 Peaks Depth TG C1 4819 58978 60452 C2 C3 C41 C4N C51 C5N - - - - - - • Sand = very light gray; clast size ranges from fine lower to very fine lower grading to silt; sub round to rounded; well developed sphericity; poor sorting; polished to pitted textures; sub mature nature; unconsolidated; moderate to abundant clay /ash matrix; very hydrophilic and loosely attached; composed of >90% quartz with minor lithic fragments; poor porosity and permeability. SZ2OCT: 4880' MD, -2360' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Maximum Minimum Average 192 174 197 281 118 208 C51 C5N Peaks Depth TG C1 C2 Average C3 C41 C4N 4880 281 54767 - - - - - - Carbonaceous Claystone /Carbonaceous Shale = grayish black mottled brownish black; firm; earthy luster; matte to mottled texture; sub planar to sub blocky fracture; composed of very carbon clay and carbon shale grading to sub lignitic coal. 33 CAIVRIG Chevron 0 Chevron - Trading Bay Unit M -20 SZ21 ST: 4917' MD, -2382' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 198 68 181 226 35 138 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 4947 226 43879 - - - - - - Sand = very light gray; clast size ranges from fine lower to very fine lower grading to silt; sub round; moderate to well developed sphericity; poor sorting; polish texture sub mature nature; unconsolidated and mostly interbedded; poor porosity and permeability. SZ21CT: 5112' MD, -2495' SS TVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 203 162 180 492 78 252 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5126 492 83267 - - - - - - Carbonaceous Shale /Carbonaceous Claystone /Coal = brownish black mottled brownish gray to • moderate brown; firm; earthy luster mottled with sub resinous lusters; matte texture; hackly to sub planar fracture along carbon shale partings; composed of very carbonaceous clay /shale and sub lignitic coals; trace out gas noted from larger lignitic coal fragments. SZ23CT: 5148' MD, -2516' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 193 180 187 538 184 378 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5148 538 88185 58 - - - - - Coal /Carbonaceous Claystone /Carbonaceous Shale = brownish black; firm; earthy to sub resinous luster; matte texture; sub hackly fracture; composed of lignite coal grading to very carbonaceous clay and shale; better grade than the 5100' coal above. III 34 CANRIG Chevron NINO SZ22ST: 5180' MD, -2534' SST Chevron - Trading Bay Unit M -20 VD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 206 40 174 295 58 125 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5193 295 55234 6 - - - - - Sand /Sandstone = very Tight gray to off white; clast size range medium upper to fine upper; sub round; moderate developed sphericity; moderate sorting; impacted to pitted textures; sub mature nature; non to very slight siliceous cement; generally unconsolidated with secondary consolidated clusters; moderate clay /ash matrix; both grain and matrix support; composed of >90% quartz; poor to fair porosity and permeability. SZ23BCT: 5309' MD, -2611' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 210 163 191 96 54 82 Peaks Depth TG C1 C2 C3 C41 Maximum C4N C51 C5N 5317 96 15172 1 - - - - - ACT: 5332' MD, -2624' SSTVD Drill Rate (ft/hr Gas (units Maximum Minimum Average Minimum Average 193 180 202 264 77 153 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 5332 264 46230 8 - - - - - Coal /Carbonaceous Shale = brownish black; brittle to firm; earthy luster; matte texture; planar to flaky fracture along shale partings; composed of very carbonaceous shale and lignitic coal. 35 CANRIG Chevron hevron - Trading Bay Unit M -20 III A2ST: 5447' MD, -2692' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 244 67 161 223 28 84 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 5544 223 43720 7 - - - - - Sand = light medium gray; some tiny spots of very light gray to off white; clast size ranges from medium upper to fine upper; sub round to round; moderate to well developed sphericity; moderate to poor sorting; polished to pitted texture; sub mature nature; non to very weak siliceous cement; dominant unconsolidated; moderate ash/ silt matrix; very hydrophilic; matrix and grain supported in parts; composed of >90% quartz, poor to fair porosity and permeability. A2CT: 5550' MD, -2753' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 121 114 122 384 149 317 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 5555 384 69269 88 15 - - - - • Coal /Carbonaceous Shale /Carbonaceous Claystone = black mottled brownish black; firm some hard; earthy to sub resinous luster; matte texture; sub planar fracture along shale partings to hackly fracture in Iignitic coal; composed of very carbonaceous shale and clay to sub lignite to lignitic coal; trace visible bleeding gas from Iignitic coals. i A2ACT: 5608' MD, -2787' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 127 122 126 69 62 63 Peaks Depth TG 01 C2 C3 041 C4N C51 C5N 5608 69 13815 1 - - - - - 36 • CANRIG hevron - Trading Bay Unit M -20 • A3ST: 5627' MD, -2798' SSTVD Chevron .111) 1111001 Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 128 58 118 201 82 153 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 5657 201 39988 5 - - - - - Sand /Sandstone/Tuffaceous Sandstone = light olive gray to medium light gray to medium gray with strong light olive gray secondary hues; increases in lightness value to light gray as matrix ash content increases; very fine lower to coarse lower; apparent fining upward; moderate to poorly sorted around transitioning mean size from fine lower to medium lower; note consistent very minor fraction of very fine lower grains are nearly all glass shards winnowed from volcanic ash; finest quartz begins at very fine upper; angular to sub angular; mostly equant, sub spherical shape; prominent tuffaceous clay and volcanic ash matrix support; trace of support from calcite mineralization; abundant loose disaggregated grains resulting from matrix clays going into solution; Note that ashiest sandstone has abundant discernible micro shards in matrix; lithic arenite to marginal compositional graywacke. A4ST: 5681' MD, -2829' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 133 58 114 112 26 57 Peaks Depth TG 01 C2 C3 C41 C4N C51 C5N 5681 112 22323 1 - - - - - A5ST: 5746' MD, -2866' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 118 108 117 160 23 83 Peaks Depth TG C1 C2 C3 C41 C4N C5l C5N 5768 160 31937 5 - - - - - 37 CANRIG Chevron ihiggi l lINIO 0 hevron - Trading Bay Unit M -20 A4CT 5786' MD, -2889' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 108 23 98 60 23 53 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 5789 60 11512 - - - - - - Carbonaceous Clay and Shale = brownish black mottled brownish gray; brittle to firm; earthy luster with mottled sub resinous lusters; matte texture; micro planar fractures along carbon shale partings to sub hackly in lignitic coal; composed of very carbonaceous clay /shale grading to carbonaceous mudstone to sub lignitic coals; no visible bleeding gas noted. A5BST: 5875' MD, -2941' SSTVD Drill Rate (ftlhr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 168 19 128 135 19 45 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 5975 135 25657 - - - - - - 411 Sand/Tuffaceous Sandstone = very Tight gray; clast size medium to fine lower; increase in clast size with decrease in tuffaceous sand; sub round; moderately developed sphericity; poor to becoming fair sorting with depth; impact to pitted texture; sub mature nature; becoming grain supported with depth; composed of 90% quartz, 10% various lithic fragments; increased porosity and permeability with depth; samples becoming arenaceous with depth; grading away from tuffaceous sands. A5CT: 5975' MD, -3000' SSTVD Drill Rate (ftlhr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 186 60 150 251 135 205 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 5977 251 28732 27 - - - - - Carbonaceous Shale /Clay and Coal = brownish black mottled black; firm; earthy mottled resinous luster; matte texture; hackly to sub planar fractures along carbon shale partings; composed of very carbonaceous clay and shale mottled with sub lignitic coals; no visible bleeding gas from coal cuttings. 38 CANRIG th evro I Chevron - Trading Bay Unit M -20 A6ST: 6039' MD, -3037' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 219 93 150 245 40 149 C5N Peaks Depth TG Cl C2 C3 C4I C4N C51 6040 245 44561 4 - - - - - Sand /Conglomerate Sand = very light gray to pinkish gray; clast size range from coarse lower to fine upper; sub round to sub angular; moderately developed sphericity; poor sorting; mean size clasts are medium grains; impacted text; sub mature nature; non to very weak siliceous cement; unconsolidated with secondary weak consolidation locally; slight hydrophilic clay matrix; dominant grain support with possible local matrix support; composed of 80% quartz, 10% chert, 10% various lithic fragments; fair porosity and permeability; no oil indicators. BCT: 6211' MD, -3139' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 127 114 122 343 160 269 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6213 343 32863 76 - - - - - Carbonaceous Clay / Mudstone and Coal = brownish black mottled black; firm; overall earthy luster mottled resinous in lignitic coal; matte to smooth textures; sub hackly fracture; composed of various grades of very carbonaceous clay /mudstone to lignitic coals; no visible bleeding gas noted in any coal fragments. B1ST: 6267' MD, -3172' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Maximum Minimum Average 168 44 121 88 32 69 C5N Peaks Depth TG C1 C2 Average C3 C4I C4N C51 6321 88 16234 - - - - - - Sand = very light gray to pinkish gray; clast size range from coarse lower to fine lower; abundant fraction of medium grain; sub round; moderately developed sphericity; poor sorting; impacted texture; sub mature nature; non to very weak siliceous cement; slight hydrophilic clay /silt matrix; dominant grain support; some interbedded coal; composed of 90% quartz, 10% chert and various lithic fragments; fair to some good porosity; fair permeability; no show of oil fluorescence or oil cuts. 39 CANRIG • Chevron WIC - Trading Bay Unit M -20 Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 128 33 116 119 29 53 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6442 119 21640 30 - - - - - Sand = very light gray; clast size range from coarse lower to fine lower; sub round; moderate developed sphericity; poor sorting; mean size medium to fine grains; impacted texture; sub mature nature; non to very weak siliceous cement; slight hydrophilic clay matrix; dominant grain support; composed of 90% quartz, 10% chert with minor meta greenstone; fair to good porosity and permeability; no oil indicators. B1CT: 6442' MD, -3276' SSTVD Drill Rate (ft/hr 202 Total Gas (units Maximum Peaks Minimum Average Maximum Minimum Average 209 46 127 25046 44 202 59 164 Depth 6443 TG C1 C2 C3 C4I C4N C51 C5N - - - - - + Carbonaceous Clay /Shale and Coal = brownish black mottled black; firm; overall earthy luster mottled resinous in Iignitic coal; matte to smooth textures; sub hackly fracture; composed of various grades of very carbonaceous clay /mudstone to Iignitic coals; no visible bleeding gas noted in any coal fragments. B3ST; 6474' MD, -3294' SSTVD Drill Rate (ft/hr 60 Total Gas (units Maximum Peaks Minimum Average Maximum Minimum Average 128 53 126 60 40 58 Depth 6483 TG C1 C2 C3 C41 C4N C51 C5N 10454 - - - - - - Sand = very light gray; clast size range from coarse lower to fine upper; sub round; moderately developed sphericity; poor sorting; mean size medium to fine grains; impacted texture; sub mature nature; non to very weak siliceous cement; slight hydrophilic clay matrix; dominant grain support; composed of 90% quartz, 10% chert with minor meta; fair to good estimated porosity and permeability; no show of oil indicators. 40 CANRIG c �hevr verage on - Trading Bay Unit M - 20 • B4ST; 6587' MD, -3361' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum A Maximum Minimum Average 127 46 120 43 28 36 C5N Peaks Depth TG C1 C2 C3 C4I C4N C51 6588 43 10225 - - - - - - Sand = very light gray; coarse upper to fine upper; sub angular to sub round; moderate sphericity; poor sorting; mean size medium to fine grains; bit impact texture; very light gray to white hydrophilic clay cement/matrix mostly washed out of sample; quartzose > 90% clear to Tight gray translucent, medium gray sub nodular chert, and traces of glauconite, citrine, argillite phyllite, feldspar and carbonaceous fragments; fair to good estimated porosity and permeability; no oil indicators. B2CT; 6677' MD, -3414' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Maximum Minimum Average 127 115 124 426 210 353 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6683 426 62862 277 Average - - - - - Carbonaceous Clay /Coal = brownish black to black with grayish black secondary hues; firm; dull earthy to traces thin bedded vitreous luster from vitrain stringers; matte smooth texture; sub hackly fracture, minor sub conchodial fracture; composed of various grades of carbonaceous mudstone /shale to lignite with traces of vitrain; scattered visible outgassing noted in coal fragments. B3CT; 6716' MD, -3436' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 161 69 118 424 107 346 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 6721 424 25397 142 - - - - - Carbonaceous Clay /Coal = brownish black to black with grayish black secondary hues; firm; dull earthy luster; matte to gritty texture; sub hackly, splintery to earthy fracture; moderately fissile in part; trace visible outgassing. 41 CANRIG • � hevron - Trading Bay Unit 1 20 B5ST; 6766' MD, - 34654' SSTVD Drill Rate (ft/hr T Gas (units Maximum Minimum Average Maximum Minimum Average 128 40 113 85 43 64 Peaks Depth TG C1 C2 15266 144 C3 C41 N C51 C5N 6818 85 Chevron - - - - Sand = very light gray to pinkish gray; medium upper to fine lower; mostly fine upper; angular to sub round; poor to moderate sphericity poor to fair sorting; polished to bit impacted texture; sub mature nature; scattered very light gray predominantly matrix supported sandstone with white hydrophilic clay /silt matrix/cement; dominant disaggregated sand grains composed of approx 90% quartz, with chert, argillite - phyllite and traces of various other lithic fragments; apparent fair to good porosity and permeability; no oil fluorescence or oil cuts. B4CT; 6883' MD, -3533' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 116 34 83 263 43 194 Peaks Depth TG 6889 C1 C2 263 24581 178 C3 C41 C4N C51 C5N 2 - - - - Carbonaceous Clay /Coal = brownish black to black with grayish black secondary hues; firm; dull earthy luster; matte to gritty texture; sub hackly, splintery to earthy fracture; moderately fissile in part; trace visible outgassing. B6ST; 6908' MD, -3548' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum 107 Minimum Average 174 124 171 100 143 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 6964 171 21125 86 16 - - - - Sand = light gray with pinkish gray and Tight greenish gray secondary hues; medium upper to fine lower, mostly medium lower; angular to sub rounded; low to moderate sphericity; fair sorting; bit impacted, chipped and crystalline textures; sub mature nature; predominantly disaggregated samples; scattered traces very Tight gray to white soluble and hydrophilic clay matrix; quartzose - composed of clear to light to medium translucent (smokey) gray quartz grains ( >90 %), chert, argillite- phyllite, feldspar, citrine and glauconite; apparent fair to good porosity /permeability; no oil indicators. 42 CANRIG . 111° hevron - Trading Bay Unit M -20 B6AST; 6978' MD, -3588' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Peaks Minimum Average Maximum Minimum Average 140 63 118 152 37 110 Depth TG C1 Chevron C2 C3 C4I C4N C51 C5N 7039 152 33232 307 - - - - - Sand /Conglomeratic Sand = medium light gray to light gray; Iithic arenite to compositional graywacke; estimate 80 -90% quartz (and volcanic glass), trace feldspar, 5 -7% various crypto silica (chalcedony, chert, agate) and other non - differentiated silica, trace lithics mostly translucent to opaque greenstone fragments and grayish black to dark gray argillite- phyllite lithics; moderately well sorted; medium upper to fine lower; note rare coarse and very coarse nodular quartz and chert grains; angular to sub rounded, rare well rounded; moderate to well developed sphericity; essentially all disaggregate in sample; occasional trace of very Tight gray sandstone with white ashy clay matrix support, matrix is soluble and mod hydrophilic; calc content masked by mud additives; no fluorescence or other oil indicators. B5CT; 7042' MD, -3635' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Peaks Minimum Average Maximum Minimum Average 133 127 129 271 147 233 Depth TG C1 C2 C3 C41 C4N C51 C5N 7046 271 58996 714 - - - - - B7SRT; 7080' MD, -3647' SSTVD Drill Rate (ft/hr Total Gas (units; Maximum Minimum Average Maximum Minimum Average 156 11 120 134 27 92 Peaks Depth TG C1 17018 C2 C3 C41 C4N C51 C5N 7083 134 170 - - - - - Sand = medium light gray to Tight gray with Tight brownish gray to light greenish gray secondary hues; quartzose (85 -95 %); upper part of unit is fine lower to medium lower; angular to sub rounded, fair to well sorted; unit coarsens downward to medium upper to fine upper; angular to sub rounded; poor to fair sorting; more very Tight gray ashy clay matrix sandstone with depth; becoming mildly conglomeratic at 7140' w/ rare scattered coarse quartz and chert angular and nodular clasts; apparent poor to fair porosity /perm; no oil indicators. 43 CANRIG Chevron Chevron - Trading Bay Unit M -20 • B8ST; 7203', -3919' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 140 64 123 383 60 182 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7270 383 55647 345 - - - - - Sand /Sandstone = medium light gray with pinkish gray and light brownish gray secondary hues; predominantly disaggregated sand interbedded with very light gray matrix supported sandstone w/ light gray to white soluble slightly hydrophilic ashy clay matrix/cement; slightly to mod calcareous; sand grains overall hi quartz ( >80 %); medium upper to fine lower; angular to sub rounded; chipped, bit broken texture; also signs of abundant re- working; sub mature to mature nature; matrix where present is ashy clay, lithifying agent; porosity and permeability vary with clay content; up to 10% medium to dark gray nodular chert, traces greenstone, feldspar, citrine, muscovite, argillite - phyllite and carbonaceous fragments; no oil indicators. CCT; 7342' MD, -3799' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 132 118 134 347 270 344 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7345 25910 256 Carbonaceous Clay /Shale and Coal = brownish black mottled dark brown to black; brittle in smaller clay /shale fragments to firm in coals; earthy lusters in carbon clays to sub resinous to resinous luster in lignitic coal; matte texture; sub planar fracture in carbon shale to hackly in coal; composed of very carbonaceous clay to carbon mudstone grading to sub lignitic to lignitic coal; very slight bleeding gas from mature lignitic coals. C1ST; 7385' MD, -3824' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 138 4 90 114 11 47 Peaks Depth TG C1 C2 C3 C41 C4N C51 C 7396 114 17970 40 - - - - - Sand /Sandstone = very light gray to salt and pepper appearance; clast size ranges from coarse lower to fine grains; sub round to sub angular; moderate developed sphericity; generally equant; some discoidal and triaxial; moderate sorting with some local poor sorting; chipped siliceous grains to impact quartz grains; sub mature to mature nature; arenaceous; non to local strong siliceous cement; slight hydrophilic clay matrix; local consolidated clusters with matrix residue; dominant clean grain support; composed of 80 -90% quartz; 20 -10% chert, dark argillite, siliceous coal grains and trace of greenstone; fair to good porosity and permeability; no show of oil fluorescence or oil cuts. S 44 CANRIG th� hevron - Trading Bay Unit M - 20 • C1CT; 7547' MD, -3918' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 93 79 94 300 96 270 Peaks Depth TG 01 C2 C3 C41 C4N C51 C 7554 300 56199 478 - - - - - Coal /Carbonaceous Claystone /Shale = brown to black; brittle in smaller clay /shale fragments to firm in coals; earthy lusters in carbon clays to sub resinous to resinous luster in lignitic coal; matte texture; sub planar fracture in carbon shale to hackly in coal; composed of very carbonaceous clay to carbonaceous mudstone grading to sub lignitic to lignitic coal; very slight bleeding gas from mature lignitic coals. C2CT; 7598' MD, -3948' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Maximum Minimum Average 114 40 94 269 36 196 Peaks Depth TG C1 C2 Average C3 C41 C4N 051 C5N 7599 269 23468 128 - - - - - Carbonaceous Clay /Coal = brownish black to black with grayish black secondary hues; firm; dull earthy luster; matte to gritty texture; sub hackly, splintery to earthy fracture; composed of very carbonaceous clay and lignitic coal; slight visible bleeding gas from lignite cuttings. C3ST; 7632' MD, -3968' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Maximum Minimum Average 119 68 110 80 50 72 Peaks Depth TG 01 C2 Average C3 C41 C4N C51 C5N 7649 80 14150 - - - - - - Sand /Sandstone = very light gray; clast size coarse lower to fine upper; sub round; moderate developed sphericity; poor sorting; chip to impact to polish textures; sub mature nature; composed of medium to some coarse sand with fine grain matrix sands with slight hydrophilic clay /ash matrix; grain support; fair porosity and permeability; no show of oil indicators. C3BST; 7667' MD, -3988' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 119 93 120 81 57 75 Peaks 45 CANRIG Chevron C hevron - Trading Bay Unit M -20 Depth TG 01 13935 C2 C3 C41 C4N C51 C5N 7670 81 - - - - - - Sand /Sandstone = light gray to very light gray; fine upper to coarse lower; discernible fining upward in unit; angular to sub rounded, mostly sub rounded; moderately developed sphericity; poor sorting; chip to impact to polish textures; sub mature nature; quartzose sand with very light gray to white ash /clay matrix; matrix is soluble, and mostly washes out of sample; predominantly grain support; fair porosity and permeability; no show of oil indicators. C4ST; 7706' MD, -4011' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 95 22 60 66 33 45 Peaks Depth TG 01 C2 C3 C41 C4N C51 C5N 7761 66 12276 - - - - - - C3CT; 7784' MD, -4059' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 84 19 55 227 23 130 C5N - Peaks Depth TG C1 C2 C3 C41 C4N C51 7794 227 54444 276 Carbonaceous Clay /Coal = black to grayish black with reddish brown hues; firm; dull, earthy to resinous lust; blocky to sub conchodial to irregular fracture; equant, planar habit; common fine light gray micro laminae in carbonaceous clay; coal is Iignitic and thinly interbedded with carbonaceous clay. No visible outgassing. C5ST; 7811' MD, -4076' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 129 5 99 137 18 94 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 7818 137 15765 40 - - - - - Sand /Sandstone = light gray with light brownish gray and pinkish gray secondary hues; very fine upper to medium upper, mostly fine upper quartzose ( >90 %), poor to fair sorting; angular to sub rounded; moderate sphericity; chipped, bit broken to crystalline text; sub mature nature; disaggregated in sample; scattered traces grading to coarse upper; largely re- worked; clasts include scattered traces of feldspar, greenstone, citrine, argillite - phyllite and occasional thin carbonaceous zones; apparent fair estimated porosity and permeability; no fluorescence or other oil indicators. • 46 CANRIG 110 � hevron - Trading Bay Unit M-__20 C4CT; 7865' MD, -4109' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Peaks Minimum Average Maximum Minimum Average 61 47 84 59 53 56 Depth TG C1 C2 C3 C41 C4N C51 C5N 7865 59 15116 - - - - - Coal = grayish black to black; dull to waxy and minor resin stiff to brittle; irregular to blocky conchoidal fracture; equant to platy cuttings; smooth to matte texture; fissile with shale partings; grading to lenses of dark gray carbon shale; scattered visible outgassing. DCT; 7952' MD, -4164' SSTVD Maximum Peaks Drill Rate (ft/hr 205 Total Gas (units Minimum Average Maximum Minimum Average 77 27 50 205 46 160 Depth 7956 TG C1 34679 C2 C3 C41 C4N 051 C5N 187 - - - - Carbonaceous Clay /Coal = black to grayish black with reddish brown hues; firm; dull, earthy to resinous lust; blocky to sub conchodial to irregular fracture; equant, planar habit; common fine light gray micro laminae in carbonaceous clay; coal is lignitic and thinly interbedded with carbonaceous clay. no visible outgassing. D1ST; 8027' MD, -4212' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Maximum Minimum Average 108 25 78 52 0 10 C5N Peaks Depth TG C1 C2 Average C3 C41 C4N C51 8033 52 9967 - - - - - - Sand /Sandstone = light gray to light yellowish gray with occasional light greenish gray; fine upper to coarse lower, mostly medium lower; quartzose ( >90 %); poor to fair sorting; angular to sub rounded; moderate sphericity; chipped, bit broken to crystalline texture; re- worked with predominantly grain support; disaggregated w/ traces siliceous cement; local trace sandstone w/ highly calcareous cement; discernible clear glass micro shards (ranging to very fine upper) are spotty to abundant in finest fraction; also scattered to trace amounts of medium gray - gray blue chert, greenish -black glauconite, yellow citrine, brownish feldspar, orange -red jasper, dark gray mafics; repeat fining upward sections; scattered dull yellow mineral fluorescence; no visible oil, odor or other oil indicators. 47 CANRIG Chevron • Chevron - Trading Bay Unit M -20 D1CT; 8410' MD, -4464' SSTVD °II 111410 Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 170 30 97 311 11 157 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 8426 311 50318 148 26 - - - - Coal /Carbonaceous Shale = brownish black to brownish gray; crunchy, brittle; irregular to sub conchoidal fracture; tab, elongated cuttings; waxy minor vitreous luster; smooth to silty texture; thick bedded with carbonaceous shale and silt partings; traces visible outgas mostly lignite, scattered sub bituminous. D2ST; 8492' MD, -4524' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Maximum Minimum Average - 168 97 136 68 40 59 - Peaks Depth TG C1 C2 Average C3 C41 C4N C51 C5N 8492 68 4962 6 1 Conglomerate Sand = mod brown to pale yellow brown; quartz and crypto- crystalline silica; clasts up to 2mm; nodular and reworked; thin interbeds. D2CT; 8589' MD, -4600' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 181 54 150 430 210 333 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 8616 430 27280 107 40 - - - - Coal /Carbonaceous Shale = brownish black to grayish black, some black; friable to firm friable; very thin bedded 60% fusain, 40% vitrain, also common thin arenaceous partings; carbonaceous shale is dusky brown, hard; irregular to splintery to sub conchoidal fracture; tabular to bladed cuttings; scattered visible outgassing; D2ACT; 8666' MD, -4663' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 182 96 152 305 138 278 48 CANRIG Chevron hevron - Trading - Bay Unit M -20 • Peaks Depth TG C1 305 28891 C2 91 C3 C41 C4N C51 C5N 8671 - - - - Coal /Carbonaceous Shale = brownish gray to grayish black; firm friable; irregular, earthy fracture; tabular bladed cuttings; dull, waxy minor greasy D3BST; 8681' MD, -4676' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 120 33 98 74 26 59 C5N Peaks Depth TG C1 C2 C3 C4I C4N C51 8703 74 6690 9 - - - - - Conglomerate Sand = medium gray to Tight brownish gray with moderate brown and pale yellow brown secondary hues; bimodal with finer component as fine upper to medium upper; coarser component includes quartz and crypto- crystalline silica clasts up to 2mm; nodular and reworked; thin interbeds. D3CT; 8796' MD, -4773' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 200 52 133 306 39 236 Peaks Depth TG C1 C2 C3 C41 C4N C51 C 8810 306 24200 86 24 - - - - Coal = black mottled brownish black; firm to hard; resinous to sub metallic in parts; matte to smooth texture along fracture points; blocky to sub conchoidal fractures; composed of sub lignitic coal to bituminous coal; visible bleeding gas from most cuttings. D4CT; 8911' MD, -4870' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 96 89 100 311 64 238 Peaks Depth TG C1 C2 C3 C4I C4N C51 C 8915 311 26354 109 24 - - - - Coal = black some mottled brownish black; firm some hard; resinous luster; matte texture; hackly to sub conchoidal fractures; composed of lignitic to bituminous coal; visible bleeding gas from coal cuttings. • 49 CANRIG th eeron hevron - Trading Trading_ Bay Bay Unit M -20 • Drill Rate (ft/hr To Gas (units Maximum Peaks Minimum Aver Maximum Minimum Average 162 63 126 347 46 227 Depth TG C1 C2 C3 C41 C4N C51 C5N 8973 347 26004 102 - - - Coal = black some mottled brownish black; firm some hard; resinous luster; matte texture; hackly to sub conchoidal fractures; composed of Iignitic to bituminous coal; visible bleeding gas from coal cuttings. D6ST; 9000' MD, -4943' SSTVD Drill Rate (ft/hr 49 Total Gas (units Maximum Peaks Minimum Average Maximum Minimum Average 145 29 117 49 16 38 Depth 9015 TG C1 C2 C3 C41 C4N C51 C5N 9072 8 - - - - - Conglomerate Sand = very light gray; -clast size ranges from very coarse lower to medium lower; sub round to sub angular; poor to moderate sorting with abundant faction medium grains to coarse • D5CT; 8969' MD, -4918' SSTVD lower; poor sorting; chip to impacted texture; sub mature nature; non to very slight siliceous cement; clay structured matrix loosely attached; some hydrophilic clays; dominant matrix support @ 9040' with some local grain support; sample clast size becoming medium to fine grains after 9090' with a distinct clast size change; moderate sorting with impacted texture; sub mature to some mature nature; sub arenaceous; slight clay matrix; dominant grain support; composed of 90% quartz, 10% chert and trace lithics; fair to good porosity and permeability; no oil. D6CT; 9085' MD, -5013' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 132 22 104 250 31 156 Peaks Depth TG C1 C2 C3 C41 C4N C51 C 9098 250 27807 133 26 - - - - 50 CANRIG Chevron Chevr - Trading Bay Unit M -20 too • D7ST; 9115' MD, -5038' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 116 17 69 81 20 40 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 9128 81 13501 26 - - - - - Tuffaceous Claystone /Devitrified Ash = pinkish gray becoming white in thin ash beds; very soft; lumpy to clumpy; clustered to clotted; gelatin slightly mushy to pasty; moderately hydrophilic; non to slight cohes9veness; moderate adhesive; amorphous fracture; pillow to massive habit; moderate earthy luster; silty to ashy texture; massive gradational silts and clay; scattered white devitrified ash; visible pyroclastic relic shards inter bedded; minor very fine to fine grained sand. D7CT; 9167' MD, -5080' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 99 32 95 168 15 97 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 9172 168 29753 30 - D1 STRAYBT; D8ST 9202' MD, -5109' SSTVD - - - - • Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 130 27 92 58 14 31 C5N Peaks Depth TG C1 C2 C3 C41 C4N C51 9244 58 10616 27 - - - - - Sand = very light gray; clast size medium upper to fine lower; sub round; moderate sphericity; moderate sorting; impact texture; sub mature nature; non to very slight siliceous cement; hydrophilic clay matrix; both grain and becoming matrix support with depth; composed of 90% quartz, 10% chert with various lithic fragments; arenaceous in parts; no oil indicators. 51 CANRIG hevron - Trading Bay Unit M -20 •■•• • D8CT; 9337' MD, -5220' SSTVD Chevron Drill Rate (ft/hr Total Gas (units Maximum Minimum Aver Maximum Minimum Average 79 77 77 172 28 95 C5N Peaks Depth TG C1 C2 C3 C4I C4N C51 9342 172 14000 46 4 - - - - Coal = black w/ minor mottled brownish black; firm to mod hard; resinous to waxy luster; smooth to matte texture; hackly to conchoidal fractures; sub bituminous; trace outgassing. D9ST; 9399' MD, -5271' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 98 17 73 48 12 29 Peaks Depth TG C1 C2 C3 C41 C4N C51 C 9442 48 9649 115 - - - - - Sandstone = light gray w/ yellowish gray and greenish gray hues; fine lower to coarse upper; angular to sub round; moderate sphericity; poor sorting; impact texture; sub mature nature; slight hydrophilic ash /clay matrix predominantly grain supported, some matrix support; numerous very coarse to 2mm • quartz and chert clasts; also thin white ash lenses quartzose ( >80 %) w/ abundant clay /ash, med gray chert, dark gray to black mafics; common greenstone, feldspar and orange red volcanics; moderate calcareous cement; common secondary silica matrix; no oil indicators. D9CT; 9488' MD, -5343' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Maximum Minimum Average 90 69 97 191 82 140 Peaks Depth TG C1 C2 Average C3 C41 C4N C51 C 9492 191 34578 275 22 - - - - Coal = grayish black to black; brittle, firm friable; irregular to blocky to conchoidal fracture; smooth to matte texture; dull to vitreous luster; cuttings are tabular, equant somewhat bladed; grades from massive amorphous bedding to micro bedding planes alternating between vitrain and fusain; sub bituminous to bituminous; scattered traces of outgassing. 52 GANRIG t_ h evron B OW hevron - Trading Bay Unit M -20 • D10ST; 9504' MD, -5356' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 132 18 91 42 13 27 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9522 42 4095 22 1 - - - - Sandstone /Conglomerate = medium to light gray with yellowish gray and pinkish gray secondary hues; fine lower to coarse upper, with abundant very coarse up to 2mm clasts of predominantly quartz and crypto crystalline silica; angular to sub rounded; bimodal sorting; fair sorting within the medium to fine range; overall sand color is influenced by interbedded tuff claystone /siltstone and by sedimentary lithics (especially tiny sand sized rip ups) with faintly greenish gray color greenstones contribute to the olive hues, but are less than 2% of sands in the interval. D10CT; 9662' MD, -5486' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 179 47 91 166 34 108 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9664 166 25740 149 - - - - - II D11ST; 9695' MD, -5513' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 116 73 109 30 22 31 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 9701 30 8442 21 - - - - - Conglomerate Sandstone = medium to light gray to light olive gray fine lower to very coarse upper, with scattered up to 2mm clasts; predominantly medium upper to coarse lower in finer range; angular to sub angular, coarse grains especially common nodular (many fine grains are sub rounded) poor sorting, fair sorting in fine to medium range; chip to bit broken to polished textures heavily re- worked sediments; sequences continuously fining upwards; estimate fair to good porosity and permeability; scattered traces mineral flour; no oil indicators. D11CT; 9743' MD, -5552' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 95 61 90 174 23 97 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 9749 174 25704 84 - - - - - 53 • CANRIG Chevron Chevron - Trading - Bay Unit M -20 • Coal = black with minor grayish black; firm to mod hard, brittle resinous to vitreous luster; smooth to matte text; hackly to conchoidal fracture; sub bituminous; thin bedded. D12ST; 9768' MD, -5572' SSTVD Drill Rate (ft/hr 101 Total Gas (units Maximum Peaks Minimum Average Maximum Minimum Average 196 65 137 101 20 43 Depth 9818 TG Cl C2 C3 5 C41 C4N C51 C5N 14502 23 - - -- Sandstone = medium light gray with pinkish gray and greenish gray secondary hues; fine upper to coarse lower with scattered very coarse, mostly coarse lower; angular to sub round; moderate sphericity; poor sorting; impact texture; sub mature nature; quartzose ( >90 %) with abundant chert, and common argillite - phyllite, greenstone, jasper and feldspar; note essentially all sandstone is easily pulverized at bit and disaggregated in cuttings; tiny sandstone pieces and individual grains have attached cementation material. D12CT; 9849' MD, -5638' SSTVD Drill Rate (ft/hr 294 Total Gas (units Maximum Minimum Average Maximum Minimum Average S 97 40 88 294 48 205 Peaks Depth 9858 TG C1 C2 C3 34 C41 C4N C51 C5N 22472 132 - - - - Coal = black to brownish black at contacts; firm; resinous luster matte texture; blocky fracture; composed of lignitic to bituminous coal; visible bleeding gas from cuttings. D13ST; 9871' MD, -5656' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 164 38 102 94 26 51 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 9848 94 10550 40 9 - - - - Conglomerate Sand = light gray; clast size very coarse upper to medium lower some pebble; angular coarse grain bit impact fragments to sub round medium grain matrix sands; moderate sphericity medium grains to poor in coarse grains; poor sorting; chip coarse grain to impacted medium grain; sub mature nature; no visible cement; very slight clay matrix; dominant grain support; composed of 85% quartz, 15% chert, feldspar, argillite, greenstone and various lithics; fair to good porosity and permeability; tight tuffaceous siltstone @ 9943'; no oil indicators. 54 CANRIG Chevron • � hevron - Trading Bay Unit M -20 D13AST; 9938' MD, -5711' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 124 12 82 57 15 38 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 9955 57 10938 23 - - - - - Sand = very light gray clast size rang coarse lower to fine upper; sub round with slight angular bit impact coarse grains; moderate developed sphericity; poor sorting; impacted texture; sub mature nature; slight siliceous cement; thin beds of tuffaceous sandstone; slight ash /silt matrix; both matrix and grain support; composed of >90% quartz with trace Iithics; arenaceous in grain supported; gradational beds of conglomerate sand, sandstone, sand and tuffaceous sand resulting in various porosity and permeability; no oil indicators. D14ST; 10,033' MD, -5788' SSTVD Drill Rate ( ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 122 14 76 43 4 31 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N • 10118 8374 22 - - - - - - Sand = very light gray; clast size range medium upper to fine lower; scattered coarse grains; moderate to some well developed sphericity; moderate sorting; impacted texture; sub mature to scattered mature nature; non to very weak siliceous cement; non to slight ash /silt hydrophilic matrix; dominant grain support; composed of >90% quartz, with minor Iithics; appears arenaceous; good porosity and permeability; no show of oil indicators. D14CT; 10,130' MD, -5867' SSTVD Drill Rate ( ft/hr T otal Gas (units Maximum Minimum Average Maximum Minimum Average 87 22 71 213 42 135 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 10134 213 37366 89 24 - - - - Coal = black mottled grayish black; brittle to firm; resinous to dull luster; grading to very carbon shale at contacts; smooth to matte texture; hackly to planar fracture along carbon shale partings; bleeding gas. • 55 CANRIG Cho • hevron - Trading Bay Unit 120 D15ST; 10,158' MD, -5890' SSTVD Drill Rate (ft/hr Tal Gas (units Maximum Minimum Average Maximum Minimum Average 54 42 48 65 30 54 Peaks Depth TG C1 C2 C3 C41 N C51 C5N 10161 65 10644 10 - - - - D15CT; 10,198' MD, -5923' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 94 61 86 242 37 200 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5 10208 242 25500 96 8 - - - - Tuffaceous Silt and Clay = pinkish gray to grayish orange pink; very poor to poorly indurated; lumpy to clumpy; clustered to clotted; gelatinous slightly mushy to pasty; non to very slight cohesiveness; moderate adhesive; amorphous habit; massive to slightly pillow habit; moderate earthy luster; ashy to colloidal texture; massive silts and clay with thin coal stringers. D16AST; 10,217' MD, -5938' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 66 15 52 53 28 48 C5N Peaks Depth TG 01 C2 C3 C41 C4N C51 10221 53 8700 23 - - - - - Sand (Tuffaceous) = very light gray to white (ash); clast size fine upper to very fine lower to silt and relic shards; sub round - round; moderate to well developed sphericity; poor sorting; polish to pitted texture; immature to sub mature nature; abundant ash and clay matrix; dominant matrix support; loosely attached, hydrophilic; composed of 90% quartz, 10% chert and various trace lithics; poor porosity and permeability; no show of oil indicators. D16CST; 10,266' MD, -5978' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 83 18 67 76 31 52 C5N Peaks Depth TG 01 02 C3 C41 C4N C51 10283 76 12578 28 - - - - - 56 CANRIG Chevron hevron - Trading - Bay Unit M -20 • Conglomerate Sand = light gray to very light gray; clast pebble to fine upper; angular bit impacted coarse grains to sub round medium matrix sands; poor to moderate sphericity; chip coarse to impacted medium grains; sub mature; no visible cement; unconsolidated; slight clay matrix hydrophilic; dominant grain support; sub graywacke to sub arenaceous; fair to good porosity and permeability; no oil indicators. D16CT; 10,375' MD, -6067' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Peaks Minimum Average Maximum Minimum Average 63 32 57 254 27 159 Depth TG Cl 10383 254 36846 147 C2 C3 51 C41 C4N C51 C5N - - - Coal = black; brittle; hackly to conchoidal fracture; smooth to matte texture; sub bituminous. 159 10,396' MD, -6084' SSTVD Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 1235 25 71 69 32 53 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N - 10420 69 9597 15 10 Sandstone = medium light gray w/ minor Tight brownish gray; clasts are fine lower to medium lower; fair to well sorted, especially at top of unit; angular to sub rounded; low to moderate sphericity; chipped, impact abrasion; totally disaggregated in sample; note that abundant grains have roughly equal dimensions which produces the effect of well developed roundness, but most are still in the angular to sub angular range; very light gray ashy clay matrix/cement is soluble and slightly hydrophilic - washes almost entirely out of samples. no oil indicators. D17CT; 10,451' MD, -6129' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 48 14 41 205 32 140 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 10465 205 17496 87 38 - - - - D18ST; 10,490' MD, -6161' SSTVD Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 31 40 79 38 63 41 Peaks 57 CANRIG Chevron Chevron - Trading Bay Unit M -20 Depth TG C1 C2 C3 C41 C4N C51 C5N 10496 41 7072 35 - - - - - 3.4. SAMPLING PROGRAM AND DISTRIBUTION Set Type and Purpose Interval Frequency Distribution Chevron North America E &P, Inc A Washed and Dried 1320' - 10500' 30' 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Attn: Debra Oudean Chevron North America E &P, Inc B Washed and Dried 1320' - 10500' 30' 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Attn: Debra Oudean 58 el CANRIG Chevron - Trading Bay Unit M -20 • 4. DRILLING DATA 4.1. DAILY ACTIVITY SUMMARY October 16, 2009: General rigging up operations: Test platform deluge system, drain lines and reactivate the system. Inspect the derrick and change out the derrick lights. Lay out and strap the 13 3/8" casing. Tighten the diverter line clamps and dress the flow line in the sub base. Adjust the derrick stop beam and attach the top drive hydraulic lines while flush through the by -pass. Load 1502 rack and make up and run 20 5/8" drift in the conductor. Drift the stack to load the shoulder on the starting head and pull out and lay down. Hold a pre spud meeting with all hands. Open the top drive hydraulic lines and check the gripper bite height for HT drill pipe. Nipple up the diverter lines and install and torque the main bolts on the north /south lines. Function test the diverter (both remote panels). Performance test the accumulator and test the assembled Gyro data tools and install them in the drill collar. Adjust the bell nipple and run a hydrostatic check of the stack and valves. Leaks observed in both north and south valves. Troubleshoot and perform various corrective actions on the leaking valves. Install cameras at the derrick board and above the V -door and run respective cables. Begin pumping cement onto the platform. Test Gyro data secondary tool assembly and hook up and fill the steam lines to the R4R tank. October 17, 2009: Continued miscellaneous work as directed by the operator. Troubleshoot and repair the south diverter valve. String and plug in cameras in the derrick. Fill the tiger tank with 445 bbls. Make up 9 5/8" test joint and wash tool and stand back in the derrick. Change out inserts in the iron roughneck. Nipple up and down the diverter system and tighten the bolts on the south diverter line and bring the wear ring and handling equipment to the rig floor. Make up the drive sub to cross over and stand back. Pick up drill pipe and pick up three joints of HWDP. Make up wear ring running tool and run a BOP diverter drill. Service the rig and tap the iron roughneck S head bolt. Grease leaking from north diverter valve. Install and remove wear bushing and land water ring. Well head started leaking and troubleshoot the same. Pull the wear ring and pull flow riser. Remove turn buckles and start nippling down the diverter valves for well head nipple down. Pick up 9 HWDP's and stand back in the derrick. October 18, 2009: Pick up three stands of HWDP and reload the skate. Nipple down the north and south diverter and remove the turn buckles. Remove covers around the riser and pick up the BOP, riser, starting head and install N2 gasket. Lower and make up the same. Install and remove the wear bushing set and set the wear ring. Land 13 3/8" drive sub on the bottom stand and rack in the derrick. Install pitcher nipple and air it up. Continue to flange up the diverter lines. Fill the diverter with filtered inlet water and pick up BHA. Run filtered inlet water down the J tube. Begin rotary drilling from 383' to 480' and stage up rig pumps to 700 gpm at 850 psi, 80 -100 rpm and 4- 5k torque. Circulate and condition at 700 gpm and bring the viscosity up to 70 and mud weight to 9.2 and then trip out of the hole (pumping out to 200' at 650 gpm at 80 rpm. Stand back the drill collars and break out the bit and bit sub. Pick up the BHA and hold a pre job safety meeting. Pick up the BHA to 61' and test the gyro and MWD in table. Pick up the BHA and make up the bit and scribe the MWD and gyro to 11' and latched up the collars and stab from the derrick. October 19, 2009: Trip in the hole with the BHA from 111' to 385' and circulate and condition the hole. Check on the MWD /GYRO shows trouble receiving T /BTM with pumps off. Rotary drill from 480' to 563' slide as directed by the directional driller. Survey every 30' and circulate and condition the hole due to lost circulation. A 50 bbl loss with 50% returns. Back down pumps to 7 bbl /min and maintained returns. Spot a 20 bbl 9.1+ LCM pill at 563' and stand back one stand of HWDP. Attempt to pump out from 563' and staged up the pumps to 12 bbl /min with 500 psi. Slight losses noticed; spot 27 bbls of 9.1+ LCM pill from 560' to 470'. Clean the suction screen on #2 mud pump and stage up pump to 12 bbl /min. No losses recorded and wash to bottom at 563'. Drill from 563' to 687' at 14 bbl /min with 850 psi and survey every 30'. Slide as directed by directional 59 • CANRIG Chevron • '''Chevron - Trading Bay Unit M -20 driller. Drill /slide from 687' to 936' at 15.5 bbl /min with 1100 psi. Continue to survey every 30' and slide /drill to 1208'. October 20, 2009: Circulate and condition the hole bottom's up. Continue drilling from 1216' and taking surveys every thirty feet to 1430'. Circulate bottoms up 2.5 times. Build mud volume and pump 50bbls of 9.2+ 180 viscosity nut plug around. Chase with 9.4+ 70 viscosity mud. Trip out of the hole and monitor the well. Well is static. Pull out of the hole from 1430' to 610'. Open hole log the well from 610' to 545'. Pull out of the hole from 545' to 210'. Stand back collars and lay down the BHA. Hook up the cement manifold and install the same. Remove the wear bushing and drain the stack and pull the wear ring. Trip in the hole with the wash tool on 5" HWDP to 450' and try to establish circulation. Circulation not established because of a packed off tool. Pull out of the hole wet and remove the bull nose off the tool. Found a rock. Change out the mule shoe and run in the hole to 450' and establish circulation. Drop the ball to open the sieve and wash down from 485' to 400' and pump 500 bbis with not much luck. October 21, 2009: Reaming and washing the hole from 485' to 400' and then pulled out of the hole from 485' to 90'. Rig up to run 13 3/8" casing. Install new cable on stabbing board and clean the flow box. Run casing from surface to 490'. Make up float equipment and bakerlok the same. Fill every joint and circulate and condition the hole. Make up the circulating swedge and fill the pipe. Circulate bottoms up and run casing from 470' to 935' and fill on the fly. Run casing from 935' to 971'. Pick up packer and pick up from 996' to 1335'. Make up extra joint and drive sub. A 16.5 bbl loss was recorded for the casing run. Run in the hole and wash through 1418' to 1426'. Circulate bottoms up and clean condition the mud to 9.5 ppg with a 68 viscosity. Stand back the drive sub and lay down joint #11. Make up hanger and landing joint. Tag at 1418' and rig up the circulating head. Wash to land and land the hanger. Bump 195 bbis and hold 500 psi for 5 minutes. Bleed down and check the floats and drop bomb load wiper. Cement in place at 23:07. Power down the S koomey, remove turnbuckles, remove koomey lines from the diverter valves and remove bolts from the south diverter valve. October 22, 2009: Pump 50 bbis of 9.8+ mud push and pump 150 bbis of 13 ppg cement, with 10.7 ppg cement to surface at 100 bbis sent away as returns to the J tube. Drain and blow down the water lines and clear the rig floor of Weatherford equipment. Clean the flow box and diverter system. Nipple down and set back the BOP on the stump. Nipple down the BOP equipment and remove the riser and N2 connection from the well head. Remove all iron from the rig floor to be inspected. Nipple down the BOP equipment and remove the spacer spool from the riser on the rig floor. Install double stud adapter on the riser. Install casing spools on the riser. Nipple up the BOP equipment and install the riser on the well head. Cut grading in the wellhead room to install the riser and annular valves. Remove the old kill line. Install the new kill line. Install three annular valves on the well head. Set the BOP on the riser. Tighten all the bolts in the well room and on the wellhead riser. Install and secure the scaffolding in the cellar. Install new kill lines on the BOP and install the bell nipples. Clean pits one through four and dump 232 bbis down the J tube. • 60 CANRIG Chevron immigi "•41111■Chevron • - Trading Bay Unit M -20 October 23, 2009: Nipple up BOP choke line and center the BOP with the turnbuckles. Install safety cables to the BOP. Grease the choke manifold and BOP valves and continue to mix the drilling mud. Lay down the BHA and move the 5" HWDP in the derrick. Grease and function test the IBOP valve. Troubleshoot and test the IBOP valve. Change out the IBOP on the top drive. Back flush, blow and work the mud pump suction header. Service the top drive and install handler saver sub lower IBOP, air bags and bails. Test BOP and fill the stack with water. Tighten leaking gland nut and install flange on the lower annulus valve to monitor the annulus. Test BOP bag to 250 psi low and 1000 psi high. Test all other valves and lines to 250 low and 3000 high. Test witnessed by AOGC Jeff Jones. A positive choke test on manual and super choke with a koomey test start pressure of 2950psi and after shut in —1300 psi with a 200 psi increase in 65 seconds full recovery. Pull the test plug after testing BOPE and space out the test joint to stand it back and set the wear ring. October 24, 2009: Work on miscellaneous work on the rig and pick up the BHA and orientate. Run in the hole from 94' to 230' and tag cement at 300'. Tag the wiper plug at 438' and the DV collar at 440'. Trip in the hole to 1328' and circulate and condition the well with the maximum units of gas was 4. Pressured tested the casing and held for thirty minutes. Drill out the shoe track and the trip gas was 43 units. Start to change over to the GEM mud and drill twenty foot of new formation to 1450'. Circulate and condition the drilling mud and prepare for the leak off test. October 25, 2009: Finish changing over the mud system and circulate and condition the drilling mud and performed a F.I.T. to 13.2 ppg, 290 psi. Drill and slide from 1450' to 2073'. Circulate and condition the hole because of hole drag and increased amount of cuttings. Drill and slide to 2203'. Circulate and condition the hole and pull out of the hole to 1698'. Hole is starting to swab with 10K over pull noted. Pump out of the hole to 1414' and circulate and condition the hole with increased cuttings. Pull out of the hole to 748' and lay down the BHA and pull out of the hole to 243' and service the rig. October October 26, 2009: Pick up 5" drill pipe and stand it back in the derrick. Pick up the BHA and make up the BHA to 105' and load the nuke sources. October 27, 2009: Surface test the MWD tool and trip in the hole from 762' to 1280'. Trip gas was 60 units. Mad pass the hole from 1280' to 1541' and pull out of the hole to the shoe and monitor the well. No mud losses noted. Service the rig and trip in the hole to 1823', in which a bridge was tagged. Wash down to 2137' and mad pass from 2137' to 2204'. No fill was noted at the bottom of the well and drilling ahead resumed. October 28, 2009: Drill formation to 3893' and serviced the rig and drilled formation to 5121'. October 29, 2009: Drill formation from 5121' to 5787'. Circulated and condition the drilling mud and pumped sweeps with returns of 874 bbls and 780 bbls early. Pull out of the hole to 4724' with 10- 15k hole drag. Pulled 30k over at 5030' and worked through tight spots. Pulled 40k over at 4727' and reamed the hole from 4727' to 4557' and back ream from 4557' to 2170' with lots of cuttings over the shakers. Mad pass the hole from 2170' to 1520' and then cut and slipped new drill line. October 30, 2009: Service the rig at the shoe and trip in the hole to 3706'. Fill the drill pipe and service the top drive. Pull out of the hole to 2370' and service the top drive again. Trip in the hole to 5455' and tag a bridge. Kelly up and wash down to 5506' and tag at 5324' and 4756', in which they were worked through without the rig pumps. Drill formation from 5791' to 6155'. Wiper gas was 81 units. 61 CANRIG Chevron "'MP/Chevron - Trading Bay Unit M -20 October 31, 2009: Drill formation from 6155' to 6738'. Pump sweeps with calculated returns. Circulate and condition the hole and drill to 6997'. Pump a sweep with calculated returns and service the rig. Drill to 7313' and circulate and condition the hole. Service the rig and then drill to 7503'. November 1, 2009: Drill formation from 7503' to 7780'. Pump a sweep with calculated returns. Drill to 8009' and pump a sweep with returns 300 strokes early. Pump a sweep at 7977' with returns 500 strokes early. Service the rig and drill formation to 8062' and tripped out of the hole. (due to 500 psi drill string loss [with the service equipment testing with no psi losses]). Begin to pump out of the hole at 4 bpm. November 2, 2009: Trip out of the hole from 5889' to 3700' with 50k over pull at 5668'. Work through and pull out of the hole to 3139' with 5 -10k hole drag. Trip out of the hole to the shoe (1425') and monitor the well. Service the rig and pull out of the hole and lay down the BHA. Stand back the HWDP and lay down the CCV tool. The collar is broken off under the stab. Clean the rig floor and service the top drive. Pick up the BHA and make up the over shot. Pick up the circulating sub and run in the hole to 967', in which a CO alarm went off. The well was secured and the mud pits cleared of CO. Trip into the hole to 1380'. November 3, 2009: Monitor the mud pits CO. content and service the rig. Circulate and condition the mud in which the H2S alarm went off. The well is secured and wait for an "all clear". All clear is given on the H2S and the rig was serviced. Circulated and conditioning of the drill mud is performed. Trip in the hole from 1380' to 7900'. The hole is tight at 7485' to 7498'. Pump through tight spots and circulate and condition the drilling mud. Trip gas was 86 units. Pump a sweep and start fishing. Swallowed the fish at 7903'. Attempt to pull the fish but the fish got away. Pull out of the hole for a smaller over shot tool. November 4, 2009: Trip out of the hole from 7641' to 6880' with 10 -15k hole drag. Circulate and spot a pill and trip out from 6880' to 1380' with 20 -30k over pull at 6340', 6278 - 6240', 6042', 5560', 5440 - 5320', 5308 - 5290', 5741' and work through all spots and monitor the well at the shoe for ten minutes. Hole mud losses averaged 1 bbl /hr. Pull out of the hole and stand back the BHA. No fish noted. Pick up a smaller over shot and service the rig. Trip in the hole with the smaller over shot to 7871'. Circulate and condition the mud with trip gas of 51 units. Commence fishing and latched onto the fish. Trip out of the hole from 7900' to 7170' and lost the fish. Chased the fish but halted upon high winds of 50 mph +. Circulate the well and move the drill pipe. November 5, 2009: Wait on the weather and continue to circulate the well at 10 bpm. Trip in the hole and wash down from 7176' to m7902' and went fishing. Catch the fish at 7903' in which the pump pressure psi increased 300 psi. The pumps were stopped and the drill string picked up over 25k over pull. Attempt to establish circulation at 2 bpm. Lost the fish and then rotated 15 rpm down onto the fish. Attempted circulation and lost the fish again. Caught the fish again and picked up 75k and pumped again. Lost the fish again at 400 psi. The top of the fish is at 7902'. Trip out of the hole from 7902' to 1185' and have a ten minute flow check and continue to pull out of the hole to the BHA. No fish noted with mud losses for the trip at 7 bbls. Lay down the BHA and test the BOPE. Pick up the BHA and make up the bit and two drill collars. November 6, 2009: Continue to pick up the BHA and run in the hole to 1400'. Circulate and condition the mud with a maximum gas reading of three units. Trip in the hole and ream clean the following sections: 4130 - 4160', 4675- 4690', 5804 - 5820', 5855 - 5868', 5870 -5966' and ream /wash from 7832' to 7922'. Circulate bottoms up with a 40% increase in cuttings. Tagged the fish at 7926'. Trip gas was 182 units. Pump a 73 bbl high viscosity sweep and circulate and condition the hole at 7918'. Pump a sweep with a 20% increase in cuttings at the shaker. Pull out of the hole to 6350' and pump a dry job. Pull out of the hole to 1425'. Hole was not tight coming out. Check the flow at the shoe = static. Pull out of the hole and lay down iron and pick up the BHA and make up the over shot. The over shot is the wrong size. Begin to service the rig. 62 CANRIG Chevron � hevron - Trading Bay Unit M -20 • • 63 CANRIG Chevron 411). C hevron - Trading Bay Unit M -20 • November 7, 2009: Service the rig and wait on third party tools. Pick up the BHA from surface to 1192' and make up the overshot. Pick up the jars and make up the BHA. Circulate and condition the mud at 1192'. Maximum gas was 3 units. Trip in the hole to 6510' and break circulation every ten stands. Circulate at 6510' with a maximum gas of 24 units. Trip in the hole to 7901' and circulate and condition the hole. Trip gas was 93 units. Latch onto the fish and begin to pull out of the hole slowly. November 8, 2009: Pull out of the hole to 1292'. Monitor the well, which is static. Pull out of the hole to 425' and hold a pre job safety meeting. Pull out of the hole to 48' and lay down the BHA, jars, bumpers and the fish. Lay down the third party tools and remove the nuke sources. Lay down the BHA and fished BHA. Clean the rig floor and pick up the new BHA. Trip into the hole and wash and ream at 4481 -4576' and 4702' to 4765'. Trip gas at midnight was 42 units. November 9, 2009: Washed and reamed from 7897' to 7991'. Mad passed the hole from 7991' to 8055'. Tagged hole fill at 8058' and trip gas was 91 units. Drill formation from 8062' to 8175' and service the rig. Drill formation from 8175' to 8240'. Circulate and condition the hole and pump a high viscosity sweep with a 30% increase in cuttings. Circulate and condition the well and check for flow. The well is static. Circulate and condition the hole for a wiper trip. November 10, 2009: Pull a wiper trip from 8240' to 7865' with a 25k over pull with no swabs and no fill on bottom. Wiper gas was 18 units. Circulate and condition the hole and pump a 57 bbl LCM pill with returns 20 bbls late with a 50% increase in cuttings. Pump a high viscosity sweep and pull out of the hole. Monitor the hole at 8213' and the hole is static. Pull out of the hole from 8213' to 1382'. Pulled 15 -25k over and worked through sections 5550 - 5524', 4700 -4259' and pull out of the hole from 1391' to the bit. Lay down 40 jars, tools and clean and clear the rig floor. Rig up casing equipment and hold a pre job safety meeting and service the rig. November 11, 2009: Run 9 5/8" casing from 85' to 1425'. Circulate and condition the hole. Maximum gas was 3 units. Run casing from 1425' to 3200'. Circulate and condition the mud. Maximum gas was 10 units. Run casing from 3200' to 4724' and circulate and condition the mud. Maximum gas was 26 units. Run casing from 4724' to 6185' and circulate and condition the mud. Maximum gas was 27 units. Run casing from 6185' to 7363'. November 12, 2009: Run casing from 7363' to 8191' and make up the landing joint. Wash down from 8191' to 8222'. Circulate and condition the hole with trip gas of 56 units. Work the casing 40' up and down while circulating. Rig up the cement manifold, install cement lines and hold a pre job safety meeting. Cement the casing to the hole with the casing set at 8222'. Rig down the cement head, lines, elevators, long bales and casing tongs and begin to rig up the tripping bales and elevators. Rig up tongs and begin to nipple BOPE. November 13, 2009: Lay down 9 5/8" test joint and clear the rig floor of excess tools. Make up 7" test joint and land the same. Change out the rams and lower rams from 9 5/8" to 7 ". Test BOPE and miscellaneous rig services performed. Mix new drilling mud, change out liners in #2 mud pump, pre job safety meeting, lay down test tools, break down test joint, blow down choke manifold + kill line and top drive. Check valve alignment, function test elmago controls, adjust handler on top drive, service the rig, pick up the PDC bit, stab, drill collars, stab, cross over, HWDP, and begin to run in the hole installing NRP on the drill pipe. 64 CANRIG Chevron • "mlIPP"Chevron - Trading Bay Unit M -20 November 14, 2009: Lay down the 5" drill pipe and trip in the hole from 2202' with XTM50 pipe. Trip in the hole from 2202' to 3435' and install NRP's (2 per joint). Fill the drill pipe at 2960' and trip in the hole from 3435' to 4099' without NPR's. Trip in the hole from 4099' to 5901' and install NPR's (2 per joint). Wash down from 5901' to 6006' and tag cement with 15k. Pump a 9.5 bpm with 900 psi. Cement pressure test the casing to 3000 psi for ten minutes with a 2% psi loss over ten minutes. Drill cement from 6002' to 6003' with wob of 3 -4k. Drill cement from 6003' to 6010' and chase hole junk from 6010' to 6469' at 120 rpm and 9 bpm. Chase junk from 6469' to 6945' and install NPR's. Circulate and condition the hole "bottoms up" with a maximum gas of 1 unit. Mud came back curdled; slow pump rates down and pressure test the casing shoe to 3000 psi and hold for 30 minutes. Break down the top drive choke manifold and the kill line. Service the top drive and work on the IBOP. Pull out of the hole and pump a dry job and pull out from 6945' to 2202'. November 15, 2009: Pull out of the hole from 2202' to the surface. Pick up the BHA and kelly up on the sub power and test at 10 bpm. The test is good. Break down the top drive and pick up the BHA and make up the smart iron from surface to 108'. Pick up the BHA and orient and load the nuke sources. Pick up the BHA from 108' to 415'. Work on the top drive electrical and service the rig. Trip in the hole from 415' to 1400' and fill the drill pipe. Test the MWD equipment and run in the hole to 3967'. Fill the drill pipe every 2000'. Trip in the hole from 3967' to 8051' and fill the drill pipe every 2000'. Wash and ream from 8051' to 8127'. Pump a high viscosity sweep and change over to the new mud. Change the oil in the top drive. The maximum gas tripping in the cased hole was 1 unit. November 16, 2009: Clean out the old mud system and all the mud pits. Drill out cement from 8205' to 8240' at 12.5 bpm. Drill the shoe from 8212' to 8214'. Drill formation from 8240' to 8260' and circulate the hole clean. Trip gas drilling the cement was 4 units. Circulate the hole and pull out of the hole from 8260' to 8146'. Run the F.I.T. and rig down and drill formation from 8260' to 8410'. • Open Rhino reamer and pull out of the hole and tag the shoe with the reamer. Ream back down to 8425' and drill formation from 8425' to 9091' at 13.8 bpm. Pump a sweep at 8870' with a 75% increase in cuttings at the shaker. Open hole log with the stethoscope hole at 180 fph from 9040' to 8995'. November 17, 2009: Open log the hole stisk test at 8995' and then wash down to 9091'. Drill formation from 9091' to 9122'. Mad Pass from 9111' to 9091'and then park the pipe with the probe at 9011'. Test was no good. Work the drill pipe and reoriented. Mad Pass from 9110' to 9091' with the test being good and then drill formation from 9122' to 10138'. Try to survey = no good. Drill ten feet to 10148'. Re -shot the survey and the survey was good. November 18, 2009: Drill formation from 10,148' to 10,324'. MAD pass hole from 10,317' to 10,298'. Park pipe at 10,298' with probe at 10,217' = test is good. Drill from 10,324' to 10,420. MAD pass from 10,417' to 10,362'. Park pipe at 10,362' probe at 10,286'. Drill from 10,420' to 10,500' (TD). Pump a sweep — returned at calculated strokes. Circulate and condition bottoms up, rotate and reciprocate the hole, pump a high viscosity sweep and rotate and reciprocate the hole. Rotate at 100 rpm while pulling pipe. Pull out of the hole from 10,500' to 8100'. Hole took 8.2 bbls over calculated displacement. Service the rig, drop Rhino dart, pull out of the hole from 8100' to 7956', to MAD pass depth. Circulate at 3.5 bpm to seat dart. Stage up pumps to 10 bpm — no bump. Circulate 4 drill pipe volumes and work pipe with no pumps and rotate = no good. Run in hole to 8430' and circulate at 11 bpm. Rotate drill pipe at 140 rpm, one drill pipe volume. No bump or pressure increase. Trip in hole from 8430' to 10,423' and wash down to 10,500 with 3' of fill. Wiper gas = 502 units. Circulate and condition the hole. Pump a high viscosity nut plug sweep and circulate at 13.3 bpm. November 19, 2009: Trip out of hole from 10,138' to 8296'. MAD pass hole from 8275' to 8230' at 120 fph. Pull 2 stands from 8230' to 8051'. MAD pass the hole from 8026' to 7956' at 120 fph. 65 • cavRIG Chevron M C hevron - Trading Bay Unit M -20 Monitor the well. Well is static. Change out elevators, pump a 21 barrel slug, and blow down the top drive. Trip out of the hole from 7956' to 743'. Strap the drill pipe. Trip out of the hole from 743' to 382'. Lay down the BHA and stand back 382' to 204'. Lay down BHA from 204' to 108'. Remove MWD sources, lay down BHA from 108' to 0'. Clear and clean the rig floor of tools. Static Toss rate's 1 bph. Rig up to run 7" casing. Service the rig. Pick up 7" liner, float equipment and begin to run 7" casing from 130'. November 20, 2009: Run liner to 2444' and change out elevators and pick up hanger and packer assembly. Install 7" wiper plug and make up the same. Circulate and condition the drilling mud with a maximum gas of 6 units. Make up the head pin and run the liner with 5 stands of 5" HWDP, 5 stands of 5" 4'/ IF drill pipe, 1 stand of 5" XTM drill pipe from 2482' to 3504'. Install the cement lines and make up the cement head. Run the liner with 5" XTM drill pipe from 3504' to 8148'. Fill the drill pipe at 4358' and 6255' with 5 units of gas noted. Circulate and condition and kelly up at 8148' and fill the drill pipe with a maximum gas of 5 units. Hold a safety meeting on the rig floor and wait on production power issues. Run the liner from 8147' to 10500'. Circulate and condition the well. Trip gas was 270 units. Work the drill string while circulating and cement the liner in place. 66 CANRIG • 0 • itiev 1111 11 01 Chevron - Trading Bay Unit M -20 4.2. SURVEY DATA Measured Vertical Course Depth Inclination Azimuth TVD _ Section +NS- +EW- Length DLS (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft ) (deg /100 ft ) 0.00 0.00 0.00 0.00 _ 0.00 0.00 0.00 0.00 0.00 347.15 0.12 168.38 347.15 _ 0.31 -0.36 0.07 347.15 0.03 434.01 0.32 11.92 434.01 0.14 -0.21 0.14 86.86 0.50 465.23 0.43 340.37 465.23 -0.03 -0.01 0.12 31.22 0.74 494.73 0.88 320.74 494.73 -0.23 0.27 -0.06 29.50 1.68 525.78 1.51 318.85 525.77 -0.53 0.76 -0.48 31.05 2.03 554.23 1.96 310.67 554.21 -0.87 1.36 -1.10 28.45 1.80 584.38 2.81 302.61 584.33 -1.19 2.09 -2.11 30.15 3.02 614.43 3.67 294.93 614.33 -1.39 2.90 -3.60 30.05 3.20 644.21 4.83 288.51 644.03 -1.39 3.70 -5.66 29.78 4.20 674.32 6.17 285.79 674.00 -1.18 4.54 -8.41 30.11 4.53 704.13 7.67 283.87 703.59 -0.77 5.45 -11.89 29.81 5.09 734.61 9.27 281.86 733.74 -0.11 6.44 -16.27 30.48 5.34 765.70 10.85 280.37 764.35 0.85 7.49 -21.59 31.09 5.15 799.00 12.47 278.90 796.96 2.21 8.61 -28.23 33.30 4.95 829.16 14.05 274.67 _ 826.32 3.95 _ 9.41 -35.10 30.16 6.14 861.64 15.88 273.23 857.70 6.45 9.98 -43.46 32.48 5.75 892.32 17.28 273.95 887.10 9.11 10.53 -52.20 30.68 4.61 924.59 18.97 271.42 917.77 12.31 10.99 -62.23 32.27 5.78 955.56 20.20 270.75 946.94 15.89 11.18 -72.61 30.97 4.04 988.47 21.38 272.32 977.71 19.83 11.50 -84.28 32.91 3.96 1019.27 22.71 270.84 1006.26 23.72 11.82 -95.84 30.80 4.68 1050.65 24.09 269.55 1035.06 28.20 11.85 - 108.30 31.38 4.69 1083.37 25.40 268.59 1064.77 33.38 11.63 - 121.99 32.72 4.19 67 CANRIG • S • Chevron Chevron - Trading Bay Unit M -20 1114.16 26.73 268.52 1092.43 38.60 11.29 - 135.51 30.79 4.32 Measured Vertical Course Depth Inclination Azimuth TVD Section +NS- +EW- Length DLS (ft ) (deg) (deg) (ft ) (ft) (ft) (ft) (ft ) (deg /100 ft) 1144.99 28.03 268.08 1119.81 44.12 10.87 - 149.69 30.83 4.27 1177.66 29.58 269.25 1148.43 50.17 10.50 - 165.42 32.67 5.05 1209.28 30.92 268.57 1175.75 56.22 10.20 - 181.35 31.62 4.37 1240.43 31.97 269.54 1202.32 62.36 9.93 - 197.60 31.15 3.74 1272.22 33.37 268.87 1229.08 68.80 9.69 - 214.75 31.79 4.55 1300.45 34.26 268.96 1252.54 74.77 9.40 - 230.46 28.23 3.16 1331.32 35.60 268.34 1277.85 81.57 8.98 - 248.13 30.87 4.49 1351.60 36.57 267.88 1294.23 86.26 8.58 - 260.07 20.28 4.97 1487.69 43.82 266.83 1398.12 121.87 4.47 - 347.74 136.09 5.35 1519.88 45.46 266.19 1421.02 131.33 3.09 - 370.32 32.19 5.28 1614.41 49.87 263.99 1484.67 162.17 -2.93 - 439.91 94.53 4.97 1709.00 54.67 261.55 1542.55 197.88 _ -12.39 - 514.09 94.59 5.47 1805.57 58.80 259.27 1595.51 239.29 -25.88 - 593.67 96.57 4.71 1899.30 62.89 257.22 1641.17 _ 283.89 -42.58 - 673.78 93.73 4.76 1992.66 66.71 255.20 1680.91 332.40 -62.73 - 755.80 93.36 4.54 2088.90 70.88 251.69 1715.72 387.40 -88.32 - 841.75 96.24 5.51 2122.71 72.54 250.43 1726.34 408.12 -98.75 - 872.12 33.81 6.05 2206.14 76.33 247.36 1748.72 462.26 - 127.69 - 947.06 83.43 5.76 2301.85 78.17 248.44 1769.85 526.34 - 162.81 - 1033.55 95.71 2.22 2396.99 77.77 248.20 1789.68 589.71 - 197.18 - 1120.02 95.14 0.49 2491.42 77.27 247.91 1810.08 652.82 - 231.64 - 1205.54 94.43 0.61 2585.96 77.48 248.37 1830.75 715.87 - 265.99 - 1291.16 94.54 0.52 2680.87 77.12 248.23 1851.61 778.95 - 300.22 - 1377.18 94.91 0.41 2774.73 76.77 248.47 1872.81 841.20 - 333.96 - 1462.17 93.86 0.45 2869.26 76.77 248.74 1894.45 903.54 - 367.53 - 1547.85 94.53 0.28 68 CANRIG • • • Chevron 11 111 111 Chevron - Trading Bay Unit M -20 Measured Vertical Course Depth Inclination Azimuth TVD Section +NS- +EW- Length DLS (ft) (deg) (deg) (ft) (ft) (ft ) (ft) (ft ) (deg /100ft ) 2964.99 76.97 248.56 1916.19 966.64 - 401.47 - 1634.68 95.73 0.28 3060.63 77.68 248.55 1937.18 1029.91 - 435.58 - 1721.53 95.64 0.74 3155.40 78.12 248.78 1957.04 1092.62 - 469.29 - 1807.84 94.77 0.52 3247.85 78.12 247.85 1976.08 1154.24 - 502.72 - 1891.91 92.45 0.98 3344.24 77.97 247.74 1996.04 1219.10 - 538.36 - 1979.21 96.39 0.19 3438.88 77.91 247.74 2015.82 1282.82 - 573.42 - 2064.87 94.64 0.06 3531.17 77.91 246.81 2035.15 1345.48 - 608.28 - 2148.10 92.29 0.99 3627.35 77.82 246.74 2055.36 1411.35 - 645.36 - 2234.51 96.18 0.12 3721.63 77.50 245.72 2075.51 1476.50 - 682.48 - 2318.80 94.28 1.11 3817.73 76.92 243.37 2096.79 1544.70 - 722.76 - 2403.41 96.10 2.46 3912.23 75.71 241.82 2119.15 1613.63 - 765.01 - 2484.92 94.50 2.04 4002.14 74.91 238.08 2141.96 1681.49 _ - 808.55 - 2560.19 89.91 4.12 4102.15 73.46 233.41 2169.23 1760.76 - 862.68 - 2639.71 100.01 4.72 4196.75 70.63 227.80 2198.41 1839.13 - 919.74 - 2709.23 94.60 6.38 4290.89 68.26 222.02 2231.48 1919.81 - 982.10 - 2771.45 94.14 6.28 4323.57 67.70 220.61 2243.74 _ 1948.26 - 1004.86 - 2791.45 32.68 4.35 4385.58 66.24 218.03 2268.00 2002.51 - 1049.00 - 2827.61 62.01 4.51 4481.08 63.60 214.77 2308.48 2085.97 - 1118.59 - 2878.94 95.50 4.14 4577.01 60.39 211.12 2353.53 _ 2168.87 - 1189.62 - 2925.02 95.93 4.74 4671.91 57.65 210.01 2402.38 2249.15 - 1259.66 - 2966.40 94.90 3.06 4766.71 55.33 208.94 2454.71 2327.37 - 1328.46 - 3005.29 94.80 2.62 4860.70 54.28 205.82 2508.89 2403.72 - 1396.64 - 3040.62 93.99 2.93 4956.52 54.91 201.56 2564.42 2481.72 - 1468.14 - 3071.98 95.82 3.68 5052.48 54.48 197.56 2619.90 2559.97 - 1541.91 - 3098.19 95.96 3.43 5147.20 54.15 193.24 2675.17 2636.47 - 1616.05 - 3118.62 94.72 3.72 69 CANRIG 0 • • ciiiiii 11111 1 0 Chevron - Trading Bay Unit M -20 Measured Vertical Course Depth Inclination Azimuth TVD Section +NS- +EW- Length DLS (ft ) (deg) (deg) (ft) (ft) (ft ) (ft) (ft ) (deg/100ft) 5240.81 53.86 187.88 2730.21 2710.85 - 1690.45 - 3132.50 93.61 4.64 5335.15 53.73 182.98 2785.96 2784.06 - 1766.20 - 3139.70 94.34 4.19 5430.34 53.58 178.93 2842.38 2855.94 - 1842.83 - 3140.98 95.19 3.43 5524.50 54.25 173.97 2897.87 2924.98 - 1918.74 - 3136.26 94.16 4.32 5620.69 54.40 170.21 2953.98 2993.19 - 1996.11 - 3125.51 96.19 3.18 5712.97 54.73 169.06 3007.48 3057.22 - 2070.07 - 3111.98 92.28 1.08 5811.78 55.04 168.85 3064.32 3125.54 - 2149.40 - 3096.49 98.81 0.36 5906.85 53.99 168.69 3119.50 3190.84 - 2225.33 - 3081.42 95.07 1.11 6001.33 54.23 168.87 3174.89 _ 3255.42 - 2300.41 - 3066.53 94.48 0.30 6098.79 53.71 170.05 3232.22 3322.41 - 2377.89 - 3052.11 97.46 1.12 6194.70 53.37 171.14 3289.21 3388.77 - 2453.99 - 3039.50 95.91 0.98 6287.87 53.80 170.77 3344.52 3453.50 - 2528.03 - 3027.71 93.17 0.56 6383.37 53.89 170.27 3400.86 3519.78 - 2604.09 - 3015.01 95.50 0.43 6478.20 54.00 169.82 3456.68 3585.36 - 2679.60 - 3001.76 94.83 0.40 6572.77 53.98 169.43 3512.28 3650.50 - 2754.85 - 2987.98 94.57 0.33 6668.28 54.13 169.28 3568.34 3716.14 - 2830.84 - 2973.70 95.51 0.20 6762.43 54.61 168.61 3623.19 3780.82 - 2905.94 - 2959.02 94.15 0.77 6858.64 54.32 169.80 3679.11 3847.18 - 2982.85 - 2944.36 96.21 1.05 6951.23 54.14 170.49 3733.23 3911.51 - 3056.86 - 2931.50 92.59 0.64 7046.85 54.40 170.18 3789.07 3978.10 - 3133.38 - 2918.47 95.62 0.38 7144.68 54.64 170.45 3845.85 4046.43 - 3211.91 - 2905.07 97.83 0.33 7239.80 54.99 170.03 3900.66 4113.06 - 3288.53 - 2891.89 95.12 0.52 7331.69 54.93 170.39 3953.42 4177.52 - 3362.67 - 2879.09 91.89 0.33 7425.99 54.66 169.66 4007.79 4243.41 - 3438.55 - 2865.75 94.30 0.69 7522.99 54.32 169.18 4064.13 4310.50 - 3516.17 - 2851.25 97.00 0.53 70 CANRIG • S • ciiiii Chevron - Trading Bay Unit M - Measured Vertical Course Depth Inclination Azimuth TVD _ Section +NS- +EW- Length DLS (ft) (deg) (deg) (ft ) (ft) (ft) (ft) (ft) (deg /100ft) 7617.57 54.25 168.42 4119.34 4375.30 - 3591.50 - 2836.34 94.58 0.66 7712.51 53.23 166.57 4175.50 4438.95 - 3666.23 - 2819.77 94.94 1.90 7805.48 52.15 164.36 4231.85 4498.93 - 3737.80 - 2801.22 92.97 2.22 7901.68 50.94 162.45 4291.68 4558.42 - 3810.00 - 2779.72 96.20 2.00 7988.29 50.02 160.21 4346.80 4609.66 - 3873.29 - 2758.34 86.61 2.26 • 8082.55 50.31 160.41 4407.18 4664.34 - 3941.43 - 2733.96 94.26 0.35 8175.70 49.73 159.86 4467.03 4718.11 - 4008.57 - 2709.70 93.15 0.77 8270.10 49.44 159.96 4528.23 4772.08 _ - 4076.06 - 2685.02 94.40 0.32 8363.91 46.64 159.82 4590.95 4824.43 - 4141.56 - 2661.04 93.81 2.99 8459.78 42.24 159.62 4659.38 4874.67 - 4204.51 - 2637.78 95.87 4.59 8553.24 37.95 159.67 4730.86 4919.67 - 4260.94 - 2616.85 93.46 4.59 8646.45 33.19 156.81 4806.66 4959.35 - 4311.29 - 2596.83 93.21 5.41 8743.84 31.56 151.12 4888.93 4994.73 - 4358.13 - 2574.02 97.39 3.55 8838.52 32.90 144.41 4969.04 5024.69 - 4400.75 - 2547.07 94.68 4.03 8933.08 33.64 142.03 5048.11 5052.14 - 4442.29 - 2516.01 94.56 1.59 9027.96 34.80 140.96 5126.56 5079.01 - 4484.03 - 2482.79 94.88 1.38 9123.66 34.66 142.23 5205.21 5106.55 - 4526.76 - 2448.92 95.70 0.77 9218.56 35.25 145.29 5283.00 _ 5135.78 - 4570.60 - 2416.79 94.90 1.95 9313.24 35.12 148.13 5360.39 5167.42 - 4616.19 - 2386.86 94.68 1.73 9408.00 35.12 150.17 5437.90 5200.90 - 4662.99 - 2358.90 94.76 1.24 9503.51 35.15 152.82 5516.01 5236.40 - 4711.28 - 2332.68 95.51 1.60 9598.35 34.91 153.81 5593.67 5272.87 - 4759.92 - 2308.23 94.84 0.65 9692.85 35.40 152.94 5670.93 5309.37 - 4808.56 - 2283.84 94.50 0.74 9787.91 35.39 151.72 5748.42 5345.55 _ - 4857.32 - 2258.28 95.06 0.74 9882.96 35.24 152.03 5825.98 5381.32 - 4905.78 - 2232.37 95.05 0.25 71 CANRIG • S S fie Chevron - Trading Bay Unit M -20 Measured Vertical Course Depth Inclination Azimuth TVD Section +NS- +EW- Length DLS (ft) (deg) (deg) (ft ) (ft) (ft) (ft) (ft) (deg /100ft) 9977.63 35.44 153.76 5903.20 5417.71 - 4954.52 - 2207.43 94.66 1.08 10,073.03 35.59 154.71 5980.86 5455.49 - 5004.43 - 2183.34 95.41 0.60 10,167.35 35.45 155.19 6057.63 5493.35 - 5054.07 - 2160.14 94.32 0.33 10,262.15 35.58 156.08 6134.80 5531.87 - 5104.24 - 2137.42 94.80 0.56 10,357.09 35.68 156.98 6211.96 5571.17 - 5154.97 - 2115.39 94.94 0.56 10,435.99 34.59 156.30 6276.49 5603.50 - 5196.66 - 2097.39 78.90 1.47 72 CANRIG ! • ! Ch Chevron - Trading Bay Unit M -20 4.3. MUD RECORD Contractor: Baroid Mud Type: 2% KCL Clayseal GEM (API Pre - Defined System) DATE DEPTH MW VIS PV YP GELS FL FC SOLIDS OIL/WATER SAND MBT pH CI Ca 10/18/09 480 9.1 69 18 25 8/10/14 5.6 2/- 4.7 -/95.0 - 12.0 9.0 1100 20 10/19/09 1216 9.3 74 19 25 8/15/18 5.2 2/- 6.7 -/93.0 - 15.0 8.5 1000 20 10/20/09 1440 9.45 73 24 27 7/15/- 4.0 1/- 7.8 -/92.0 0.15 11.0 9.2 340 40 10/21/09 1430 9.5 67 19 18 7/19/29 4.5 2/- 8.2 -/91.5 0.50 12.0 8.5 1000 80 10/22/09 1430 9.5 55 12 17 7/18/28 4.6 1/- 8.2 -/91.5 0.50 12.0 8.6 1000 80 10/23/09 1430 9.1 50 7 15 5/6/8 6.2 1/- 3.2 -/96.0 - - 9.4 8200 40 10/24/09 1450 9.1 47 9 13 4/5/6 6.5 1/- 3.2 -/96.0 - - 9.5 8300 - 10/25/09 2205 9.3 48 10 18 6/7/7 5.3 1/- 5.7 -/93.5 0.50 2.0 9.0 9000 80 10/26/09 2205 9.3 47 9 16 6/7/7 5.5 1/- 5.7 -/93.5 0.10 2.0 8.9 9000 80 10/27/09 2972 9.25 49 13 19 8/10/12 6.0 1/- 6.1 -/93.0 0.10 5.0 8.8 10000 120 10/28/09 5100 9.3 51 14 18 5/8/11 5.0 1/- 6.5 -/92.5 1.00 8.5 8.4 11000 360 10/29/09 5787 9.45 48 13 16 4/9/12 5.2 1/- 7.9 -/91.5 1.00 7.5 8.5 5500 280 10/30/09 6200 9.45 48 13 16 5/14/17 5.8 1/- 7.9 -/91.5 1.00 11.0 8.5 6000 340 10/31/09 7503 9.5 50 16 18 6/17/23 4.9 1/- 8.1 0.5/90.5 0.50 12.5 8.9 11000 280 11/01/09 8062 9.55 59 23 23 7/21/23 4.5 1/- 10.8 0.1/88.0 0.50 14.0 8.9 14000 240 11/02/09 8062 9.4 85 21 19 7/15/19 5.8 1/- 7.7 0.1/91.0 0.10 15.0 8.6 15000 280 11/03/09 8062 9.6 59 18 24 7/22/30 5.6 1/- 8.3 0.5/90.0 0.10 15.0 8.5 15000 800 11/04/09 8062 9.5 54 15 18 6/20/27 6.2 1/- 7.4 0.5/91.0 0.10 12.5 8.8 13000 840 73 CANRIG • 0 • cnu 10 10 1 Chevron - Trading Bay Unit M -20 11/05/09 8062 9.5+ 52 14 20 8/20/26 7.2 1/- 7.8 0.5/90.5 0.10 12.5 8.5 15000 780 DATE DEPTH MW VIS PV YP GELS FL FC SOLIDS OIL/WATER SAND MBT pH CI Ca 11/06/09 8062 9.5+ 60 14 20 7/23/30 7.6 1/- 7.9 0.5/90.5 0.10 15.0 8.5 13500 640 11/07/09 8062 9.5+ 55 18 22 9/24/32 7.2 1/- 7.8 0.5/90.5 0.10 12.5 8.5 14000 600 11/08/09 8062 9.6 67 16 23 8/23/31 8.2 1/- 8.0 0.4/90.5 0.10 15.0 8.6 13500 580 11/09/09 8235 9.3+ 46 14 22 7/16/18 9.0 1/- 6.2 0.2/92.4 0.10 10.0 9.2 14500 400 11/10/09 8240 9.5 54 18 21 7/13/17 7.6 1/- 7.6 0.2/91.0 0.10 12.5 9.2 15000 240 11/11/09 8240 9.5 60 17 27 10/18/24 7.0 1/- 7.3 0.1/91.4 0.10 12.5 8.6 14500 240 11/12/09 8240 9.5 48 14 20 8/18/23 8.0 1/- 7.4 0.3/91.2 0.10 10.0 7.5 13500 300 11/13/09 8240 9.5 80 9 33 12/17/23 8.0 1/- 6.7 0.2/92.0 0.10 10.0 8.0 13000 300 - 11/14/09 8240 9.4 45 15 20 8/17/22 9.0 1/- 6.8 0.1/92.0 0.10 10.0 8.5 13000 300 11/15/09 8240 9.2+ 44 9 12 4/6/6 5.5 1/- 4.0 -/95.0 - - 9.5 11000 80 11/16/09 9000 9.2+ 43 12 20 5/8/11 4.5 1/- 3.1 0.5/95.0 - - 9.0 16500 300 11/17/09 9200 9.2+ 43 13 18 5/8/11 4.5 1/- 3.1 0.5/95.0 - 5.0 9.0 16000 300 11/18/09 10,500 9.2 44 12 21 5/7/9 3.8 1/- 4.2 2.0/92.0 1.00 5.0 9.0 22000 340 11/19/09 10,500 9.2 47 12 18 5/6/8 3.8 1/- 4.2 2.0/92.0 1.00 5.0 9.0 22000 320 11/20/09 10500 9.2+ 46 13 16 5/6/8 3.9 1/- 4.2 2.0/92.0 1.0 5.0 9.0 22000 320 74 CANRIG S • • Chevron hevron - Trading Bay Unit M -20 BIT RECORD BIT NO SIZE " MK TYPE S/N JETS/TFA IN OUT FEET HOURS AVE WOB CONDITION 1 17.5 HTC GTX -C1 6058303 3x18, 1x20 480' 1430' 950' 9.66 137.1 14.8 1- 1- WT- A- E- 1 /16 -WT -TD 2 12.25 STC XR +C PJ4206 3x18, 1x15 1430' 2204' 774' 7.51 121.4 22.7 1- 1- BT- A- E -1 -WT -BHA 3 12.25 STC MSi -616 JY7275 6x13 2204' 8062' 5859' 41:59 145 6 TF 2rr1 12.25" STC XR +C PJ4206 3X18, 1X15 8062' 8062' 0 0 0 0 CLEAN OUT RUN 4 12.25" STC MSI -616 JY6074 6X13 8062' 8240' 178 14:00 31 3.8 1- 1- NO- A- X -I -TD 5 12.25" STC MSI -616 JD1265 3X11,3X12 8240' 8240 0 0 0 0 CLEAN OUT RUN 6 12.25" STC MSI -616 JD1264 3X11, 3X12 8240' 10500' 2260' 15:30 85 8.5 5- 3- CT- A- X- I -BT -TD 75 CANRIG 0 DEPTH (FT) 1 g 1 1 1 g 1 1 I g g g . D 10/12/09 • -< C,) 10/13/09 - • 10/14/09 - • cn 10/15/09 - • 0 m 10/16/09 • -0 H 10/17/09 - I 10/18/09 - 10/19/09 - 10/20/09 - 10/21 /09 - • 10/22/09 - • 10/23/09 - • 10/24/09 - 10/25/09 - (t. 10/26/09 - o m- 10/27/09 10/28/09 10/29/09 4 • 10/30/09 a 10/31/09 3 o rM 11/1/09 N 11/2/09 - 11/3/09 • f8 I N 0 11/4/09 - • 11/5/09 • 11/6/09 - 11 /7/09 - 11 /8/09 - 11 /9/09 - 11 /10/09 - 11/11/09 - 11 /12/09 - • 1 1 1 11 /13/09 - • T T T OD 1 11/14/09 • N N 1 1 /15/09 • x - 11 /16/09 - • c q. _ _ 11/17/09 - • m m Cl) 11/18/09 - • • rn 11/19/09 - • 11/20/09 • • • Chevron 111 110 1 Chevron - Trading Bay Unit M -20 5. DAILY REPORTS 77 CANRIG Daily Report Page 1 of 1 Chevron EPOCH TBU DAILY WELLSITE REPORT PI M -20 REPORT FOR Dave Smith / Shane Hauck • DATE Oct 16, 2009 DEPTH 80 PRESENT OPERATION General rig up operations TIME 2400 YESTERDAY 80 24 HOUR FOOTAGE 0 CASING INFORMATION 2T @ 480' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH Surface MW 89 VIS 69 PV 20 YP 24 FL 65 Gels 7/10/14 CL- 700 FC 2 SOL 42 SD 025 OIL 0/95.5 MBL 120 pH 90 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (0-4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION III LITHOLOGY PRESENT LITHOLOGY General rig up operations Test platform deluge system, and then drain lines and reactivate Inspect derrick Change out derrick lights Lay out and strap 13 3/8" casing. Tighten drverter line clamps Dress now line DAILY teeter -totter in subbase Adjust derrick stop beam. Attach topdrive hydraulic lines and flush through by -pass Load 1502 rack Make up and run 20 5/8" drift in conductor. Drift stack to load shoulder on starting head ACTIVITY (79.86') and the pull out and lay down Hold Pre -Spud meeting with all hands Open topdrrve hydraulic lines and check gripper bite height for HT drill pipe Nipple up diverter lines. Install and torque main bolts on SUMMARY north -south lines Function test drverter Function both remote panels Performance test accumulator Test assembled Gyrodata tools and install in drill collar. Adjust bell nipple Do hydrostatic check of stack and valves Leaks observed in both north and south valves Troubleshoot and perform various corrective actions on leaking valves Install cameras at derrick board and above V -door and run respectrue cables Begin pumping cement onto platform. Test Gyrodata secondary tool assembly Hook up fill and steam lines to R4R tank EPOCH PERSONNEL ON BOARD 2 C.Silva, J.Dubowski DAILY COST DML: 3425 RW: 1265 REPORT BY Josh Dubowski ID file: / /C:\Documents and Settings\Administrator \My Documents\My Wells \M -20 \Morn rp... 10/17/2009 Daily Report Page 1 of 1 Chevron EPOCH DAILY WELLSITE REPORT HI M -20 REPORT FOR Dave Smith / Shane Hauck ID DATE Oct 17, 2009 DEPTH 80 PRESENT OPERATION General rig up operations TIME 2400 YESTERDAY 80 24 HOUR FOOTAGE 0 CASING INFORMATION 20" ilg 480' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/FIR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 89 VIS 69 PV 19 YP 25 FL 65 Gels 8/11/15 CL- 700 FC 21- SOL 42 SD - OIL -/955 MBL 12 pH 9 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE(C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION ID LITHOLOGY PRESENT LITHOLOGY Miscellaneous work as directed by operator. troubleshoot and repairsouth diverter valve String /plug in cameras in derrick Fill tiger tank w/445 bbls FIW M/U steam T /same M/U 9 5/8" test Joint and wash tool DAILY stand back in derrick C/O inserts iron roughneck on job training drverter drill abandon platform drill and lessons learned M/U was tool stand back in derrick. nipple up /down BOP's Nipple up /down drverter system. ACTIVITY tighten bolts on south diverter line bring wear ring and handling equipment to the floor MN drive sub to XO and stand back pick up drill pipe P/U 3 joints of HWDP M/U wear ring running tool BOP TEC drverter SUMMARY drill Service rig Drill and tap iron roughneck head bolt grease leaking north drverter valve BOP ETC firre alarm, SW upper well bay all hands musterd Install/remove wear bushing land wear nng well head started leaking troubleshoot pull wear ring PJSM, pull flow riser remove turn - buckles start nipping down drverter valves for well head nipple down P/U 9 HWDP stand back EPOCH PERSONNEL ON BOARD 2 C. Silva, J. Dubowski DAILY COST DML: 3425 RW: 1265 REPORT BY Josh Dubowski file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 10/18/2009 Daily Report Page 1 of 1 Chevron EPOCH DAILY WELLSITE REPORT Ell M -20 REPORT FOR Dave Smith / Shane Hauck 4111 DATE Oct 18, 2009 DEPTH 480 PRESENT OPERATION Topping TIME 2400 YESTERDAY 80 24 HOUR FOOTAGE 400 CASING INFORMATION 20" @ 480' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 17 5" Hughes GTX -C1 6058303 3x18 1014 TFA= 896 480' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 91 VIS 69 PV 18 YP 25 FL 5.6 Gels 8/10/14 CL- 1100 FC 2/- SOL 4 7 SD OIL 0/95 5 MBL 12 pH 9 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 34 @ 454 0 @ 384 11 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE(C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION • LITHOLOGY PRESENT LITHOLOGY P/U 3 stands of HWDP. Reload skate W/D P & D C skate not working, troubleshoot N/D north and south drverter remove turnbuckles remove covers around nser P/U BOP, riser, starting head and install N2 DAILY gasket, lower and M/U same instalVremove wear bushing set wear ring - I D = 17 75" 13 3/8" drive sub on bottom stand, rack in derrick install pitcher nippl, air up same, continue Range up drverter lines fill drverter ACTIVITY w /FIW pick up BHA MN stands of 8" NM D C. fluid test BOPS and drverter valves M/U be, bit sub and 17 1/2" stabilizer circulate and condition. RIH to 383' tag circulate and displace to spud mud @9ppg and 58 SUMMARY vis dump 306 bbl FlWdown the J tube Rotary drilling drill 1/383' to 480' stage up pumps700 gpm @ 850 psi. 80 -100 rpm 4 -5 tq circulate and condition @700 gpm, @ 100gpm 4 tq bring vis up to 70 MW @ 9 2 trip out of hole 1 /480'. pumping out to 200' @ 650 gpm 80 rpm stand back collars break out bit and bit sub P/U BHA PJSM, PN BHA to 61' test gyro and MWD in table P/U BHA M/U bit and scribe MWD and gym to 111'. latch up collars and stab from derrick EPOCH PERSONNEL ON BOARD 2 C. Silva J. Dubowski DAILY COST DML: 3425 RW: 1265 REPORT BY Josh Dubowski • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 10/19/2009 Daily Report Page 1 of 1 Chevron EPOCH DAILY WELLSITE REPORT M -20 • REPORT FOR Shane Hauck / David Smith DATE Oct 19, 2009 DEPTH 1208 PRESENT OPERATION Dulling TIME 2400 YESTERDAY 480 24 HOUR FOOTAGE 728 CASING INFORMATION 20" @ 480' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1019 27 22 71 270 84 100626 1050 65 24 09 269.55 1035.06 SURVEY DATA 1083 37 25 4 268 59 1064.77 114.16 26 73 268 52 1092 43 1144 99 28 03 268 08 1119.81 BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 17 5" Hughes GTX -C1 6058303 3x18 1014 TFA= 896 480' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1655 2 © 1121 17 8 @ 524 147 0 221 FT /HR SURFACE TORQUE 9922 @ 1178 1660 CO 524 16120 0 AMPS WEIGHT ON BIT 36 @ 1200 1 @ 1121 14 8 14 KLBS ROTARY RPM 64 @ 486 0 @ 612 147 0 RPM PUMP PRESSURE 1503 @ 1087 578 @ 486 10406 1195 PSI DRILLING MUD REPORT DEPTH 1100' MW 93 VIS 74 PV 19 YP 25 FL 52 Gels 8/15/18 CL- 1000 FC 2/- SOL 67 SD OIL -/93 MBL 15 pH 85 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 258 @ 879 2 @ 541 66 TRIP GAS CUTTING GAS 0 @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 51779 @ 879 472 @ 541 10189 CONNECTION GAS HIGH 71 ETHANE (C -2) @ @ AVG 21 PROPANE (C -3) @ @ CURRENT 61 BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG 36 • PENTANE (C @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TIH w /BHA from 111' to 385'. circulate and condition check MIND /GYRO trouble gettm T /BTM w /pumps off 6/0 single and make connection rotary dulling from 480'563' slide as directed by driller survey every DAILY 30' Circulate and condition due to lost circulation 50 bbl loss w/50% returns back down pumps to 7 bbls /min maintain returns spot 20 bbls 9 1 +ppg LCM pill @ 563' stand back 1 stand of HWDP. attempt to ACTIVITY pump out from 563'stage up pump to 12bbls/min with 500 psi slight losses spot 27 bbls of 9 1• LCM pilifrom 560' to 470' clean suction screen 82 mud pumpstage up pump to 12 bbl/min no losses wash to SUMMARY bottom © 563' Drill from 563'-687 @ 14 bbls/min w/850 psisurvey /gyro every 30' slide as directed by dnllerback ream slides slide drilling from 687' to 936 @ 15 5 bbls /minw /1100 psi continue surveying every 30' slide dnlhng to 1208 at report time EPOCH PERSONNEL ON BOARD 2 C. Silva J. Dubowski DAILY COST DML: 3425 RW: 1265 REPORT BY J. Dubowski IP file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 10/20/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR Mike Leslie / David Smith DATE Oct 20, 2009 DEPTH 1430 PRESENT OPERATION preping to run 13 3/8" casing TIME 24:00 YESTERDAY 1216 24 HOUR FOOTAGE 214 CASING INFORMATION 20" @ 480' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1240.43 31.97 269.54 1202.32 SURVEY DATA 1272.22 33.37 268.87 1229.08 1300.45 34.26 268.96 1252.54 1331.32 35.60 268.34 1277.85 1351.60 36.57 267.88 1294.23 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 17.5" GTX -C1 6058303 3x18 1x14 TFA =.896 480 1430 950 9:39:42 1- 1- WT- A- E- 1 -NO -TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 297.3 @ 1251 29.4 © 1372 100.5 58 FT /HR SURFACE TORQUE 8522 @ 1314 3439 @ 1320 1839.9 0 AMPS WEIGHT ON BIT 28 @ 1334 0 @ 1406 14.8 15.6 KLBS ROTARY RPM 63 @ 1275 0 @ 1234 15.4 0 RPM PUMP PRESSURE 1432 © 1280 846 @ 1395 1072.6 942.1 PSI DRILLING MUD REPORT DEPTH 1430 MW 9.45 VIS 73 PV 24 YP 27 FL 4 Gels 7/15/- CL- 340 FC 1/- SOL 7.8 SD 0.15 OIL -/92 MBL 11 pH 9.20 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS al GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 269 @ 1413 22 @ 1217 72.5 TRIP GAS 0 CUTTING GAS 0 © 1430 0 @ 1430 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 53969 @ 1413 4494 © 1217 14503.5 CONNECTION GAS HIGH 0 ETHANE (C -2) 8 @ 1413 0 @ 1405 0.5 AVG 0 PROPANE (C -3) @ @ CURRENT 0 BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 29 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 40% Sand 30% Tuffaceous siltstone 10% shale 10% coal 10% Sandstone PRESENT LITHOLOGY 70% Sand 10% Siltstone 10% Tuffaceous claystone 10% Circulate and Condition, circulate btms up. repair /tightne thread ed conn. on std pipe manifold. continue drilling from 1216' taking survey /gyro every 30'. drill to TD @ 1430' MD. CBU 2.5x. pull suction screen on mud pump #2. clean suction screen on mud pump #1. build volume, weight DAILY pump 50 bbls of 9.2+ 180 vis nut plug sweep. chase with 9.4+ 70 vis. trip out of hole and monitor. static. POOH from 1430' to 610'open hole logs, ACTIVITY log from 610' to 545'. cont. POOH from 545' to 210'. stand back colla rs and L/D BHA lay down BHA clear of BHA and hook up cement SUMMARY manifoldinstall /remove wear bushing drain stack. pull wear ring. TIH with wash tool on 5" HWDP to 450'. try to establish circ. no circ. packed tool off. POOH wet remove bull noseoff of tool. flound rock. change out with muel shoeRlH to 450' establish circ. drop ball open slieve wash from 485' to 400' pump 500 bbls not much back. EPOCH PERSONNEL ON BOARD 2 C. Silva J. Dubowski DAILY COST DML: 3425 RW: 1265 REPORT BY Josh Dubowski IP file: / /C: \Documents and Settings\Administrator\My Documents \My Wells \Chevron \2009... 10/21/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 ID REPORT FOR Mike Leslie / David Smith DATE Oct 21, 2009 DEPTH 1430 PRESENT OPERATION prep 2nd stage cement job TIME 24:00 YESTERDAY 1430 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 465' 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.5 VIS 87 PV 19 YP 18 FL 4.5 Gels 7/19/29 CL- 1000 FC 2/- SOL 8.2 SD 0 50 OIL -/91.5 MBL 12 pH 8.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 28u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS . INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY no new footage drilled PRESENT LITHOLOGY no new footage drilled Reaming /washing from 485' to 400'. PJSM to POOH.POOH from 485' to 90'. Rig up to run 13 3/8" casing. install new cable on stabbing board and clean flow box PJSM with all 3rd party personel to run casing service ng inspect T.D. and derrick. run csaing from surface to 490' M/U float equipment. bakerlok same. 811 every joint. circulate and condition MN circ swedge. fill pipe. CBU. run DAILY casing from 470' to 935' fill on the fly. run casing from 935' to 971'. P/U davis lynch packer. P/U from 996' to 1335' M/U extra joint and drive sub. 18.5 bbl loss for casing run. RIH wash through 1418' ACTIVITY to 1426'. CBU clean condition mud to 9 5 VIS. 68 stand back drive sub. UD joint #11. M/U hangar and landing joint. tag @ 1418' rig up circ head . wash to land. land hangar, R.I.L.D. test seals. rig SUMMARY down weatherford. M/U cement head. PJSM for cement job. test cement lines to 3000 psi. pump 100bb1 mud push SLB pump 165 bbls cement. lead pump 112 bbl tad cement. launch wiper. chase with rig. bump195 bbl. hold 500 for over 5 min. bleed down, chck floats. drop bomb load wiper. SLB set packer cement in place @ 23 power down koomey, remove turnbuckles, remove koomey lines from diverter valves. remove bolts from south diverter valve. EPOCH PERSONNEL ON BOARD 2 C. Silva J. Dubowski DAILY COST DML: 3425 RW: 1265 REPORT BY Josh Dubowski file: / /C: \Documents and Settings\Administrator\My Documents \My Wells \Chevron \2009... 10/22/2009 Daily Report /'� Page 1 of 1 Chevron EPOCH H DAILY WELLSITE REPORT M -20 • REPORT FOR Mike Leslie / David Smith DATE Oct 22, 2009 DEPTH 1430 PRESENT OPERATION Nipple up BOP TIME 24:00 YESTERDAY 1430 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 465' 11375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1430 MW 9.5 VIS 72 PV 18 YP 17 FL 4.9 Gels 8/24/29 CL- 900 FC 21- SOL 82 SD 1.00 OIL -/91.5 MBL 12 pH 8 Ca+ 320 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS • INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY no new footage dulled PRESENT LITHOLOGY no new footage drilled shift second stage tool via SLB. pump 50 bbls 9.8+ mud push. pump 150 bblsl3ppg cement10.7 ppg cement to surface@ 100 bbls away returns to 1 -tube. open up and continue pumping 13 ppg DAILY cement for total of 255 bbls drop closing plugchase w/7 bbls H2O displace w/59 bbls 9.4+ ppg mud. RID cement head. B/O landing joint. R/D J -tube hoses. drain/blow down water IinesF /rain for ACTIVITY rent tank clear floor of Weatherford equip clean flow box. diverter system N/D set back BOP on stump. nipple down BOPS remove riser and N2 connection from well head bring to floor. remove all SUMMARY SLB iron the rig floor to be inspected. N/D BOPS remove spacer spool from riser on rig floor. install double stud adapter on riser. install casing spools on riser. nipple up BOPS install dser on well head cut grading in wellhead room to install riser and annular valves. remove old kill line. install kill line. install 3 annular valveson well head set BOPS on riser. tighten all bolts in well room on well headand riser. install and secure scafoling in cellar, install new kill line on BOPS. install bell nipples cleaned pits 1 -4. dumped 232 down the J -tube. EPOCH PERSONNEL ON BOARD 2 C. Silva J. Dubowski DAILY COST DML: 3425 RW: 1265 REPORT BY Josh Dubowski IP file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 10/23/2009 Daily Report Page 1 of 1 Chevron EPOCH DAILY WELLSITE REPORT El M -20 • REPORT FOR Mike Leslie / David Smith DATE Oct 23, 2009 DEPTH 1430 PRESENT OPERATION Testing BOP TIME 24:00 YESTERDAY 1430 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 465' 13.375" (dj 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ (40 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM (JD @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.10 VIS 50 PV 7 YP 15 FL 62 Gels 5/6/8 CL- 8200 FC 1/- SOL 3.2 SD OIL -/98.0 MBL pH 9.40 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ (ov1 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS • INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY N/U BOP choke line. center BOPE w/tumbuckles install safety cables grease choke manifold and BOP valves and continue to mix mud. LID BHA. L/D cond /BOP wash tool. ball still in tool. move DAILY test joint still in derrick. move 5" HWDP in derrick. grease/function IBOP valve. troubleshoot/test same. C/O IBOP on T.D. back flush/blow/work mud pump suction header. service top drive install ACTIVITY handler saver sub lower SOP, air bags and bails. test BOP's fill stack with water. tighten leaking gland nut, install flange on lower annulus valveto monitor anulus. test BOP bag to 250psi low, SUMMARY 1000psi high.. all other valves and lines to 250 low 3000 high. test witnessed by AOGC Jeff Jones Positive choke test on manuel and super choke. koomey test start pressure 2950, after shut in 1300, 200psi increase 65 sec full recovery, 3 min. 49 sec. average psi on 8 nitrogen MI 1834 psi. test BOPS pull test plug. space out test joint to stand back. set wear ring. EPOCH PERSONNEL ON BOARD 2 C. Silva J. Dubowski DAILY COST DML: 3425 RW: 1265 REPORT BY Josh Dubowski ill file: / /C: \Documents and Settings\Administrator\My Documents \My Wells \Chevron \2009... 10/24/2009 Daily Report Chevron Page 1 of 1 DAILY WELLSITE REPORT EPOCH M -20 0 REPORT FOR LESLIE /SMITH DATE Oct 24, 2009 DEPTH 1450.00000 PRESENT OPERATION PREP FOR LEAK OFF TEST TIME 24:00 YESTERDAY 1430.00000 24 HOUR FOOTAGE 20' CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 12.25" XR +C PJ4206 3X18, 1X15 1430' 1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 295.0 © 1447.00000 58.0 @ 1430.00000 222.8 144.16724 FT /HR SURFACE TORQUE 0 © 1450.00000 0 @ 1450.00000 0.0 0.00000 AMPS WEIGHT ON BIT 18 @ 1433.00000 6 © 1434.00000 14.1 14.87116 KLBS ROTARY RPM 0 @ 1450.00000 0 @ 1446.00000 -0.0 - 0.00992 RPM PUMP PRESSURE 942 @ 1430.00000 825 @ 1442.00000 912.5 886.60901 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 295 @ 1439.00000 72 © 1430.00000 235.0 TRIP GAS 43 @ 1430' CUTTING GAS @ @ WIPER GAS - II) CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 58900 @ 1439.00000 14533 @ 1430.00000 45829.5 CONNECTION GAS HIGH - ETHANE (C -2) 0 @ 1450.00000 0 © 1450.00000 0.0 AVG - PROPANE (C -3) 0 @ 1450.00000 0 @ 1450.00000 0.0 CURRENT - BUTANE (C -4) 0 @ 1450.00000 0 @ 1450.00000 0.0 CURRENT BACKGROUND /AVG 106 PENTANE (C -5) 0 @ 1450.00000 0 @ 1450.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTI ON LITHOLOGY 70% SAND, 10% SANDSTONE, 10% TUFFACEOUS SILTSTONE PRESENT LITHOLOGY 1450' = 70% SAND, 10% SANDSTONE, 10% SILTSTONE DAILY MISC WORK ON THE RIG, PICK UP BHA AND ORIENTATE, RUN IN THE HOLE FROM 94' TO 230', TAG CEMENT AT 300', TAG WIPER ACTIVITY PLUG AT 438', TAG DV COLLAR AT 440', TRIP IN THE HOLE TO 1328', CIRCULATE AND CONDITION, MAXIMUM GAS 4 UNITS, SUMMARY PRESSURE TEST THE CASING AND HOLD THIRTY MINUTES, DRILL OUT SHOE TRACK, TRIP GAS WAS 43 UNITS, START TO CHANGE OVER TO GEM MUD, DRILL 20' OF NEW FORMATION TO 1450', CIRCULATE AND CONDITION THE MUD PREP FOR L.O.T. EPOCH PERSONNEL ON BOARD SILVA, BROWNE + 2 SC DAILY COST DML $4225 RW : 1265 REPORT BY LEES F. BROWNE JR. III file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 10/25/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR LESLIE /SMITH DATE Oct 25, 2009 DEPTH 2204.00000 PRESENT OPERATION WORKING ON BHA & DP TIME 24:00 YESTERDAY 1450.00000 24 HOUR FOOTAGE 754' CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2205 76.20 247.70 1748.51' SURVEY DATA 2088 70.88 251.69 1715.72' 1899 62.89 257.22 1641.16' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 12.25" XR +C PJ4206 3X18, 1X15 1430 2205 774' 7.51 1- 1- BT- A- E -I -WT -BHA BHA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 284.1 @ 1728.00000 23.6 @ 1837.00000 118.8 109.19017 FT /HR SURFACE TORQUE 8332 @ 2146.00000 2947 @ 2190.00000 593.3 0.00000 AMPS WEIGHT ON BIT 35 @ 2179.00000 2 @ 2048.00000 23.0 33.47084 KLBS ROTARY RPM 57 @ 1533.00000 0 @ 1456.00000 4.2 0.12529 RPM PUMP PRESSURE 1119 @ 2146.00000 696 @ 1574.00000 924.0 943.41577 PSI DRILLING MUD REPORT DEPTH 1430' MW 9.1 VIS 48 PV 8 YP 12 FL 6.6 Gels 5/5/6 CL- 8300 FC 1/- SOL 3.2 SD 3.2 OIL - MBL - pH 9.5 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE 4111 DITCH GAS 453 © 1467.00000 21 @ 2077.00000 145.6 TRIP GAS - CUTTING GAS @ @ WIPER GAS WIPER GAS SURVEY - METHANE (C -1) 86456 @ 1467.00000 4342 @ 2077.00000 28498.9 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ 2204.00000 0 @ 2204.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 2204.00000 0 @ 2204.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 2204.00000 0 @ 2204.00000 0.0 CURRENT BACKGROUND /AVG 0 PENTANE (C -5) 0 @ 2204.00000 0 @ 2204.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, TUFFACEOUIS CLAY, TUFFACEOUS SILT, COAL, CARBONACEOUS SHALE PRESENT LITHOLOGY 2205' = 20% CARBON SHALE, 50% COAL, 10% SAND, 10% TUFFACEOUS CLAY, 10% TUFFACEOUS SILTR CHANGE OVER THE MUD SYSTEM AND CIRCULATE AND CONDITION THE MUD, PERFORM A F.I.T TO 13.2 PPG, 290 PSI, DRILL/SLIDE DAILY FROM 1450' TO 2073', CIRCULATE AND CONDITION THE HOLE = HOLE DRAG AND INCREASED CUTTINGS, DRILL /SLIDE TO 2203', ACTIVITY CIRCULATE AND CONDITION THE HOLE AND PULL OUT OF THE HOLE TO 1698', HOLE IS STARTING TO SWAB WITH 10K OVERPULL, SUMMARY PUMP OUT OF THE HOLE TO 1414', CIRCULATE AND CONDITION THE HOLE WITH INCREASE IN CUTTINGS, PULL OUT OF THE HOLE TO 748', LAY DOWN THE BHA AND PULL OUT OF THE HOLE TO 243', SERICE THE RIG. EPOCH PERSONNEL ON BOARD BROWNE, SILVE W/ 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C:\Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 10/26/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 REPORT FOR LESLIE /SMITH DATE Oct 26, 2009 DEPTH 2204.00000 PRESENT OPERATION PICK UP BHA #5 TIME 24:00 YESTERDAY 2204.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2205' 76.20 247.70 1748.51' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25" STC MSI -616 JY275 6X13 2205' 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2205' MW 9.3 VIS 48 PV 10 YP 18 FL 5.3 Gels 6/7/7 CL- 9000 FC 1/- SOL 5.7 SD .50 OIL - MBL 2.0 pH 9.0 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS • CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BU TANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS NO DRILLING MUD CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 2205' = 20% CARBON SHALE, 50% COAL, 10% SAND, 10% TUFFACEOUS CLAY, 10% TUFFACEOUS SILT PRESENT LITHOLOGY DAILY ACTIVITY PICK UP DRILL PIPE AND STAND BACK IN THE DERRICK, PICK UP BHA AND MAKE UP THE BHA TO 105', LOAD NUKE SUMMARY SOURCES EPOCH PERSONNEL ON BOARD BROWNE, SILVA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 10/27/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 411 REPORT FOR LESLIE /MOORE DATE Oct 27, 2009 DEPTH 2944.00000 PRESENT OPERATION DRILLING FORMATION TIME 24:00 YESTERDAY 2204.00000 24 HOUR FOOTAGE 740' CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25" STC MSI -616 JY275 6X13 2205' 6.25 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 256.8 @ 2405.00000 5.7 @ 2656.00000 164.3 177.58484 FT /HR SURFACE TORQUE 11750 @ 2763.00000 5341 @ 2257.00000 8132.0 8654.51367 AMPS WEIGHT ON BIT 33 @ 2204.00000 0 @ 2598.00000 4.2 5.68522 KLBS ROTARY RPM 185 @ 2837.00000 0 @ 2204.00000 139.5 171.50233 RPM PUMP PRESSURE 1585 @ 2812.00000 739 @ 2479.00000 1270.7 1022.30994 PSI DRILLING MUD REPORT DEPTH 2205' MW 9.3 VIS 47 PV 9 YP 16 FL 5.5 Gels 6/7/7 CL- 9000 FC 1/- SOL 5.7 SD 0.10 OIL - MBL 2.0 pH 8.9 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 551 @ 2579.00000 26 © 2927.00000 152.2 TRIP GAS 60 @ 2205' CUTTING GAS @ @ WIPER GAS - • CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 106016 @ 2578.00000 5122 @ 2927.00000 29111.0 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ 2944.00000 0 @ 2944.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 2944.00000 0 @ 2944.00000 0.0 CURRENT 0 BUTANE (C -4) 0 © 2944.00000 0 @ 2944.00000 0.0 CURRENT BACKGROUND /AVG 35 PENTANE (C -5) 0 @ 2944.00000 0 @ 2944.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATE SAND, COAL, CARBON SILT + CLAY, tUFFACEOUS SILT + CLAY, ASH PRESENT LITHOLOGY 2940' = 20% SAND, 50% TUFFACEOUS SILTSTONE, 30% TUFFACEOUS CLAYSTONE DAILY ACTIVITY SURFACE TEST MWD TOOL, TRIP IN THE HOLE FROM 762' TO 1280', TRIP GAS WAS 60 UNITS, MAD PASS HOLE FROM 1280' TO SUMMARY 1541', PULL OUT OF THE HOLE TO THE SHOE, MONTIOR THE WELL, NO LOSSES, SERVICE THE RIG, TRIP IN THE HOLE TO 1823', TAG 20K, WASH DOWN TO 2137', MAD PASS FROM 2137' TO 2204', NO FILL AT BOTTOM, DRILL AHEAD. EPOCH PERSONNEL ON BOARD BROWNE, SILVA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 10/28/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 411 REPORT FOR LESLIE /MOORE DATE Oct 28, 2009 DEPTH 5121.00000 PRESENT OPERATION DRILLING TIME 24:00 YESTERDAY 2944.00000 24 HOUR FOOTAGE 2177' CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4196.75 70.63 227.80 2198.41 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25" STC MSI -616 JY275 6X13 2205' 20:17 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 235.8 @ 4839.00000 6.2 © 3284.00000 175.4 162.41090 FT /HR SURFACE TORQUE 16206 © 4000.00000 6961 @ 3024.00000 11986.7 14793.02539 AMPS WEIGHT ON BIT 14 © 3289.00000 0 @ 4600.00000 3.7 6.84479 KLBS ROTARY RPM 187 © 4174.00000 137 @ 3289.00000 170.0 165.14854 RPM PUMP PRESSURE 2147 © 5085.00000 655 @ 3036.00000 1781.6 2071.38623 PSI DRILLING MUD REPORT DEPTH 2890' MW 9.2+ VIS 49 PV 13 YP 19 FL 6.0 Gels 8/10/12 CL- 10000 FC 1/- SOL 6.1 SD 0.10 OIL - MBL 5.0 pH 8.8 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 366 @ 4617.00000 0 @ 5121.00000 72.7 TRIP GAS - • CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 71295 @ 4617.00000 10 @ 4173.00000 13298.3 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ 5121.00000 0 @ 5121.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 5121.00000 0 @ 5121.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 5121.00000 0 @ 5121.00000 0.0 CURRENT BACKGROUND /AVG 100 PENTANE (C -5) 0 @ 5121.00000 0 @ 5121.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, COAL, CARBON SHALE/CLAY PRESENT LITHOLOGY 5120' = 40% CARBON CLAY /SHALE, 40% TUFFACEOUS CLAY, 20% TUFFACEOUS SILT DAILY ACTIVITY SUMMARY DRILL FORMATION TO 3893', SERVICE THE RIG, DRILL FORMATION TO 5121'. EPOCH PERSONNEL ON BOARD SILVA, BROWNE + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 10/29/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 IIII REPORT FOR LESLIE /MOORE DATE Oct 29, 2009 DEPTH 5787.00000 PRESENT OPERATION CUT /SLIP NEW DRILL LINE @ SHOE TIME 24:00 YESTERDAY 5121.00000 24 HOUR FOOTAGE 666' CASING INFORMATION 13.375" © 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5712.97 54.73 169.06 3007.48' SURVEY DATA 5524.50 54.25 173.97 2897.87' 5335.15 53.73 182.98 2785.96' 5147.20 54.15 193.24 2675.17' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25" STC MSI -616 JY275 6X13 2205' 25:03 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 244.3 @ 5503.00000 40.4 @ 5182.00000 152.3 108.08215 FT /HR SURFACE TORQUE 18591 @ 5560.00000 13115 @ 5197.00000 15530.7 17475.58398 AMPS WEIGHT ON BIT 12 @ 5181.00000 0 @ 5781.00000 5.2 3.90669 KLBS ROTARY RPM 178 @ 5598.00000 163 @ 5540.00000 170.9 166.22925 RPM PUMP PRESSURE 2258 © 5756.00000 725 © 5503.00000 2085.7 2224.09277 PSI DRILLING MUD REPORT DEPTH 4980' MW 9.3 VIS 51 PV 14 YP 18 FL 5.0 Gels 5/8/11 CL- 11000 FC 1/- SOL 6.5 SD 1.00 OIL - MBL 8.5 pH 8.4 Ca+ 360 CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW 538 @ AVERAGE DITCH GAS 5151.00000 12 @ 5412.00000 127.6 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 88185 @ 5148.00000 2416 @ 5412.00000 23350.5 CONNECTION GAS HIGH 47 @ 5126' ETHANE (C -2) 88 @ 5561.00000 0 @ 5618.00000 5.5 AVG 5< PROPANE (C -3) 15 © 5566.00000 1 © 5571.00000 0.1 CURRENT 0 BUTANE (C -4) 0 @ 5787.00000 0 @ 5787.00000 0.0 CURRENT BACKGROUND /AVG 0 PENTANE (C -5) 0 @ 5787.00000 0 @ 5787.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, TUFFACEOUS SAND, COAL, CARBON SHALE /CLAY, TUFFACEOUS CLAY, TUFFACEOUS SILT PRESENT LITHOLOGY 5787' = SAND 20 %, SANDSTONE 10 %, TUFFACEOUS CLAY 20% TUFFACEOUS SILT 30 %, TUFFACEOUS SAND 20% DAILY DRILL FORMATION TO 5787', CIRCULATE AND CONDITION THE DRILLING MUD, PUMPING SWEEPS, RETURNS OF 874 BBLS AND ACTIVITY 780 BBLS EARLY, PULL OUT OF THE HOLE TO 4724' WITH 10 -15K HOLE DRAG, 30K OVER PULL AT 5030', WORK THROUGH TIGHT SUMMARY SPOTS, PULL 40K+ OVER AT 4727', REAM HOLE FROM 4727' TO 4557' AND BACK REAM 4557' TO 2170' WITH LOTS OF CUTTINGS OVER THE SHAKERS, MAS PASS HOLE FROM 2170' TO 1520', CUT AND SLIP NEW DRILL LINE. EPOCH PERSONNEL ON BOARD BROWNE, SILVA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 10/30/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR LESLIE /MOORE DATE Oct 30, 2009 DEPTH 6155.00000 PRESENT OPERATION DRILLING TIME 24:00 YESTERDAY 5787.00000 24 HOUR FOOTAGE 368' CASING INFORMATION 13.375 '"@ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5712.97 54.73 169.06 3007.48' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25" STC MSI -616 JY275 6X13 2205' 28:00 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 233.5 @ 5794.00000 19.0 © 5966.00000 136.2 152.26494 FT /HR SURFACE TORQUE 20743 @ 6077.00000 13222 © 5788.00000 17438.0 18488.33789 AMPS WEIGHT ON BIT 13 @ 6019.00000 0 @ 6065.00000 5.4 7.03251 KLBS ROTARY RPM 184 @ 6131.00000 159 @ 5887.00000 170.0 180.31863 RPM PUMP PRESSURE 2256 © 6059.00000 1442 @ 5906.00000 2124.8 2174.53613 PSI DRILLING MUD REPORT DEPTH 5787' MW 9.5 VIS 51 PV 15 YP 15 FL 4.6 Gels 4/8/12 CL- 6000 FC 1/- SOL 7.9 SD 1.00 OIL - MBL 7.5 pH 8.5 Ca+ 320 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 251 @ 5987.00000 17 © 5792.00000 77.9 TRIP GAS - • CUTTING GAS @ @ WIPER GAS 81 @ 5787' CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 46154 @ 6034.00000 3278 @ 5792.00000 13122.4 CONNECTION GAS HIGH 0 ETHANE (C -2) 27 @ 5986.00000 0 @ 6018.00000 0.9 AVG 0 PROPANE (C -3) 0 @ 6155.00000 0 @ 6155.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 6155.00000 0 @ 6155.00000 0.0 CURRENT BACKGROUND /AVG 47 PENTANE (C -5) 0 @ 6155.00000 0 @ 6155.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTI ON LITHOLOGY SAND, SANDSTONE, CONGLOMERATE SAND, TUFFACEOUS SANDSTONE, TUFFACEOUS SILT, TUFFACEOUS CLAY, COAL, CARBONACEOUS SHALE /CLAY PRESENT 6155' = TUFFACEOUS SANDSTONE 30 %, TUFFACEOUS CLAYSTONE 40 %, TUFFACEOUS SILTSTONE, 20% SAND 20% LITHOLOGY DAILY SERVICE THE RIG AT THE SHOE, TRIP IN THE HOLE TO 3706', FILL THE DRILL PIPE, SERVICE THE RIG TOP DRIVE, PULL OUT OF ACTIVITY THE HOLE TO 2370', SERVICE THE RIG TOP DRIVE, TRIP IN THE HOLE TO 5455' AND TAG, KELLY UP AND WASH DOWN TO 5506', SUMMARY TAG @ 5324' AND 4756', WORKED THROUGH WITHOUT RIG PUMPS, DRILL FORMATION FROM 5791' TO 6155', WIPER GAS WAS 81 UNITS. EPOCH PERSONNEL ON BOARD BROWNE, SILVA + 2 SC DAILY COST $4225 DML, RW $1265 REPORT BY LEES F. BROWNE JR. 411 file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 10/31/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR LESLIE /MOORE DATE Oct 31, 2009 DEPTH 7503.00000 PRESENT OPERATION DRILLING TIME 24:00 YESTERDAY 6155.00000 24 HOUR FOOTAGE 1348' CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6762.43 54.61 168.61 3623.19' SURVEY DATA 6572.77 53.98 169.43 3512.28' 6383.37 53.89 170.27 3400.86' 6194.70 53.37 171.14 3289.21' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25" STC MSI -616 JY275 6X13 2205' 42:19 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 208.5 © 6458.00000 4.0 @ 7490.00000 116.3 15.09902 FT /HR SURFACE TORQUE 27714 @ 7503.00000 17384 @ 6175.00000 21949.2 27714.12109 AMPS WEIGHT ON BIT 14 © 7130.00000 0 © 6557.00000 7.7 12.01580 KLBS ROTARY RPM 193 @ 7249.00000 146 © 6416.00000 173.8 149.10103 RPM PUMP PRESSURE 2531 © 7503.00000 1493 @ 7416.00000 2269.7 2531.37646 PSI DRILLING MUD REPORT DEPTH 6120' MW 9.4+ VIS 48 PV 13 YP 16 FL 5.8 Gels 5/14/17 CL- 6000 FC 1/- SOL 7.9 SD 1.00 OIL - MBL 11.0 pH 8.5 Ca+ 340 CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 426 © 6697.00000 13 @ 7489.00000 108.7 TRIP GAS CUTTING GAS @ @ WIPER GAS 18 @ 7309 (IBOP) CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 62862 © 6683.00000 2461 @ 6265.00000 13144.5 CONNECTION GAS HIGH 0 ETHANE (C -2) 714 @ 7049.00000 0 @ 6268.00000 45.3 AVG 0 PROPANE (C -3) 16 @ 6919.00000 0 @ 6891.00000 0.2 CURRENT 0 BUTANE (C -4) 0 @ 7503.00000 0 @ 7503.00000 0.0 CURRENT BACKGROUND /AVG 20 PENTANE (C -5) 0 @ 7503.00000 0 @ 7503.00000 0.0 HYDROCARBON SHOWS NO LARGE GAS KICKS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, TUFFACEOUS SAND, SANDSTONE, CONGLOMERATE SAND, TUFFACEOUS SILT AND CLAY, COAL AND CARBON CLAY PRESENT LITHOLOGY 7500' =70% SANDSTONE, 30% SAND DAILY ACTIVITY DRILL FORMATION FROM 6155' TO 6738', PUMP SWEEPS WITH CALCULATED RETURNS, CIRCULATE AND CONDITION THE SUMMARY DRILLING MUD AND CLEAN THE HOLE, DRILL TO 6997', PUMP A SWEEP WITH CALCULATED RETURNS, SERVICE THE RIG, DRILL TO 7313', CIRCULATE AND CONDITION THE HOLE, SERVICE THE RIG, DRILL TO 7503' EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225, DML $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator\My Documents \My Wells \Chevron \20091... 11/1/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 S REPORT FOR LESLIE/MOORE DATE Nov 01, 2009 DEPTH 8062.00000 PRESENT OPERATION PULL OUT OF HOLE: WASHOUT TIME 24:00 YESTERDAY 7503.00000 24 HOUR FOOTAGE 559' CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7901.68 50.94 162.45 4291.68' SURVEY DATA 7805.48 52.15 164.36 4231.85' 7712.51 53.23 166.57 4175.50' 7617.57' 54.25 168.42 4119.34' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25" STC MSI -616 JY275 6X13 2205 53:20 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 129.4 @ 7835.00000 3.5 © 7504.00000 67.7 11.00000 FT /HR SURFACE TORQUE 27714 @ 7503.00000 21110 © 7617.00000 22104.3 AMPS WEIGHT ON BIT 20 @ 7882.00000 4 © 8057.00000 14.8 16.50000 KLBS ROTARY RPM 188 @ 7879.00000 146 @ 7504.00000 166.8 RPM PUMP PRESSURE 2624 @ 7986.00000 1684 @ 7601.00000 2378.1 PSI DRILLING MUD REPORT DEPTH 7450' MW 9.5 VIS 50 PV 16 YP 18 FL 4.9 Gels 6/17/23 CL- 11000 FC 1/- SOL 8.1 SD 0.50 OIL 0.5 MBL 12.5 pH 8.9 Ca+ 280 CCI MWD SUMMARY INTERVAL TO TOOLS 0 GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 300 @ 7534.00000 0 @ 8035.00000 70.3 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 56199 @ 7534.00000 197 @ 8029.00000 11029.4 CONNECTION GAS HIGH 0 ETHANE (C -2) 478 @ 7537.00000 0 © 7857.00000 29.2 AVG 0 PROPANE (C -3) 0 @ 8062.00000 0 © 8062.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 8062.00000 0 © 8062.00000 0.0 CURRENT BACKGROUND /AVG 3 PUMP OUT 4 BPM PENTANE (C -5) 0 @ 8062.00000 0 @ 8062.00000 0.0 HYDROCARBON SHOWS NO LARGE GAS KICKS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, CARBON CLAY, COAL, TUFFACEOUS CLAY, TUFFACEOUS SILT PRESENT LITHOLOGY 8062' = 80% SAND, 20% SANDSTONE DAILY DRILL FORMATION FROM 7503' TO 7780', PUMP A SWEEP WITH CALCULATED RETURNS, DRILL TO 8009', PUMP A SWEEP AT 7882' ACTIVITY WITH RETURNS 300 STROKES EARLY, PUMP A SWEEP AT 7977', RETURNS 500 STROKES EARLY, SERVICE THE RIG, DRILL SUMMARY FORMATION TO 8062', TRIP OUT OF THE HOLE DUE TO 500 PSI DRILL STRING LOSS, TEST SURFACE EQUIPMENT (GOOD), PUMP OUT @ 4 BPM. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. S file: / /C:\Documents and Settings\Administrator \My Documents \My Wells \Chevron \20091... 11/2/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR HAUCK/MOORE DATE Nov 02, 2009 DEPTH 8062.00000 PRESENT OPERATION PREP TO GO FISHING TIME 24:00 YESTERDAY 8062.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7901.68' 50.94 162.45 4291.68' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25" STC MSI -616 JY275 6X13 2205 53:20 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7960' MW 9.6 VIS 67 PV 25 YP 25 FL 4.3 Gels 8/23/- CL- 14000 FC 1/- SOL 8.4 SD 0.10 OIL 0.5 MBL 13.0 pH 8.8 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 99 © POOH 2 © POOH 5 (POOH) TRIP GAS - 40 CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG - PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NO SAMPLES COLLECTED THE LAST 24 HOURS PRESENT LITHOLOGY 8062' = 80% SAND, 20% SANDSTONE TRIP OUT OF THE HOLE FROM 5889' TO 3700' WITH 50K OVERPULL AT 5668', WORK THROUGH AND PULL OUT OF THE HOLE TO DAILY 3139' WITH 5 -10K HOLE DRAG, TRIP OUT OF THE HOLE TO THE SHOE (1425'), MONITOR THE HOLE, RIG SERVICE, PULL OUT OF THE ACTIVITY VHOLE AND LAY DOWN BHA, STAND BACK THE HWDP, LAY DOWN THE CCV TOOL, COLLAR BROKEN OFF UNDER THE STAB, CLEAN SUMMARY THE RIG FLOOR, SERVICE THE TOP DRIVE, PICK UP THE BHA, MAKE UP THE OVERSHOT, PICK UP CIRCULATING SUB AND RUN IN THE HOLE TO 967', LEL ALARM - SECURE THE WELL, TRIP IN THE HOLE TO 1380', CLEAR MUD PITS OF CO. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. III file: / /C: \Documents and Settings\Administrator\My Documents \My Wells \Chevron \20091... 11/3/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 III REPORT FOR HAUCK/MOORE DATE Nov 03, 2009 DEPTH 8062.00000 PRESENT OPERATION POOH FOR SMALLER OVERSHOT TIME 24:00 YESTERDAY 8062.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7901.68' 50.94 162.45 4291.68' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 12.25" OVERSHOT 8206' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8062' MW 9.4 VIS 85 PV 21 YP 19 FL 5.8 Gels 7/15/19 CL- 15000 FC 1/- SOL 7.7 SD 0.10 OIL 0.1 MBL 15.0 pH 8.6 Ca+ 280 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 86 (TG) @ TIH 4 @ TIH 15 (CIRC) TRIP GAS 86 @ 8062' • CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 (POOH) PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8062' = 80% SAND, 20% SANDSTONE MONITOR THE MUD PITS CO CONTENT, SERVICE THE RIG, CIRCULATE AND CONDITION THE DRILLING MUD, H2S ALARM = SECURE DAILY THE WELL AND WAIT FOR ALL CLEAR, ALL CLEAR ON H2S ALARM, RIG SERVICE, CIRCULATE AND CONDITION THE DRILLING MUD, ACTIVITY TRIP IN THE HOLE FROM 1380' TO 7900', HOLE IS TIGHT AT 7485' TO 7498', PUMP THROUGH TIGHT SPOTS, CIRCULATE AND SUMMARY CONDITION THE DRILLING MUD, TRIP GAS WAS 86 UNITS, PUMP A SWEEP, START FISHING, SWALLOW THE FISH @ 7903', ATTEMPT TO PULL THE FISH, FISH GOT AWAY, PULL OUT OF THE HOLE FOR SMALLER OVERSHOT TOOL. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \20091... 11/4/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR HAUCK/MOORE DATE Nov 04, 2009 DEPTH 8062.00000 PRESENT OPERATION FISHING TIME 24:00 YESTERDAY 8062.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7901.68' 50.94 162.45 4291.68' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 12.25" OVERSHOT 8206' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8062' MW 9.6 VIS 59 PV 18 YP 24 FL 5.6 Gels 7/22/30 CL- 15000 FC 1/- SOL 8.3 SD 0.10 OIL 0.5 MBL 15.0 pH 8.5 Ca+ 800 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 51 TG @ 7900' 3 @ CIRC 5 TRIP GAS 51 @ 7900' • CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 4 CIRC PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8062' = 80% SAND, 20% SANDSTONE TRIP OUT OF THE HOLE FROM 7641' TO 6880' WITH 10 -15K HOLE DRAG, CIRCULATE AND SPOT A PILL, TRIP OUT FROM 6880' TO 1380' WITH 20-30K OVER PULL AT 6340', 6278'- 6240', 6042', 5560', 5440'- 5320', 5308' - 5290', 5741' - WORK THROUGH ALL SPOTS AND DAILY MONITOR THE WELL AT THE SHOE FOR TEN MINUTES, HOLE MUD LOSS AVE. 1BBUHR, PULL OUT OF THE HOLE AND STAND BACK ACTIVITY THE BHA, NO FISH, PICK UP SMALLER OVERSHOT, SERVICE THE RIG, TRIP IN THE HOLE WITH NEW OVERSHOT TO 7871', SUMMARY CIRCULATE AND CONDITION THE MUD, TRIP GAS WAS 51 UNITS, BEGIN FISHING, LATCH ONTO THE FISH, TRIP OUT OF THE HOLE FROM 7900' TO 7170' AND LOST THE FISH, CHASE THE FISH, WAIT ON WEATHER = HIGH WINDS, CIRCULATE THE WELL AND MOVE THE DRILL PIPE. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225, DML $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \20091... 10/5/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR HAUCK/MOORE DATE Nov 05, 2009 DEPTH 8062.00000 PRESENT OPERATION MAKE UP CLEAN OUT BHA TIME 24:00 YESTERDAY 8062.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7901.68' 50.94 162.45 4291.68' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25" STC MSI -616 JY275 6X13 2203 8062 5859' 41.59 TW 4 12.25" STC XR +C PJ4206 3X32, 1X14 8062 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8062' MW 9.5 VIS 54 PV 15 YP 18 FL 6.2 Gels 6/20/27 CL- 13000 FC 1/- SOL 7.4 SD 0.10 OIL 0.5 MBL 12.5 pH 8.8 Ca+ 840 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE • DITCH GAS 13 @ CIRC 2 @ CIRC @ @ 4 TRIP GAS - CUTTING GAS WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ © AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTI ON LITHOLOGY PRESENT LITHOLOGY 8062' = 80% SAND, 20% SANDSTONE WAIT ON WEATHER (50 MPH+ WINDS), CIRCULATE THE WELL AT 10 BPM, TRIP IN THE HOLE AND WASH DOWN FROM 7176' TO 7902', DAILY FISHING, LATCH THE FISH @ 7903' PSI INCREASE TO 300 STOP PUMPS, PICK UP 25K OVER PILL, ATTEMPT TO ESTABLISH ACTIVITY CIRCULATION AT 2 BPM, LOST THE FISH, ROTATE 15 RPM DOWN ONTO THE FISH, ATTEMPT CIRCULATION, LOST THE FISH, SUMMARY RETRIEVE THE FISH AGAIN PICK UP 75K AND PUMP AGAIN, LOST FISH AT 400 PSI, TOP OF FISH AT 7902', TRIP OUT OF THE HOLE FROM 7902' TO 1185', 10 MINUTE FLOW CHECK AND PULL OUT OF THE HOLE TO THE BHA, NO FISH, MUD LOSS FOR THE TRIP WAS SEVEN BBLS, LAY DOWN THE BHA AND TEST THE BOPE, PICK UP THE BHA AND MAKE UP BIT AND TWO DRILL COLLARS. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML. $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \20091... 11/6/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 III REPORT FOR DATE Nov 06, 2009 DEPTH 8062.00000 PRESENT OPERATION PREP OVERSHOT BHA TIME YESTERDAY 8062.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7901.68' 50.94 162.45 4291.68' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 RR1 12.25" STC XR +C PJ4206 3X32, 1X14 8062 8062 0 0 BHA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8062' MW 9.5+ VIS 52 PV 14 YP 20 FL 7.2 Gels 8/20/26 CL- 15000 FC 1/- SOL 7.8 SD 0.10 OIL 0.5 MBL 12.5 pH 8.5 Ca+ 780 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 182 TG © TD 12 @ CIRC 20 CIRC TRIP GAS 182 @ 7926' . CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8062' = 80% SAND, 20% SANDSTONE CONTINUE TO PICK UP BHA AND RUN IN THE HOLE TO 1400', CIRCULATE AND CONDITION THE MUD, MAXIMUM GAS WAS 3 UNITS, TRIP IN THE HOLE AND REAM CLEAN THE FOLLOWING SECTIONS: 4130 - 4160', 4675- 4690', 5804- 5820', 5855 - 5868', 5870 - 5966', DAILY REAM/WASH FROM 7832 TO 7922', CIRCULATE BOTTOMS UP WITH A 40% INCREASE IN CUTTINGS AT THE SHAKER, TAG THE FISH ACTIVITY AT 7926', TRIP GAS WAS 182 UNITS, PUMP A 73 BBL HIGH VISCOSITY SWEEP AND CIRCULATE AND CONDITION THE HOLE AT 7918', SUMMARY PUMP A SWEEP WITH A 20% INCREASE IN CUTTINGS, PULL OUT OF THE HOLE TO 6350' AND PUMP A DRY JOB, PULL OUT OF THE HOLE TO 1425', HOLE WAS NOT TIGHT COMING OUT, CHECK FLOW = STATIC, PULL OUT OF THE HOLE AND LAY DOWN IRON, PICK UP BHA AND MAKE UP THE OVERSHOT, OVERSHOT IS THE WRONG SIZE, SERVICE THE RIG. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \20091... 11/7/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 110 REPORT FOR HAUCK/MOORE DATE Nov 07, 2009 DEPTH 8062.00000 PRESENT OPERATION POOH W/ FISH TIME 24:00 YESTERDAY 8062.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7901.68' 50.94 162.45 4291.68' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED OVERSHOT TOOL DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8062' MW 9.5+ VIS 55 PV PV 18 YP 22 FL 7.2 Gels 9/24/32 CL- 14000 FC 1/- SOL 7.8 SD 0.10 OIL 0.5 MBL 12.5 pH 8.5 Ca+ 600 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 93 @ TG 4 @ CIRC 9 CIRC TRIP GAS 93 @ 7901' 0 CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 (POOH) PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTI ON LITHOLOGY PRESENT LITHOLOGY 8062' = 80$ SAND, 20% SANDSTONE SERVICE THE RIG AND WAIT ON THIRD PARTY TOOLS, PICL UP BHA FROM SURFACE TO 1192', MAKE UP OVER SHOT, PICK UP DAILY JARS AND MAKE UP THE BHA, CIRCULATE AND CONDITION THE MUD AT 1192' MAXIMUM GAS WAS 3 UNITS, TRIP IN THE HOLE TO ACTIVITY 6510', BREAK CIRCULATION EVERY TEN STANDS, CIRCULATE AT V6510' MAXIMUM GAS WAS 24 UNITS, TRIP IN THE HOLE TO 7901' SUMMARY CIRCULATE AND CONDITION THE HOLE, TRIP GAS WAS 93 UNITS, LATCH ONTO THE FISH AND BEGIN TO PULL OUT OF THE HOLE - SLOW. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA DAILY COST $3995 DML, $1265 RW REPORT BY LEES F. BROWNE JR. 0 file: / /C: \Documents and Settings\Administrator\My Documents \My Wells \Chevron \20091... 11/8/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR HAUCK/MOORE DATE Nov 08, 2009 DEPTH 8062.00000 PRESENT OPERATION TRIP IN HOLE TO DRILL TIME 24:00 YESTERDAY 8062.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7901.68' 50.94 162.45 4291.68' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 5 12.25" STC MSI -616 JY6074 6X13 8062 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8062' MW 9.5+ VIS 55 PV 18 YP 22 FL 7.2 Gels 9/24/32 CL- 14000 FC 1/- SOL 7.8 SD 0.10 OIL 0.5 MBL 12.5 pH 8.5 Ca+ 600 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 42 © TIH CIRC 3 @ CIRC 5 CIRC TRIP GAS 42 TIH CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 15 PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTI ON LITHOLOGY PRESENT LITHOLOGY 8062' 80% SAND, 20% SANDSTONE DAILY PULL OUT OF THE HOLE FROM 4169 TO 1292', WELL IS STATIC, PULL OUT OF THE HOLE TO 425', PRE JOB SAFETY MEETING, PULL ACTIVITY OUT OF THE HOLE TO 48', LAY DOWN THE BHA, JARS, BUMPERS AND FISH, LAY DOWN THIRD PARTY TOOLS, PULL THE NUKES SUMMARY SOURCE, LAY DOWN BHA AND FISHED BHA, CLEAN THE RIG FLOOR, PICK UP NEW BHA, TRIP IN THE HOLE AND WASH AND REAM AT 4481 -4576' AND 4702 - 4765', TRIP GAS AT REPORT TIME IS 42 UNITS. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA DAILY COST $3995 DML, $1265 RW REPORT BY LEES F. BROWNE JR. II file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \20091... 11/9/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 III REPORT FOR HAUCK/MOORE DATE Nov 09, 2009 DEPTH 8240.00000 PRESENT OPERATION WIPER TRIP @ CSG POINT TIME 24:00 YESTERDAY 8062.00000 24 HOUR FOOTAGE 178' CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8240' 4505' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 5 12.25" STC MSI -616 JY6074 6X13 8062' 8240' 178 14:00 N/A CP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 105.5 @ 8113.00000 1.4 @ 8239.00000 30.6 7.68815 FT /HR SURFACE TORQUE 28369 @ 8136.00000 23240 @ 8199.00000 26220.6 26932.96094 AMPS WEIGHT ON BIT 16 © 8062.00000 0 @ 8154.00000 3.8 6.10456 KLBS ROTARY RPM 175 @ 8092.00000 55 @ 8117.00000 111.7 129.69731 RPM PUMP PRESSURE 2595 @ 8116.00000 2173 @ 8180.00000 2450.1 2473.10986 PSI DRILLING MUD REPORT DEPTH 8062' MW 9.6 VIS 67 PV 16 YP 23 FL 8.2 Gels 8/23/31 CL- 13500 FC 1/- SOL 8.0 SD 0.10 OIL 0.4 MBL 15.0 pH 8.6 Ca+ 580 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 30 @ 8085.00000 3 @ 8171.00000 9.7 TRIP GAS 91 @ 8062' . CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 5024 @ 8085.00000 448 @ 8171.00000 1610.3 CONNECTION GAS HIGH 0 ETHANE (C -2) 113 © 8087.00000 2 @ 8063.00000 9.0 AVG 0 PROPANE (C -3) 0 @ 8240.00000 0 @ 8240.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 8240.00000 0 © 8240.00000 0.0 CURRENT BACKGROUND /AVG 10 CIRC PENTANE (C -5) 0 @ 8240.00000 0 @ 8240.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, CONGLOMERATE SAND, TUFFACEOUS CLAYSTONE PRESENT LITHOLOGY 8240' = SANDSTONE 10 %, SAND 60 %, CONGLOMERATE SAND 30% DAILY WASH AND REAM FROM 7897' TO 7991', MAD PASS THE HOLE FROM 7991' TO 8055', TAG HOLE FILL AT 8058', TRIP GAS WAS 91 UNITS AT TD, DRILL FORMATION FROM 8062' TO 8175', SERVICE THE RIG, DRILL FORMATION FROM 8175' TO 8240', CIRCULATE ACTIVITY SUMMARY AND CONDITION THE HOLE, PUMP A HIGH VISCOSITY SWEEP WITH A 30% INCREASE IN CUTTINGS, CIRCULATE AND CONDITION THE WELL, CHECK FOR FLOW, CIRCULATE FOR WIPER TRIP. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA DAILY COST $3995 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 11/10/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 III REPORT FOR HAUCK/SMITH DATE Nov 10, 2009 DEPTH 8240.00000 PRESENT OPERATION PREP TO RUN CASING TIME 24:00 YESTERDAY 8240.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8175.70' 49.73 159.86 4467.03' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 5 12.25" STC MSI -616 JY6074 6X13 8062 8240 178 14:00 1- 1- NO -A -X -I TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8235' MW 9.3+ VIS 46 PV 14 YP 22 FL 9.0 Gels 7/16/18 CL- 14500 FC 1/- SOL 6.2 SD 0.10 OIL 0.2 MBL 10.0 pH 9.2 Ca+ 400 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 18 @ WG 2 @ CIRC 8 CIRC TRIP GAS - • CUTTING GAS @ @ WIPER GAS 18 @ 8240 CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH 0 ETHANE (C -2) @ @ AVG 0 PROPANE (C -3) @ @ CURRENT 0 BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY SAND 60 %, CONGLOMERATE SAND 30 %, SANDSTONE 10% WIPER TRIP FROM 8240' TO 7865', 25K OVER PULL WITH NO SWABS AND NO FILL ON BOTTOM, WIPER GAS MAXIMUM WAS 18 DAILY UNITS, CIRCULATE AND CONDITION, PUMP A 57 BBL LCM PILL WITH RETURNS 20 BBLS LATE WITH A 50% INCREASE IN CUTTINGS, ACTIVITY PUMP A HIGH VISCOSITY SWEEP AND PULL OUT OF THE HOLE, MONITOR THE HOLE AT 8213' HOLE IS STATIC, PULL OUT OF THE SUMMARY HOLE FROM 8213 TO 1382', PULLED 15 -25K OVER AND WORKED THROUGH SECTIONS 5550 - 5524', 4700 -4259' AND PULL OUT OF THE HOLE FROM 1391 CTO THE BIT, LAY DOWN 40 JARS, TOOLS AND CLEAN AND CLEAR THE DRILL FLOOR, RIG UP CASING EQUIPMENT, HOLD A PJSM, SERVICE THE RIG. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA DAILY COST $3995 DML, $1265 RW REPORT BY LEES F. BROWNE JR III file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 11/11/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR HAUCK/SMITH DATE Nov 11, 2009 DEPTH 8240.00000 PRESENT OPERATION TRIP IN WITH 9 5/8" CASING TIME 24:00 YESTERDAY 8240.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 1423' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8175.70' 49.73 159.86 4467.03' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8240' MW 9.5 VIS 60 PV 17 YP 27 FL 7.0 Gels 10/18/24 CL- 14500 FC 1/ - SOL 7.3 SD 0.10 OIL 0.1 MBL 12.5 pH 8.6 Ca+ 240 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 27 @ TIH 2 @ TIH 13 TIH TRIP GAS - CUTTING GAS @ @ WIPER GAS - • CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 2 TIH PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8240' = SAND 60 %, CONGLOMERATE SAND 30 %, SANDSTONE 10% DAILY RUN 9 5/8" CASING FROM 85' TO 1425', CIRCULATE AND CONDITION THE HOLE, MAXIMUM GAS WAS 3 UNITS, RUN CASING FROM ACTIVITY 1425' TO 3200', CIRCULATE AND CONDITION THE MUD, MAXIMUM GAS WAS 10 UNITS, RUN CASING FROM 3200' TO 4724', SUMMARY CIRCULATE AND CONDITION THE MUD, MAXIMUM GAS WAS 26 UNITS, RUN CASING FROM 4724' TO 6185', CIRCULATE AND CONDITION THE MUD, MAXIMUM GAS WAS 27 UNITS, RUN CASING FROM 6185' TO 7363'. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA DAILY COST $3995 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 11/12/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 ill REPORT FOR HAUCK/SMITH DATE Nov 12, 2009 DEPTH 8240.00000 PRESENT OPERATION NIPPLE DOWN BOPE TIME 24:00 YESTERDAY 8240.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8222' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8175.70' 49.73 159.86 4467.03' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8240' MW 9.5 VIS 60 PV 17 YP 27 FL 7.0 Gels 10/18/24 CL- 14500 FC 1/- SOL 7.3 SD 0.10 OIL 0.1 MBL 12.5 pH 8.6 Ca+ 240 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 56 @ TG 2 © TIH 5 CIRC TRIP GAS 56 @ 8222' CUTTING GAS @ @ WIPER GAS - ID CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) © @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG - PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8240' = SAND 60 %, CONGLOMERATE SAND 30 %, SANDSTONE 10% DAILY RUN CASING FROM 7363' TO 8191', MAKE UP LANDING JOINT, WASH DOWN FROM 8191' TO 8222', CIRCULATE AND CONDITION THE ACTIVITY HOLE, TRIP GAS WAS 56 UNITS, WORK CASING 40' UP AND DOWN, RIG UP CEMENT MANIFOLD, INSTALL CEMENT LINES, PRE JOB SUMMARY SAFETY MEETING, CEMENT CASING, CASING SET AT 8222', RIG DOWN CEMENT HEAD AND LINES, ELEVATORS, LONG BALES AND CASING TONGS, RIG UP TRIPPING BALES AND ELEVATORS, RIG UPTONGS AND BEGIN TO NIPPLE THE BOPE. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA DAILY COST $3995 DML. $1265 RW REPORT BY LEES F. BROWNE JR. ill file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 11/13/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR HAUCK/SMITH DATE Nov 13, 2009 DEPTH 8240.00000 PRESENT OPERATION TRIP IN HOLE WITH DUMB IRON TIME 24:00 YESTERDAY 8240.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8222' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8125.70' 49.73 159.86 4467.03' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8240' MW 9.5 VIS 48 PV 14 YP 20 FL 8.0 Gels 8/18/23 CL- 13500 FC 1/- SOL 7.4 SD 0.10 OIL 0.3 MBL 10.0 pH 7.5 Ca+ 300 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - • CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG - PENTANE (C -5) @ @ HYDROCARBON SHOWS NO FLUIDS CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8240' = SAND 60 %, CONGLOMERATE SAND 30 %, SANDSTONE 10% LAY DOWN 9 5/8" TEST JOINT, CLEAR RIG FLOOR, MAKE UP 7" TEST JOINT AND LAND, CHANGE RAMS, CHANGE OUT LOWER RAMS DAILY FROM 9 5/8" TO 7 ", TEST BOPE AND MISC RIG SERVICE, MIX NEW DRILLING MUD, CHANGE OUT LINERS IN #2 MUD PUMP, PRE JOB ACTIVITY SAFETY MEETING, LAY DOWN TEST TOOLS, BREAK DOWN TEST JOINT, BLOW DOWN CHOKE MANIFOLD, KILL LINE AND TOP SUMMARY DRIVE, CHECK VALVE ALINGMENT, FUCTION TEST ELMAGO CONTROLS, ADJUST HANDLER ON TOP DRIVE, SERVICE THE RIG, PICK UP PDC BIT, STAB, DRILL COLLARS, STAB, CROSS OVER, HWDP AND BEGIN TO RUN IN THE HOLE INSTALLING NRP ON THE DRILL PIPE. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA DAILY COST $3995 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 11/14/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR HAUCK, SMITH DATE Nov 14, 2009 DEPTH 8240.00000 PRESENT OPERATION PULL OUT OF THE HOLE TIME 24:00 YESTERDAY 8240.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" © 8222' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8125.70' 49.73 159.86 4467.03' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 5 8.5" STC MSI -616 JD1265 3X11, 3X12 8222 0 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8240' MW 9.5 VIS 80 PV 9 YP 33 FL 8.0 Gels 12/17/23 CL- 13000 FC 1/- SOL 6.7 SD 0.10 OIL 0.2 MBL 10.0 pH 8.0 Ca+ 300 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1 © CIRC 0 @ CIRC 1 TRIP GAS 0 0 CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8240' = $3995 DML, $1265 RW LAY DOWN THE 5" DP, TRIP IN THE HOLE FROM 2202' WITH XTM50, TRIP IN THE HOLE FROM 2202' TO 3435' AND INSTALL NRP'S (2 PER JOINT), FILL PIPE AT 2960', TRIP IN THE HOLE FROM 3435' TO 4099' WITHOUT NPR'S, TRIP IN THE HOLE FROM 4099' TO 5901' AND INSTALL NPR (2 PER JOINT), WASH DOWN FROM 5901' TO 6006' AND TAG CEMENT WITH 5K, PUMP AT 9.5 BBUMIN WITH 900 PSI, DAILY CEMENT PRESSURE TEST CASING TO 3000 PSI FOR 10 MINUTES - 2% PSI LOSS /10 MINS, DRILL CEMENT FROM 6002' TO 6003' WITH ACTIVITY WOB 3 -4K, DRILL CEMENT FROM 6003' TO 6010', CHASE HOLE JUNK FROM 6010' TO 6469' AT 120 RPM AND 9 BPM, CHASE JUNK SUMMARY FROM 6469' TO 6945' AND INSTALL NPR'S, CIRCULATE AND CONDITION THE HOLE BOTTOMS UP, GAS MAXIMUM WAS 1 UNIT, MUD CURDLED - SLOW PUMP RATES DOWN, PRESSURE TEST THE CASING SHOE TO 3000 PSI AND HOLD FOR 30 MINS, BREAK DOWN THE TOP DRIVE CHOKE MANIFOLD AND KILL LINE, SERVICE THE TOP DRIVE AND WORK ON THE BOP, PULL OUT OF THE HOLE, PUMP A DRY JOB AND PULL OUT FROM 6945' TO 2202' EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator\My Documents \My Wells \Chevron \2009... 11/15/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT I EPOCH M -20 • REPORT FOR HAUCK/SMITH DATE Nov 15, 2009 DEPTH 8240.00000 PRESENT OPERATION WASH & REAM 8051 -8147 TIME 24:00 YESTERDAY 8240.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" © 8222' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8125.70' 49.73 159.86 4467.03' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 5 8.5" STC MSI -616 JD1265 3X11, 3X12 8240 8240 0 0 BHA 6 8.5" STC MSI -616 JD1264 3X11, 3X12 8240 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8240 MW 9.4 VIS 45 PV 15 YP 20 FL 9.0 Gels 8/17/22 CL- 13000 FC 1/- SOL 6.8 SD 0.10 OIL 0.10 MBL 10.0 pH 8.5 Ca+ 300 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE • DITCH GAS 1 @ TIH 0 @ TIH .5 CIRC TRIP GAS - CUTTING GAS @ @ WIPER GAS WIPER GAS SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG - PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8240' = SAND 60 %, CONGLOMERATE SAND 30 %, SANDSTONE 10% PULL OUT OF THE HOLE FROM 2202' NTO SURFACE, PICK UP BHA AND KELLY UP ON SUB POWER AND TEST AT 10 BPM, TEST GOOD, BREAK DOWN THE TOP DRIVE, PICK UP BHA AND MAKE UP SMART IRON FROM SURFACE TO 108', PICK UP BHA AND DAILY ORIENT AND LOAD NUKE SOURCES, PICK UP BHA FROM 108' TO 415', WORK ON TOP DRIVE ELECTIRC'S, SERVICE THE RIG, TRIP IN ACTIVITY THE HOLE FROM 415' TO 1400' FILLING THE DRILL PIPE, TEST MWD, RUN IN THE HOLE TO 3967' FILL THE DRILL PIPE EVERY 2000', SUMMARY TRIP IN THE HOLE FROM 3967' TO 8051' FILL THE DRILL PIPE EVERY 2000', WASH AND REAM FROM 8051' TO 8127', PUMP A HIGH VISCOSITY SWEEP, CHANGE OVER TO NEW MUD, CHANGE OIL IN TOP DRIVE, MAXIMUM GAS TRIPPING IN THE CASED HOLE WAS 1 UNIT TO 8127'. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 11/16/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR HAUCK/SMITH DATE Nov 15, 2009 DEPTH 8240.00000 PRESENT OPERATION WASH & REAM 8051 -8147 TIME 24:00 YESTERDAY 8240.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" © 8222' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8125.70' 49.73 159.86 4467.03' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 5 8.5" STC MSI -616 JD1265 3X11, 3X12 8240 8240 0 0 BHA 6 8.5" STC MSI -616 JD1264 3X11, 3X12 8240 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8240 MW 9.4 VIS 45 PV 15 YP 20 FL 9.0 Gels 8/17/22 CL- 13000 FC 1/- SOL 6.8 SD 0.10 OIL 0.10 MBL 10.0 pH 8.5 Ca+ 300 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE III DITCH GAS 1 @ TIH 0 @ TIH .5 CIRC TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG - PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8240' = SAND 60 %, CONGLOMERATE SAND 30 %, SANDSTONE 10% PULL OUT OF THE HOLE FROM 2202' NTO SURFACE, PICK UP BHA AND KELLY UP ON SUB POWER AND TEST AT 10 BPM, TEST GOOD, BREAK DOWN THE TOP DRIVE, PICK UP BHA AND MAKE UP SMART IRON FROM SURFACE TO 108', PICK UP BHA AND DAILY ORIENT AND LOAD NUKE SOURCES, PICK UP BHA FROM 108' TO 415', WORK ON TOP DRIVE ELECTIRC'S, SERVICE THE RIG, TRIP IN ACTIVITY THE HOLE FROM 415' TO 1400' FILLING THE DRILL PIPE, TEST MWD, RUN IN THE HOLE TO 3967' FILL THE DRILL PIPE EVERY 2000', SUMMARY TRIP IN THE HOLE FROM 3967' TO 8051' FILL THE DRILL PIPE EVERY 2000', WASH AND REAM FROM 8051' TO 8127', PUMP A HIGH VISCOSITY SWEEP, CHANGE OVER TO NEW MUD, CHANGE OIL IN TOP DRIVE, MAXIMUM GAS TRIPPING IN THE CASED HOLE WAS 1 UNIT TO 8127'. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 11/16/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR LESLIE, SMITH DATE Nov 16, 2009 DEPTH 9091.00000 PRESENT OPERATION OPEN HOLE STETHOSKOPE HOLE TIME 24:00 YESTERDAY 8240.00000 24 HOUR FOOTAGE 851' CASING INFORMATION 9 5/8" @ 8222' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8553.24 37.95 159.67 4730.86 8363.91 46.64 159.82 4590.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 6 8.5" SIC MSI -616 JD1264 3X11, 3X12 8240 9:51 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 200.4 @ 8812.00000 7.7 @ 8240.00000 100.2 59.98201 FT /HR SURFACE TORQUE 27876 © 9046.00000 22163 @ 8468.00000 24155.9 25765.89258 AMPS WEIGHT ON BIT 12 @ 8720.00000 0 © 8716.00000 8.6 9.62304 KLBS ROTARY RPM 134 © 9090.00000 0 @ 8807.00000 112.7 130.43855 RPM PUMP PRESSURE 2473 © 8240.00000 839 @ 8544.00000 1860.2 2036.23364 PSI DRILLING MUD REPORT DEPTH 8240' MW 9.2+ VIS 44 PV 9 YP 12 FL 5.5 Gels 4/6/6 CL- 11000 FC 1/- SOL 4.0 SD - OIL - MBL - pH 9.5 Ca+ 80 CCI MIND SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE • DITCH GAS 430 © 8607.00000 1 @ 8260.00000 77.2 TRIP GAS 4 © 8240' CUTTING GAS 0 @ 9091.00000 0 @ 9091.00000 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 50318 @ 8426.00000 171 @ 8260.00000 8626.5 CONNECTION GAS HIGH 5 ETHANE (C -2) 148 @ 8426.00000 0 @ 8519.00000 16.9 AVG 1 PROPANE (C -3) 40 © 8606.00000 0 @ 8519.00000 1.6 CURRENT 1 BUTANE (C -4) 0 © 9091.00000 0 @ 9091.00000 0.0 CURRENT BACKGROUND /AVG 50 PENTANE (C -5) 0 © 9091.00000 0 @ 9091.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAY, TUFFACEOUS SILTSTONE, COAL, CARBON SHALE, SAND, CONGLOMERATE SAND PRESENT LITHOLOGY 9090' =COAL 30 %, TUFFACEOUS CLAY 40 %, TUFFACEOUS SILT 30% CLEAN OUT MUD SYSTEM AND ALL PITS, DRILL OUT CEMENT FROM 8205' TO 8240' @ 12.5 BPM, DRILL SHOE 8212 - 8214', DRILL DAILY FORMATION FROM 8240' TO 8260', CIRCULATE AND CONDITION THE HOLE, TRIP GAS DRILLING OUT CEMENT WAS 4 UNITS, ACTIVITY CIRCULATE THE HOLE AND PULL OUT OF THE HOLE FROM 8260 TO 8146', RUN THE F.I.T. AND RIG DOWN AND DRILL FROM 8260 TO SUMMARY 8410', OPEN RHINO REAMER AND PULL OUT OF THE HOLE AND TAG THE SHOE WITH THE REAMER, REAM BACK DOWN TO 8425', DRILL FROM 8425 TO 9091' © 13.8 BPM, PUMP A SWEEP AT 8870' WITH A 75% INCREASE IN CUTTINGS, OPEN HOLE LOG WITH STETHOSCOPE HOLE AT 180 FPH FROM 9040 TO 8995' EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. S file: / /C: \Documents and Settings\Administrator\My Documents \My Wells \Chevron \2009... 11/17/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 ID REPORT FOR LESLIE, SMITH DATE Nov 16, 2009 DEPTH 9091.00000 PRESENT OPERATION OPEN HOLE STETHOSKOPE HOLE TIME 24:00 YESTERDAY 8240.00000 24 HOUR FOOTAGE 851' CASING INFORMATION 9 5/8" @ 8222' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8553.24 37.95 159.67 4730.86 8363.91 46.64 159.82 4590.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 6 8.5" STC MSI -616 JD1264 3X11, 3X12 8240 9:51 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 200.4 @ 8812.00000 7.7 @ 8240.00000 100.2 59.98201 FT /HR SURFACE TORQUE 27876 @ 9046.00000 22163 © 8468.00000 24155.9 25765.89258 AMPS WEIGHT ON BIT 12 @ 8720.00000 0 @ 8716.00000 8.6 9.62304 KLBS ROTARY RPM 134 © 9090.00000 0 © 8807.00000 112.7 130.43855 RPM PUMP PRESSURE 2473 @ 8240.00000 839 @ 8544.00000 1860.2 2036.23364 PSI DRILLING MUD REPORT DEPTH 8240' MW 9.2+ VIS 44 PV 9 YP 12 FL 5.5 Gels 4/6/6 CL- 11000 FC 1/- SOL 4.0 SD - OIL - MBL - pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE I/ DITCH GAS 430 © 8607.00000 1 @ 8260.00000 77.2 TRIP GAS 4 © 8240' CUTTING GAS 0 @ 9091.00000 0 @ 9091.00000 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 50318 @ 8426.00000 171 @ 8260.00000 8626.5 CONNECTION GAS HIGH 5 ETHANE (C -2) 148 @ 8426.00000 0 © 8519.00000 16.9 AVG 1 PROPANE (C -3) 40 @ 8606.00000 0 @ 8519.00000 1.6 CURRENT 1 BUTANE (C -4) 0 @ 9091.00000 0 @ 9091.00000 0.0 CURRENT BACKGROUND /AVG 50 PENTANE (C -5) 0 @ 9091.00000 0 @ 9091.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAY, TUFFACEOUS SILTSTONE, COAL, CARBON SHALE, SAND, CONGLOMERATE SAND PRESENT LITHOLOGY 9090' =COAL 30 %, TUFFACEOUS CLAY 40 %, TUFFACEOUS SILT 30% CLEAN OUT MUD SYSTEM AND ALL PITS, DRILL OUT CEMENT FROM 8205' TO 8240' @ 12.5 BPM, DRILL SHOE 8212 - 8214', DRILL DAILY FORMATION FROM 8240' TO 8260', CIRCULATE AND CONDITION THE HOLE, TRIP GAS DRILLING OUT CEMENT WAS 4 UNITS, ACTIVITY CIRCULATE THE HOLE AND PULL OUT OF THE HOLE FROM 8260 TO 8146', RUN THE F.I.T. AND RIG DOWN AND DRILL FROM 8260 TO 8410', OPEN RHINO REAMER AND PULL OUT OF THE HOLE AND TAG THE SHOE WITH THE REAMER, REAM BACK DOWN TO 8425', SUMMARY DRILL FROM 8425 TO 9091' @ 13.8 BPM, PUMP A SWEEP AT 8870' WITH A 75% INCREASE IN CUTTINGS, OPEN HOLE LOG WITH STETHOSCOPE HOLE AT 180 FPH FROM 9040 TO 8995' EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C:\Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 11/17/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR SMITH, LESLIE DATE Nov 17, 2009 DEPTH 10148.00000 PRESENT OPERATION DRILLING TIME 24:00 YESTERDAY 9091.00000 24 HOUR FOOTAGE 1057 CASING INFORMATION 9 5/8" © 8222' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9692.85' 35.40 152.94 5670.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 6 8.5" STC MSI -616 JD1264 3X11, 3X12 8240' 25:00 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 196.4 @ 9790.00000 12.4 @ 9943.00000 82.3 55.38717 FT /HR SURFACE TORQUE 28294 @ 9657.00000 21194 @ 9794.00000 24660.5 22073.85742 AMPS WEIGHT ON BIT 13 @ 9754.00000 0 @ 10039.00000 8.4 11.65936 KLBS ROTARY RPM 155 © 9890.00000 0 @ 9757.00000 138.6 150.81270 RPM PUMP PRESSURE 2197 @ 9828.00000 1393 @ 9128.00000 2053.1 2170.85571 PSI DRILLING MUD REPORT DEPTH 9000' MW 9.2+ VIS 43 PV 12 YP 20 FL 4.5 Gels 5/8/11 CL- 16500 FC 1/- SOL 3.1 SD - OIL 0.5 MBL - pH 9.0 Ca+ 300 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 294 @ 9858.00000 4 © 10107.00000 46.1 TRIP GAS - CUTTING GAS 0 © @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 37366 @ 10134.00000 860 @ 10107.00000 6823.4 CONNECTION GAS HIGH 4 ETHANE (C -2) 275 @ 9492.00000 0 @ 9148.00000 20.3 AVG 0 -2 PROPANE (C -3) 34 © 9864.00000 0 © 9564.00000 1.4 CURRENT 1 BUTANE (C -4) 0 @ 10148.00000 0 @ 10148.00000 0.0 CURRENT BACKGROUND /AVG 55 PENTANE (C -5) 0 © 10148.00000 0 @ 10148.00000 0.0 HYDROCARBON SHOWS NO GAS SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATE SAND, TUFFACEOUS SAND, CONGLOMERATE, TUFFACEOUS CLAY, TUFFACEROUS SILT, COAL, CARBON SHALE PRESENT 10140' = COAL 70% CARBON SHALE 30% LITHOLOGY DAILY OPEN LOG THE HOLE STISK TEST @ 8995', WASH DOWN TO 9091', DRILL FORMATION FROM 9091' TO 9122', MAD PASS HOLE ACTIVITY FROM 9111' TO 9091', PARK THE PIPE WITH PROBE @ 9011.26' = TEST NO GOOD, WORK THE DRILL PIPE REORIENTATE, MAD SUMMARY PASS 9110' TO 9091' TEST GOOD, DRILL FORMATION FROM 9122' TO 10138', TRY SURVEY = NO GOOD, DRILL 10' TO 10148' AND RESHOOT SURVEY = GOOD, EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML. $1265 RW REPORT BY LEES F. BROWNE JR. III file: / /C: \Documents and Settings\Administrator \My Documents \My Wells \Chevron \2009... 11/18/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 • REPORT FOR LESLIE, SMITH DATE Nov 18, 2009 DEPTH 10500.00000 PRESENT OPERATION PULL OUT OF THE HOLE FROM 10500' TIME 24:00 YESTERDAY 10148.00000 24 HOUR FOOTAGE 352' CASING INFORMATION 9 5/8" @ 8222' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10435.99' 34.59 156.30 6276.49' SURVEY DATA 10262.15' 35.58 156.08 6134.80' 10073.03' 35.59 154.71 5980.86' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 6 8.5" STC MSI -616 JD1264 3X11, 3X12 8240' 10500' 2260' 33:50 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 124.8 @ 10422.00000 13.7 @ 10449.00000 54.4 57.44650 FT /HR SURFACE TORQUE 26409 © 10440.00000 20372 © 10484.00000 23320.0 22960.56250 AMPS WEIGHT ON BIT 14 @ 10324.00000 0 @ 10224.00000 8.9 12.60705 KLBS ROTARY RPM 156 @ 10438.00000 112 @ 10488.00000 145.7 142.24477 RPM PUMP PRESSURE 2218 @ 10412.00000 1606 @ 10292.00000 2112.3 2089.88647 PSI DRILLING MUD REPORT DEPTH 10036' (PIT #4) MW 9.2 VIS 42 PV 11 YP 19 FL 4.0 Gels 7/8/10 CL- 20000 FC 1/- SOL 3.9 SD 1.0 OIL 2.0 MBL 1.0 pH 8.8 Ca+ 320 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE el DITCH GAS 254 @ 10387.00000 27 @ 10375.00000 61.1 TRIP GAS - CUTTING GAS @ @ WIPER GAS 502 @ 10500' CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 37905 @ 10252.00000 2575 © 10476.00000 8402.8 CONNECTION GAS HIGH 2 ETHANE (C -2) 147 @ 10385.00000 0 @ 10419.00000 21.1 AVG 0 -2 PROPANE (C -3) 51 @ 10385.00000 0 @ 10159.00000 3.5 CURRENT 0 BUTANE (C -4) 0 @ 10500.00000 0 @ 10500.00000 0.0 CURRENT BACKGROUND /AVG 0 PENTANE (C -5) 0 @ 10500.00000 0 @ 10500.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILT, TUFFACEOUS CLAY, COAL, CARBON SHALE, SAND, SANDSTONE, CONGLOMERATE SAND, TUFFACEOUS SAND PRESENT 10500' = 50% TUFFACEOUS SILTSTONE, 30% TUFFACEOUS CLAYSTONE, 20% SANDSTONE LITHOLOGY DRILL FORMATION FROM 10148' TO 10324', MAD PASS HOLE FROM 10317' TO 10298', PARK PIPE AT 10298' WITH PROBE AT 10217' = TEST IS GOOD, DRILL FROM 10324' TO 10420', MAD PASS FROM 10417' TO 10362', PARK PIPE AT 10362' PROBE AT 10286', DRILL FROM 10420' TO 10500' (TD), PUMP A SWEEP - RETURNED AT CALCULATED STROKES, CIRCULATE AND CONDITION BOTTOMS UP, ROTATE AND RECIPROCATE THE HOLE, PUMP A HIGH VISCOSITY SWEEP AND ROTATE AND RECIPROCATE THE HOLE, ROTATE AT 100 RPM DAILY WHILE PULLING PIPE, PULL OUT OF THE HOLE FROM 10500' TO 8100', HOLE TOOK 8.2 BBLS OVER CALCULATED DISPLACEMENT, ACTIVITY SERVICE THE RIG, DROP RHINO DART, PULL OUT OF THE HOLE FROM 8100' TO 7956' TO MAD PASS DEPTH, CIRCULATE AT 3.5 BPM SUMMARY TO SEAT DART, STAGE UP PUMPS TO 10 BPM NO BUMP, CIRCULATE 4 DRILL PIPE VOLUMES AND WORK PIPE WITH NO PUMPS AND ROTATE = NO GOOD, RUN IN THE HOLE TO 8430 AND CIRCULATE AT 11 BPM, ROTATE DRILL PIPE AT 140 RPM, ONE DRILL PIPE VOLUME, NO BUMP OR PRESSURE INCREASE, TRIP IN THE HOLE FROM 8430 TO 10423' AND WASH DOWN TO 10500' WITH 3' OF FILL, WIPER GAS WAS 502 UNITS, CIRCULATE AND COMDITION THE HOLE, PUMP A HIGH VISCOSITY NUT PLUG SWEEP AND CIRCULATE AT 13.3 BPM EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA + 2 SC DAILY COST $4225 DML, $1265 RW REPORT BY LEES F. BROWNE JR. III file: / /C: \DOCUMENTS AND SETTINGS\ADMINISTRATOR \MY DOCUMENTS \MY ... 11/19/2009 Daily Report Page 1 of 1 Chevron DAILY WELLSITE REPORT EPOCH M -20 III REPORT FOR LESLIE, SMITH DATE Nov 18, 2009 DEPTH 10500.00000 PRESENT OPERATION TRIP IN WITH 7" CASING TIME 24:00 YESTERDAY 10500.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 8222' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10435.99' 34.59 156.30 6276.49' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 6 8.5" STC MSI -616 JD1264 3X11, 3X12 8240' 10500' 2260' 33:50 5- 3- BT- A- X -I -CT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10500 MW 9.2 VIS 44 PV 12 YP 21 FL 3.8 Gels 5/7/9 CL- 22000 FC 1/- SOL 4.2 SD 1.00 OIL 2.0 MBL 5.0 pH 9.0 Ca+ 340 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - • CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG - PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 10500' = 50% TUFFACEOUS SILTSTONE, 30% TUFFACEOUS CLAYSTONE, 20% SANDSTONE TRIP OUT OF THE HOLE FROM 10138' TO 8296', MAD PASS HOLE FROM 8275' TO 8230' AT 120 FPH, PULL TWO STANDS FROM 8230' DAILY TO 8051', MAD PASS THE HOLE FROM 8026' TO 7956' AT 120 FPH, MONITOR THE WELL, WELL IS STATIC, CHANGE OUT ELEVATORS, ACTIVITY PUMP A 21 BBL SLUG AND BLOW DOWN THE TOP DRIVE, TRIP OUT OF THE HOLE FROM 7956 TO 743', STRAP THE DRILL PIPE, TRIP SUMMARY OUT OF THE HOLE FROM 743' TO 382', LAY DOWN THE BHA AND STAND BACK 382' TO 204', LAY DOWN BHA FROM 204' TO 108', REMOVE MWD SOURCES, LAY DOWN THE BHA FROM 108' TO 0', CLEAR AND CLEAN THE RIG FLORR OF TOOLS, STATIC LOSS RATE IS 1 BPH, RIG UP TO RUN 7" CASING, RIG SERVICE, PICK UP 7" LINER, FLOAT EQUIPMENT AND BEGIN TO RUN 7" CASING FROM 130'. EPOCH PERSONNEL ON BOARD BROWNE, DYKEMA DAILY COST $3425 DML, $1265 RW REPORT BY LEES F. BROWNE JR. • file: / /C: \DOCUMENTS AND SETTINGS\ADMINISTRATOR \MY DOCUMENTS \MY ... 11/20/2009